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Home My WebLink About208-047MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-220 PRUDHOE BAY UN ORIN L-220 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 L-220 50-029-23387-00-00 208-047-0 G SPT 4121 2080470 1500 2578 2592 2593 2595 781 792 790 788 4YRTST P Sully Sullivan 10/6/2024 tested to 3293 for 500 psi dp 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-220 Inspection Date: Tubing OA Packer Depth 0 3293 3180 3162IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009100153 BBL Pumped:3.5 BBL Returned:2.7 Friday, December 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 11:04:43 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-220 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-047 50-029-23387-00-00 7235 Conductor Surface Intermediate Production Liner 4805 80 3774 7193 6677 20" 9-5/8" 7" 4372 31 - 111 30 - 3804 27 - 7220 31 - 111 30 - 2749 27 - 4793 None 3090 5410 6677 5750 7240 6442 - 6962 3-1/2" 9.2# L80 25 - 6977 4195 - 4590 Structural 3-1/2" HES Dual Feed Thru Packers (2) 6545, 4272 / 6755, 4431 / 6878, 4525 6341, 6545, 6683, 6755, 6878 4121, 4272, 4376, 4431, 4525 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, SCHRADER BLUFF OIL, Orion Development Area Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 25 - 4602 N/A N/A 3872 2772 0 0 2323 2437 N/A 13b. Pools active after work:SCHRADER BLUFF OIL, Orion Development Area 3-1/2" HES Single Feed Thru Packers (3) 6341, 4121 / 6683, 4376 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.17 10:11:11 - 08'00' Torin Roschinger (4662) By Grace Christianson at 1:21 pm, Jul 17, 2024 DSR-7/17/24WCB 9-30-2024 RBDMS JSB 071924 ACTIVITY DATE SUMMARY 7/12/2024 ***WELL INJECTING ON ARRIVAL*** (profile modification) RAN 3-1/2" BRUSH & 2.75" G. RING TO RED SPIDER AT 6,904' MD (LRS pumped 80 bbls hot diesel) SET 3-1/2" PX PLUG AT 6,677' MD PERFORM SUCCESSFUL DRAWDOWN (see log) ***WELL LEFT S/I ON DEPARTURE*** 7/12/2024 T/I/O = 2000/0/670. Assist Slickline. Pumped 80bbls 190*F diesel down tubing. FWHP's = 1600/0/690 Daily Report of Well Operations PBU L-220 ) SET 3-1/2" PX PLUG AT 6,677' MD MEMORANDUM State of Alaska Permit Number: 208-047-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg I / DATE: Monday, October 26, 2020 P.I. Supervisor SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial Hiloorp North Slope, LLC Well L-220 FROM: Bob Noble PRUDHOE BAY UN ORIN L-220 Petroleum Inspector 1667 1667 - Src: Inspector 1660 ' Reviewed By: 2080470 P.I. Sup" Jep— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-220 API Well Number 50-029-23387-00-00 Inspector Name: Bob Noble Permit Number: 208-047-0 Inspection Date: 10/19/2020 Insp Num: mitRCN201019162727 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-220 Type Inj c - TVD 4121 - Tubing 1667 1667 - 1664 1660 ' PTD 2080470 IType Test SPT Test psi Iwo ' IA 0 2405 - 2344 - 2377 - BBL Pumped: 3.6 - BBL Returned: 1.6 OA 717 728 729 728 ' Interval 4YRTST P/F p Notes: — -- CUPN( 6 (20Zo , Pu* 6"I f J 1L)I'W(.'Ft,'w Monday, October 26, 2020 Page I of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, October 16, 2020 7:17 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector L-220 (PTD #2080470) Lapse 4 year MIT -IA Mr. Wallace, Injector L220 (PTD # 2080470) is now operational ready to be placed on injection and will have a 4 year AOGCC witnessed MIT -IA performed as soon as the well temperature and rate is stable. The well is now classified as OPERABLE and can be placed on injection. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Sunday, September 20, 20201:02 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Sm ith @ h i Ico rp. co m> Subject: NOT OPERABLE: Injector L-220 (PTD #2080470) Lapse 4 year MIT -IA Mr. Wallace, Injector L220 (PTD # 2080470) will not be on injection for 4 year AOGCC MIT -IA due in September. The well is now classified as NOT OPERABLE for tracking purposes and will remain shut in until injection resumes. 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 AK, GWO SUPT Well Integrity Sent:July 29, 2016 8:10 PM To: AK, OPS G <AKOPSGC20SM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead < C2Well adLead b .com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; i Doug A <CismosDA@BP.com>; Daniel, Ryan <Rvan.Daniel@bp.com>; AK, GWO SUPT Slickline <akdcWirelineo erationssu eri nt b .com>; AK, GWO SUPT Special Projects <akdcWeIIse rvicesoperationssuperintendent@bp.com>; AK, R est Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <A BEastWellsO tEn r b .com>; AK, OPS Well Pad LV <AKOPSWeIIPadLV@bp.com>; Rupert, C. Ryan <RVan.RuPert@BP.co ;' hris.wallace@alaska.gov' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, September 20, 2020 1:02 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki; Travis Smith - (C) Subject: NOT OPERABLE: Injector L-220 (PTD #2080470) Lapse 4 year MIT -IA Mr. Wallace, Injector L220 (PTD # 2080470) will not be on injection for 4 year AOGCC MIT -IA due in September. The well is now classified as NOT OPERABLE for tracking purposes and will remain shut in until injection resumes. 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 From: AK, GWO SUPT Well Integrity Seat: Friday, July 29, 2016 8:10 PM To: A�, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS Prod Controllers <AKOPSProdC�r�lers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, GWO SUPT Slickline\< kdcWirelineoperationssuperintendent@bp.com>; AK, GWO SUPT Special Projects <akdcWellservicesoperationssuperintendent@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP-com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadL'V@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; 'ch ris.waIlace@alaska.gov' <chris.waIlace @alaska.gov> \ Cc: AK, GWO DHD Well Integrity <AKD&CGHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelIIntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; Pettus,'Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: WAG Injector L-220 (PTD #2080470) Duefor 4 Year Compliance Testing Injector L-220 (PTD #2080470) passed an MIT -IA on July 29 2016 and is operationally ready to be placed on injection. The well is now reclassified as Operable. Plan Forward: Operations: Put on Injection - watch for thermal expansion, liquid packed annulus Fullbore: AOGCC MIT -IA once thermally stable Please call with any questions or concerns. Ryan Holt . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Tuesday,September 20,2016 P.I.Supervisor '1.-eget `9('7,0ll(.0 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-220 FROM: Chuck Scheve PRUDHOE BAY UN ORIN L-220 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry_16/2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-220 API Well Number 50-029-23387-00-00 Inspector Name: Chuck Scheve Permit Number: 208-047-0 Inspection Date: 9/2/2016 Insp Num: mitCS160902153046 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-220 . Type Inj W' TVD 4121 - Tubing' 1711 1710 -' 1700 - 1694 PTD 2080470 (Type Test SPT Test psi 1500 • IA 29 2498 - 2446 - 2436 - (Interval 4YRTST 1P/F P s/ OA j 472 476 - 476 476 Notes: SCANNED JUN 2 9 01 Tuesday,September 20,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,July 29, 2016 8:10 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, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV; Rupert, C. Ryan;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity; Pettus,Whitney; Sternicki, Oliver R; Regg,James B (DOA) Subject: OPERABLE:WAG Injector L-220 (PTD#2080470) Due For 4 Year Compliance Testing All, Injector L-220(PTD#2080470) passed an MIT-IA on July 292016 and is operationally ready to be placed on injection.The well is now reclassified as Operable. Plan Forward: 1. Operations: Put on Injection - watch for thermal expansion, liquid packed annulus 2. Fullbore:AOGCC MIT-IA once thermally stable Please call with any questions or concerns. SCANNED OCT ` 076 Ryan Holt BP Alaska-Well Integrity GANG /�j Global Wells y Organjzattor Office: 907.659.5102 rom: AK, D&C Well Integrity Coordinator Se . hursday, April 04, 2013 5:43 PM To: AK, 0* C2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, • ': s AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt En• • •K, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Kirchner, Carolyn J; 'jim.regg@alaska.gov'; 'chris. : •ce@alaska.gov' Cc: AK, D&C DHD Well Integrity Eno'.-er; AK, D&C Well Integrity Coordinator; Holt, Ryan P; Arend, Jon Subject: NOT OPERABLE: WAG Injector 0 (PTD #2080470) Due For 4 Year Compliance Testing All, WAG Injector L-220(PTD#2080470) is due for its 4 year AOG MIT-IA on 04/15/2013. The well will not be placed on injection prior to the AOGCC MIT-IA anniversary date. The well is -classified as Not Operable and will be added to the quarterly AOGCC Not Operable Injector Report. Plan forward: 1. Fullbore: Prior to placing on injection, MIT-IA to 4000 psi 2. Fullbore: Once on injection,AOGCC MIT-IA to 4000 psi when well is therm. stable Please call with any questions. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - Q ~- ~ Well History File Identifier Organizing (done) Two-sided III II'III II III II III ^ Rescan Needed III II'III II II III III RESCAN DIG TAL DATA OVERSIZED (Scannable) for Items: Diskettes, No. l ^ Maps: ^ Greyscale Items: Other, NolType: C ~ N~ I ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: NOTES: Date: ^ Logs of various kinds: ^ Other:: !s/ BY: Project Proofing BY: /s/ Date: ~ ~/ Scanning Preparation ~~ x 30 = ~ + ~ 5 =TOTAL PAGES~~ (Count does not include cover sheet) t /~/J BY: Mari Date: ~, /Q' 1 ~D ls~ v r ~, Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: '/ YES _ BY: Maria Date: ~/ ! ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. tymP ~IIIIIIIIIIIIIIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIIII III II'I III 10Jti/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080470 Well NameiNo. PRUDHOE BAY UNIT L-220 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23387-00-00 MD 7235 TVD 4805 Completion Date 4/25/2008 Completion Status WAGIN Current Status WAGIN I REQUIRED INFORMATION --- Mud Log No Samples No Directional Survey ~ es ~ 1 DATAINFORMATgN Types Electric or Other Logs Run: MWD, GR, RES, Azi-Den, NEU, PWD, LWD, GYRO, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / meairrmi numcer Name D Asc Directional Survey Directional Survey Sonic C Pds 16331~onic C Lis 16376~mma Ray C Asc Directional Survey D irectional Survey C Li / R 16520 `G s amma ay Induction/Res istivity 1 nd uction/Resistivity Caliper log C Lis // 1719'Nllnduction/Resistivity Injection Profile C Pds 18677~njection Profile JCare meara NO Star[ Jtop l:Fi K@Celvea l:OmmentS 0 7235 Open 4/24/2008 0 7235 Open 4/24/2008 5 Col 100 7100 Case 5/23/2008 USIT, GR, CCL, GPTI 22- Apr-2008 100 7100 Case 5/23/2008 USIT, GR,-CCL, GPTI 22- Apr-2008 100 7092 Case 6/6/2008 LIS Veri, GR, CET 0 1000 Open 5/10/2008 0 1000 Open 5/10/2008 100 7092 Case 7/1/2008 LIS Veri, GR, TENS, CCL 25 CoI 108 7199 Open 7/1/2008 MD Vision Service 25 Col 108 7199 Open 7/1/2008 TVD Vision Service 25 Col 3710 7199 Open 7/1/2008 MD Density Caliper 116 7235 Open LIS Veri, GR, ROP, FET, RPM, RAM, DRHO, NPHI 5 Blu 6287 6942 Case 9/16/2009 Mem Inject Pro, Spin, Pres, Temp, GR, CCL 30- Ju1-2009 6287 6942 Case 9/16/2009 Mem Inject Pro, Spin, Pres, Temp, GR, CCL 30- Ju1-2009 DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drill 2080470 Well Name/No. PRUDHOE BAY UNIT L-220 Operator BP EX PLORATION (ALASFCIy INC API No. 50-029-23387-00-00 MD~7235 ED C Pds TVD 4805 Completion Date 4/25/2008 Completion Status WAGIN 1891 Injection Profile Current Status WAGIN 6287 6942 Case 11/6/2009 UIC Y Mem Inject Pro, Spin Pres, Temp, GR, CCL 30- Ju1-2009 (~,,~ sG~ c Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y / N Formation Tops Y / N Comments: r, ~~ Compliance Reviewed By: _ Date: _ _ /^ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 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, r ~'~~~ 0 C T 0 ~ 2009 Alaska gil & Gas Cons. Gomrnission Anchorage ~~~ ~ ~ ~~ M ~,~.~ 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 Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-0.04) nsre L pad R/1'i/2n09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al L-01 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 50029231010000 NA 1.6 NA 10.2 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 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 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 316.2 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-117 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 2.2 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 L-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 17 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 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 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 0.25 NA 10.2 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 surface NA NA L-220 2080470 50029233670000 NA 2 NA 20.4 6!2812009 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 rea~Ka vn a lass cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job It Log Description Date BL Color CD MPI-13 AWJI-00055 SCMT ^- 10!18/09 1 1 MPC-07 AXED-00057 MEM PROD PROFILE - 10/24/09 1 1 04-11A AWLS-00040 INJECTION PROFILE - 10/24/09 1 1 V-220 AYS4-00100 INJECTKN PROFILE -T 10/04/09 1 1 L-220 61JJ-00035 MEM INJ PROFILE REVISED ~. - 07/30/09 1 1 V-221 AXBD-00037 MEM INJ PROFILE REVISED ~C `a~'.-b( ~~ 07/28/09 1 1 L-214A AP30-00064 INJ PROFILE/RST 10/06/09 1 1 S-228 AYTU-00052 INJECTION PROFILE - 10/27/09 1 1 14-07 8581-00016 PROD PROFILE tl 10/27/09 1 1 07-05 AYS4-00105 SCMT 10/28/09 1 1 R-28 AWLS-00041 USIT 10/26/09 1 1 2-OSlK-16 AZCM-00046 PRODUCTION PROFILE / - 10/30/09 1 1 PSI-05 8148-00080 TEMP WARMBACK SURVEY p$ - 11/03/09 1 1 C-128 B2WY-00030 MCNL - '- 09/19/09 1 1 U-05A 09AKA0074 OH MWD/LWD EDIT T -Q 08/19/09 2 1 01-18A 09AKA0151 OH MWWLWD EDIT _ 08/27/09 4 1 H-09 ANHY-00110 RST ~ ~2rb _ / 09/20/09 1 - PI FASF ACKNf1W1 Fr1r1F ocr c~oT GV Ci!]u~~ ln w~~n o~T~~suu~~ ~u~ wi.nv ~..... ~... BP Exploration (Alaska) Inc. Petrotechnical Data Center L.R2-1 900 E. Benson Blvd. ~E Alaska Data & Consulting Services 2525 Gambell Street, Sufte 400 Anchorage, AK 99503-2838 i ; ~~ ~~' r Scbtumberger Alaska Data & Consulting Services 2525 Gambell Strwl, Suite 400 Anchorage, AK 99503-2a3a ATTN: Belh Well Job 0 N0.5353 Company: State of Alaska Alaska Oil & Gas Cons Comm Ann: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD V-02 82WY-00018 MEM PRODUCTION PROFILE 07/27/09 1 1 W-26A H-32 B1 JJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ~ PRODUCTION PROFILE ~ L - 07/26/09 07/25/09 1 1 1 1 P2-29 L2-ii AYTU-00052 ANHY-00106 INJECTION PROFILE '7 _ LDL 08/02/09 08/02/08 1 1 1 1 L2-06 869K-00007 CROSS FL W CHECK - 07/31/09 1 1 P2-28 L-213 AYTU-00051 B2WY-00019 INJECTION PROFILE L - MEM INJECTION PROFI E' 08/01/09 07/28/09 1 1 1 1 V-221 AXBD-00037 MEM INJECTION PROFILE" - 07/28/09 1 1 L-220 81JJ-00035 MEM INJECTION PROFILE I 07/30/09 1 1 07-22 04-02A AZCM-00036 AYS4-00091 PRODUCTION PROFILE " USIT ~ 08/08/09 08/11/09 1 1 1 1 J-11A AWLS-00029 USIT 08/05/09 1 1 L1-09 AYS4-00089 PRODU TIONPROFILE _~ 08/08/09 1 1 X-28 L2-06 AXED-00026 B3S0-00020 MEM INJECTION PROFILE PRODUCTION PROFILE 05/17/09 08/14/09 1 1 1 1 3-29/J-32 AP30-00055 IBP SET RECORD W/CROSSGLOW 08/08/09 1 1 06-04A 85JN-00009 RST 08/23/09 1 1 15-098 62NJ-00013 MCNL 07/15/09 1 1 03-326 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 1 G-14B AWJW0043 MCNL 07/24/09 1 1 L2.13A AWJI-00036 MCNL 06/17/09 1 18-028 AWJI-00045 MCNL $~ 08/17/09 1 1 P7-05 AWLB-00032 RST 08/09/09 1 1 B-16A B2WY-00020 MCNL - '- 08/03/09 1 1 J-208 AXED-00020 MCNL (REVISED) ~ (~ ,"C-' 04/12/09 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 09/11/09 v~ l - _ ~ f F, s ~ G ~ . , ~ ~ ~ SARAH PALIN, GOVERNOR .. ~ z ~-~ ~t~~Tm , ~~ O~ Al`D ~ rye 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'i`IOI1T COMDIISSIOI~T ~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 d FAX (907) 276-7542 Taylor West Production Engineer BP Exploration (Alaska) Inc. ~ ~~ PO Box 196612 ~~~ ~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Orion Oil Pool, L-220 Sundry Number: 309-101 Dear Mr. West: Enclosed is the Application for Sundry Approval relating to the above referenced well. The Alaska Oil and Gas Conservation Commission (Commission) is returning this application to you unapproved. Alternative work completed by BP Exploration (Alaska) Inc. (BPXA) in consultation with the Commission deems the proposed work unnecessary. BPXA provided the sundry application to the Commission proposing cement down squeeze of the outer annulus of Prudhoe Bay L-220 (PTD 2080470). Diagnostic data provided with the application and in response to requests by the Commission during the review indicate the source of outer annulus pressure is external to the wellbore. Sand intervals below the 9-5/8-inch surface casing shoe are a likely source. Diagnostic tests confirm that PBU L-220 has competent production and surface casings with no evidence of pressure communication between the inner and outer casing annuli. Discussions subsequent to receipt of the sundry application resulted in BPXA pursuing an alternative approach to performing a cement down squeeze, namely loading the outer annulus with brine to overbalance the pressure influx. The Commission believes cement down squeeze in this situation would only serve to mask the problem. BPXA loaded the outer annulus of PBU L-220 with brine on March 22, 2009. Reports of monitored well pressures provided to the Commission show the brine load to be successful in mitigating the annulus pressure. This alternative approach preserves the ability to monitor changes in the well's outer annulus mechanical integrity. Well pressure data provided to the Commission on May 4, 2009 again show the outer annulus pressure in PBU L-220 to be low (less than 200 psi) and relatively stable. Results of the alternative work completed by BPXA indicate the sundry application is unnecessary. Please contact Tom Maunder, PE at 793-1250 or Jim Regg at 793-1236 if you have questions or require clarification. Sincerely, Cathy . Foerster Commissioner Dated this 22nd day of May, 2009 Enclosure RECEIVED • STATE OF ALASKA ~` MAR 1 7 209 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~aska Oil & Gas Gons. Gommissior~ 20 AAC 25.280 Anchoragw~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Iter casing ^ Repair well Q Plug Pertorations^ Stimulate ^ Time Extension ^ OA SQUEEZE Change approve program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration ( ska), Inc. Developmenl^ Exploratory ^ 208-0470 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage, AK 9951 12 50-029-23387-00-00 7. If pertorating, closest approach in pool(s) o ed by this operation to nearest 8. Well Name and Number: property line where ownership or landownershi hanges: L-220 Spacing Exception Required? Yes No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028239 78.6 RT PRUDHOE BAY Field / ORION SCHRADER BLUFF Pool 11. S N WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective epth ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7235 4805.19 7 4726.3 9 NONE NONE Casing Length Size D TVD Burst Collapse Conductor 108' 20" 91.5# A-53 S ce 108' Surface 108' s,D~d~ct~c3~ 3804' 9-5/8" 40# L-80 30 ~£3 4' 30' 2749' 5750 3090 ~~ ` r`~~r~ 7220' 7" 26# L-80 2T 72~.'C~ 2T 4793' 7240 5410 ~~i " ~J /:i1 Y l Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: ubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.2#~~ r L-80 SURFACE - 6976' - - - - ~~ ~ V ~ - Packers and SSSV Type: 7" HES AHR PKR W/1/4" FEED THRU Packers and SSSV M 6341' 7" HES AHR PKR W/1/4" FEED THRU ~ 6545' 7" HES AHR PKR W/1/4" FEED THRU ,~/ 6683' 7" HES AHR PKR W/1/4" FEED THRU ~ 755' 6878' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: ~~, Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Devel p n ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/31/2009 OIL ^ GAS ^ PLUGGE ABANDONED ^ 16. Verbal Approval: Date: WAG ^Q GINJ ^ WINJ WDSPL ^ Commission Representative: Prepared by Gary Prebl 64-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor West Printed Name Taylor West Title Production Engineer Signature "'~ Phone 564-4647 Date 3/17/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ' Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/200Ej ~ ~) t,.,,' Submit in Duplicate i F.,.4' } ~ ~.~ ~. L-220 208-047 DCDC ATTA/'!1-IMFAIT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L-220 4/20/08 PER 6,442. 6,468. 4,195.01 4,214.36 L-220 4120/08 PER 6,620. 6,674. 4,328.62 4,369.3 L-220 4/20/08 PER 6,710. 6,748. 4,396.46 4,425.24 L-220 4/20/08 PER 6,766. 6,788. 4,438.92 4,455.68 L-220 4/20!08 PER 6,836. 6,858. 4,492.43 4,509.36 L-220 4/20/08 PER 6,904. 6,962. 4,544.89 4,589.87 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE bP ~ To: Jeny Bixby/Clark Olsen NSU, ADW Well Operations Supervisor From: Tiffany Quy, WIE Subject: L-220 Cement down squeeze AFE: ORLPDWL20-N Please add the followin ste s to the WBL: Date: March 16, 2009 Est. Cost: $80M IOR: (Ini - Reg Compl) Step Type Procedure 1 F Establish OA LLR (pre-OA down squeeze). Break down OA shoe if required. 2 FP OA cement down squeeze w/ SLB Cementers (pending injectivity) 3 FP MIT-OA to 2000 psi (WOC 3 days) Current Status: WAG Injector, Under Eval for high OAP Last Injection Rate: 03/14/09: 500 bwpd (PW) @ 1848 psi, 114°F Exp. OA Injectivity: 16.15 gpm (0.38 bpm) @ 2000 psi Latest H2S value: No Data for Injectors - L-Pad is an H2S Site L-220 is a WAG injector under evaluation for sustained casing pressure on the OA from an unknown gas source. The pressure builds up quickly to MOASP and will not stay bled down. This is a 3.5" L-80 completion from 4/2008. Well passed aMIT-IA to 2500 psi 10/02109. The IAP does not build or track with the OA indicating that the OAP source is external (not IAxOA). The plan for this well is to down squeeze the OA with cement to isolate the gas source and mitigate the high OAP. A MIT-OA failed to 2000 psi with a LLR of 16 gpm (0.38 bpm) 2/24/09. The OA FL was depressed to 1345' 03/11 /09 leaving 1000. psi on the OA. Due to the current low OA injectivity rate from the last MIT-OA, the time to pump the cement and displacement is approximately 284 min (4.7 hours -107 bbls @ 0.38 bpm @ 2000 psi). Before the cementing operations, the OA will be over pressured to break down the shoe and establish injectivity. If you have any questions or comments regarding this procedure, please call the WIC 659-5102, WIE 659-5525, or Taylor West (APE) 564-4647 (w), 377-2028 (c). cc: w/a: Well File NSU, ADW Well Integrity Engineer JOB PLANNING DETAILS: The procedure includes the following major steps: 1. D Shoot fluid levels and record WHP's 2. F Fluid pack OA (~37 bbls) with crude and establish LLR. Break down OA shoe if needed. Bleed the T, IA, and OA to <200 psi 3. F OA cement down squeeze 4. FP MIT OA after waiting on cement (WOC). OA= 9-5/8" 40# L-80, I D 8.835" IA= 7" 26# L-80 Shoe @ 3804' MD (2748'TVD) OAxIA Annular Capacity = 0.0282 bpf Last OA FL @ 1345' MD 3111/09 Volume to shoe = 107.3679 bbls 500' of cement= 14.1125 bbls Displacement= 107 - 15 (cement) - 5 (meth) - 2 (from shoe) = 85 bbls Minimum Fluid Requirements: Fresh Water: 165 bbls of 80 °F + cement mix requirements (110° fresh water) 60/40 Methanol: 15 bbls Crude: 85 bbls (displacement) + 162 bbls (1.5x OA volume) + ~40 bbls (inj) + 38bbls (load) = 325 bbls Arctic Set Cement (15.8 ppg): 15 bbls pumpable cement Note: Adjustments may be made as necessary by WSL. Please discuss temperature and application with SLB rep. Consider recommendations for this application including a gas block additive. Discussion of breaking down the shoe: The limiting rating for breaking down the shoe is the internal yield of the 40# 9-5/8" casing (80% of yield is 4600 psi). The 80% burst on the surface casing will be reached with dead crude (0.39 psi/ft) and 3500 psi surface pressure. During the break down, the well will remain on injection. 80% of collapse on the tubing is 8426 psi and it should not come close to seeing this pressure. 80% collapse on the 7" production casing is 4328 psi. The IA will be fluid packed. Worst case if the IA is filled with diesel (.353 psi/ft), the column will leave 970 psi at the shoe - a differential of 3600 psi between the IA and OA at the shoe, well below the collapse rating. L-220 Bun3tlCol ae Differential Shoe with iven SC Pressure Casing Failure rating 80°~O Hydrostatic String Size Wieght (psi) Yi $'d Fluid at Shoe (psi) 2000 3000 3500 4000 SC 9-518" 40# Ykld 5750 4600 crude 1072 3073 4073 4573 5073 PC 7" 28# Col a 5410 5410 diesel 970 2103 3103 3803 4103 3-112" 8.2# Coll 10533 10533 none 0 3073 4073 4573 5073 Shoe Depth ~ 2748' TVD PREP WORK (pre-downsgueeze): DHD: 1. Shoot IA and OA FL. Record WHPs. Fullbore: 2. MIRU FB pump. 3. Pressure up IA 10 1000 psi to decrease pressure differential at the shoe. 4. Fluid pack OA with crude and establish OA LLR (injectivity). If leak rate is less than 2 bpm @ 2000 psi (expected -last LLR on OA was 0.38 bpm @ 2000 psi), break down the shoe by overpressuring the OA as follows. a. Pressure up OA to 2000 psi for 30 min. If LLR < 2 bpm, continue PU the OA in 300 psi increments up to 3500 psi. Hold at each increment 15 minutes before stepping pressure up again and record injectivity. b. Maintain 3500 for 30 min. If OA shoe is still holding, contact PE. c. If shoe breaks down, record injectivity at break down pressure, 1000 psi, and 2000 psi. d. Displace at least 162 bbls (1.5x OA volume) down the OA to establish and confirm injectivity @ 2000 psi. ~`**NOTE: If we are unable to establish a minimum of ~1.5 bpm injectivity into the OA, SD pumps and contact WSL. If we are unable to pump the cement, a brine load or gel diesel load will be considered. 5. Bleed the OAP to < 200 psi. 6. Ensure IA is fluid packed. Load if needed 7. RDMO FB. CEMENTING OPERATIONS: Full Bore: 8. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. Line up cementers and FB to swap on the fly. Include 2 heaters and contamination truck in RU. Well will be left on injection during RU to increase temperature for setting up the cement. 9. Flood lines with methanol and PT hard line to 3000 psi. 10. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate possible from the maximum OA surface pressure of 2000 psi. Continuously note injectivity during displacement and record any changes. Monitor IAP and keep below 1000 psi during operation. Start pumping into the OA as follows: cementers: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls surfactant (may be omitted) c. 162 barrels of 80°F freshwater to flush OA (approx. 1.5 x annular volume) d. 15 bbls pumpable cement. (Please reference cement design form for specs) e. (3 bbls of fresh water flush -bleed off to half drum to flush lines. Do not pump behind cement to keep from leaving an ice plug in the OA.) • f. 5 bbls meth to flush HL to cement truck. Release cementers and swap to FB pump to pump crude. Make swap as quickly as possible so cement does not fall out too far before displacement. **NOTE: If crude has a FP > 73°F and VP < 1.99 psi, it .may be pumped by cementers. Crude may be taken to SLB lab for testing during RU to assure FB pump is necessary. Fullbore: g. 85 bbls of 80° crude to displace cement. Deliver cement down the OA at maximum rate possible at a max OAP of 2000 psi. (The OA infectivity will depend on OA breakdown done prior to squeeze. Please reference WSRs prior to this job.) Pump at maximum allowable rate (upto 5 bpm) until 75 bbls of displacement is pumped. Cut rate to 1 bpm for another 5 bbls. Drop rate to 0.5 bpm for the last 5 bbls. The leading edge of the cement should be 2 bbls (~70') short of the shoe when the pump stops. Let cement fall out after SD pumps. 11. Shut down pumps and allow cement to fall out. Please DO NOT try to achieve a squeeze or to build squeeze aressure. The intent of this job is to place cement at the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump truck. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 12. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases while the cement sets. DHD will monitor OA frequently for several days following the OA downsqueeze. OAP should be maintained below 500 psi. Post Squeeze: FP: (WOC 3 days) 13. MIT-OA to 2000 psi. Have apre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. TRH= 4-1/i6` pW WEt.LFFJ4D= F ACTUATOR = BAKER KB. ELEV = 78. BF. f3EV = 48.1 KOP = tulax Angle = 64° ~ 2857 Daum MD = 681 Datum TV D = 4400'. ~9~1e` CSG, aoll, L-~ BTC, D = 8.835' I--I 3soa' f 7" CSG, 261f, L-~ TCI XO TO L~80 $TGM 5277' 7'x3-1J2' FIeS DUAL l PKR D = 2.965" 6341' 7't~AARK92JOMw/RA PPTAG 6418' Minimum ® = 2.75" @ 6965' 3-112" HES XN NIPPLE 3-112" FIESS X NIP, D = 2.813' 6514' 7"X3-112" HES SMGLE FEEDTHRU PKF; ID = 2.965 664$' L-220 ~4-ucxs-ircxu, u=z.aa 3.1/2' FEES X Nli? D =2.813` GAS LFT htANDRBS oEV TYPE vLV LATCH 43 l~A6G DMY RK 3-ur FMS x NP, D =2.813' 13-trr NDPG ~ Ste , D = 2.992 WAT9t PL~71DN MAPDFBS ST IuD TVD DEV TYPE VLV LATCH PORE DATE 9 8372 4143 43 NIwAC,-W OMY RK 0 04/24!08 8 8488 4213 42 ~M~Ka-W R15 Fi;F( 14 ~118f08 7 8571 4291 d1 I4NLrW OMY RK 0 04124/08 6 8859 4358 41 A~uG-W R15 RK 17 09118J08 5 6710 4398 41 f~AG-W DMY RK 0 04/24108 4 6737 4417 41 MMG-W R15 RK 15 09/18!08 3 6787 4455 40 MNG-W OAAY RK 0 04124108 2 6649 4503 40 bYuG-W R15 FCC 15 09118/08 1 6915 4553 ~ AOu1G-W R15 F8( 17 09118108 " 6965 4592 39 -- routx rrrtt 17'X3-112' FfS DUAL F1S=DfHRU FKR ID = 2.965" I i3-1/2" NOPG A~LTISH~LSOR Sl8 , D = 2.892 I 3-1/2' FMS X Nom, ID = 2.813" D = 2.992 3-112' RA RP7AG 1-i 6749' I F1CR, D = 2965' 6755' Pf3~FORATION SUNH~44RY REFLOG: SLB RFAL7NuE LWD ON 04118/08 ANGLE AT TOP PBtF: 42 ° ~ 8442' Pbte; Refer b PtoduCtion DB for hisbrical perf data SQE SPF ZO NTHZVAL OprVSgz DOTE 4-12" 5 Nb 6442 - 6488 O 04120108 4-111° 5 OA 6620 -6674 O 04120X18 4-12" 5 O$a 6710 - 6748 O 041mX16 4-112' 5 OBb 6766-6788 O 04120X~ 4-1/2` 5 OBc 6836 -6858 O 04/20X18 4-112` 5 O$d 6904 -6962 O 04120X18 ,D= ,D= oroa nrvc nxtisanui~Werauc~n, u= 6781' 3-1/2' HES X N@? D = 2.813' 17'X3-112' SNGLE FEf31i1A1 RCR ~ = 2.965" ~ 3-112" NOPG t~.l1.SBJSOR SU9 , D = 2992 3-112` FiES X NP, D =2.813" 3-112" FE;S X NP, D = 2.813" '~ @977' r"'13-11T WLEG, D= 289 H.I~ NDTLOGGED DATE REV BY COM~JTS OwATE RL'V $Y COMhE~RS ORION UPM'T 04125A8 N9FS ORIGINAL COYPLETIOHi WH.L: L~20 05122X18 ?/ PJC DRLG DRAFT OORRBCIIDNS P@iMtT No: 2080470 07101X18 TWIPJC ORLG DRAFT COPo2f~T10NS AR No; 50,029-23387-00 10H 6X18 JIPJC GLV C10 {0!V 18l~) PX PLl1G SEC 34, T12N, R11 E, 2389' FSI.81522' FWL BP Bq-br~lon (Alasta) • ! TIO Plot for Well L-220: a.ooo 3,000 -~ Tbg -i- IA 2.000 -~- OA ~ OOA OOOA -~- On ~I 1,000 i ~' ~ v osn s~os os/i sroe o~~zoroe aanaoe osvzoroe i orn ros n rn roa i znzros m rrzros oz~zzros ATTACHMENT A BP CEMENT DESIGN FORM Date: March 17, 2009 Cement Type :Standard Arctic Set Cement BHST 45°F BHCT 45°F Well: L-220 Pumpable Volume : 15 bbls Submitted By: Tiffany Quy Thickening Time 5-6 hours incl. 1 hr batch mix plus 1 hr pumping plus 2 hr safe Density 15.8 ppg Free water 0 ml Fluid Loss Target <50 cc/30 min API, cc/30 min. at BHCT Compressive strength 500 psi In 8 hours The slurry should have no free water. Results: Please submit results to Company Man. Date of Test: Service Co. Engineer: Lab API Fluid Loss(cc/30min) Thickening Time (hrs): Slurry Density(Ib/gal): Free Fluid(ml): UCA Compressive Strength (psi): RE: UNDER EVALUATION: ,,~-101 (PTD #2001150) Exhibiting S1ow~Repressurizati... Page 1 of 2 S Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, March 18, 2009 3:00 PM To: Maunder, Thomas E (DOA) Cc: West, Taylor; NSU, ADW Well Integrity Engineer Subject: RE: L-220 (208-047) Hi Tom, Gas lift gas was jumpered over from well L-110 to depress the fluid in the OA of L-220. With the characterization seen on the TIO plot, it is my opinion that the OA pressure is stable although elevated. To mitigate the high OA pressure, I believe an OA downsqueeze is the best approach. Thanks, Anna ~u6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 18, 2009 2:14 PM To: NSU, ADW Well Integrity Engineer Cc: West, Taylor Subject: RE: L-220 (208-047) Thanks Anna. What was used to depress the fluid? Is it your opinion that the OA pressure is stable although elevated? Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, March 18, 2009 1:58 PM To: Maunder, Thomas E (DOA) Cc: West, Taylor; NSU, ADW Well Integrity Engineer Subject: RE: L-220 (208-047) Hi Tom, Here is the information you have requested for L-220 (PTD #2080470). 1. Do you have a TIO plot? -Attached 2. Do you have a summary of the diagnostics performed? > 02/21/09: Bled OAP from 910 psi to 680 psi. Original wellhead pressures were tubing/IA/OA equal to 1360/5/910, final pressures were 1360/0/680. > 02/22/09: OAP increased 100 psi overnight > 02/24/09: MITOA failed at 16.15 gpm at 1000 psi. > 02/25/09-03/04/09: Depressed OA fluid level to 1458' 3/18/2009 ' RE: UNDER EVALUATION: ~-101 (PTD #2001150) Exhibiting Slow~Repressurizati... Page 2 of 2 > 03/09/09: Bled OAP from 1170 to 990 psi. > 03/10/09: OAP increased 60 psi overnight > 03/11/09: OA fluid level at 1345' post OA FL depress 3. Do you have a gas analysis? A gas analysis was not obtained because liquid mixed with gas contaminated sample. 4. What is the maximum pressure seen on the OA and how fast does it build? The maximum pressure seen on the OA, not imposed by efforts to depress the fluid level, was 950 psi in late 01/09. The OA pressure builds from 60-100 psi/day. 5. Do you have any fluid level information? The fluid level was recorded at surface on 2/2209 and at 1345' on 03/11 /09 after the fluid level was depressed in preparation for the OA downsqueeze. 6. Do you have the freeze protection summary? The well was completed in 04/08 with crude in the OA. Approximately 10 gallons of Methanol was used during the MITOA. Please let me know if there is any other information you need. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 18, 2009 12:33 PM To: NSU, ADW Well Integrity Engineer Subject: L-220 (208-047) Anna, You may have gotten a question from Taylor West or others regarding the OA pressure on L-220. 1 am seeking a couple of items ... 1. Do you have a TIO plot? 2. Do you have a summary of the diagnostics performed? 3. Do you have a gas analysis? 4. What is the maximum pressure seen on the OA and how fast does it build? 5. Do you have any fluid level information? 6. Do you have the freeze protection summary? Thanks in advance. I'd have copied you on the original message, but I am having some issues with sending emails. Best regards. I look forward to your reply. Tom Maunder, PE AOGCC 3/18/2009 L-220 (PTD #2080470) TIO Plot 4,~0 3,000 2,000 1,000 f Tbg -E IA -~- OA w OOA -~- OOOA On • 12/20/08 1212??08 01?0~~09 01110!09 01?i?!03 01!24109 01?31!09 02I0?J09 OZl14109 02!21109 02/28/09 03101!09 03?14!09 Sundry for L-220 • Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Wednesday, March 18, 2009 11:45 AM To: West, Taylor; Quy, Tiffany Cc: 'Preble, Gary B (SAIC)' Subject: RE: Sundry for L-220 (208-047) Taylor and Tiffany, I am seeking some additional information regarding the sundry submitted to cement the OA on this well. The Well Integrity Engineer(s) on the slope may have additional information. I have examined the file and logs and there appear to be some sand intervals below the 9-5/8" shoe. 1. Was there any indication of gas when the well was drilled through these intervals? I did not find any indication from the operations reports. 2. Is there a gas analysis available for the OA gas? 3. Is there a T-I-O plot available for the well? How high does the OA pressure build and how quickly? Well Integrity may have this. 4. When was the well freeze protected? Is there pumping information available for this operation? Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Wednesday, March 18, 2009 9:41 AM To: Maunder, Thomas E (DOA) Cc: West, Taylor; Quy, Tiffany Subject: Sundry for L-220 Tom, I submitted a 10-403 for L-220 (208-047) yesterday afternoon. It would be greatly appreciated if this 10-403 could be expedited. Thanks you sir Gary Preb/e /reformation Techno/ogy and Services Petrotechnica/ Data Team Coordinator SA/C 907-564944 907 350-6879 3/18/2009 Sundry for L-220 ~ • Page 1 of 1 Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Wednesday, March 18, 2009 9:41 AM To: Maunder, Thomas E (DOA) Cc: West, Taylor; Quy, Tiffany Subject: Sundry for L-220 Tom, I submitted a 10-403 for L-220 (208-047) yesterday afternoon. It would be greatly appreciated if this 10-403 could be expedited. Thanks you sir Gary Preb/e /nformation Techno/ogy and Services Petrotechnica/ Data Team Coordinator SA/C 907-564-4944 907-350-6879 3/18/2009 UNDER EVALUATION: L-2~PTD #2080470) High OA Pressure' ~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] t Sent: Monday, February 23, 2009 11:27 PM ~~f'~~ ~4~ ~~'~ To: GPB, Area Mgr West (GC2MlRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Regg, James B (DOA); Townsend, S. Eliot; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: L-220 (PTD #2080470) High OA Pressure Attachments: L-220.pdf; L-220 TIO and Injection Plot.doc v.- Hi all, ~'. Well L-220 (PTD #2080470) is exhibiting high OA~ressure due to an unknown source. The well has been reclassified as Under Evaluation and may remain on injection while diagnostics are being completed. The plan forward is to attempt to establish infectivity on the OA by conducting a MITOA. If the source of the high OA pressure can not be mitigated, the Well Integrity Coordinator will review the well for a request for Administrative Approval to continue injection. A wellbore schematic, TIO plot, and Injection plot have been included for reference. «L-220.pdf» «L-220 TIO and Injection Plot.doc» Please let us know if you have any questions. Thank you, Anna 1~u6e, ~~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659100 x1154 3/9/2009 PBU L-220 PTD 208-047 2/23/2009 TIO Plot 4.OOC'~ 3.000 .000 1.000 11129x08 12106108 1~~113J08 12i20?03 12127,'f_IR 01103!03 0111tt103 01,•'1F,•Y3 0112~!L€3 l1?31?03 02107103 02,'1#,•03 02?21!03 i ._. #- Tbg -~- IA -~ OA ...~};. OOA. ~ ODD~k On Injection Plot 2,O~Ir~ ~ 1,200 1,501 -~ 1,000 ~ WHIP ~ .M `~ ~~~ ~ sW { 1,i ICI? -i --~ M I ,. ~ 600 ~ G X300 c~ Other 50s_~ -~ On 2110 -----~~.Y ....~._. _ n??1°?08 0~t11$108 05119108 06:19?08 Or120r'i18 03120!0$ 03120='08 111;21?08 1112110v 1:.'1":''2103 01?2?'09 02?22103 TREE= 4-1/16" CM/ WELLHEAD F ACTUATOR = BAKER KB. ELEV - 78.6' KOP = 400' _. Max Angle = 64° @ 2657 ' Datum MD = 6818' Datum TVD = 4400'. SS 20" CONDUCTOR, ID = ? 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" ~--~ 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM - 7" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" - 7' MARKERJOINTw/RA PIP TAG - Minimum ID = 2.75" @ 6965' 3-1/2" HES XN NIPPLE 3-112" HES X NIP, ID = 2.813" - ~ 17" X 3-112" HES SINGLE FEEDTHRU PKR, ID = 2.965" I 17" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" ~ ~ L 2 2 0 S NOTES: **" HES PKR @ 6341' IS "PULL TO RELEASE' BUT GAN BE REt.EASED BY PRESSURE DO NOT EXC®4300 PSI. TEST PRESSURE PKR RATING = 5415 PSI 4332 PSI IS 80°1o OF PKR RATING *** 26' 4-1/2" X 3-1/2" XO, ID = 2.992", 3270' 3-112" HES X N~, D = 2.813" GAS LEI' MANDRELS 57 MD TVD DEV TYPE VLV LATCH PORT DATE 10 6307 4096 43 MMG DMY RK 0 09/18/01 6325' 3-1/2" HES X N~, O = 2.813" 3804' 6354' -13-112" NDPG MULTI-SENSOR SUB , ~ = 2.992 WATER ~1.lECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 6372 4143 43 MMG-W DMY RK 0 04/24!08 8 6466 4213 42 MMG-W P-15 RK 14 09!18108 7 6571 4291 41 MIMG-W DMY RK 0 04/24108 6 6659 4358 41 Ngv1G-W P-15 RK 17 09118/08 5 6710 4396 41 W~11G-W DMY RK 0 04/24/08 4 6737 4417 41 MMG-W P-15 RK 15 09(18!08 3 6787 4455 40 MMG-W DftRY RK 0 04!24/08 2 6849 4503 40 MMG-W P-15 RK 15 09!18!08 1 6915 4553 39 N~+AG-W R15 RK 17 09(18(08 6965 4592 39 1' 8' ( 6514' I " IV51Ut X NIF'I'Lt 655$' 3-1 /2" NDPG MULTI-SENSOR SUB , ID = 2.992 6677' 3-112° HES X NN', ~ = 2.813" I 6683' I 13-1/2" NDPG MULT4-SENSOR SUB , ID = 2.992 I I3-1(2" RA PIP TAG 7" X 3-1/2" HES SINGLE FEEDTHRU FKR, ID = 2.965" I 6749' I PERFORATION SUMMARY REF LOG: SLB REALTIME LWD ON 04/18108 ANGLE AT TOP PERF: 42 ° @ 6442' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-112" 5 Nb 6442 - 6468 O 04/20!08 4-112" 5 OA 6620 - 6674 O 04/20(08 4-112" 5 OBa 6710 - 6748 O 04/20108 4-112" 5 OBb 6766 - 6788 O 04/20/08 4=U2" 5 OBc 6836 - 6858 O 04!20/08 4-1/2" 5 OBd 6904 - 6962 O 04/20/08 3-112" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" 6977 PBTD 7136' 7" CSG, 26#, L-80 BTGM, .0383 bpfi, ID = 6.276" 7220' DATE REV BY COMMENTS DATE REV BY COMMEMS 04/25!08 N9ES ORIGINAL COMPLETION 05/22/08 ?! PJC DRLG DRAFT CORRECT~NS 07/01/08 TtNiPJC DRLG DRAFT CORRECTIONS 10/16/08 JLJ/PJC GLV C/O {09(18/08) PX PLUG ORiON UNIT WELL: L-220 PERMIT No: '1080470 API No: 50-029-23387-00 SEC 34, T12N, R11 E, 2369' FSL & 1522' FWL BP Exploration (Alaska) 676$' --~ 3-112" NDPG MULTI-SENSOR SUB , ~ = 2.992 67$1° 3-1/2" HES X NIP, ID = 2.813" 687$' -~ 7" X 3-112" S~+1GLE FEEDTHRU PKR, ~ = 2.965" 6892' 3-1/2" NDPG MULTI-SENSOR SUB , ~ = 2.992 6904' 3-112" HES X NIP, ®= 2.813" 6944' 3-1/2" HE5 X N~, O = 2.813" 6965' 3-112" HES XN NIP, O = 2.750" 6965' 3-112" PX PLUG 6977' 3-112" WLEG, ID = 2.992 ~~ ELMD NOT LOGGED MEMORANDUM • T®~ Jim Regg P.Y. Supervisor ~I ~ ~(~~~I FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Cornmission DATE: Monday, Apri120, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-220 PRUDHOE BAY iJNIT L-220 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -~~~ r_omm W eli Name: PRUDHOE BAY UNIT L-220 Insp Num: mitJCr090416091018 Rel Insp Num: API dVeli Number' 50-029-23387-00-00 Permit Number: 208-047-0 Inspector Name• John Crisp Inspection Date: 4/15/2009 Packer Depth Pretest Initial IS 1VIin. 301YIin. 4510'Iin. 601VIin. ~eii L-220 T,'pe IIlJ W T~D 4121 ~ ~ 60 4000 3880 3860 ~ P~.~ 2080470 TypeTes$ 3PT 'l'est pSl 1500 ~ ®A 120 130 130 130 Interval OTHER P/F P ~ Tubing 1700 1700 1700 1700 NOtes: 2.5 bbl's pumped for test. No problems witnessed Test for gas injection integrity. Monday, April 20, 2009 Page 1 of 1 UPDATE: L-220 (PTD #2080 OA Pressure under Operating Limit • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, March 31, 2009 9:58 AM To: Maunder, Thomas E (DOA) Subject: FW: UPDATE: L-220 (PTD #2080470) OA Pressure under Operating Limit Attachments: L-220 TIO Plot.doc Page 1 of ~~ Confirms my suspicion that frequent bleeding (removing liquids without replacing) reduced hydrostatic. Saw this in GOM over and over again when operators blow down annulus and recover both gas and liquid. Our remedy was to require them to attempt bleeding gas only, document volume of liqud recovered, and replace recovered liquid with equal or greater weighted liquid. We have not exercised any real oversight for bleeding (not suggesting we should) - I have no doubt that the field operators are bleeding as fast as possible (particularly when rigged up to containment) without any understanding about what the action represents. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, March 30, 2009 7:20 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Townsend, S. Eliot; West, Taylor; Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: UPDATE: L-220 (PTD #2080470) OA Pressure under Operating Limit Jim and Tom, An updated plot for L-220 is attached. The OA pressure has effectively stabilized at -100 psi post-OA load. The well will remain on the monthly injection report for at least another month for surveillance. «L-220 TIO Plot.doc» Please call with any questions or concerns. Thank you, Andrea Hughes Fro U, ADW Well Integrity Engineer Sent: Monday, 3, 2009 8:31 PM To: 'Regg, James B (DOA)'; r, Thomas E (DOA)' Cc: Townsend, S. Eliot; West, Taylor; NS Well Integrity Subject: RE: OPERABLE: L-220 (PTD #2080470) OA gir ngel, Harry R nder Operating Limit Hi Jim and Tom, Here is an up TIO plot. Unfortunately due to the way data feed into the system, tTih Today's ead pressures were tubing/IA/OA equal to 180010/130. The pressures will ored and I'll ask that Winton send another plot in approximately one week. is one day behind. 5/21/2009 4,000 3.ODu 2.D00 1,000 • L-ZZO TIC PIOt -*- Tbg -~- IA ~- OA OOA ~- OODA ~- On 01!03!09 01110!09 01117109 01124109 01131!09 02/07109 02114!09 021211D9 02t29J09 03107/09 D3114109 03!21109 03129JD9 • From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, March 23, 2009 8:31 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: OPERABLE: L-220 (PTD #2080470) OA Pressure under Operating Limit Hi Jim and Tom, Here is an updated TIO plot. Unfortunately due to the way data feed into the system, this plot is one day behind. Today's wellhead pressures were tubing/IA/OA equal to 1800/0/130. The pressures will continued to be monitored and I'll ask that Winton send another plot in approximately one week. r 4,000 3,000 2,000 t 1,000 Thank you. Anna Dube From: NSU, ADW Well Integrity Engineer t: Sunday, March 22, 2009 8:39 PM To: B, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad ;GPB, Optimizatio ngr; GPB, Wells Opt Eng; GPB, Prod Controllers; 'Regg, James B (DOA)'; 'Maunder, Thomas E '; Townsend, S. Eliot; Rossbe Steven; Engel, Harry R Cc: Townsend, S. Eliot; Taylor; NSU, ADW Well Integrity Engineer Subject: OPERABLE: L-220 #2080470) OA Pressure under Operatin All, Well L-220 (PTD #2080470) hash e OA loa d with brine on 3/22/09 to keep the OA pressure below operating li ~ he well will contin o be monitored while a solution to the high OA pressure is pr essed with the AOGCC. Thew as been reclassified as Operable and shall remain - ine to assist in allowing the OA pressure t abilize. Wellhead pressures prior to the ne load were tubing/IA/OA equal to 1850/20/450. Afte e brine load they were 180 00. ~- Tbg -i IA -~- OA ODA -i-- OOOA On 12,27108 0110309 0111009 01117!09 01!24105 01!31!03 02107/09 02/14/09 02/21109 0212>;105 03/07/09 03/14109 03/21/09 "iJPDATE: L-220 (PTD #208) OA Pressure under Operating Limi~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, March 30, 2009 7:20 AM ~~~q ~l''al~~`~1 To: Regg, James B (DOA); Maunder, Thomas E (DOA) c Cc: Townsend, S. Eliot; West, Taylor; Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: UPDATE: L-220 (PTD #2080470) OA Pressure under Operating Limit Attachments: L-220 TIO Plot.doc Jim and Tom, An updated plot for L-220 is attached. The OA pressure has effectively stabilized at 100 psi post-OA load. The well will remain on the monthly injection report for at least another month or surveillance. «L-220 TIO Plot.doc» Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Monday, March 23, 2009 8:31 PM To: 'Regg, James B (DOA}'; 'Maunder, Thomas E (DOA)' Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: OPERABLE: L-220 (PTD #2080470) OA Pressure under Operating Limit Hi Jim and Tam, Here is an updated TIO plot- Unfortunately due to the way data feed into the system, this plot is one day behind. Today's wellhead pressures were tubing/IA/OA equal to 1800!0/130. The pressures will continued to be monitored and I'll ask that Winton send another plot in approximately one week. Thank you, Anna Dube From: NSU, ADW Well Integrity Engineer Sent: Sunday, March 22, 2009 8:39 PM To: GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Townsend, S. Eliot; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer Subject: OPERABLE: L-220 (PTD #2080470) OA Pressure under Operating Limit All, Well L-220 (PTD #2080470) has had the OA loaded with brine on 3122109 to keep the OA pressure below operating limits. The well will continue to be monitored while a solution to the high OA pressure is progressed with the AOGCC. The well has been reclassified as Operable and shall remain on-line to assist in allowing the 3/31 /2009 `iJPDATE: L-220 (PTD #208) OA Pressure under Operating Limi~ Page 2 of 2 OA pressure to stabilize. Wellhead pressures prior to the brine load were tubing/IA/OA equal to 1850/20/450. .After the brine load they were 1800!0/400. Please let us know if you have any questions. Thank you, Anna 1~u6e, ~~'. ~. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, February 23, 2009 11:27 PM To: GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; 'Regg, James B (DOA)'; Townsend, S. Eliot; Rossberg, R Steven; Engel, Hany R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: L-220 (PTD #2080470) High OA Pressure Hi all, Well L-220 (PTD #2080470) is exhibiting high OA pressure due to an unknown source. The well has been reclassified as Under Evaluation and may remain on injection while diagnostics are being completed. The plan forward is to attempt to establish infectivity on the OA by conducting a MITOA. If the source of the high OA pressure can not be mitigated, the Well Integrity Coordinator will review the well for a request for Administrative Approval to continue injection. A wellbore schematic, TIO plot, and Injection plot have been included for reference. « File: L-220.pdf» « File: L-220 TIO and Injection Plot.doc» Please let us know if you have any questions. Thank you, Anna mud e, ~.~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 '~/'~ 1 /2OO9 PBU L-220 PTD 208-047 3/30/2009 TIO Pressures i 1,0~~ -~- Tbg -,-- IA -~- OA -- OOA -~ DDOA ~- On 011C13~h~~ 01?1l1lU~ fJ1?17~0~ U1~~~~~0~ Oll31r0'~ Q~r'07~1~3 ~~~1~lCJ3 ~~~l~1l09 IJ212r'r~0~ l~~r'07~fi~ 0~~1~~'li9 0~~~1t[~ ~1~~~0~09 '~ ._N.. _ _ _ _ _ _ ~~ )oa~,~,~ ~ ~ ~-, n ~. ~ 3lzzl ~7 RE: OPERABLE: L-220 (PTT~080470) OA Pressure under Operatil~iimit Page 1 aft' Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, March 23, 2009 8:31 PM ~~~(~j ~l-z~ ~zc;~'j To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: OPERABLE: L-220 (PTD #2080470) OA Pressure under Operating Limit Hi Jim and Tom, Here is an updated TIO plot. Unfortunately due to the way data feed into the system, this plot is one day behind. Today's wellhead pressures were tubing/IA/OA equal to 1800!0!130. The pressures will continued to be monitored and I'll ask that Winton send another plot in approximately one week. ~ P ~ J-~x~c i,~~ i '.. a..L /.. L.^-LLL/ L L.-^~^ /. /..L./././. L-L/../ / LL-L /-^ / L /-/ L LL/-LL LLL^i-LL-/ L-/-L-/L^-L-L-L /-L LL L-L-^ L L-^ L-L-L-/-L-/-LL f ~. ~ ~1~ 1 L' `'?t~~3 iii ?Ci3~`t~°3 Cil ?1 Q?t~~ Ci ~ ? l ~.~i Ci1 i 2~1?i~~ 01 ?31:'L~9 t]?' _ r:'Ci'3 L12?1 d:'Ci9 I~~:'4'1 ? i?9 i_l?? ~'~?09 p~:? C~ r Thank you.. Anna Dube From: NSU, ADW Well Integrity Engineer Sent: Sunday, March 22, 2009 8:39 PM To: GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operati s Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; 'Regg, James B (D )'; 'Maunder, Thomas E (DOA)'; Townsend, S. Eliot; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW ell Integrity Engineer Subject: OPERABLE: L-220 (PTD #20804 OA Pressure under Operating Limit All, Well L-220 (PTD #208 0} has had the OA loaded with brine on 3/22/09 to keep the OA pressure below operating limits. The ell will continue to be monitored while a solution to the high OA pressure is progressed with the AOGCC. a well has been reclassified as Operable and shall remain on-line to assist in allowing the OA pressure to abilize. Wellhead pressures prior to the brine load were tubing/IA/OA equal to 1850/20!450. After the brin oad they were 1800/0/400. ~t"et us know if you have any questions. you, 3/24/2009 F~fJr' lZ/t.fJ k;flltr ! {~.fJ 6llf ~fJr'r C1 C~l7l~Zr' SCI ~i~! l ~r'~ l~1 6Qr t~ G(ZfJ F;I~I~CI!ZfJ FJ~{ ~t r lfJ k~fJr`1~ ~{ lid 6fJr'L Gl LO 6fJr'fJ i.l GIJ F ll{C:Or' GCi ~Ot 1 Zl ~ I. up ~. b'000 - b'00 'd0 -~ b'I --~- 6q 1 --~- ~-aafa~ata-aa.a.-aa.i-a-afsafaa~~.a.a,~-a-aa-aaai.f.a_a.a-aa.asfaa~.rsa_~aaaa.f-s~_aa_aaaaaa~s-~aa-a-as-aa-fa a~.r~a~a ....... w ~~~~~2) CJ~Gf~` l fjQCi'Z fJfJG+~ OtlfJ'tr '`OPERABLE: L-220 (PTD #208) ~A Pressure under Operating Limi~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, March 22, 2009 8:39 PM ~~ To: GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Regg, James B (DOA); Maunder, Thomas E (DOA); Townsend, S. Eliot; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer Subject: OPERABLE: L-220 (PTD #2080470) OA Pressure under Operating Limit All, Well L-220 (PTD #2080470) has had the OA loaded with brine on 3!22!09 to keep the OA pressure below ~ operating limits. The well will continue to be monitored while a solution to the high OA pressure is progressed with the AOGCC. The well has been reclassified as Operable and shall remain on-line to assist in allowing the OA pressure to stabilize. Wellhead pressures prior to the brine load were tubingllA/OA equal to 1850/20!450. After the brine load they were 1800!0!400. Please let us know if you have any questions. Thank you, j~?Z1ZCl I~Zl~1E, ~: ~. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-590? Pager: {907) 659-5100 x1454 From: NSU, ADW Well Integrity Engineer Sent: Monday, February 23, 2009 11:27 PM To: GPB; Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; 'Regg, James B (DOA)'; Townsend, S. Eliot; Rossberg, R Steven; Engel, Harry R Cc: Townsend, S. Eliot; West, Taylor; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: L-220 (PTD #2080470) High OA Pressure Hi all, Well L-220 (PTD #2080470) is exhibiting high OA pressure due to an .unknown source. The well has been reclassified as Under Evaluation and may remain on injection while diagnostics are being completed. The plan forward is to attempt to establish infectivity on the OA by conducting a MITOA. If the source of the high OA pressure can not be mitigated, the Well Integrity Coordinator will review the well for a request for Administrative Approval to continue injection. A wellbore schematic, TIO plot, and Injection plot have been included for reference. « File: L-220.pdf» « File: L-220 TIO and Injection Plot.doc » Please let us know if you have any questions. Thank you, Anna 1~u6e, ~ ~. 3/23/2009 '.OPERABLE: L-220 (PTD #2080) OA Pressure under Operating Lim Page 2 of 2 Well Integrity Coordinator GP8 Wells Group Phone: (907) 559-5102 Pager: (907) 659-5100 x1154 3/23/2009 RE: UNDER EVALUATION: 5-101 (PTD #2001150) Exhibiting Slow IA Repressurizati... Page 1 of ~ i ~~ Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, March 20, 2009 2:32 PM To: Maunder, Thomas E (DOA) Cc: West, Taytor; Engel, Harry R; Regg, James B (DOA); NSU, ADW Well Integrity Engineer Subject: RE: L-220 (208-047) Hi Tom, We're going to go ahead with a brine load on the outer annulus with a known amount of brine. From there we will continue to monitor the pressure build up and keep the well under BP operating limits. We will converse again on Monday. Have a good weekend and thank you, Anna ~Du6e, l? E. Well integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 20, 2009 1;48 PM To: NSU, ADW Well Integrity Engineer Cc: West, Taylor; Engel, Harry R; Regg, James B (DOA) Subject: RE: L-220 (208-047) All, Following upon this morning's call, it is Jim's and my understanding that it is likely that the OA pressure on this well will be monitored through the weekend and we will converse again on Monday. I confirm with this message that Jim and I do not see any issue with keeping the well on water injection. Internal integrity (IA) and deep external integrity (cement) are effective. We look forward to speaking on Monday. Call or message with any questions. Tom Maunder, PE AOGCC Fro SU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: We ay, March 18, 2009 3:00 PM To: Maunder, Tho E (DOA) Cc: West, Taylor; NSU, ell Integrity Engineer Subject: RE: L-220 (208-047) ° ' Hi Tom, Gas lift gas was jumpered over from I~''r10 to depress the ~ in the OA of L-220..With the characterization seen on the TIO plot, it is my ~ n that the OA pressure is stable a h elevated. To mitigate the high OA pressure, I believe an ownsqueeze is the best approach. S/21/2009 Page 1 of 1 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Friday, March 20, 2009 11:48 AM To: Maunder, Thomas E (DOA) Subject: Admin Approvals with allowable OA>10% Max OA in these is 1500psi CPAI KRU 1 C-10; PTD 182-193; AIO 26.036 (8-25-2008) KRU 2K-03; PTD 188-120; AIO 2B.016 (10-17-2007) KRU 2K-10; PTD 189-059; AIO 26.017 (10-17-2007) BPXA MPU E-03; PTD 189-017; AIO 108,006; (312-2008) PBU Z-19A; PTD 206-105; AIO 3.017 (approved 4-13-2007 for OA=1000psi; amended 5-17-2007 for OA=1500psi) Guess this is not as much an issue as I thought. And I stand corrected - it does appear that they are consistent in addressing OA pressure. Appears they shut in Z-19A in July 2008 - possibty because of inability to manage OA pressures below 1000psi . If I understand plan for L-220, they are going to monitor pressures over weekend (after the infectivity test done yesterday) and will report that to us along with the results of irjectivity test (?), and I guess the ball will be back in our court if we want to approve sundry as is. I'd really like to see max stabilized OA pressure before we make a decision. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 5/21/2009 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, October 02, 2008 11:58 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU L-220 / PTD # 208-047 Hi Art, Please reference the following well: Well Name: PBU L-220 Permit 208-047 API #: 50-029-23387-00-00 Tap Pert MD: 6442' Bottom PerF MD: 6962' This well began Injection on September 20, 2008 Method of Operations is: Produced Water Injection Date of Test: N1A 10/2/2008 MEM®RANDUM To: Jim Regg ~~QN~ ~~7~ ~~`~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, Octoher 09, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-220 PRUDHOE BAY UNIT L-220 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J.*~F- Comm Well Name: PRUDHOE BAY UNIT L-220 Insp Num: mitJCr08 1008 1 14708 Rel Insp Num: API Well Number: 50-029-23387-00-00 Permit Number: 208-047-0 Inspector Name: John Crisp Inspection Date: 10/2/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-220 Type Inj. i W ~ TVD 4120 I,ct, 1570 i 2500 2460 2450 P T ~ zosoa7o TypeTest j SPT ;Test psi isoo pA i soo i sso s3o szo Interval Ii~IITAL p~F P ,~ Tubing ~ 1400 ~ 1350 1350 1350 ~ Notes' .8 bbl's pumped for test. Thursday, October 09, 2008 Page 1 of 1 3~C:iANICA.L INTEGRITY REPORT ' ~ • := BUD u-..'." : ~~~~_C;~ OPER & FIELD l~ ~ ~~" ~CrC ~G~..;: ~~~4~1. G r I:., ~~ I _ ~~~5 -O~ h.:.I.L NtTMBER ~~ ~ ~ ~ t :~~ LL DAT =_ TD : ~~~`~.?~.. ~~TVD ; ?BTD : ~~~ ~' ~ ~~~ ~, TVD C G s in ~ . ~ Shoe : '`1,~~MD ~'1~~ TVD ; liV : ~v ~ ?~ ~ ~, •?'ti'D _,.,e_ . _ ~~?^~ Shoe. '~ ~'~`,TD ; _ir . '•~ :'rD _voi~~ ~~~•~\ P ~ic~r lc~j~~''~D^'~~~~TV'il; Set Gt Cc,~~~ :ole Sy.. e ~~~~_ and ~ Perf3 l3 '1 to lv~t~~. ~= L'r"...~?~ =r~.L iNTEGR?TY - P A.RT # ~ .. \ C omen t ~ , ..~-J~`~ r c ~ ~ ~ ~5 ~ ~,-v ~~C~Q L'~ ~ /~ ~Y ~ i~5 vJ~~`C c'~ _. ~ U e rnn;;lus ?ress Test: _? ? 5 ciin Sa min t-' ~ CHI~?~1Cr..:~... INTEGRITY -PART # 2 ~ 1 ~~`" 1 S ~ Cement Volcimes :~. Amt. Liner ~_~; Csg'~1;~~ DV ~~ Cmt Jot. to cover aer~ s ~: ~G2.c;AC 5 y~ ~;h\ S ~•~ 5~~~.t~~c~. ._ _ =eoretical TOC C 3~~c 1~.5 ~= \~1~~Li i . Cement Bond Log (Yes yr No) '~°~,~ ~`~ ~T In AOGCC File~~E~ ~C~~t.;~S C3Z Evaluation, zone aoove perfs ~ ~c~C ~ `~~(,`~ ~c~~ <<Cn~ = y'~~~~; Production Log: I"ppe Evaluation • • CON~LJ5ION5 i ?art # - - _ _ _,. • STATE OF ALASKA ~'~ ALASKA IL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~EI~/E ivi~Y 1 9 2008 ~~;~sk~ Cii ~ Gay Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.,05 zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. Well Class: i1G lOfB ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 4125/20081 •0$ 12. Permit to Drill Number 208-047 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 4/11/2008 ~ 13. API Number 50-029-23387-00-00 4a. Location of Welt (Governmental Section): Surface: 6 ' S ' 7. Date T.D. Reached 4/18/2008 ~ 14. Well Name and Number: PBU L-220i ' 23 9 F L, 3757 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 3468' FSL, 2705' FEL, SEC. 03, T11 N, R11 E, UM 8. KB (ft above MSL): 78.6' Ground (ft MSL): 30.5' 15. Field /Pool(s): - Prudhoe Bay Field / Orion Total Depth: 2962' FSL, 2685' FEL, SEC. 03, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 7136' 4726' - Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 583159 y- 5978090 Zone- ASP4 10. Total Depth (MD+TVD) 7235' ~ 4805' 16. Property Designation: ADL 028239 TPI: x- 584266 y- 5973922 Zone- ASP4 Total Depth: x- 584292 y- 5973417 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit I roni and rin information er 20 AA 25. 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, Azi-Den, NEU, PWD, LWD, GYRO, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTHiTVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 1.5# A-5 rf e 108' rfac 1 34" 26 x Ar is Se A rox. 9-5/8" 40# L-80 30' 3 04' 30' 2749' 12-1 /4" ~~ sx DeepCRETE, 332 sx'G'. 72 sx DuraSTONE 7" 26# L-80 27' 7220' 27' 4793' 8-3/4" 40 sx LiteCRETE 274 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ NO 24, TUBING RECORD tf Yes, list each I (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MO PACKER SET MD 4-1/2" Gun Diameter, 5 SPF 3-1/2", 9.2#, L-80 6977' 6341', 6545', 6683' MD TVD MD TVD ~ ~~ ~ & 6755', 6878' 6442' -6468' 4195' - 4214' ~ 6620' - 6674' 4329' - 4369' ` ~'~'~ '25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. _ 6710' - 6748' 4396' -4425' '~ ~~ ' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ~ ~c 6766' - 6788' 4439' - 4456' 6836' - 6858' 4492' -4509' Freeze Protected with 100 Bbls of Diesel 6904' -6962' 4545' - 4590' ~ ~~ 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. (-A~flPL~TiON ;I None ~~ n~ ~• °===- 6 F' Form 10-407 ReVISed 02/2007 ONTINUED ON REVERSE .SIDE ~ ~ ~ s ~~r ~u~ ~ ~ coos ~l-~ ~' ~.~~, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top 30.5' 30.5' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1860' 1746' detailed test information per 20 AAC 25.071. Top of Ugnu 3896' 2792' Ugnu MA 6063' 3922' None Ugnu M61 6126' 3966' Ugnu MB2 6208' 4025' Ugnu MC 6305' 4094' Schrader Bluff NA 6407' 4169' Schrader Bluff NB 6443' 4196' Schrader Bluff NC 6487 4229' Schrader Bluff NE 6497' 4236' Schrader Bluff NF 6567' 4289' Schrader Bluff OA 6622' 4330' Schrader Bluff OBA 6711' 4397' Schrader Bluff OBB 6763' 4437' Schrader Bluff OBC 6837' 4493' Schrader Bluff OBD 6905' 4546' Schrader Bluff OBE 6983' 4606' Schrader Bluff OBF 7032' 4644' Base of Schrader Bluff OBF /Top of Colville Mudstone 7095' 4694' Formation at Total Depth (Name): Colville Mudstone 7235' 4805' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ ~ ~ ~ C""". ' . Signed Son a Stewma Title Drilling Technologist Date ~ ~ ~ "(,~ PBU L-2201 208-047 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Bob Coolidge, 564-5776 Permit No. / A r val No. INSTRUCTIONS GeNewu: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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). Irene 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-tn, or Other (explain). Irene 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = 4=1116" CRN ~~ SAF TES: *"`HES PKR ~ 5341' tS "PULL T4 L -~ ~ O RELE115E" Bt3T CAN ALSO BE R~EAS~18Y PF~SUF+l1=. DQ NOT ExC~ 4100 PSI. TEST' PRESSI.~ PKR RATING = 5415 PSI (431? PSI IS 80Y" flF PFQi. RATINGy"`~' 2fi* ........4.112" XO 3-112", ID = 2.992" 3270' ~~ 3-1/2" HES X NIP, ID = 2.813" [9-5J8" CSC, 40#. L-80, TGI6, L1= 8.835" ~~ 3,$04" T` CSG, 2&#, L=80, TGa~, .D383 bpf, (D = 6.276" , 277' ~i-~af~'~ ~EcJ XN N~~P~.E MARKER JOINT w r RA TAG N b 6, 418'.... CEMRALQERw! RA TAG Nc 6750" GA S LIFT MANDRELS ST MD TVD DEV TY PE 11LV LATCH PORT DATE 10 6347 4496 43 MMG DCR-1 RKP 0 04124108 WATER INJECTION N~A(JDRELS 57 MD TbD DEV TYPE VLV LATCH PORT DATE 9 6372 4143 43 MMG-W DMY R}C 4 ..04124108 8 64&6 4233 42 N~UlG-1N t~MY RK 0 04124108 7 6571 4291 41 MMG-W DMY RK 4 04124108 5 6659 4358 41 MMG-W C)hAY RK 4 04124108 5 6710 4396 41 MMG-W DMY RK 4 04124108 4 6737 4417 41 N~v(G-W i~utY R}C 0 04124108 3 6787 4455 44 Iu11yfG-W C~VTY RK 0 04124/08 2 6849 4503 40 MMG-W DiuTY RK 0 04124108 1 6915 4553 39 MNtG-W t'~1Y RK' 0 04124108 PERF{~RATION SUMMA RY REF LOG: SB Realt~ne LWD: 41181200& A NGLE AT TOP PERT: 42° ~ 6442' Note: Refer to Production DB for f~ist~rical pert data SSE SPF INTERVAL Opn/Sqz DATE 4-112' S 6442 - 6468 Q 44120/08 4-112" 5 662t? - 5674 O 04/20/08 4w112" 5 6710 - 6748 {} 04120108 4-112° 5 s7ss - 6788 o fl4120748 4-112" 5 6836 -68'58 Q 04120108 4-112° 5 6904 - 6962 O fl4Y10/08 9.2#, L-80, TGII, .~87 bpf, ID = 2.992" 6976' 6325' -~ 3-1 /2" HES X NIP, ID = 2.813" 6341' -{ 7" HESHES AHR PKR w! 1!4" F THRU, ~ = 2.90" 6354' MULTI DROP SGM FOR NDPG GAUGE, ID=2.910" 6514' ~ 3-1t2" HES X NIP, ID=2.813" 6545" 7" HES A HR PKR w f 1 f4 FE® THRU, ID 2 920" 635$' MULTf DRfJP SGM FOR NDPG GAUGE, ID=2.91fl" 6677` 3-172" HES X NIP, ID = 2.813" 66$3' T' HES A HR PKR vv ! 114" FEED THRU, ID = 2.920" 6697" MULTI DROP SGM FOR NDPG GAUGE, ID=2.910" 6756" 7" HES A HR PKR w / i 14" FEFD THRU, = 2.920" 6768' MULTI DROP SGM FOR NDPG GAUGE, X2.910" `, IU ~ 6$78` 7" HES A HR PKR w 1114" FEED THRU, 1D =2.920" 6$92' SINGLE SGM FOR NDPG GAUGE, ID=2.913" 6904* 3-112" HES X N8', ID = 2.813" 6944* 3-112" HES X N0', ID = 2.89 3" 6965* 3-112" HES XN NIP, ID = 2.75" 6977' 3-112" WLEG, [D = 2.992" ,fl383 bpf, ID = 6.276 (-j 7219 DATE REV 04!25/08 IV9. ORION UNIT' WELL: L-2241 PERMIT No: 2084470 API Nn: 54-429-23387-40 2369' FSL; 3757' FEL', Sep 34, Tw p 12N, Rge 11 E BP Exploration (A9aska} BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: L-220 Common Well Name: L-220 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Start: 4/10/2008 Rig Release: 4/25/2008 Rig Number: Spud Date: 4/11/2008 End: 4/25/2008 Date From - To I Hours Task Code NPT Phase Description of Operations 4/10/2008 00:00 - 06:00 6.00 CONS P PRE ND 9ES diverter line on L-221 i - NU 7es diverter on L-220i. (NOTE: 7ES diverter knife valve flange will not MU to 9E diverter line.) Rig crew working on Pad preparation for Rig, cellar, and diverter line saddles. 06:00 - 07:00 1.00 MOB P PRE Pull rig off L-221 i to allow removal of the 9ES diverter system for RU on L-220i. Rig crew continues working on Pad preparation for Rig, cellar, and diverter line saddles. 07:00 - 14:00 7.00 RIGU P PRE Continue to RU diverter system on new well, set rig mats and acce ted ri at 07:00 hours (based upon rig crew finishing pad preparation for location/diverter system work, rig accept was shifted). Rig crew working on Pad preparation for Rig, cellar, and diverter line saddles. 14:00 - 16:00 2.00 RIGU P PRE Move rig over L-220i. 16:00 - 17:00 1.00 RIGU P PRE Spot mud pits. 17:00 - 22:00 5.00 RIGU P PRE Continue to RU, bearm rig & pits, secure all landings and stairways, set cuttings box, hook-up inter-connect and mud lines, air-up flow-line, lower beaver slide, hook-up geronimo line, change-out 16" nipple to 20", install riser and begin to load pipe shed. 22:00 - 00:00 2.00 RIGU P PRE Take on water, mix spud mud and continue to load pipe shed. 4/11/2008 00:00 - 02:00 2.00 RIGU P PRE Continue to load pipe shed with drillpipe and mix spud mud (some problems with bulk gel system). Held pre-spud meeting at crew change at 01:30 hours (tour change safety/planning meeting). 02:00 - 10:30 8.50 RIGU P PRE Continue to prepare to spud well - PU DP and mix spud mud. 10:30 - 16:30 6.00 RIGU P SURF PU BHA #1, PU motor, bit, x/o UHT-40, 1 stand HWDP. Pump and rotate thru ice-plug and chase to bottom of conductor at 108'. Stand-back HWDP. PU MWD & orient. Function tested diverter system -annular close time 20 sec. / knife valve open time 5 sec. (Test witnessed by J. LeBlanc - WSL & M. Ashley NAD. Withness waived by Chuck Sheve - AAOGC.) 16:30 - 19:00 2.50 DRILL P SURF Spud well and drill from 108' to 358', UWT = 52K, DWT = 50K, RWT = 52K, 550 gpm, 860 psi off, 965 psi on, 60 rpm, .5K torq off, 1.4K torq on. 19:00 - 20:00 1.00 DRILL P SURF TOH to 85' to PU gyro survey equipment and finish MU BHA. 20:00 - 20:30 0.50 DRILL P SURF TIH. Finish MU BHA #1, PU stabilizer & jar stand. RIH to 281'. 20:30 - 21:00 0.50 DRILL P SURF Ream hole f/281' to 358' at 550 gpm, 970 psi, 60 rpm, .6K torq. 21:00 - 00:00 3.00 DRILL P SURF Directionally drill ahead (sliding) taking gyro surveys every 100' ~ IJWT 65K, DWT 63K, RWT 60K 550 gpm, 1060 psi off 1110 psi on, 60 rpm, 0.7K torq off, 1.5K torq on, WOB 15-20K 9.1 ppg mud weight, viscosity 400 sec/qt Wipe 30' on each connection AST = .78 hours /ART = 1.02 hours / ADT = 1.8 hours. 4/12/2008 00:00 - 15:00 15.00 DRILL P SURF Drill from 649' to 1779' MD, WOB - 35K, RPM - 80, Flow - 550 gpm, torq - 4.6K on, SSP on - 1700 psi, SSP off - 1550 psi, UWT - 75K, DWT - 69K, RWT - 75K, 9.2 ppg Mud Wt. Monitor Printed: 5/19/2008 11:26:43 AM ~ ~ BP EXPLORATION Operations Summary Report Page2of9~ Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABOBS 9ES Rig Number: i Date From - To ', Hours Task ~ Code NPT Phase Description of Operations 14/12/2008 100:00 - 15:00 I 15.001 DRILL I P 15:00 - 17:00 I 2.001 DRILL I P 17:00 - 18:00 I 1.001 DRILL I P 18:00 - 21:30 I 3.501 DRILL I N I RREP I SURF 21:30 - 00:00 2.50 DRILL N RREP SURF 4/13/2008 00:00 - 01:00 1.00 DRILL N RREP SURF 01:00 - 02:30 1.50 DRILL N RREP SURF 02:30 - 05:00 2.50 DRILL N RREP SURF 05:00 - 22:30 17.50 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 4/14/2008 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 02:00 1.50 DRILL P SURF 02:00 - 07:00 5.00 DRILL P SURF 07:00 - 11:00 I 4.001 DRILL I P I I SURF 11:00 - 13:00 2.00 DRILL P SURF 13:00 - 15:30 2.50 DRILL P SURF 15:30 - 16:30 1.00 CASE P SURF 16:30 - 19:00 2.50 CASE P SURF 19:00 - 20:00 1.00 CASE P SURF 20:00 - 00:00 I 4.001 CASE I P I I SURF 4/15/2008 100:00 - 05:30 1 5.501 CASE I P I I SURF well prior to trip. AST = 6.99 hrs /ART = 2.98 hrs /ADT = 9.97 hrs Back-reamed out of hole to 1398' MD to circulate the hole clean (2 x BU's) & TOH to 281' (top BHA) w/minor tight spots (5-10K over-pulls) at 1318' & 1013' MD (wipe w/o pumps). RIH with some tight hole at same 1013' & 1318' MD locations (no pumps needed to work into hole). Ream from 1683' to bottom w/o problem and prepared to drill ahead when fire in engine room curtailed drilling operations, 550 gpm, 1650 psi, 80 rpm, 4K torq. POOH due to fire in engine room (turbo failure on #1 engine). Circulated 1 BU at -250 gpm and POOH with some tight hole at 1318' and 1013' MD (no pumps required). Stand back BHA #1. Change-out turbo on #1 engine and clean engine room area. Repaired/replaced turbo on #1 engine and clean engine room area. Diagnose problem with the inertia brake. (Service top-drive) RIH w/BHA #2 (same BiUBHA as BHA #1 ), washed last stand to bottom at 550 gpm, 1400 psi. Circulated BU at reduced flow-rate to circulate out thick mud. Resume drilling operations. Drill from 1779' MD to 3814' MD_ (12-1/4" TD), WOB - 20-35K, 550-650 gpm, 5.5-7.5K torq, 3250 psi Off, 3300 psi On, 95K Up, 70K Down, 80K Rotate, 9.6 ppg mud, 160 ft/hr Slide, 233 Whr Rotate. AST = 4.22 hrs -ART = 5.85 hrs -ADT = 10.07 hrs Circulate and condition hole in preparation for short trip, 3 x BU, 120 RPM, 675 gpm, 3160 psi, 4.2K tq, Up 95K, Down 70K. Continue to circulate and condition well in preparation for short trip, 2XBU, 675 gpm, 3160 psi, 120 rpm, 4K torq, up 95K, down 70K. POH to 1682' MD w/o problems (25K over-pulls at 2680' & 2620' MD w/o pumping). RIH back to the 12-1/4" TD at 3814' MD. Had to pump at 125 gpm from f/2100' t/2500', however, dry-RIH after washing thru 1-time. Circulate 3 bottoms up, back-ream slowly f/3814' to 3488' MD while circulate and condition well at 120 RPM, 650 gpm, 3300 psi, 5/6K torq, monitor well f/10 minutes. POOH f/3488' to BHA w/o problems. LD BHA. Clean & clear rig floor. Make dummy run w/9-5/8" landing joint. Secure stack and fill. PJSM for casing job w/all personnel. RU Franks tool. MU &RIH with 9-5/8" shoe track (Baker lock connections) and check floats - OK. RIH w/9-5/8" casing from 120' to 1817' MD, 40#, L-80, BTC connections, torq to position, average torque is 9.4 KfUlbs. Bowspring centralizers on the first 25 joints Continue running 9-5/8" casing from 1,817' to 3,771' MD. Make up hanger and landing joint. Land casing on depth at ~] OI~A~ SURF SURF SURF Printed: 5/19/2008 11:26:43 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: L-220 Common Well Name: L-220 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date ,From - To Hours ' Task ~ Code ~NPT 4/15/2008 00:00 - 05:30 5.50 CASE P Spud Date: 4/11 /2008 Start: 4/10/2008 End: 4/25/2008 Rig Release: 4/25/2008 Rig Number: Phase i Description of Operations SURF *No mud losses for casing run. Halliburton 9 5/8" Float Shoe set ~ 3,803.54' 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar 1 Jt 9 5/8" 40# L-80 BTC Casing (#3) 9 5/8" 40# L-80 BTC Pup Jts (9.80' & 15.19') 91 Jts 9 5/8" 40# L-80 BTC Casing (#4-#96) 9 5/8" 40# L-80 BTC Hanger P x P Pup Jt. 9 5/8" Fluted Casing Hanger PU Wt - 170k, SO Wt - 92k w/ 35K 05:30 - 06:00 0.50 CASE P 06:00 - 09:30 3.50 CEMT P 09:30 - 13:30 I 4.001 CEMT I P 13:30 - 14:30 I 1.001 CEMT I P 14:30 - 18:30 I 4.001 CEMT I P 18:30 - 23:00 I 4.501 DIVRTR I P Baker-Lok Shoe-track Jts #1-3 Bowsprings Centralizers: 1 on stop ring 5' above shoe on jt #1 1 on joints #2- #24 25 Total Centralizers SURF Rig down Franks tool and rig up cement head. SURF Circulate and condition mud for cement job. Reciprocate casing in 10 ft strokes. Stage pumps up to 5 bpm, 350 psi. PU - 160k, SO - 98k. MW - 9.5 ppg, Vis - 82, PV - 22, YP - 18 Held PJSM while circulating. SURF Switch to Dowell. Pump 5 bbls of fresh water. Test lines to 4,000 psi - OK. Mix and pump 40 bbls of 10.5 ppg MudPush II spacer ~ 4 bpm avg. Drop bottom plug. Mix on the fly and pump 443 bbls of 10.7 ppg DeepCrete lead cement C~3 5 bpm avg, 265 psi ICP, 435 psi ICP. Batch mix and pump 68.5 bbls of 15.8 ppg Class "G" tail cement ~ 4 bpm avg, 480 psi ICP, 250 psi FCP. Stop reciprocating casing. PU - 165k, SO - 61 k. Batch mix and pump 15 bbls of 16.3 ppg Class "G" with DuraStone tail cement ~ 2.5 bpm avg, 140 psi ICP, 90 psi FCP. Switch to rig and displace cement @ 4.5 bpm avg, 140 psi ICP, 640 psi FCP. Slowed pumps to 3 bpm, 4 bbls prior to bumping plug. Bumped plug on schedule with 1,050 psi and held for 3 minutes. CIP ~ 13:35 hr. *Returned 120 bbls of "Sidewalk cement to surface. *No mud losses. SURF Increase pressure to 3,500 psi and hold for 30 minutes - ood test. Bleed off pressure and check floats - OK. SURF Rig down casing and cementing equipment. Clean residual cement from all surface equipment. SURF Nipple down surface diverter system. Printed: 5/19/2008 11:26:43 AM • BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2008 23:00 - 00:00 1.00 WHSUR P SURF Prep hanger neck for wellhead installation. 4/16/2008 00:00 - 03:30 3.50 WHSUR P SURF Nipple up casing head and tubing spool. Changed out valves on tubing spool due to bent valve stems. Test metal to metal seals to 1,000 psi for 10 minutes - OK. 03:30 - 08:30 5.00 BOPSU P SURF Nipple up BOPE. 08:30 - 09:30 1.00 BOPSU P SURF Rig up to test BOPE. 09:30 - 13:30 4.00 BOPSU P SURF Pressure test BOP to 250 psi low, 4,000 psi high. Test annular preventer to 250 psi low, 3,500 psi high. All tests held for 5 minutes each. Perform accumulator draw-down test. Tests were witnessed by AOGCC rep John Crisp, BP WSL Tom Anglen, and NAD TP Mark Ashley. 13:30 - 14:30 1.00 BOPSU P SURF Rig down BOPE test equipment. Install wear bushing. 14:30 - 16:00 1.50 DRILL P PROD1 Pick up 12 joints of 4" drill pipe and rack back in derrick. 16:00 - 18:30 2.50 DRILL P PROD1 PJSM. Pick up and make up BHA #3: New 8 3/4" HTC HCM506Z bit, XP motor with 1.15' ABH, ARC6, MWD, ADN6, NM DC, NM Stab, tea NM DCs, Saver sub, Jar stand. 18:30 - 19:30 1.00 DRILL N HMAN PROD1 Run in hole with 1 stand of 4" HWDP. Make up and over torqued connection on 2nd stand. Change out 2 joints of HWDP. 19:30 - 21:00 1.50 DRILL P PROD1 Run in hole with HWDP to 1,023'. Shallow hole test MWD - OK. 21:00 - 00:00 3.00 DRILL P PROD1 Pick up 1st ghost reamer and run in hole picking up drill pipe from 1,028' to 2,264'. Pick up 2nd ghost reamer and continure picking up drill pipe from 2,270' to 3,131'. 'UCA results - 500 psi in 27 hrs, 10 min, 1,000 psi in 35 hrs, 32 min. 4/17/2008 00:00 - 01:00 1.00 DRILL P PROD1 Continue running in hole with BHA #3, picking up drill pipe from 3,131'to 3,414'. 01:00 - 02:00 1.00 DRILL P PROD1 Slip and cut drilling line 77 ft. 02:00 - 03:00 1.00 DRILL P PROD1 Service top drive, crown and drawworks. 03:00 - 04:00 1.00 DRILL P PROD1 Run in hole from 3,414' to 3,601'. Wash from 3,601' to top of cement at 3 710'. 500 gpm, 2,000 psi, 60 rpm, 4.5k TQ. PU - 108k, SO - 65k, RWT - 80k. 04:00 - 04:45 0.75 DRILL P PROD1 Drill cement from 3,710' to float collar on depth at 3,720'. Drill out float track and rathole to 3,814'. Start displacing spud mud with 8.8 ppg LSND mud before drilling out float shoe. 500 gpm, 2,050 psi, 60 rpm, 5.5k TO. 04:45 - 05:00 0.25 DRILL P PROD1 Drill new hole from 3,814' to 3,824'. Had to slow mud pumps to allow Vac truck to keep up off loading new mud. 05:00 - 05:45 0.75 DRILL P PROD1 Continue swapping out mud to 8.8 ppg LSND mud. 290 gpm, 520 psi, 60 rpm, 5.7k TO. 05:45 - 06:45 1.00 DRILL P PROD1 Clean surface mud equipment. 06:45 - 07:00 0.25 DRILL P PROD1 Drill new hole from 3,824' to 3,834'. 07:00 - 07:30 0.50 DRILL P PROD1 Perform Leak off Test. MD - 3,804', TVD - 2,748' MW - 8.8 ppg, Leak off Pressure - 445 psi EMW - 11.91 07:30 - 07:45 0.25 DRILL P PROD1 Obtain benchmark ECD's and SPR's. 585 gpm, 1,500 psi. ECD = 9.53 ppg, CECD = 9.19 ppg, Correction = -0.34 ppg. 07:45 - 12:00 4.25 DRILL P PROD1 Directionally drill 8 3/4" hole from 3,834' to 4,550'. 585 gpm, 1,800 psi off, 2,200 psi on. Printed: 5/19/2008 11:26:43 AM • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABOBS 9ES Rig Number: I Date j From - To Hours i Task Code I NPT I Phase ', Description of Operations -- 1 4/17/2008 ---- 07:45 - 12:00 4.25 DRILL P PROD1 100 rpm, 4-5k TO off, 5-7k TO on. PU - 109k, SO - 70k, RWT - 85k, WOB - 15-22k AST - 0.77 hrs, ART - 1.58 hrs MW - 9.0 ppg in and out. CECD - 9.83 ppg, AECD - 10.35 ppg 12:00 - 00:00 12.00 DRILL P PROD1 Directionally drill 8 3/4" hole from 4,550' to 6,736'. 585 gpm, 2,760 psi off, 3,010 psi on. 100 rpm, 7.4k TO off, 9k TO on. PU - 145k, SO - 87k, RWT - 108k, WOB - 15k AST - 1.87 hrs, ART - 4.77 hrs MW - 9.0 ppg in and out. CECD - 9.83 ppg, AECD - 10.90 ppg 4/18/2008 00:00 - 03:15 3.25 DRILL P PROD1 Directionall drill 8 3/4" hole from 6,736' to TD ~ 7 235' MD / 4,809' TVD. 585 gpm, 3,050 psi off, 3,280 psi on. 100 rpm, 9k TO off, 10.5k TO on. PU - 160k, SO - 92k, RWT - 115k, WOB - 10-20k MW - 9.0 ppg in and out. CECD - 9.83 ppg, AECD - 11.0 ppg 03:15 - 05:00 1.75 DRILL P PROD1 Circulate 1 bottoms up @ 585 gpm, 3,050 psi. Pump Hi Vis sweep surface to surface ~ 585 gpm, 2,990 psi. 120 rpm, 9-10k TO. Sweep returned 10% increase in cuttings when back to surface. MW - 9.0 ppg in and out. CECD - 9.83 pppg, AECD - 10.3 ppg. 05:00 - 06:00 1.00 DRILL P PROD1 Monitor well - OK. Attempt to POH dry. 1st 2 stands pulled good, 3rd stand started pulling tight. Run back in hole to bottom to start backreaming. 06:00 - 11:00 5.00 DRILL P PROD1 Backream from 7,235' to 6,068'. 550 gpm, 3,000 psi, 100 rpm, 9-10k TO. Rotated ghost reamer into casing 3 stands while circulating a bottoms up. 11:00 - 12:30 1.50 DRILL P PROD1 POH dry from 6,068' to 3,768' without problem. PU - 150k, SO - 75k. 12:30 - 13:00 0.50 DRILL P PROD1 Pump dry job. Remove topdrive blower hose. Blowdown topdrive. 13:00 - 15:30 2.50 DRILL P PROD1 POH from 3,768' to 288'. 15:30 - 19:00 3.50 DRILL P PROD1 Laydown BHA #3. Bit grade: 3 - 2 - BT - A - X - I - RO - TD. 19:00 - 19:30 0.50 DRILL P PROD1 Clear and clean rig floor. 19:30 - 21:00 1.50 BOPSU P RUNPRD Pull wear bushing. Function rams. Flush BOP stack with ported sub. Install test plug. 21:00 - 22:30 1.50 BOPSU P RUNPRD Change upper rams from VBR's to 7". 22:30 - 00:00 1.50 BOPSU P RUNPRD ig up to test rams. est 7" rams to 250 psi low, 4,000 psi high. Hold each test for 5 minutes. 4/19/2008 00:00 - 00:30 0.50 BOPSU P RUNPRD Finish rigging down BOP test equipment. 00:30 - 02:00 1.50 CASE P RUNPRD Finish rigging up to run casing. Make dummy hanger run. 02:00 - 06:30 4.50 CASE P RUNPRD PJSM. Baker-Lok and make up 7' 26# L-80 BTC-M casing. shoe track. Check floats - OK. Baker-Lok and make up next 3 jts with torque rings installed in boxes. Run in hole with a total of 46 joints of 7" casing to 1,904'. Make up crossover joint and set in slips at 1,942. Fill every joint, top off and record PU / SO Wts every 10 joints. BTC-M make up torque - 8,500 ft/Ibs. Used BOL 2000 NM Printed: 5/19/2008 11:26:43 AM BP EXPLORATION Operations Summary Report Page6of9~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date II From - To L-220 L-220 DRILL+C NABOR NABOR Hours OMPLE S ALASK S 9ES ~ Task TE Start A DRILLING I Rig Rig Code ~ NPT ' Phase Spud Date: 4/11/2008 : 4/10/2008 End: 4/25/2008 Release: 4/25/2008 Number: Description of Operations 4/19/2008 02:00 - 06:30 4.50 CASE P RUNPRD pipe dope. Ran 2 straight blade centralizers, separated by stop ring on every joint. 1 centralizer free floating on 20' marker joint. 06:30 - 07:00 0.50 CASE P RUNPRD Rig up TCII torque turn equipment. 07:00 - 09:30 2.50 CASE P RUNPRD Run in hole with 7" 26# L-80 TCII casin from 1 942' to 3 804'. Fill every joint, top off and record PU / SO Wts every 10 joints. TCII make up torque - 10,100 ft/Ibs. Used JLSG pipe dope. Ran 2 straight blade centralizers, separated by stop ring every joint for the 1st 11 joints. 1 centralizer free floating on 2 pup joints. 119 total centralizers, 58 stop rings. 09:30 - 10:30 1.00 CASE P RUNPRD Circulate 1.5 times bottoms up. 5 bpm, 400 psi. PU - 110k, SO - 84k. 10:30 - 11:00 0.50 CASE P RUNPRD Run in open hole with 7" BTC-M x TCII casing from 3,804' to 4,000'^ Started pushing mud away. 11:00 - 13:00 2.00 CASE P RUNPRD Establish circulation and wash down from 4,000'to 4,133' with good returns. 3 bpm, 650 psi. 13:00 - 17:00 4.00 CASE P RUNPRD Run in hole from 4,133'to 6,054. Fill everyjoint and circulate down every 10 joints at 3 bpm. Record PU - SO WTs every 10 joints. 17:00 - 18:00 1.00 CASE P RUNPRD Circulate a bottoms up while while running in hole from 6,054' to 6,258'. 4.2 bpm, 630 psi. 18:00 - 20:00 2.00 CASE P RUNPRD Run in hole from 6,258' to 7,190'. Fill every joint and circulate down every 10 joints at 3 bpm. Record PU - SO WTs every 10 joints. Ran total of 127 joints of TCII casing. RA to at 6,421'. 20:00 - 21:00 1.00 CASE P RUNPRD Make up hanger and landing joint. Land casing on depth at 7.220. PU - 210k, SO - 98k with 36k blocks. Rig down casing fill-up tool. Make up Dowell 2 plug cementing head and cement line. 21:00 - 00:00 3.00 CEMT P RUNPRD Circulate and condition mud for cement 'ob. Stage pump from 2 bpm to 5 bpm, 560 psi ICP, 520 psi FCP. MW - 9.2 ppg, Vis - 47, PV - 15, YP - 18. PU - 210k, SO - 98k with 36k blocks. "No mud losses for casing run and circulatin . 4/20/2008 00:00 - 02:30 2.50 CEMT P RUNPRD Switch over to Dowell. Held cement PJSM during Pre-tour meeting) Pump 5 bbls of fresh water. Test lines to 4,200 psi - OK. Pump 42.5 bbls of batched mixed 10.5 ppg MudPush II Spacer. Drop bottom plug. Pump 24 bbls of batched mixed 11.0 ppg LiteCrete cement. Pump 57 bbls of batched mixed 15.8 ppg Premium "G" cement. Wash up lines to rig floor. Switch to rig. Kick out top plug and pump 273.5 bbls of 9.0 ppg brine. 1st 240 bbls at 5 bpm, 100 psi ICP, 1,065 psi FCP. Last 33.5 bbls at 3 bpm, 740 psi ICP, 1,270 psi FCP. Reciprocated casing in 15 ft strokes until 262 bbls were away. Printed: 5/19/2006 11:26:43 AM • BP EXPLORATION Page 7 of 9 Operations. Summary Report Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABOBS 9ES Rig Number: Date i, From - To Hours , Task Code NPT ~, Phase .Description of Operations 4/20/2008 00:00 - 02:30 2.50 CEMT P RUNPRD Landed Wts: PU - 175k, SO - 73k with 36k blocks. Bumped plug on schedule to 1,750 psi, 95% pump efc. CIP at 02:10 hr. **No losses. Bleed off pressure, check floats - OK. 02:30 - 03:00 0.50 CEMT P RUNPRD Pressure test casin to 4,000 si - 30 min - pod test. 03:00 - 05:00 2.00 CEMT P RUNPRD Blowdown surface lines. Rig down cement head and lines. Laydown landing joint. Change out bales. 05:00 - 06:00 1.00 CEMT P RUNPRD Set and test pack-off to 5,000 psi - 30 min -good test. 06:00 - 07:00 1.00 CEMT P RUNPRD Perform post cement LOT, Infectivity test. Pumped 3 bbls at 3 bpm. MW - 9.2 pP9 TVD - 2,748' LOP - 500 psi EMW - 12.7 PP9 FCP - 725 psi, SIP - 375 psi. 07:00 - 08:00 1.00 BOPSU P RUNPRD Change out upper rams from 7" to VBR's. 08:00 - 10:00 2.00 BOPSU P RUNPRD Rig up and test upper rams with 3.5" and 4" test joints. Tested to 250 psi low, 4,000 psi high for 5 minutes each test. Test witnessed by BP WSL T. Anglen and NAD TP M. Ashley. Blow down, and rig down BOP test equipment. 10:00 - 10:30 0.50 BOPSU P RUNPRD Install wear bushing. 10:30 - 11:30 1.00 PERFO P OTHCMP Rig up pert gun handling equipment. 11:30 - 14:30 3.00 PERFO P OTHCMP Pick up and make up DPC pert assembly with magnet on bottom. Make up bumper sub and Impulse MWD. Change out handling equipment. 4.5", 5SPF, 4505PJ guns. 220 ft loaded, 327 ft blank. 14:30 - 17:30 3.00 PERFO P OTHCMP Run in hole with DPC pert assembly from 611' to 4,580'. 17:30 - 18:00 0.50 PERFO P OTHCMP Shallow hole test MWD. 260 gpm, 740 psi. Blow down topdrive. 18:00 - 20:30 2.50 PERFO P OTHCMP Run in hole with DPC pert assembly from 4,580' to top of landing collar plugs at 7,136'. On depth. 20:30 - 23:00 2.50 PERFO P OTHCMP Log from 6,543' to 6,364' (gamma tools depths). Make +2 ft depth correction. Repeat log pass from 6,470' to 6,368'. Postion top shot for top pert at 6,442' and bottom pert at 6,962'. PU - 165k, SO - 80k. 23:00 - 23:30 0.50 PERFO P OTHCMP Initiate gun firing sequence. Fire auns on depth. 1 Nb perfs: 6,442' to 6,468'. OA perfs: 6,620' to 6,674'. Oba perfs: 6,710' to 6,748'. OBb perfs: 6,766' to 6,788'. OBc perfs: 6,836' to 6,858'. OBd perfs: 6,904' to 6,962'. Monitor well -falling very slowly. *Hole initial) took 10 bbls of 9.0 ppg brine. 23:30 - 00:00 0.50 PERFO P OTHCMP POH from 6,970' to 6,296'. PU 165k. Lost 11 bbls of 9.0 ppg brine to perfs. 4/21/2008 00:00 - 01:00 1.00 PERFO P OTHCMP Circulate 2 bottoms up. 306 gpm, 1,140 psi. Dynamic loss rate = 20 bph. Monitor well -falling very slowly. MW - 9.0 ppg in and out. 01:00 - 01:30 0.50 PERFO P OTHCMP POH, laying down drill pipe from 6,296' to 5,420'. Printed: 5/19/2008 11:26:43 AM BP EXPLORATION Operations Summary Report Page8of9j Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABORS 9ES Rig Number: I ' Date From - To Task ~I Hours Code NPT Phase Description of Operations 4/21/2008 01:00 - 01:30 0.50 PERFO P OTHCMP 2 bph loss rate. 01:30 - 02:00 0.50 PERFO P OTHCMP Service topdrive, drawworks, crown and blocks. 02:00 - 03:30 1.50 PERFO N RREP OTHCMP Repair hydraulic hose fitting on iron roughneck. 03:30 - 07:30 4.00 PERFO P OTHCMP Continue POH, laying down drill pipe from 5,425' to 610'. 07:30 - 12:00 4.50 PERFO P OTHCMP Laydown MWD and bumper sub. Laydown pert guns. Ton 3 12:00 - 13:00 1.00 PERFO P OTHCMP Rig down pert running equipment. Clear and clean rig floor. 13:00 - 15:30 2.50 PERFO P OTHCMP Run in hole with 17 stands of excess drill pipe. POH, laying down 51 joints of drill pipe. 15:30 - 18:00 2.50 EVAL P OTHCMP PJSM. Rig up SLB E-line equipment. 18:00 - 20:00 2.00 EVAL P OTHCMP W nrn #~;_-.Run in hole with 5.91" aauae rina and funk basket to 7,123'. POH and empty junk basket. Recovered appx 1 Vis cup full of pert debris. 20:00 - 22:00 2.00 EVAL P OTHCMP WL run #2: Chance out oaua .rina to 6 1 ~~" Run in hol to_ 22:00 - 00:00 I 2.001 EVAL I P 4/22/2008 00:00 - 00:30 0.50 EVAL P 00:30 - 03:00 2.50 EVAL P 03:00 - 05:30 2.50 EVAL P 05:30 - 06:30 1.00 EVAL P 06:30 - 11:00 4.50 EVAL P 11:00 - 11:30 I 0.50 I EVAL I P 11:30 - 12:00 I 0.50 12:00 - 12:30 I 0.50 12:30 - 16:30 4.00 16:30 - 18:00 1.50 18:00 - 00:00 I 6.00 debris. OTHCMP WL run #3: Change out gauge ring to 6.05". Run in hole td 7,123'. Tool took some weight ~ 6.628' but able to work hv_ POH. 'Lost 100 bbls of 9.2 ppg brine for the dav. Lost rate at end of day - 1 bph. OTHCMP Continue WL run #3 with 6.05" gauge ring and junk basket. POH and empty junk basket. Recovered 5 gallons of pert OTHCMP WL run #4: Run back in hole with 6.05" au a rin and 'unk basket to 7 127'. POH and empty junk basket. Recovered 1 OTHCMP 5: Chan a out gauge ring to 6.125" and run in hole to 7,129'. POH and empty junk basket. Recovered 1/4 cup of pert debris. OTHCMP Rig up USIT logging tools. OTHCMP Run in hole with USIT logging tools to 7,100'. Log Hi-Res pass from 7,100' and to 5,989' md. Log standard resolution pass from 7,100' to surface for primary depth control. Logs indicated top of cement stringers @ 3,830', with competent cement top ~ 4,060'. (Note: 9-5/8" casing shoe depth C~3 3,804'). Perfs on Depth. OTHCMP Rig down Schlumberger E-Line unit. Clean and Clear floor and remove wear bushing. RUNCMP Rig up to run tubing. -Make up landing jt. to hanger. RUNCMP Make dummy run with landing jt. -Remove and lay down hanger and landing jt. -Fill stack and secure cellar RUNCMP Pick up tools and rig up to run 3 1/2" completion assembly RUNCMP PJSM with WSL, NAD Toolpusher, HES, Schlumberger, NAD Casing, and all rig hands -Pick up 3 1/2" completion assembly to 99'. -Bakerlok every jt. below first packer. -Torque turn all jts to 2300 ft/Ibs. RUNCMP PJSM. Run in hole with completion jewelry to 432'. Test line connections to 5,000 psi - OK. Test I-wire continuity - OK. Printed: 5/19/2008 11:26:43 AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: L-220 Common Well Name: L-220 Spud Date: 4/11/2008 Event Name: DRILL+COMPLETE Start: 4/10/2008 End: 4/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/25/2008 Rig Name: NABOBS 9ES Rig Number: ' From - To Hours ' Task Code NPT Phase Description of Operations Date 4/23/2008 00:00 - 12:00 12.00 BUNCO RUNCMP Continue RIH w/jewelry from 432' to 3965' -Torque all connections to 2300 ft/Ibs. -Test all I-wire. Good test -Dope all connections with Jet Lube Seal Guard. -Up Wt. 58k Down Wt. 48k 12:00 - 18:30 6.50 BUNCO RUNCMP RIH on joints of 3.5" 9.2# TC-II tubing from 3965' to 6974' -Torque all connections to 2300 fUlbs. -Test all I-wire. Good test -Dope all connections with Jet Lube Seal Guard. -Up Wt. 94k Down Wt. 59k -Total Jewelery in Hole -10 GLM's and 5 Packers -200 Jts. of 3.5" 9.2# TC-I I -7 X nipples and 1 XN nipple -5 NDPG's -Total of 111 Full Clamps and 28 Half Clamps run in completion 18:30 - 00:00 5.50 BUNCO RUNCMP PJSM, Rig up Schlumberger Wireline to run correlation log. -Log tubing to verify location of GLM's and Packer's -Correlate Depth, no correct needed -Rig Down Schlumberger Wireline 4/24/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Continue to terminate I-wires, run in hole and land tubing hanger. Run in lock down screws and torque to 450 ft/Ibs. 02:00 - 02:30 0.50 BUNCO RUNCMP Clean and Clear Floor and prepare to set packers 02:30 - 04:30 2.00 BUNCO RUNCMP Drop 1 5/16" ball & rod with rollers. Pressure to 4000 psi to set packers. Test tubing to 4000 psi f/30 min. Bleed tubin down to 2,500 si an pressure up annu us to ,000 psi. est annulus to 4000 si for 30 min. Bleed annular pressure own to zero, bleed tubing pressure down to zero, pressure up annulus to 2,250 psi and shear DCR valve. Pump 2 bbls both ways to confirm ability to pump. 04:30 - 06:00 1.50 BOPSU P RUNCMP Drain stack and drv rod install two way check w/ T-Bar. Test to 1,000 psi from below and chart for 10 minutes. 06:00 - 11:00 5.00 BOPSU P RUNCMP Nipple Down BOP. 11:00 - 15:00 4.00 WHSUR P RUNCMP PJSM. Nipple up tree adapter. Terminate I-wires on tree adapter. Test connections to 5,000 psi - OK. Test I-wire continuity - OK. Test adapter to 5,000 psi - OK. 15:00 - 17:00 2.00 WHSUR P RUNCMP Nipple up double master valve dry hole tree. 17:00 - 18:30 1.50 WHSUR N WAIT RUNCMP Waiting on DSM for TWC Removal 18:30 - 20:00 1.50 WHSUR P RUNCMP PJSM. Rig Up lubricator and test to 500 psi. Good Test. Pull TWC and ng own u nca or. 20:00 - 21:00 1.00 WHSUR P RUNCMP ig up secondary kill line to reverse circulate 21:00 - 00:00 3.00 WHSUR P RUNCMP Displace well with 126 bbls of 9 ppg brine, 80 bbls of 9ppg corrosion inhibited brine ~ 3 bpm ~ 310 psi. Rig up Little Red to freeze protect with 100 bbls of 60 deg. Diesel. 4/25/2008 00:00 - 04:00 4.00 WHSUR P RUNCMP U-tube diesel back to tubing. 04:00 - 05:00 1.00 WHSUR P RUNCMP Ri u DSM lubricator. Install BPV. Te below - OK. 05:00 - 06:00 1.00 WHSUR P RUNCMP Rig up to install VR plugs in IA. Secure tree and cellar. Release rig at 0600 Printed: 5/19/2008 11:26:43 AM BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: L-220 Common Name: L-220 Test Date Test Type 4/17/2008 ~ LOT -- - - -- Test Depth (TMD) ~ Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) 3,803.5 (ft) 2,748.0 (ft) 8.80 (ppg) 445 (psi) 1,701 (psi) EMW 11.92(PPg) Printed: 5/19/2008 11:26:35 AM by ~~ -~ ~4 _~. ~~n~~ L-220 Survev Report Schlumherger Report Date: April 18, 2008 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 166.660° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 tt, E 0.000 tt Structure /Slot: L-PAD / S-I TVD Reference Datum: Rotary Table Well: L-220 TVD Reference Elevation: 78.60 ft relative to MSL Borehole: L-220 Sea Bed /Ground Level Elevation: 48.10 ft relative to MSL UWVAPI#: 500292338700 Magnetic Dedination: 22.991 ° Survey Name /Date: L-220 /April 14, 2008 Total Field Strength: 57647.354 nT Tort /AHD / DDI / ERD ratio: 121.367° / 4826.13 ft / 5.945 / 1.004 Magnetic Dip: 80.883° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 14, 2008 Location LaVLong: N 70.35011144, W 149.32484344 Magnetic Declination Model: BGGM 2007 Location Grid NIE Y/X: N 5978089.960 ftUS, E 583159.380 ttUS North Reference: True North Grid Convergence Angle: +0.63584216° Total Corr Mag North -> True North: +22.991 ° Grid Scale Fodor: 0.99990786 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft tt ft ft ft ft de OOtt ftUS ftUS Fi I t U. UU U.UU U .UU -RS.tiU U.UU U.UU U. UU U. UU U.UU O.UU U.UU 59/8089.96 583159.38 N 70.35011144 W 149. 32484344 GYD CT DMS 100. 00 0.27 211 .86 21.40 100.00 0.17 0. 24 0. 24 -0. 20 -0.12 0.27 5978089.76 583159 .26 N 70.35011090 W 149. 32484445 200. 00 0.47 187 .27 121.40 200.00 0.72 0. 87 0. 86 -0. 81 -0.30 0.25 5978089.15 583159 .09 N 70.35010924 W 149. 32484588 300. 00 0.47 192 .15 221.39 299.99 1.47 1. 69 1. 67 -1. 61 -0.44 0.04 5978088.34 583158 .96 N 70.35010703 W 149. 32484700 400. 00 1.02 152 .32 321.39 399.99 2.70 2. 95 2. 81 -2. 80 -0.11 0.72 5978087.16 583159 .30 N 70.35010378 W 149. 32484435 500 .00 3.40 155 .30 421.30 499.90 6.47 6. 80 6. 47 -6. 29 1.54 2.38 5978083.69 583160 .99 N 70.35009427 W 149. 32483093 600 .00 6.68 156 .85 520.90 599.50 15.11 15. 59 15. 20 -14. 33 5.07 3.28 5978075.69 583164 .61 N 70.35007229 W 149. 32480230 700 .00 9.46 163 .02 619.91 698.51 29.05 29. 61 29. 22 -27. 54 9.76 2.91 5978062.53 583169 .44 N 70.35003620 W 149. 32476425 800 .00 11.57 168 .37 718.22 796.82 47.28 47. 84 47. 40 -45. 23 14.18 2.32 5978044.90 583174 .06 N 70.34998789 W 149. 32472835 900 .00 13.94 168 .49 815.75 894.35 69.34 69. 92 69. 39 -66. 85 18.60 2.37 5978023.32 583178 .72 N 70.34992880 W 149. 32469242 1000 .00 16.97 171 .00 912.12 990.72 95.94 96. 56 95. 95 -93. 08 23.29 3.10 5977997.16 583183 .70 N 70.34985716 W 149. 32465 MWD+IFR+MS 1041 .65 17.67 169 .66 951.88 1030.48 108.31 108. 96 108. 31 -105. 30 25.38 1.93 5977984.96 583185 .92 N 70.34982377 W 149. 32463 1136 .33 20.02 167 .22 1041.48 1120.08 138.87 139. 54 138. 87 -135. 25 31.54 2.62 5977955.09 583192 .42 N 70.34974196 W 149. 32458 1232 .78 23.18 165 .35 1131.15 1209.75 174.37 175. 04 174. 37 -169 .72 40.00 3.35 5977920.71 583201 .25 N 70.34964778 W 149. 32451876 1327 .98 24.45 165 .03 1218.24 1296.84 212.80 213. 48 212. 80 -206 .88 49.82 1.34 5977883.66 583211 .49 N 70.34954626 W 149. 32443898 1424 .70 28.10 166 .63 1304.96 1383.56 255.60 256. 28 255. 60 -248 .39 60.27 3.84 5977842.27 583222 .39 N 70.34943285 W 149. 32435422 1520 .36 31.61 161 .91 1387.92 1466.52 303.13 303. 87 303. 15 -294 .16 73.27 4.41 5977796.66 583235 .90 N 70.34930781 W 149. 32424870 1614 .82 34.28 159 .33 1467.19 1545.79 354.20 355. 23 354. 31 -342 .60 90.35 3.19 5977748.42 583253 .51 N 70.34917550 W 149. 32411006 1710 .18 35.76 160 .51 1545.28 1623.88 408.54 409. 95 408 .82 -393 .99 109.12 1.71 5977697.24 583272 .86 N 70.34903509 W 149. 32395764 1803 .82 34.88 162 .33 1621.69 1700.29 462.44 464. 09 462. 89 -445 .30 126.38 1.46 5977646.13 583290 .68 N 70.34889492 W 149. 32381756 1899 .41 38.12 162 .96 1698.52 1777.12 519.16 520. 94 519. 72 -499 .57 143.33 3.41 5977592.06 583308 .23 N 70.34874667 W 149. 32368001 1993 .58 43.45 162 .99 1769.79 1848.39 580.52 582. 43 581. 20 -558 .36 161.33 5.66 5977533.47 583326 .88 N 70.34858604 W 149. 32353388 2086 .83 43.18 163 .43 1837.64 1916.24 644.37 646. 40 645 .17 -619 .61 179.81 0.43 5977472.45 583346 .04 N 70.34841873 W 149. 32338389 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-I\L-220\L-220\L-220 Generated 5/19/2008 9:56 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft tt ft it ft ft ft de 100 ft ftUS ftUS 11ti1./U 4/.ZU lfi4. L/ lyUb.ly lytS:i./y /11.Ly /14. 4U /1J.1/ -titi4. y:i lyt5. /1 4.'L4 5y//4U/.:ib b23:i:itib.bli N /U.J4t3'14UL25 W 14y. :iL:iL:fUbl 2279.04 50.18 164. 60 1968. 78 2047.38 784.60 786. 76 785.52 -754. 63 218. 12 3.10 5977337. 87 583385. 84 N 70.34804985 W 149. 32307297 2374.79 54.91 165. 68 2027. 00 2105.60 860.56 862. 75 861.49 -828. 08 237. 58 5.02 5977264. 64 583406. 12 N 70.34784919 W 149. 32291498 2468.84 60.75 165. 72 2077. 05 2155.65 940.12 942. 32 941.03 -905. 19 257. 24 6.21 5977187. 76 583426. 62 N 70.34763853 W 149. 32275547 2562.99 63.72 164. 91 2120. 91 2199.51 1023.40 1025. 62 1024.32 -985. 77 278. 36 3.25 5977107. 43 583448. 64 N 70.34741840 W 149. 32258403 2657.24 64.45 164. 51 2162. 10 2240.70 1108.12 1110. 39 1109.09 -1067. 54 300. 72 0.86 5977025. 92 583471. 90 N 70.34719500 W 149. 32240260 2752.96 64.10 164. 17 2203. 64 2282.24 1194.28 1196. 63 1195.32 -1150. 57 323. 99 0.49 5976943. 16 583496. 09 N 70.34696817 W 149. 32221370 2847.80 64.10 164. 15 2245. 07 2323.67 1279.52 1281. 94 1280.63 -1232. 65 347. 28 0.02 5976861. 36 583520. 28 N 70.34674394 W 149. 32202473 2943.31 63.99 164. 00 2286. 87 2365.47 1365.30 1367. 82 1366.51 -1315 .23 370. 84 0.18 5976779. 05 583544. 76 N 70.34651834 W 149. 32183351 3039.24 63.44 164. 01 2329. 35 2407.95 1451.22 1453. 83 1452.52 -1397 .91 394. 54 0.57 5976696. 65 583569. 37 N 70.34629246 W 149. 32164118 3134.97 63.71 162. 97 2371. 96 2450.56 1536.82 1539. 56 1538.24 -1480 .10 418. 91 1.01 5976614. 74 583594. 65 N 70.34606791 W 149. 32144348 3228.74 63.53 164. 45 2413. 62 2492.22 1620.71 1623 .56 1622.24 -1560 .73 442. 47 1.43 5976534. 38 583619. 10 N 70.34584764 W 149. 32125 3322.76 63.77 163. 93 2455. 35 2533.95 1704.88 1707 .81 1706.49 -1641 .79 465. 42 0.56 5976453 .59 583642. 95 N 70.34562618 W 149. 32106602 3418.94 64.14 164. 24 2497. 58 2576.18 1791.21 1794 .22 1792.90 -1724 .89 489. 12 0.48 5976370 .76 583667. 56 N 70.34539915 W 149. 32087375 3513.99 63.77 164. 32 2539. 32 2617.92 1876.53 1879 .62 1878.30 -1807 .10 512. 26 0.40 5976288 .83 583691. 61 N 70.34517457 W 149. 32068601 3609.21 62.88 164. 82 2582. 07 2660.67 1961.56 1964 .71 1963.38 -1889 .11 534. 90 1.05 5976207 .08 583715. 15 N 70.34495050 W 149. 32050232 3704.03 63.26 164. 77 2625. 01 2703.61 2046.05 2049 .24 2047.91 -1970 .69 557. 07 0.40 5976125 .76 583738. 23 N 70.34472764 W 149. 32032243 3745.81 63.46 165. 09 2643. 74 2722.34 2083.38 2086 .59 2085.26 -2006 .75 566. 78 0.84 5976089 .81 583748. 34 N 70.34462912 W 149. 32024365 3819.63 62.35 163. 75 2677. 37 2755.97 2149.04 2152 .31 2150.97 -2070 .05 584. 42 2.21 5976026 .71 583766. 68 N 70.34445618 W 149. 32010048 3914.13 60.55 165. 16 2722. 53 2801.13 2231.98 2235 .31 2233.97 -2150 .02 606. 68 2.31 5975947 .01 583789. 82 N 70.34423772 W 149. 31991994 4009.07 59.10 165. 30 2770. 25 2848.85 2314.03 2317 .38 2316.03 -2229 .38 627. 60 1.53 5975867 .89 583811. 62 N 70.34402091 W 149. 31975018 4105.55 60.85 165. 51 2818. 52 2897.12 2397.54 2400 .91 2399.55 -2310 .21 648. 65 1.82 5975787 .30 583833. 56 N 70.34380007 W 149. 31957943 4200.74 60.78 164. 51 2864. 94 2943.54 2480.61 2484 .02 2482.65 -2390 .49 670. 14 0.92 5975707 .28 583855. 94 N 70.34358076 W 149. 31940505 4297.26 61.60 164. 80 2911. 46 2990.06 2565.13 2568 .59 2567.22 -2472 .05 692. 52 0.89 5975625 .98 583879. 22 N 70.34335795 W 149. 31922350 4391.76 63.41 164. 75 2955. 08 3033.68 2648.91 2652 .41 2651.04 -2552 .93 714. 54 1.92 5975545 .36 583902. 13 N 70.34313698 W 149. 31904492 4487.01 62.54 165. 15 2998. 36 3076.96 2733.72 2737 .26 2735.88 -2634 .87 736. 57 0.99 5975463 .68 583925. 07 N 70.34291313 W 149 .31886618 4581.42 63.25 164. 25 3041. 38 3119.98 2817.71 2821 .30 2819.92 -2715 .93 758. 75 1.13 5975382 .88 583948. 14 N 70.34269168 W 149 .31868628 4677.00 63.11 164. 35 3084. 50 3163.10 2902.94 2906 .60 2905.22 -2798 .04 781. 83 0.17 5975301 .03 583972. 13 N 70.34246734 W 149 .31849904 4771.35 63.06 163. 91 3127. 21 3205.81 2986.98 2990 .73 2989.35 -2878 .96 804. 83 0.42 5975220 .37 583996. 03 N 70.34224626 W 149 .318 4864.54 62.31 164. 55 3169. 97 3248.57 3069.71 3073 .53 3072.14 -2958 .65 827. 34 1.01 5975140 .96 584019. 42 N 70.34202857 W 149 3 .3181 4960.60 62.07 164. 49 3214. 79 3293.39 3154.61 3158 .49 3157.11 -3040 .53 850. 01 0.26 5975059 .34 584043. 00 N 70.34180486 W 149 .31794594 5056.40 61.87 164. 08 3259. 81 3338.41 3239.10 3243 .06 3241.67 -3121 .93 872. 92 0.43 5974978 .20 584066. 80 N 70.34158248 W 149 .31776016 5152.22 61.14 165. 48 3305 .53 3384.13 3323.27 3327 .27 3325.88 -3203 .18 895. 03 1.49 5974897 .21 584089. 81 N 70.34136049 W 149 .31758083 5245.32 60.76 165. 26 3350 .73 3429.33 3404.63 3408 .65 3407.25 -3281 .93 915. 58 0.46 5974818 .70 584111. 24 N 70.34114535 W 149 .31741410 5339.65 59.74 165. 57 3397 .54 3476.14 3486.51 3490 .55 3489.14 -3361 .19 936. 21 1.12 5974739 .68 584132. 74 N 70.34092882 W 149 .31724683 5434.20 58.51 165. 39 3446 .06 3524.66 3567.64 3571 .70 3570.27 -3439 .75 956. 55 1.31 5974661 .36 584153. 95 N 70.34071420 W 149 .31708183 5528.04 55.65 167. 59 3497 .06 3575.66 3646.40 3650 .46 3648.98 -3516 .32 974. 98 3.63 5974585 .01 584173. 22 N 70.34050501 W 149 .31693243 5623.74 52.08 169. 65 3553 .49 3632.09 3723.62 3727 .74 3726.06 -3592 .06 990. 25 4.12 5974509 .44 584189. 34 N 70.34029807 W 149 .31680855 5719.47 50.66 170. 57 3613 .25 3691.85 3798.27 3802 .52 3800.50 -3665 .73 1003. 10 1.66 5974435 .93 584203. 00 N 70.34009681 W 149 .31670436 5815.14 49.89 169. 77 3674 .39 3752.99 3871.71 3876 .10 3873.75 -3738 .23 1015. 66 1.03 5974363 .58 584216 .37 N 70.33989874 W 149 .31660254 5910.75 47.74 171. 78 3737 .35 3815.95 3943.47 3948 .05 3945.31 -3809 .24 1027. 22 2.75 5974292 .71 584228 .71 N 70.33970475 W 149 .31650887 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-I\L-220\L-220\L-220 Generated 5/19/2008 9:56 AM Page 2 of 3 Comments Measured Inclination Azimuth SulSSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft tt de 100 ft ftUS ftUS 6UU4./~J 45.2/ 1/x.425 3tfUL.U/ J2323V.b/ 4U71.31 4U7b.Zb 4UlZ.`JZ -325/b.i5`J IVSb.`J`J Z.~4 by/4LGb. l/ 6100.17 44.72 174.91 3869.52 3948.12 4078.16 4083.69 4079.51 -3943.97 1042.81 1.21 5974158. 17 6196.41 44.85 174.87 3937.83 4016.43 4145.26 4151.49 4146.35 -4011.50 1048.85 0.14 5974090. 72 6291.99 43.49 176.03 4006.39 4084.99 4211.08 4218.09 4211.93 -4077.89 1054.14 1.66 5974024. 41 6387.08 42.68 176.76 4075.84 4154.44 4275.09 4283.04 4275.73 -4142.71 1058.23 1.00 5973959. 64 6481.94 41.60 176.83 4146.17 4224.77 4337.75 4346.68 4338.20 -4206.25 1061.79 1.14 5973896. 14 6577.49 41.00 177.11 4217.96 4296.56 4399.79 4409.75 4400.09 -4269.23 1065.12 0.66 5973833. 21 6672.39 41.17 177.95 4289.49 4368.09 4461.04 4472.11 4461.21 -4331.54 1067.81 0.61 5973770. 95 6768.05 40.47 177.62 4361.88 4440.48 4522.39 4534.64 4522.48 -4394.02 1070.22 0.77 5973708. 50 6863.57 39.53 177.41 4435.05 4513.65 4582.69 4596.04 4582.72 -4455.36 1072.88 0.99 5973647. 20 6959.08 39.00 177.47 4509.00 4587.60 4642.07 4656.49 4642.08 -4515.75 1075.58 0.56 5973586. 85 7053.40 38.36 178.82 4582.63 4661.23 4699.84 4715.44 4699.84 -4574.66 1077.50 1.12 5973527. 97 7148.81 37.34 178.23 4657.97 4736.57 ~ 4757.13 4773.98 4757.17 -4633.18 1079.00 1.13 5973469. 47 Final Survey 7170.08 37.22 178.30 4674.89 4753.49 4769.75 4786.86 4769.80 -4646.06 1079.39 0.60 5973456. 60 TD (Projected) 7235.00 37.22 178.30 4726.59 4805.19 4808.21 4826.13 4808.30 -4685.31 1080.56 0.00 5973417. 37 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in dril l-pipe.) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Ass umes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) f ftUSl Easting (X) fftUSl Surface : 2368 FSL 375 7 FEL S34 T12N Ri 1 E UM 5978089.96 583159.38 BHL : 2963 FSL 268 6 FEL S3 T11 N R11 E UM 5973417.37 584291.76 JZ54L36.LG IV /U.33yb I yyJ VV 14y.J 1043/ /~ 584245.79 N 70.33933667 W 149.31638249 584252.58 N 70.33915219 W 149.31633357 584258.61 N 70.33897083 W 149.31629072 584263.41 N 70.33879373 W 149.31625763 584267.68 N 70.33862013 W 149.31622883 584271.71 N 70.33844809 W 149.31620185 584275.09 N 70.33827787 W 149.31618012 584278.19 N 70.33810717 W 149.31616060 584281.54 N 70.33793959 W 149.31613908 584284.91 N 70.33777461 W 149.31611724 584287.47 N 70.33761367 W 149.3161 t~ 584289.62 N 70.33745379 W 149.31608966 584290.16 N 70.33741861 W 149.31608651 584291.76 N 70.33731138 W 149.31607711 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-I\L-220\L-220\L-220 Generated 5/19/2008 9:56 AM Page 3 of 3 • 713!461-3146 Fax: 7t3/461-0920 May 2, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: L-Pad, Wel! #L-22Q Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Shoup North American Regional Manager RS:kI Serving the VJorldUride Energy Industry with Preci~~or~ S' ~~ ~t l~~t~ ~ .~.; iior gyro data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston. Texas 77043 713/461-3146 Fax 713/461-0920 SURVEY REPORT BP L-Pad #L-220 Prudhoe Bay, AK ~AK0408G 118 12 April 2008 Serving the ~^Jnrld~rviue Energy hidu~'tr~,~ with Rrec~si~r Sur~~.~e~d !nszrur;ie^a~iic;n ~p~-U~17 A Gyrodata Directional Survey for B.P. EXPLORATION Lease: L- PAD Well: L-220, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK0408G 118 Run Date: 12 Apr 2008 Surveyor: Henry Drew Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350111 deg. N Longitude: 149.324843 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Lease: L- PAD Well: L-220, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK0408G 118 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG VERTICAL CLOSURE HORIZONTAL SEVERITY DEPTH DIST. AZIMUTH COORDINATES deg./ feet feet deg. feet 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E 0 - 1000 FT. RATE GYROSCOPIC MULTISHOT RUN INSIDE 4" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9-ES ROTARY TABLE CELLAR BOX ELEV. = 48.10 FT. REL TO MSL, ROTARY TABLE ELEV = 78.60 FT. REL TO MSL,RIG HEIGHT= 30.50 FT. - ------------------------------------------------------------------------------------------------------------------------------------ 100.00 0.27 211.86 S 31 52 W 0.27 100.00 0.2 211.9 0.20 S 0.12W 200.00 0.47 187.27 S 7 16 W 0.26 200.00 0.9 200.3 0.81 S 0.30W 300.00 0.47 192.15 S 12 9 W 0.04 299.99 1.7 195.1 1.62 S 0.44W 400.00 1.02 152.32 S 27 41 E 0.73 399.99 2.8 182.2 2.81 S 0.11 W 500.00 3.40 155.30 S 24 42 E 2.37 499.90 6.5 166.2 6.29 S 1.54 E 600.00 6.68 156.85 S 23 9 E 3.28 599.50 15.2 160.5 14.33 S 5.07 E 700.00 9.46 163.02 S 16 59 E 2.91 698.51 29.2 160.5 27.54 S 9.76 E 800.00 11.57 168.37 S 11 38 E 2.32 796.82 47.4 162.6 45.23 S 14.18 E 900.00 13.94 168.49 S 11 31 E 2.37 894.35 69.4 164.4 66.85 S 18.60 E 1000.00 16.97 171.00 S 9 0 E 3.10 990.72 95.9 165.9. 93.07 S 23.29 E Final Station Closure: Distance: 95.94 ft Az: 165.95 deg. A Gyrodata Directional Survey • 2 B.P. Exploration Well: L- PAD L-220 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 0- -1C -20 -30 -40 w z -50 O z -60 -~o -so -90 - I - -~---------------- --- - ----- --- I--- ----------------------------- - ----- ------ ---------- ------------------------ --- --- ---- - ----- ----------- ------ ---I ,, -- --- - - __ --- -_ _---- --- __ -- - --- ---- - _------ _ -- - __ .. -- I -------- --------- -------- I -- --- --- __ _____- ~ i i -----~- ----------------- ----------- ------------ ~- --------- ---------- - _ B ---- --- - --- ------- --- - TTO M H OL L CAT E D M :1000.00 0 5 10 y ~ -,'~ Inrun Gyrodata AK0408G 118 DEFINITIVE r~ LJ -- ~~ FASTING (ft) B. P. Exploration -Well: L- PAD L-220 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 10 9 8 7 w 0 0 ~ 6 rn v v ... ~ 5 w w ~ 4 C7 O 3 2 1 0- Inrun Gyrodata ' o-~ndnQ~ 1 1 Q ~1CCTMTTT\/C ~ ~ - - - - ---- --------- i - ~ I ~' i ~ i i ' ~ I ' , ~ ~ ~ ~ ~ ~ ~ -- ~ _-.__._ . _---_-_ _ j _-__- _____-- _ I Y .__---- i -- -- ~ - ---__ ~ __------ I -- -- - ~ -- -- - ----- -- ~ .---- -- ----- -- ~ I i i j ~ ~ i ---- I ~ ----- - ----- ------------- --- .-- - t _ ------- -- - _ ---- - I------------- - ---- ----- _ ~ _----_-- ------- - ---- -- - ~ ~ --- --- -- - ------- ------- ------- --------- ---------- I -___..__-- -_.-.. ~ i -------- ------------- t---------- --__-- - _ I _- - -1 ---- - ~ ~ -~ - -____ - ---..._ - ------... ~ - - _ __ _. 1 --------- - --BDTTO-Nf ~f IOtE _ i ; LOCATE I MD: 100 .00 - - - -- _ --- - ~ __-_ - - i _ I _______ -- -- ~ i __ - -- --- i -. ------ -- -- f ---- ---_-- i --__.._ - ~ ___ __ -' _ _ ---- ~ ~ ~ - --- ' ~ i I - _- ---- I _.._ ___.-__-_,I _.___ ----- I ~ ----- --- --- '- - -- ---_ i I _ • • 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) B.P. Exploration Well: L- PAD L-220 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 66 64 62 60 a~ 58 ~- a 56 w F- 54 52 50 48 Inrun Gyrodata Ol!(1df1S2r y ~ Q IICCTI\ITTT\/G ---- -------- -------- - , --------- ~ ~----- BOTTOM --L6C~TE D MD: 100 HOLE ~ _ -__ .00 ' - -- - -- ~ ' - --- --- - -- - - ~ ~- - ~ - -- f ---- - ---- r - ---- -- - -- i _. ~ .____ _ _ __ _--- ~---- ---- ~ ---~-- ----- ~ .__. -- - -- --. __ ___ -- ~ ~ -- ~ } -- _- -__ _ ~ ---_ --- _ _ ~ ~- .._-- - -_. __ ~ ~ - _ _ _ _ ___ _ I _-- -_ _ ___ I _ . - -- I a ---- _ __--- -- - - __--- --------- , ----- _ -_._ ---- - - _-- I ~---- --__- i ------------ { ___ __ _-_._. _-_ ____ .~ __.. _____ .. _--- ----- I .--- -_ _----_ ~ t ----- ~----- r------------~ --------- -- --- --- -- -------- --- ------ ---- - ..._ __--- i ~ _. -------- --- -- ----- - _- ~ _-- -- - i ----- --- I l I -- - -- - ----- -~ ------ ~ - -- - ~-- -- _ i ~ i ~ ---- --- ---~ ----------~ i -----------r I ---- ~ i -------_-- -------- -_ I --i ----_---~ ------- ----- ~ -__. -------- ------ - ----~ ---- ---- --- _ -- -- ~ ---- - I i i I ~ ~ I ~ ~ i -+ - ~ ------------ ~ ~ -------- ------- ~ ~ I ~ I i 100 200 300 400 500 600 700 $00 900 1000 1100 MEASURED DEPTH (ft) `B.P. Exploration Well: L- PAD L-220 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 1.6 14 12 X10 Q z` J V ,8 Z ~..~ 6 4 2 0- Inrun Gyrodata ' nKn4nRr 1 1 R r1FFTNTTT\/G - ---- 1--------- ---------- ~ ~ ~ ' i ~ - - BOTTOM LOCATED --~-;--ram- ~ OLE ~-._. -- - -- i ~ I - ~ ~ ~ I ~ _--- ~ _-._ - --- -- ~ _--- --- --- - -- I , ___._ ---__ ------ __ L_ ----- __-- L I ---__. - ~ I ( ~ I i ~ ~ i I - I ~ ~ ~ - __ _ ----- - i i ~ ~ -I ~ --------- ---- ------- -t ~ - ~ ---------- -- ---- ~ i i I ---------- ' i ~ --------- - -- --- I ~ i - 1 ----- --- ~ ----- I~ J 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) B.P. Exploration - Well: L- PAD L-220 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 211 20! 20( 19~ 19( 4=- 18~ ~ ` Q 18C 17~ 17C 165 160 155 150 Inrun Gyrodata AK0408G 1 1 R r)FFTNTTT\/F - _- i - I ~ j ~ ' ~ ~ I - - _ _ I I -- - _ I i I -- -- - -- -- - I I - ---- --_ -- --- _ ------ I -._ ---- j --- --------- -- I - ---- - - -- ------- ~ --__- ----- ~ -- - -- ---- -- _ -- ~ _ _ - _ I ----- - - -- f i ~- --- -------- -- -------- ~ -~ ------ -- ~ ~ I ------ i 1 - .. --- --- - - t----------- --- --- -- I -- _ - __ _ _ -- ~ _------- --- - - ' _-- - -- ----- t _ _ _ -- - -- I -- --- -- -- - -- --------- I i - - . _ _ --- _ ~ - ____ - -- --- - -------- -- - ---------- - ----------- ---- --j -- --- ---- - I I ------ } ------I - I --- --------t ~ -------- ~ -- - -- --- ~ ~ ~ - --------- --------- ------- - --- - - i - I -----------~ - ------ ~ ----_ ---- --- I -___ - -} I - __---- ~ _-- -- ~ __------ ----- BOTTOM M --LOeAT-ED ~ OLE __ _ - i I ~ i ~ MD: 1000 00 ---- ~ - - -- --- - ---- _ + ----- _..------ --- t ___ __ ~ ~ ---- -. ~ _._- ~ _ _. - ~ ~ i I r i ~ --- ----- ---- _- ~ - ------- - --- - II t ~ ~ II ----- --------t ~ --_ ~ I -_.- ___. ---- _ r ~ --__._. ___ -- -7 -- ---- -- -- t ------ ---- - --- i -------I I ~ -- --i i ---------- ~ ~ ---- --- -- ~ -----------I ~ ------- -- - ~ ~ --- - ------- ------ ______~ I -- --j- ----- - ---_ _ _--- - ~ ~ ~ -t-=-~--~- - _ _ 10 0 20 0 30 0 40 0 50 0 60 0 70 0 80 0 90 0 100 0 iln n • MEASURED DEPTH (ft) SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-220 API number ................ 50-029-23387-00 Engineer .................. 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.......: 48.10 ft KB above permanent.......: NA (Topdrive) DF above permanent.......: 78.60 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 Vsect Origin to target: 166.66 degrees 18-Apr-2008 08:33:47 Page 1 of 4 Spud date ................. 11-Apr-08 Last survey date.......... 18-Apr-08 Total accepted surveys...: 79 MD of first survey.......: 0.00 ft MD of last survey........: 7235.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 10-Apr-2008 Magnetic field strength..: 57647.21 GAMA Magnetic dec (+E/W-).....: 23.00 degrees Magnetic dip .............. 80.88 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G ............... H ............... Dip ............. of G............ of H............ of Dip..... ... Criteria --------- 1002.68 meal 57647.00 LAMA 80.8$ degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.00 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.00 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 ~0~-~~7 • e ' SCHLUMBERGER Survey Report 18-Apr-2008 08:33:47 Page 2 of 4 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 0.27 211.86 100.00 100.00 0.17 -0.20 -0.12 0.24 211.86 0.27 BP _GYD CT DMS 3 200.00 0.47 187.27 100.00 200.00 0.72 -0.81 -0.30 0.86 200.43 0.25 BP _GYD CT DMS 4 300.00 0.47 192.15 100.00 299.99 1.47 -1.61 -0.44 1.67 195.20 0.04 BP _GYD CT DMS 5 400.00 1.02 152.32 100.00 399.99 2.70 -2.80 -0.11 2.81 182.28 0.72 BP GYD CT DMS 6 500.00 3.40 155.30 100.00 499.90. 6.47 -6.29 1.54 6.47 166.23 2.38 BP _GYD CT DMS 7 600.00 6.68 156.85 100.00 599.50 15.11 -14.33 5.07 15.20 160.53 3.28 BP _GYD CT DMS 8 700.00 9.46 163.02 100.00 698.51 29.05 -27.54 9.76 29.22 160.50 2.91 BP _GYD CT DMS 9 800.00 11.57 168.37 100.00 796.82 47.28 -45.23 14.18 47.40 162.59 2.32 BP _GYD CT DMS 10 900.00 13.94 168.49 100.00 894.35 69.34 -66.85 18.60 69.39 164.45 2.37 BP GYD CT DMS 11 1000.00 16.97 171.00 100.00 990.72 95.94 -93.08 23.29 95.95 165.95 3.10 BP _GYD CT DMS 12 1041.65 17.67 169.66 41.65 1030.48 108.31 -105.30 25.38 108.31 166.45 1.93 BP _MWD+IFR+MS 13 1136.33 20.02 167.22 94.68 1120.08 138.87 -135.25 31.54 138.87 166.87 2.62 BP _MWD+IFR+MS 14 1232.78 23.18 165.35 96.45 1209.75 174.37 -169.72 40.00 174.37 166.74 3.35 BP _MWD+IFR+MS 15 1327.98 24.45 165.03 95.20 1296.84 212.80 -206.88 49.82 212.80 166.46 1.34 BP MWD+IFR+MS 16 1424.70 28.10 166.63 96.72 1383.56 255.60 -248.39 60.27 255.60 166.36 3.84 BP _MWD+IFR+MS 17 1520.36 31.61 161.91 95.66 1466.52 303.13 -294.16 73.27 303.15 166.01 4.41 BP _MWD+IFR+MS 18 1614.82 34.28 159.33 94.46 1545.79 354.20 -342.60 90.35 354.31 165.23 3.19 BP _MWD+IFR+MS 19 1710.18 35.76 160.51 95.36 1623.88 408.54 -393.99 109.12 408.82 164.52 1.71 BP _MWD+IFR+MS 20 1803.82 34.88 162.33 93.64 1700.29 462.44 -445.30 126.38 462.89 164.16 1.46 BP MWD+IFR+MS 21 1899.41 38.12 162.96 95.59 1777.12 519.16 -499.57 143.33 519.72 163.99 3.41 BP _MWD+IFR+MS 22 1993.58- 43.45 162.99 94.17 1848.39 580.52 -558.36 161.33 581.20 163.88 5.66 BP _MWD+IFR+MS 23 2086.83 43.18 163.43 93.25 1916.24 644.37 -619.61 179.81 645.17 163.82 0.43 BP _MWD+IFR+MS 24 2182.70. 47.20 164.27 95.87 1983.79 712.29 -684.93 198.71 713.17 163.82 4.24 BP MWD+IFR+MS 25 2279.04 50.18 164.60 96.34 2047.38 784.60 -754.63 218.12 785.52 163.88 3.10 BP MWD+IFR+MS 26 2374.79 54.91 165.68 95.75 2105.60 860.56 -828.08 237.58 861.49 163.99 5.02 BP _MWD+IFR+MS 27 2468.84 60.75 165.72 94.05 2155.65 940.12 -905.19 257.24 941.03 164.14 6.21 BP _MWD+IFR+MS 28 2562.99 63.72 164.91 94.15 2199.51 1023.40 -985.77 278.36 1024.32 164.23 3.25 BP MWD+IFR+MS 29 2657.24 64.45 164.51 94.25 2240.70 1108.12 -1067.54 300.72 1109.09 164.27 0.86 BP _MWD+IFR+MS 30 2752.96 64.10 164.17 95.72 2282.24 1194.28 -1150.57 323.99 1195.32 164.27 0.49 BP MWD+IFR+MS r1 U ' SCHLUMBERGER Survey Report 18 -Apr-2008 08:33:47 Page 3 of 4 --- 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 2847.80 64.10 164.15 94.84 2323.67 1279.52 -1232.65 347.28 1280.63 164.27 0.02 BP _MWD+IFR+MS 32 2943.31 63.99 164.00 95.51 2365.47 1365.30 -1315.23 370.84 1366.51 164.25 0.18 BP _MWD+IFR+MS 33 3039.24 63.44 164.01 95.93 2407.95 1451.22 -1397.91 394.54 1452.52 164.24 0.57 BP _MWD+IFR+MS 34 3134.97 63.71 162.97 95.73 2450.56 1536.82 -1480.10 418.91 1538.24 164.20 1.01 BP _MWD+IFR+MS 35 3228.74 63.53 164.45 93.77 2492.22 1620.71 -1560.73 442.47 1622.24 164.17 1.43 BP MWD+IFR+MS 36 3322.76 63.77 163.93 94.02 2533.95 1704.88 -1641.79 465.42 1706.49 164.17 0.56 BP _MWD+IFR+MS 37 3418.94 64.14 164.24 96.18 2576.18 1791.21 -1724.89 489.12 1792.90 164.17 0.48 BP _MWD+IFR+MS • 38 3513.99 63.77 164.32 95.05 2617.92 1876.53 -1807.10 512.26 1878.30 164.17 0.40 BP MWD+IFR+MS 39 3609.21 62.88 164.82 95.22 2660.67 1961.56 -1889.11 534.90 1963.38 164.19 1.05 BP _MWD+IFR+MS 40 3704.03 63.26 164.77 94.82 2703.61 2046.05 -1970.69 557.07 2047.91 164.22 0.40 BP MWD+IFR+MS 41 3745.81 63.46 165.09 41.78 2722.34 2083.38 -2006.75 566.78 2085.26 164.23 0.84 BP _MWD+IFR+MS 42 3819.63 62.35 163.75 73.82 2755.97 2149.04 -2070.05 584.42 2150.97 164.23 2.21 BP _MWD+IFR+MS 43 3914.13 60.55 165.16 94.50 2801.13 2231.98 -2150.02 606.68 2233.97 164.24 2.31 BP _MWD+IFR+MS 44 4009.07 59.10 165.30 94.94 2848.85 2314.03 -2229.38 627.60 2316.03 164.28 1.53 BP _MWD+IFR+MS 45 4105.55 60.85 165.51 96.48 2897.12 2397.54 -2310.21 648.65 2399.55 164.32 1.82 BP MWD+IFR+MS 46 4200.74 60.78 164.51 95.19 2943.54 2480.61 -2390.49 670.14 2482.65 164.34 0.92 BP MWD+IFR+MS 47 4297.26 61.60 164.80 96.52 2990.06 2565.13 -2472.05 692.52 2567.22 164.35 0.89 BP _MWD+IFR+MS 48 4391.76 63.41 164.75 94.50 3033.68 2648.91 -2552.93 714.54 2651.04 164.36 1.92 BP _MWD+IFR+MS 49 4487.01 62.54 165.15 95.25 3076.96 2733.72 -2634.87 736.57 2735.88 164.38 0.99 BP _MWD+IFR+MS 50 4581.42 63.25 164.25 94.41 3119.98 2817.71 -2715.93 758.75 2819.92 164.39 1.13 BP MWD+IFR+MS 51 4677.00 63.11 164.35 95.58 3163.10 2902.94 -2798.04 781.83 2905.22 164.39 0.17 BP _MWD+IFR+MS , 52 4771.35 63.06 163.91 94.35 3205.81 2986.98 -2878.96 804.83 2989.35 164.38 0.42 BP _MWD+IFR+MS 53 4864.54 62.31 164.55 93.19 3248.57 3069.71 -2958.65 827.34 3072.14 164.38 1.01 BP _MWD+IFR+MS 54 4960.60 62.07 164.49 96.06 3293.39 3154.61 -3040.53 850.01 3157.11 164.38 0.26 BP _MWD+IFR+MS 55 5056.40 61.87 164.08 95.80 3338.41 3239.10 -3121.93 872.92 3241.67 164.38 0.43 BP MWD+IFR+MS 56 5152.22 61.14 165.48 95.82 3384.13 3323.27 -3203.18 895.03 3325.88 164.39 1.49 BP _MWD+IFR+MS 57 5245.32 60.76 165.26 93.10 3429.33 3404.63 -3281.93 915.58 3407.25 164.41 0.46 BP _MWD+IFR+MS 58 5339.65 59:74 165.57 94.33 3476.14 3486.51 -3361.19 936.21 3489.14 164.44 1.12 BP MWD+IFR+MS 59 5434.20 58.51 165.39 94.55 3524.66 3567.64 -3439.75 956.55 3570.27 164.46 1.31 BP _MWD+IFR+MS 60 5528.04 55.65 167.59 93.84 3575.66 3646.40 -3516:32 974.98 3648.98 164.50 3.63 BP MWD+IFR+MS SCHLUMBERGER Survey Report 18-Apr-2008 08:33:47 Page 4 of 4 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) 61 5623.74 52.08 169.65 95.70 3632.09 3723.62 -3592.06 990.25 3726.06 164.59 4.12 BP _MWD+IFR+MS 62 5719.47 50.66 170.57 95.73 3691.85 3798.27 -3665.73 1003.10 3800.50 164.70 1.66 BP _MWD+IFR+MS 63 5815.14 49.89 169.77 95.67 3752.99 3871.71 -3738.23 1015.66 3873.75 164.80 1.03 BP _MWD+IFR+MS 64 5910.75 47.74 171.78 95.61 3815.95 3943.47 -3809.24 1027.22 3945.31 164.91 2.75 BP _MWD+IFR+MS 65 6004.79 45.27 173.48 94.04 3880.67 4011.31 -3876.89 1035.99 4012.92 165.04 2.94 BP _MWD+IFR+MS 66 6100.17 44.72 174.91 95.38 3948.13 4078.16 -3943.97 1042.81 4079.51 165.19 1.21 BP _MWD+IFR+MS . 67 6196.41 44.85 174.87 96.24 4016.43 4145.26 -4011.50 1048.85 4146.35 165.35 0.14 BP _MWD+IFR+MS 68 6291.99 43.49 176.03 95.58 4084.99 4211.08 -4077.88 1054.14 4211.93 165.51 1.66 BP _MWD+IFR+MS 69 6387.08 42.68 176.76 95.09 4154.44 4275.09 -4142.71 1058.23 4275.73 165.67 1.00 BP MWD+IFR+MS 70 6481.94 41.60 176.83 94.86 4224.77 4337.75 -4206.25 1061.79 4338.20 165.83 1.14 BP _MWD+IFR+MS 71 6577.49 41.00 177.11 95.55 4296.56 4399.79 -4269.23 1065.12 4400.09 165.99 0.66 BP _MWD+IFR+MS 72 6672.39 41.17 177.95 94.90 4368.09 4461.04 -4331.54 1067.81 4461.21 166.15 0.61 BP _MWD+IFR+MS 73 6768.05 40.47 177.62 95.66 4440.48 4522.39 -4394.02 1070.22 4522.48 166.31 0.77 BP _MWD+IFR+MS 74 6863.57 39.53 177.41 95.52 4513.65 4582.69 -4455.36 1072.88 4582.72 166.46 0.99 BP _MWD+IFR+MS 75 6959.08 39.00 177.47 95.51 4587.60 4642.07 -4515.75 1075.58 4642.08 166.60 0.56 BP _MWD+IFR+MS 76 7053.40 38.36 178.82 94.32 4661.23 4699.84 -4574.66 1077.50 4699.84 166.75 1.12 BP _MWD+IFR+MS 77 7148.81 37.34 178.23 95.41 4736.57 4757.13 -4633.18 1079.00 4757.17 166.89 1.13 BP _MWD+IFR+MS 78 7170.08 37.22 178.30 21.27 4753.49 4769.75 -4646.06 1079.39 4769.80 166.92 0.60 BP _MWD+IFR+MS 79 7235.00 37.22 178.30 64.92 4805.19 4808.21 -4685.31 1080.56 4808.30 167.01 0.00 Pr ojected to TD [(c)2008 IDEAL ID13 OC 05] 06/25/08 ~~~~~~~~ NO. 4750 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wnll .Inh ik 1 nn I•tr±er_rintinn Data BL Cnlnr CD Pi-12 11978462 STATIC PRESS & TEMP ~ - (" ,<" ~" - c~ 06/01/08 1 1 X-12 11978466 PRODUCTION PROFILE ~ •-- ~P ~ ~' 06/04/08 1 1 G-05 12017499 PRODUCTION PROFILE f ~ ~' ...- ~" f"~• ~ r ~ ~ 06/12/08 1 1 E-14A 12034899 SCMT l °' ~ " ""`" 06/10/08 1 1 MPH-17 12066526 MEM INJ PROFILE r~ °'~} ~~ ~. r ,--' ~' 05/26/08 1 1 L-220 11975763 CH EDIT PDC GR (USIT) REVISED CD'S ONLY; ! 04/22/08 1 L-220 40016915 OH MWD/LWD EDIT ._ st - 04/18/08 3 V~ lEa:-<' ,F- ., C°. L-221 40016787 OH MWD/LWD EDIT r - (~-°."~ 04!03/08 3 1 01-01C 40015644 OH MWD/LWD EDIT '~" ~~- '~ ~ ~I"r, ~'`' .f ~•°w'~ 08/15/07 2 1 G-19B 40015844 OH MWD/LWD EDIT~~y`°r •- q ~~~- ^`" °^-" ~ " 10/20/07 2 1 X-17 12057619 RST r`~ ~'( %~~~,)~ ~ 05/24/08 1 1 L3-11 11966254 RST c ^'-e"-~. ~~"~) ,~d,~°j,„^I°~ 05/01/08 1 1 Y-36 12014013 RST ' ~~ `'2 •~ +~`%~ ~ d ;_' ~ ' ^ 05/11/08 1 1 P2-37A 11216182 MCNL ~ ~ ~'-- ' ~~ °- ^ ~". ~~" ' 03/17/08 1 1 05-34A 40016888 OH MWD/LWD EDIT ' ;^ _ ,,. ~°.f- !° f`~'1: 04/27/08 2 1 t'LtH,t Hl:tiNUWLtUl9t tltt;tlY I tlY SIIaNINIi HNU tit! UtiNlNla UNt I:UYT tHl:ti I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 'ii ~I z' y ,iiltn Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40» Anchorage, AK 99503-288 ! 1 ATTN: Beth '~ ~!// ~ '/ Received by: ! ?' r` ~5 06/04/08 ~~i~f~~~~~~~~ N0.4736 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 wou r.,r. ~ i n.. ~~ L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 1 L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ' 03/20/08 2 1 W-30 12034892 RST ~ -( (,/ 04/11/08 1 1 G-11B 11963085 MCNL 0$- / 04/01/08 1 1 05-28B 11649987 MCNL (p- 08/17/07 1 1 P2-36A 11209594 MCNL 03/26/06 1 1 07-016 12021155 MCNL `)~ 04/28/08 1 1 OS-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - (~ 05/23/08 1 1 W-31 11999015 LDL 05/25/08 1 1 GNI-02A 12057618 PRESS/TEMP SURVEY ~ - 3 g 05!24/08 1 1 13-12 11982434 USIT _ [. ~~- 05/29/08 1 1 • ~~~..~ ............~~.~..a~ „~.."r , ..., JI~.11Y11Yti NIYN nC l VfI1Y11Y17 VIVC lA/r'r cra~,n i v: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: - Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: 05/13/08 ~c~lumb~~ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh it NO.4702 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-11 12017492 CEMENT & CORROSION LOG 7(j~ -/ ~ ~ / 04/22/08 v 1 v 1V 1-21/K-25 12061694 PRODUCTION LOG ~~ _~jl~ ~j ~° a~~ ~ ~ 04/18/08 1 1 GNI-04 12057606 STEP RATE INJECTIVI'i ~ I t5I ' y U'LG / 33~f 04/23/08 1 1 L-220 11975763 USIT 04/22/08 1 1 MPS-31 11962598 USIT C ~ 05/03/08 1 1 X-17 12034894 USIT - / ~ /~ 33 ~ 05/03/08 1 1 04-47 11978458 MEM LDL 19y-6 3 3 05/01/08 1 1 Y-07A 11966254 TEMP & PRESS LOG aV'~-- ` 05/02/08 1 1 L5-36 11975768 PRODUCTION PROFILE W/FSI --U /' 04/28/08 1 1 Z-112 40016350 OH MWD/LWD EDIT ~- 02/15/08 2 1 Z-112 PB 40016350 OH MWD/LWD EDIT p'~- ~~ 02/11/08 2 1 Y-07A 11962781 CH EDIT PDC GR /SCMTI ~~ /(~~ ~(p p~-( 02/03/08 1 L2-16 11975760 RST ~ (~~=_~~)- (~ ~'S~~ 03/31/08 1 1 L2-33 11998999 RST j - 04/01/08 1 1 Li-14 11999000 RST ~ 04/02/08 1 1 D-26B 40016518 OH MWD/LWD EDIT `~j' 02/21/08 1 1 o~ Door wnvw.~un r BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: .+. ..w............., n._. vn.vnvaa vrvc ~.vr i cN~.n ~ v: ,.., "°'1 ; ~ ., r A i~.,t Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 , Anchorage, AK 99503-2838 j~ ATTN: Beth e \~ Received by: ~l0 • i Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No L-220 Dispatched To: Christine Mahnken (AOGCC) Date Dispatched: 22-Apr-08 Installation/Rig _Nabors 9ES Dispatched By: F. Medina Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H.,lohnson RecelVed By: ' V. '~ BP Exploration (Alaska) Inc. Petrotechnical Data CenterlLR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~?bp.com LWD Log Delivery V2.1, 03-06-06 ~~~ - ~y7 Permit # 2080470 (L-221 in P_ oe Bay Field) Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, Aprii 09, 2008 3:59 PM To: 'Coolidge, Robert B' Subject: RE: Permit # ~~' ~ t in Prudhoe Bay Field) Bob, This is as we discussed. BP is using information to from other wells to optimize the cement design. As noted, these plans should not compromise meet the State's requirement. Call or message with any questions. 1 will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Coolidge, Robert B [mailto:Robert.Coolidge@bp.com] Sent: Wednesday, April 09, 2008 3:16 PM To: Maunder, Thomas E (DOA) Subject: Permit # 2080470 (L-221 in Prudhoe Bay Field) Tom, As a follow up to our phone conversation, I plan to reduce from the typical 30% excess which we pump in the 7" casing interval of the Schrader Bluff welts, to 20% excess. This is a modest reduction in cement volume. We are simply attempting to keep TOC to be 1000' below the 9 5/8" shoe as has been our basis of design, and as stated in our recently approved permit. Fully competent cement recently has been coming up into the 9 5/8" shoe recently in prior tike well plans. Our current intent is to compensate for these recent observations and experiences of smaller gage hole being present during cementing, Obviously several variables can effect the hole size present during cementing. We feel that drilling faster recently, has reduced the washout, although further study is on-going. We do not feet we will be risking in any way NOT being able to meet the state's requirement for TOC as a minimum of 500 feet MD above the top of the Ma formation. Let me know if you need any further information. Best Regards, Tom. Bob Coolidge BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling Robert. Coolidge@bp. com Office: 907-564-577fi Cell: 907-980-7183 Fax: 907-5fi4-4040 4/9/2008 •' SARAH PALIN, GOVERNOR ALASS-A OIL A1~TD GA5 CO1~T5ERVATIOIIT COMDIIS5IOI~T Robert Tirpack Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay, Prudhoe Bay Oil Pool, PBU L-220i BP Exploration Alaska, Inc. Permit No: 208-047 Surface Location: 2369' FSL, 3757' FEL, SEC. 34, T12N, R11E; UM Bottomhole Location: 2975' FSL, 2658' FEL, SEC. 03, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right. to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, aniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM PERMIT TO DRILL 20 AAC 25.005 ~~~~~~~V MAR 2 6 2008 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ~ Development Gas ®Service Multiple Zone ^ Stratigraphic Test ^ Development Oil Single Zone 1 c. C~ ~ ~ ~ fT11SSlOt1 oalbed Metha~Q,~'~iydrates Gas ~^^++~~ ~~w 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 1-2201 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 7219' TVD 4796' 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 7' FEL 2369' FSL 3 SEC E 7. Property Designation: ADL 028239 Schrader Bluff , 75 , . 34, T12N, R11 , UM Top of Productive Horizon: 3201' FSL, 2674' FEL, SEC. 03, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 5, 2008 Total Depth: 2975' FSL, 2658' FEL, SEC. 03, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 8620' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583159 -5978090 Zone-ASP4 10. KB Elevation (Hei ht above GL): 48.10' feet 15. Distance to Nearest Well Within Pool: 1424 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 61 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2122 Surface: 1643 i .: _ .f. k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4" 2 91. A- WLD 1 rf rf 1 110' x Ar i rox. 12-1/4" - / " 4 # L- BT 714' 714' 717' 665 sx Dee CRETE, 332 sx'G' 71sx DuraSTONE -/" 7" T -I 1 7' ' - /4" 7" BT - 1 1' 7 1 47 6' 19. PRESE NT WELL CONDITIONS UMMARY (To be completed for Red rill and Reentry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asin Len th Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Bob Coolidge, 564-5776 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number Si nature ~~l Phone 564-4166 Date 3~~~ I~c~` Sondra Stewman 564-4750 Commission Use On Permit To Drill v?O~~ D API Number: 50-t~?9i?33~~' ~ Permit Approval O~ See cover letter for i Conditions of Approval: ~ \'~'~ ~~~~~} cyvCA~~ `®~ If box is checked, well may not be used toe lore ~or, terror produce coalbed meth~a e, gas hydrates, or gas contained shales: ~d~~ 'QS ~ `3 ~ 0 '~~cS~C-' 0.S \ ~~~ Samples Req'd: ^~ s L1A No Mud Log Req'd: ^ es Cd"No ~ HZS Measures: ~ Yes ^ No Directional Survey Req'd: t~es ^ No ~~-~~~ n ~~o~~~~ ~L~~ I+~~~4 ~ Other: ~~~~~L t'2h©~Cz~Ci-~~ ~ ~~C ~~~~ii ~`'~~~~~`.~ a~~~lh~~.~~ 7 ~ APPROVED BY THE COMMISSION Date COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate ORIGINAL ~ w Well Name: L-220i Drill and Complete Plan Summary Well Design: USH Grassroots Schrader Bluff Injector 3-'/x",9.2#, L-80, TC-II, multi packer, zonal injection, and zonal Drillin En ineer: Bob Coolid e Prodtn. En ineer: Ta for West Geolo ist: Gre Bernaski API NUMBER Estimated Start Date: A ri15, 2008 O eratin da s: 15 Ri Nabors 9ES TMD 7219 TVD RKB: 4796 RKB/GL 28.5'/48.10' RTE 76.60' Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface 583,159 5,978,090 48.1 12N 11E 34 2368 3757 To of Nb Sands 584,275 5,973,955 4100.0 11N 11E 3 3500 2695 To of OBd Sands 584,300 5,973,655 4465.0 11N 11E 3 3201 2674 BHL 584,319 5,973,430 4718.6 11N 11E 3 2975 2658 Formation Markers: Formation Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Name TVDss feet Yes/No Psi EMW G1 -255 +/- 50' no 115 8.7 SV6 -880 +/- 50' no 396 8.7 Fault #1 (L Pad Fault 1270 +/- 100' M.D. -see fault section for details EOCU -1350 +/- 50' no 608 8.7 SV5 -1420 +/- 50' no 639 8.7 SV4 -1560 +/- 50' Gash drates 702 8.7 BPRF -1700 +/- 50' - 765 8.7 SV3 -1930 +/- 50' Gas h drates 869 8.7 SV2 -2090 +/- 50' Gash drates 941 8.7 SV1 -2425 +/- 50' Gas h drates 1091 8.7 UG4 -2720 +/- 50' 1224 8.7 UG4A -2750 +/- 50' Heavy Oil - 2765' - 2865' SS 1238 8.7 UG3 -3100 +/- 50' Thin coals 1395 8.7 UG1 -3565 +/- 50' Heavy Oil -3685'- 3840' SS 1604 8.7 UG_Ma -3820 +/- 50' No -wet 1719 8.7 UG_Mb1 -3865 +/- 50' No -wet 1739 8.7 UG_Mb2 -3930 +/- 50' No -wet 1769 8.7 UG_Mc -4015 +/- 50' No -wet 1807 8.7 SB Na -4075 +/- 25' No -wet 1834 8.7 Page 2 of 31 SB_Nb -4100 +/- 25' No -wet 1860 8.7 SB_Nc -4130 +/- 25' No -wet 1850 8.6 SB_Ne -4140 +/- 25' No -wet 1855 8.6 SB_OA -4235 +/- 25' No -wet 1880 8.5 SB_OBa -4305 +/- 25' No -wet 1910 8.5 SB_OBb -4345 +/- 25' No -wet 1920 8.5 SB_OBc -4415 +/- 25' No -wet 1950 8.5 SB_OBd -4465 +/- 25' No -wet 1965 8.5 SB_OBe -4525 +/- 25' Poss. Oil 1990 8.5 SB_OBf -4565 +/- 25' Poss. Oil 2010 8.5 Base_SB_OBf -4615 +/- 25' Poss. Oil 2030 8.5 TD -4712 No 2100 8.6 Casing/Tubin~ Program: Hole Size Csg/ Tbg O.D. Wt1Ft Grade Connection Length (ft) Top MD/TVD RTE (ft) Btm MD/TVD RTE (ft) 34" Insulated 20" 91.5 A-53 WLD 80 GL 108/108 12-1/a" 9-5/8" 40 L-80 BTC 3714 GL 3714/2717 8-3/a" 7" 26 L-80 TC-II 6018 GL 6018/3897 8 3/a" 7" 26 L-80 BTC-M 1201 6018/3897 7219/4796 Tubin 3-i/i" 9.2 L-80 TC-II 7219 GL 7219/4796 Note: To roduction acker within 200' MD of to erforation X Ni le at 2500 TVD +/- for future SSSV Mud Program & Disposal: Fluid Svctem F.auinment dia¢ram nn file with AOGCC for this rig 12-1/a" Surface Hole Mud Pro erties S ud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL +400 initial 110-1,910 Base Permafrost 8.8-9.2 * 55-30 70-55 NC - 8.0 <1000 300 final 250 initial 1,910' - 3,713' 9.2 - 9.5 55 - 30 60 - 45 8.0 <1000 225 final 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3713' - 7218 8.8-9.2 12 - 18 18 - 24 < 6.0 N/C 9 - 10 Completion Fluid+ +/- 9.Oppg Brine & 6.8 Diesel Disposal of Drilling Mud & Cuttings No annular disposal in this well. Haul all drilling and completion fluids, and other Class II wastes, to DS-04 for disposal. Haul any and all Class I wastes to Pad 3 for disposal. Directional & Survey Program: Refer to attached Directional Plan #4 (Final Approved) Page 3 of 31 Surface Cementin Casin Size Surface Casin - 9-5/g" 40 lb/ft L-80 BTC Sin le Sta e Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface. Tail: O en hole volume + 40% excess + 80' shoe track. TOC = 1000' above 9 5/8" shoe. Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: Wash None i acer 50 bbls of MudPush II wei hted to 10.5 Lead 442 bbls of 10.7 Dee CRETE cement (665 SACKS; Yield = 3.73 ft3/sk) Tail 68 bbls of 15.8 lb/gal Class G (332 sacks; Yield = 1.16 ft3/sk) followed by 15 bbls of 16.3 DuraSTONE (71 SACKS; Yield: = 1.18 ft3/sk ) Temp BHST ~ 52° F Surface Shoe Integrity Test: Perform Formation Integrity Test within 20' - 50' from 9-5/8" shoe Production Cementin Casin Size Production Casin - 7" 261b/ft L-80 BTC-M x TC-II -Sin le Sta e Basis Lead: Open hole volume + 30% excess. TOC to 1000' below 9 5/8" shoe. Tail: O en hole volume + 30% excess + 80' shoe track. TOC to 500' above to of Ma. Fluid Se uence & Volume: This cement 'ob is lanned for one sta e. Wash None S acer 40 bbl of MUDPUSH II S acer wei hted to 10.5 Lead 20.3 bbls of 11 ppg LiteCRETE (60sacks; Yield = 1.88 ft3/sk) based on open hole volume + 30% excess. Tail 70 bbl (335 sacks; Yield = 1.17 ft3/sk) 15.8 class G cement + Latex. Dis lace 9.0 brine Temn BHST ~ 95° F 8-3/a" Hole Section Cement Inte rit A USIT log run on wireline over the interval from ~20' above PBTD surface. The distance to the nearest Well within Pool: 1424' from WKUPST-O1 Exploration Well The distance to the nearest property line boundary: 8620' from PBU boundary wells wlLnln a Lia tulle oI Ln1s 1n ecuon weir wi~niii ~ciirauer niuii ruin: Well Name Dist Ft. Annulus Inte rit Comments NONE Page 4 of 31 Well Control Surface hole will be drilled with a dverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. unction pressure test of the casing rams is required after changing the casing rams. Anticipated surface pressures will not exceed 3,000psi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics for Nabors Rig 9ES are on file with the AOGCC. AOGCC requires a 24 hour notice of all Diverter and BOP tests. Surface Section Integrity: • Diverter: Hydril GK, 21-1/4", 2000 psi • Maximum anticipated BHP: 1131 psi - SV 1 (8.7 ppg EMW @ 2501' TVD) • Planned BOP test pressure: Function Test • 9-5/8" Casing Test: 3,500 psi surface pressure test • Kick Tolerance: NA Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to ,i drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. To mitigate risk involved while no flow paddle is in operation, we will ensure PVT alarms are used, pit levels are accurately monitored for any pit gain, and will visually look down the riser during connections to ensure the well is not flowing. Production Section Integrity: • BOPE: • Maximum anticipated BHP: • Maximum Anticipated surfa • Planned BOP test pressure: • 7" Casing Test: Estimated BHT: Hydril, 13-5/8", 5000 psi 2122 psi - TD (OBf) (8.7 ppg EMW @ 4795' TVD) ce pressure: 1643 psi -Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular 4,000 psi surface pressure test 95°F @ 4615' TVDss (estimated) Page 5 of 31 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control /Reservoir Pressures: a. The Schrader Bluff sands are expected to be pressured at 8.5-8.7 ppg EMW. Kick Tolerance / Inte rit Testin Summar Table Casing /Interval Casing Test Pressure Maximum Influx Volume Mud Wei ht Exp Pore Press LOT /FIT 9 5/8" Surface Casing / 12 1/4" hole 3500 psi 82 BBLS (assuming 12.5 LOT) 9.5ppg 8.7ppg LOT Interm. / Prdtn Casin 4000 si NA NA NA NA 2. Hydrates and Shallow gas: a. Gas hydrates and/or free gas may be present in the SVS thru SV 1 surface hole interval below base Permafrost. Use standard operating procedures for hydrates. Set surface casing below deepest SV 1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. 3. Faults /Lost Circulation /Breathing: a. Fault #1 (L Pad fault) is expected at 1377'MD +/- 100' with a 30'-50' throw. This fault has been penetrated by nearly all wells drilled from the pad. Wells penetrating this fault at a similar depth/stratigraphic zone include L-O1, -03, -101, -107, -108, -117, -118, -120, -200, -202, and -212PB2. The planned L-221i well will also penetrate the L Pad fault at a similar depth. 4. Stuck Pipe & Casing a. 9 5/8" & 7" Casing: low probability of differential sticking. Assure clean hole prior to running casing, follow the centralizer program, keep casing moving while RIH, and reciprocate and rotate while cementing it. 5. Hydrogen Sulfide a. L Pad is not designated as an HZS site, however Standard Operating Procedures for HZS precautions should be followed at all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Watch for nossible H2S when drilling near wells on MI injection. Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level L-120 90 m 6/26/2007 #2 Closest SHL Well H2S Level L-107 20 m 11/22/2007 #2 Closest SHL Well H2S Level L-110 70 m 10/11/2007 #1 Closest BHL Well H2S Level L-116 140 m 8/30/2007 #2 Closest BHL Well H2S Level L-O1 25 m 7/4/2007 Wells within a'/a mile of this in'ection well within Schrader ~31utt Yooi: Well Name Dist Ft. Annulus Inte rit Comments NONE CONSULT THE L PAD DATA SHEET & THE WELL PLAN FOR ADDITIONAL INFORMATION Page 6 of 31 L-220i -Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Remove well houses on each side of this slot. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple u~ and function test diverter, providing AOGCC 24 hour notice of test. 3. MU 12 /4" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. The surface hole TD will be approximately 441' MD / 385' TVD' below the top of the SV 1. 4. Run and cement 9 s/8" surface casing. A TAM port collar may be run at 1000' as a contingency. Use Durastone in the last 15 bbls of tail cement. Pressure test casing to 3500 psi for 30 minutes at plug bump. 5. ND diverter and NU casing /tubing head. NU BOPE and test, providing AOGCC 24 hour notice of test. 6. Make up 8 3/a" drilling BHA with MWD/GR/RES/Azi-Den/NEU/PWD and RIH to float collar. Drill out shoe track and displace well to LSND drilling fluid. Dri1120' - 50' of new formation and perform LOT. 7. Drill ahead to production hole target TD (approx. 7218' MD, 250' below the top of the OBe). Circulate one BU, back- ream out of hole until the ghost reamer is inside the surface shoe, assure hole is sufficiently clean, then POOH to run casing. 8. Run and cement the 7" production casing. Displace with 9.0 ppg brine. Pressure test casing to 4000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-5/8" annulus. 9. PU &RIH with LWD/ GR for correlation on 4.5" Power Jet 4505 5-spf DPC guns to perf -200' of Nb through OBd. Circulate in clean 9.0 brine while correlating guns with LWD. Dispose of old brine. 10. Space out perf guns by tagging PBTD and utilizing GR and RA tags in 7" casing. Confirm cement compressive strength is at least 1000 psi before firing. Perforate Nb, OA, OBa, OBb, OBc, and OBd POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as the USIT will be primary depth control for future well work 13. Run the 3-'/z", 9.2# completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of the top perfs. 14. Confirm that packers are on depth using E-line. 15. Run in lockdown screws, drop ball & rod, and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4000 psi each. Shear the DCR valve and pump both ways to confirm circulation ability. 16. Install and test TWC. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to 2500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 18. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-1/z" annulus valve and secure the well. Ensure that IA/OA are protected with two barriers. 19. RDMO. Post-Rig Work: 1. MIRU slick line. Pull the ball and rod / RHC plug. 2. Pull DCR shear valve from top mandrel (#10) and replace with a dummy GLV. 3. Pull dummy valves from injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. Page 7 of 31 TRFF = WELLHEAD = ACTUATOR = Dectric KB. ELEV = BF. ELEV = KOP = 300' Max Angle = 60 deg E>atum MD = Datum TVD = 4-1/2" TBG, 12.6#, L-80, TC-II, .0152 bpf, ID=3.958" 29' ~ 9-5/8" CSG, 40#, L-80, TGII, ID = 8.835" 3713' 7"Casing 26#, L-80, TC-II , 0.0383bpf, ID = 6.276 @ 5214 Minimum ID = 2.75" ca xxxx' 3-1/2" HES XN NIPPLE 7" MARKER JOINTw/ RA 6370 TAG MARKER JOINTw/ RA TAG 6420' DA 110 ~ 6301 ~ I I MMG I DCR ~ RK I I `~ WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 6367 MNIG-W DMY RK 8 6426 . MMG-W DMY RK 7 6542 MMG-W DMY RK 6 6626 ~MIG-W DMY RK 5 6674 MV1G-W DMY RK 4 6713 MMG-W DMY RK 3 6760 MMGW DMY RK 2 6844 MVIG-W DMY RK 1 6910 M1AG-W DMY RK PERFORATION SUMMARY #tEF LOG: SLB Reaftime LWD A NGLE AT TOP PERF: Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 41/2" 5 Nbxxxx'-xxxx' O 41/2" 5 OA xxxx'-xxxx' O 41/2" 5 OBa xxxx'-xxxx' O 41/2" 5 OBbxxxx'-xxxx' O 41/2" 5 OBc xxxx'-xxxx' O 41/2" 5 OBd xxxx'-xxxx' I3-1/2" TBG, 9.2#, L-80, TC-N, .008.7 bpf, ID = 2.992" PBTD 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 - -i 8962' I 7218' SAFETII~TES: ***HES PKR @ 6331' IS "PULL TO RELEASE" BUT CAN ALSO BE RELEASED BY PRESSURE. DON'T EXCEED 4300 PSI. TEST PRESSURE IS 4332 PSI (80% OF 5415 PSI PKR \ RATING)*** 2~9' I 4-1 /2" XO 3-112", ID = 2.992" 3273' I-~3-1/2" HES X NIP, ID = 2.813" 6312' ~3-1/2" HES X NIP, ID = 2.813" 6331' ~ 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920" 6346' HSGM FOR NDPG GAUGE, ID=2.910" 6447' -13-1/2" HES X NIP, ID= 2.813" 651 7" HES AHR PKR w/ 1/4" FEED THRU, ID = 2.920" 6b2b' SGM FOR NDPG GAUGE, ID=2.910" 6637' 3-1/2" HES X NIP, ID = 2.813" 6646' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 6661' HSGM FOR NDPG GAUGE, ID=2.910" 6723' H 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" ~ 6738' HSGM FOR NDPG GAUGE, 12.910" 6746' H3-1/2" HES X NIP, ID = 2.81 6868' H 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 6882' HSGM FOR NDPG GAUGE, ID=2.910" 6890' 3-1/2" HES X NIP, ID = 2.813" 6930' 3-1/2" HES XNIP, O = 2.813" 6961' 3-1/2" HES XN NIP, ID = 2.75" 6962' ~ 3-1/2" WLEG, ID=2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/04/07 ALM Proposed tNBD 12/06/07 ALM Updated for wp03 depths 03/20/08 RBC UPDATE FOR WP4 DEPTHSlREi/ISEO TALLY ORION UNIT WELL: L-220i PERMff No: xxxxx AR No: 50-029-xxxxx Sec 34, Tw p 12N, Rge 11 E BP Exploration (Alaska) 41/16"~ L-220~Proposed by L-220 (P41 Proposal Schlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: Well: L-PAD / S-I ~ Plan L•220 (S-I) Borehole: ' ~ ~ Plan L-220 uwuAPla: ~ 5oa2s Survey Name 1 Date: L-220 (P4) /January 22, 2008 Tort 1 AHD 1 DDI 1 ERD ratio: 85.792° 14816.52 ft / 5.794 / 1.004 Gdd Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.35011144, W 149.32484344 Location Grid NIE YIX: N 5978089.960 ftUS, E 583159.380 ftUS Grid Convergence Angle: +0.63584216° Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 166.660° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 76.60 ft relative to MSL Sea Bed 1 Ground Level Elevation: 48.10 ft relative to MSL Magnetic Declination: 23.010° Total Field Strength: 57646.504 nT Magnetic Dip: 80.883° Declination Date: April 01, 2008 Magnetic Declination Model: BGGM 2007 North Reference: True Nortfl Total Corr Mag North -> True North: +23.010° u Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grev DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 it Index ftUS ftUS Klt U.UU U.UU 164.y5 -/6.6U U.UU U.UU U.UU U.UU -- U.UU 0.UU by/tSUtSy.yti btS3lbyAtf N /U.3bU17144 W 14y.3L4tS4344 KOP Bld 1.5/100 300.00 0.00 164.95 223.40 300.00 0.00 0.00 0.00 164.95M 0.00 0.00 5978089.96 583159.38 N 70.35011144 W 149.32484344 G1 331.60 0.32 164.95 255.00 331.60 0.09 -0.08 0.02 164.95M 1.00 0.00 5978089.88 583159.40 N 70.35011121 W 149.32484326 Bld 2/100 400.00 1.00 164.95 323.39 399.99 0.87 -0.84 0.23 164.95M 1.00 0.00 5978089.12 583159.62 N 70.35010914 W 149.32484160 500.00 3.00 164.95 423.33 499.93 4.36 -4.21 1.13 164.95M 2.00 1.12 5978085.76 583160.56 N 70.35009993 W 149.32483424 600.00 5.00 164.95 523.08 599.68 11.33 -10.95 2.94 HS 2.00 1.75 5978079.05 583162.45 N 70.35008153 W 149.32481954 700.00 7.00 164.95 622.53 699.13 21.78 -21.04 5.66 HS 2.00 2.18 5978068.98 583165.27 N 70.35005396 W 149.32479751 800.00 9.00 164.95 721.55 798.15 35.69 -34.48 9.27 HS 2.00 2.51 5978055.59 583169.03 N 70.35001724 W 149.32476817 900.00 11.00 164.95 820.02 896.62 53.05 -51.25 13.78 HS 2.00 2.77 5978038.87 583173.73 N 70.34997143 W 149.32473157 Bld 3.5/100 961.23 12.22 164.95 880.00 956.60 65.37 -63.15 16.98 HS 2.00 2.90 5978027.01 583177.06 N 70.34993892 W 149.32470560 SV6 961.24 12.22 164.95 880.01 956.61 65.37 -63.15 16.98 HS 3.50 2.90 5978027.00 583177.06 N 70.34993891 W 149.324 1000.00 13.58 164.95 917.79 994.39 74.02 -71.51 19.23 HS 3.50 3.00 5978018.67 583179.40 N 70.34991608 W 149.3246 5 1100.00 17.08 164.95 1014.22 1090.82 100.44 -97.04 26.09 HS 3.50 3.24 5977993.22 583186.55 N 70.34984633 W 149.32463162 1200.00 20.58 164.95 1108.85 1185.45 132.70 -128.21 34.47 HS 3.50 3.44 5977962.15 583195.27 N 70.34976119 W 149.32456360 1300.00 24.08 164.95 1201.34 1277.94 170.68 -164.90 44.34 HS 3.50 3.62 5977925.58 583205.54 N 70.34966096 W 149.32448352 Fault Crossing 1376.03 26.74 164.95 1270.00 1346.60 203.28 -196.40 52.81 HS 3.50 3.74 5977894.18 583214.36 N 70.34957490 W 149.32441476 1400.00 27.58 164.95 1291.33 1367.93 214.22 -206.97 55.65 HS 3.50 3.78 5977883.64 583217.32 N 70.34954602 W 149.32439169 EOCU 1466.93 29.92 164.95 1350.00 1426.60 246.40 -238.06 64.01 HS 3.50 3.88 5977852.65 583226.02 N 70.34946110 W 149.32432384 1500.00 31.08 164.95 1378.50 1455.10 263.18 -254.27 68.37 HS 3.50 3.93 5977836.49 583230.56 N 70.34941681 W 149.32428845 SV5 1548.91 32.79 164.95 1420.00 1496.60 289.04 -279.25 75.09 HS 3.50 3.99 5977811.59 583237.55 N 70.34934855 W 149.32423392 1600.00 34.58 164.95 1462.51 1539.11 317.36 -306.62 82.44 HS 3.50 4.06 5977784.31 583245.21 N 70.34927380 W 149.32417420 1700.00 38.08 164.95 1543.06 1619.66 376.58 -363.82 97.83 HS 3.50 4.18 5977727.28 583261.23 N 70.34911752 W 149.32404934 WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-I\Plan L-220 (S-I)\Plan L-220\L-220 (P4) Generated 3/5/2008 2:27 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de h ft ft R ft de de 1100 ft Index ftUS ttUS JV4 7/17.64 :itf.tf4 7ti4.yb lb(iU.UU 7ti:i(i.(iU ;fyU.U;f -;i/fi.tSL 7U7.:i1 HJ :f.bU 4.1U by///74.11 btJJ104.tJ/ IV /U.34yUC1U7 w 74y.JL4U[Uytf 1800.00 41.58 164.95 1619.84 1696.44 440.59 -425.67 114.46 HS 3.50 4.29 5977665.63 583278.54 N 70.34894856 W 149.32391436 End Crv 1882.30 44.46 164.95 1680.00 1756.60 496.71 -479.89 129.03 -- 3.50 4.37 5977611.58 583293.72 N 70.34880043 W 149.32379603 Base Perm 1910.32 44.46 164.95 1700.00 1776.60 516.33 -498.84 134.13 --- 0.00 4.39 5977592.69 583299.03 N 70.34874865 W 149.32375466 Crv 3.5/100 1938.34 44.46 164.95 1720.00 1796.60 535.95 -517.80 139.23 2.17E 0.00 4.41 5977573.79 583304.33 N 70.34869687 W 149.32371329 2000.00 46.62 164.84 1763.18 1839.78 579.93 -560.28 150.70 2.09E 3.50 4.47 5977531.44 583316.27 N 70.34858081 W 149.32362020 2100.00 50.12 164.67 1829.61 1906.21 654.62 -632.38 170.35 1.98E 3.50 4.56 5977459.57 583336.72 N 70.34838384 W 149.32346068 2200.00 53.61 164.52 1891.35 1967.95 733.21 -708.20 191.24 1.89E 3.50 4.64 5977384.00 583358.45 N 70.34817671 W 149.32329112 SV3 2267.04 55.96 164.43 1930.00 2006.60 787.94 -760.96 205.90 1.83E 3.50 4.70 5977331.40 583373.69 N 70.34803255 W 149.32317213 2300.00 57.11 164.38 1948.18 2024.78 815.42 -787.45 213.29 1.81 L 3.50 4.72 5977305.00 583381.38 N 70.34796019 W 149.32311 13 2400.00 60.61 164.26 1999.88 2076.48 900.92 -869.84 236.42 1.74E 3.50 4.80 5977222.88 583405.42 N 70.34773510 W 149.322 End Crv 2406.55 60.84 164.25 2003.08 2079.68 906.63 -875.34 237.97 -- 3.50 4.81 5977217.40 583407.03 N 70.34772008 W 149.322 SV2 2584.93 60.84 164.25 2090.00 2166.60 1062.27 -1025.27 280.26 -- 0.00 4.89 5977067.96 583450.97 N 70.34731049 W 149.32256863 SV1 3272.46 60.84 164.25 2425.00 2501.60 1662.13 -1603.12 443.24 -- 0.00 5.12 5976492.01 583620.34 N 70.34573184 W 149.32124603 9-518" Csg Pt ~-3713.71 60.84 164.25 2640.00 2716.60 2047.12 -1973.97 547.84 -- 0.00 5.23 5976122.37 583729.04 N 70.34471867 W 149.32039730 UG4 3877.90 60.84 164.25 2720.00 2796.60 2190.37 -2111.97 586.76 -- 0.00 5.27 5975984.83 583769.49 N 70.34434968 W 149.32008151 UG4A 3939.47 60.84 164.25 2750.00 2826.60 2244.09 -2163.72 601.36 -- 0.00 5.28 5975933.25 583784.66 N 70.34420030 W 149.31996309 UG3 4657.78 60.84 164.25 3100.00 3176.60 2870.81 -2767.44 771.64 -- 0.00 5.41 5975331.52 583961.61 N 70.34255095 W 149.31858169 Crv 4/100 5544.24 60.84 164.25 3531.93 3608.53 3644.23 -3512.48 981.78 154.38R 0.00 5.53 5974588.92 584179.98 N 70.34051550 W 149.31687723 5600.00 58.83 165.38 3559.94 3636.54 3692.41 -3559.00 994.41 153.81 R 4.00 5.56 5974542.55 584193.13 N 70.34038840 W 149.31677477 UG1 5609.72 58.48 165.58 3565.00 3641.60 3700.71 -3567.04 996.49 153.71R 4.00 5.56 5974534.54 584195.30 N 70.34036645 W 149.31675789 5700.00 55.26 167.52 3614.33 3690.93 3776.30 -3640.55 1014.10 152.65R 4.00 5.59 5974461.23 584213.72 N 70.34016561 W 149.31661512 5800.00 51.73 169.86 3673.82 3750.42 3856.61 -3719.34 1029.89 151.25R 4.00 5.63 5974382.63 584230.38 N 70.33995035 W 149.31648706 5900.00 48.25 172.44 3738.10 3814.70 3932.95 -3794.99 1041.71 149.59R 4.00 5.66 5974307.12 584243.04 N 70.33974367 W 149.31639122 6000.00 44.84 175.31 3806.88 3883.48 4004.95 -3867.14 1049.51 147.62R 4.00 5.69 5974235.07 584251.64 N 70.33954657 W 149.31632807 Drp 0.5/100 6018.40 44.22 175.88 3820.00 3896.60 4017.69 -3880.00 1050.50 HS 4.00 5.70 5974222.22 584252.77 N 70.33951143 W 149.31632003 Ma 6018.41 44.22 175.88 3820.01 3896.61 4017.70 -3880.01 1050.50 LS 0.50 5.70 5974222.21 584252.77 N 70.33951140 W 149.31632003 Mb1 6081.02 43.90 175.88 3865.00 3941.60 4060.68 -3923.44 1053.63 LS 0.50 5.70 5974178.83 584256.38 N 70.33939277 W 149.31629467 6100.00 43.81 175.88 3878.69 3955.29 4073.66 -3936.55 1054.58 LS 0.50 5.70 5974165.72 584257.47 N 70.33935694 W 149.316 Mb2 6170.90 43.45 175.88 3930.00 4006.60 4121.94 -3985.34 1058.09 LS 0.50 5.71 5974116.98 584261.53 N 70.33922364 W 149.31625854 6200.00 43.31 175.88 3951.15 4027.75 4141.68 -4005.28 1059.53 LS 0.50 5.71 5974097.06 584263.19 N 70.33916917 W 149.31624691 Mc 6287.43 42.87 175.88 4015.00 4091.60 4200.63 -4064.85 1063.82 LS 0.50 5.72 5974037.54 584268.14 N 70.33900643 W 149.31621217 6300.00 42.81 175.88 4024.22 4100.82 4209.07 -4073.38 1064.43 LS 0.50 5.72 5974029.03 584268.85 N 70.33898313 W 149.31620720 Na 6369.03 42.46 175.88 4075.00 4151.60 4255.22 -4120.01 1067.79 LS 0.50 5.73 5973982.44 584272.72 N 70.33885574 W 149.31618002 6370.10 42.46 175.88 4075.79 4152.39 4255.93 -4120.73 1067.84 --- 0.50 5.73 5973981.72 584272.78 N 70.33885377 W 149.31617960 6370.72 42.46 175.88 4076.25 4152.85 4256.35 -4121.15 1067.87 2.40E 0.00 5.73 5973981.30 584272.82 N 70.33885262 W 149.31617936 6400.00 42.60 175.88 4097.83 4174.43 4275.88 -4140.89 1069.29 2.39E 0.50 5.73 5973961.58 584274.46 N 70.33879869 W 149.31616784 Nb 6402.95 42.62 175.87 4100.00 4176.60 4277.86 -4142.89 1069.44 2.39E 0.50 5.73 5973959.58 584274.62 N 70.33879324 W 149.31616668 6409.25 42.65 175.87 4104.63 4181.23 4282.07 -4147.14 1069.75 -- 0.50 5.73 5973955.33 584274.98 N 70.33878162 W 149.31616419 L-220 Tgt 6409.75 42.65 175.87 4105.00 4181.60 4282.40 -4147.48 1069.77 LS 0.00 5.73 5973955.00 584275.00 N 70.33878070 W 149.31616400 WeIlDesign Ver SP 2.1 Bld( docAOx_100) S-I\Plan L-220 (S-I)\Plan L-220\L-220 (P4) Generated 3/5/2008 2:27 PM Page 2 of 3 Comments Measured Inclination A>•Smuth SutrSea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS NC (i44J.(i'J 4L.4ti 7/b.ti/ 47JU.UU 4ZU(i.6U 43Ub.U6 -47/U.Jti Ne 6457.25 42.41 175.87 4140.00 4216.60 4314.09 -4179.50 6500.00 42.20 175.87 4171.62 4248.22 4342.50 -4208.21 OA 6585.28 41.78 175.87 4235.00 4311.60 4398.82 -4265.11 6600.00 41.71 175.87 4245.99 4322.59 4408.49 -4274.89 OBa 6678.81 41.32 175.87 4305.00 4381.60 4460.05 -4326.99 6700.00 41.21 175.87 4320.93 4397.53 4473.85 -4340.93 OBb 6731.96 41.05 175.87 4345.00 4421.60 4494.60 -4361.89 6800.00 40.71 175.87 4396.44 4473.04 4538.56 -4406.31 OBc 6824.46 40.59 175.87 4415.00 4491.60 4554.29 -4422.21 L-220 Tgt 2 OBd 6863.91 40.40 175.87 4445.00 4521.60 4579.58 -4447.76 OBd 6890.15 40.27 175.87 4465.00 4541.60 4596.34 -4464.70 6900.00 40.22 175.87 4472.52 4549.12 4602.62 -4471.04 6968.55 39.87 175.87 4525.00 4601.60 4646.16 -4515.04 OBe 6968.57 39.87 175.87 4525.01 4601.61 4646.17 -4515.05 7000.00 39.72 175.87 4549.16 4625.76 4666.03 -4535.11 OBf 7020.58 39.61 175.87 4565.00 4641.60 4678.99 -4548.21 OBf Base 7085.33 39.29 175.87 4615.00 4691.60 4719.61 -4589.25 7100.00 39.22 175.87 4626.36 4702.96 4728.77 -4598.51 7200.00 38.72 175.87 4704.11 4780.71 4790.85 -4661.24 TD / 7" Csg 7218.55 38.62 175.87 4718.59 4795.19 4802.29 -4672.80 Legal Description: Northi ng (Y) [ftUS] Surface : 2368 FSL 3757 FEL S34 T12N R11E UM 5978089.96 L-220 Tgt : 3501 FSL 2696 FEL S3 T11 N R11 E UM 5973955.00 L-220 Tgt 2 OBd : 3200 FSL 2674 FEL S3 T11 N R11 E UM 5973655.00 BHL : 2975 FSL 2659 FEL S3 T11 N R11 E UM 5973430.18 7 U/7.4Z LJ U.OU 5./J DJ/J`JJZ.7L OC4L/O.`J7 /V /V.JJO/7U7J VV 74`J.J707AU07 1072.08 LS 0.50 5.73 5973923.00 584277.67 N 70.33869321 W 149.31614528 1074.15 LS 0.50 5.74 5973894.33 584280.06 N 70.33861479 W 149.31612851 1078.26 LS 0.50 5.75 5973837.48 584284.80 N 70.33845933 W 149.31609526 1078.96 LS 0.50 5.75 5973827.71 584285.61 N 70.33843262 W 149.31608954 1082.72 LS 0.50 5.75 5973775.66 584289.95 N 70.33829030 W 149.31605910 1083.73 LS 0.50 5.75 5973761.74 584291.11 N 70.33825221 W 149.31605096 1085.24 LS 0.50 5.76 5973740.79 584292.86 N 70.33819493 W 149.31603871 1088.45 LS 0.50 5.76 5973696.41 584296.55 N 70.33807358 W 149.31601275 1089.60 LS 0.50 5.76 5973680.53 584297.88 N 70.33803016 W 149.31600 6 1091.44 LS 0.50 5.77 5973655.00 584300.00 N 70.33796035 W 149.315 1092.66 LS 0.50 5.77 5973638.08 584301.41 N 70.33791408 W 149.3159 4 1093.12 LS 0.50 5.77 5973631.74 584301.94 N 70.33789674 W 149.31597493 1096.30 LS 0.50 5.78 5973587.79 584305.60 N 70.33777655 W 149.31594922 1096.30 LS 0.50 5.78 5973587.78 584305.61 N 70.33777653 W 149.31594922 1097.74 LS 0.50 5.78 5973567.73 584307.28 N 70.33772171 W 149.31593749 1098.69 LS 0.50 5.78 5973554.65 584308.37 N 70.33768592 W 149.31592984 1101.65 LS 0.50 5.78 5973513.64 584311.78 N 70.33757380 W 149.31590586 1102.32 LS 0.50 5.79 5973504.40 584312.55 N 70.33754850 W 149.31590045 1106.85 LS 0.50 5.79 5973441.73 584317.78 N 70.33737714 W 149.31586380 1107.68 --- 0.50 5.79 5973430.18 584318.74 N 70.33734555 W 149.31585704 Easting (X) [ftUS] 583159.38 584275.00 584300.00 584318.74 s WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-I\Plan L-220 (S-I)\Plan L-220\L-220 (P4) Generated 3/5/2008 2:27 PM Page 3 of 3 by Schlumberger WELL L-220 (P4) FIELD Prudhoe Bay Unit - WOA STRUCTURE L-PAD Mag~retlc Parameters Sudaca Lecatien NA02]Alaska Slade Planes. Zone 04, US Feet Miscellaneous Model'. BGGM 200] Dip'. 00 B83° Dale: April lll, 2008 Lat'. N]0210601 NoMi~g: 59]BOB99fi M15 Grid C°nv: ~O.fi3584216° SI NO Rat Rotary Table l]6608abeve MSL) Mag Dec. X23010° FS'. 5]fi4fi.5 nT Lan W149 1929.436 Easbng: 58]169.38 M1US Scale Fad:099990]6858 Plan. L-2201P41 Srvy Dale. January 22. 2608 -800 0 800 1600 2400 3200 4000 4800 0 800 1600 O O 00 C u 2400 a> U 3200 4000 4800 RTE KOP Bld 1.5/100 Bld 21100 ~1d.3.5IJA0......:. Fault Crossing 51100 ~°-°°~ End Crv a wr\ .............:..................................:...................................................... -..-..-..w.-..-..-..-..-..-..-..-.: y::.::.:: ~::~::~::-..-..-..~..-..-..-~:~ -..-..-. -1.-..-..-..-..-..-..-..- -..-..- -. -..- ..t..-..-..-..-..-..-..-.. . r.. . ..................................:..................................:...... crv anbo }. ..-..-..-..-..-..-..- .~..-..-..-..-..-..-..-..-..~..-..-..-..-.....-..-..-.5-..-..-..-..-..-..-..-..-.~-..-..-..-..-..-..-..-..-i.-..-..-..-..- ~. -..K..-..-..-.._..-..-..-..-..i..-..-..-..-.. Drp 0.51100 0 800 1600 2400 3200 4000 -800 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 166.66°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 4800 4800 by Schlumherger WELL FIELD STRUCTURE L-220 (P4) Prudhoe Bay Unit - WOA L-PAD Magnetic Palamelers Su~ace Location NA02] Alaska SiNe Planas. Zone Od, US Feel MiscelWneous Model. BGGM 200] Dip: 80083° Dale Apnl Ot, 2006 lal: N)0210401 Norifling' S9T8089961ttIS GM Cpnv'. +06368d21fi' Sld. 5-I TVD ReI: Rotary Table l~B.fi0flabove MSL) Mag Dec'. +23010° FS: 5]646.5 nT Lon: W1491929d]fi Easling. fi83t39.38 !IUS Scale Fact'.099990T8368 Plan'. L-2201Pdj Sny Data. January 22, 2006 -600 0 600 1200 1800 -600 -1200 n -1800 n n Z 0 0 -600 -1200 -1800 0 0 m c -2400 a~ m U V V V -3000 -3600 -4200 -2400 -3000 -3600 -4200 -600 0 600 1200 1800 c« W Scale = 1(in):600(ft) E »> Field: Prudhoe Ba~• Site: PB L Pad Nell: Plan L-220 (S-I) Wellpath: Plan L-220 ', vwec~~~~~M Plan L-220 (S-I)/Plan L-220 I PLANT - ~ 15'00'00" GRID L-PAD ^ N-L (NWE-i) L-111i ^ L-51 ^`~' L-na ^ L-so ^~ L-121 ^ L-110 L- 2201 L-116 L-109 ^ L-04i ^..~- L-01 ^ L-107 ^ L-03 ^ L-213i ^ L-108i ^ L-105i ^ L-106 ^ L-204 ^s- L-104 ^ L-214i ^~.-- L-102 ^ // ^ N-A (NWE-2) ^ L-2181 ^ L-124 ^ L-lni ^ L-02 ^ L-123i ~ L-122 ^ L-2111 ^ L-1151 ^ L-117 ^ L-116 ^ L-250-~' ^ L-200 ^ L-202 ^ L-212i ^ L-217i ^ L-203 ^ L-2161 ^ L-103i ^ L-2151 ^ L-201 ^ L-1191 ^ L-2101 ^ 1-120 ^ L-zlsi ~~ i 34 L-PAD 3 35 -N I T12N T11 N I~ w 1 ~ ', 2 VICINITY MAP N.T.S. WELL N0. L-220i REVISION NOTE THIS AS-BUILT DRAWING IS A RE-ISSUE OF A PREVIOUS CONDUCTOR AS-BUILT FOR WELL SLOT L-SI DATED 4/19/2001. WELL SLOT L-SI IS BEING RENAMED TO WELL L-220i. ~_ A ~b ~ °°° °°9 ~o°49TM a~ °°~°°o°°°°°°°°°°°°°°°°°°°°°°°°° °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° °°° Richard F. Allison ~s~oO°o~,,1~0608 -tea ' "'r'ESS I ONP~~ ~'~ 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 AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 01, 2008. LEGEND NOTES AS-BUILT CONDUCTOR 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. ^ EXISTING CONDUCTOR GEODETIC POSITIONS ARE NAD 27. 2. HORIZONTAL AND VERTICAL CONTROL IS BASED ON L PAD OPERATOR MONUMENTATION. 3. ELEVATIONS ARE BPX M.S.L. DATUM 4. MEAN PAD SCALE FACTOR IS 0.999907827. AS-BUILT CONDUCTOR DATA FOR RENAMED WELL L-2201 (OLD L-SI) L-2201 Y=5,978,089.96 N= 9,820.01 70'21'00.401" 70.3501114' 481• 2,369' FSL X= 583,159.38 E= 5,120.07 149'19'29.436" 149.3248433' 3,757' FEL F. Robert °RAWN: >f6 (~ CHECKED:RFA by 0 DATE:2~1 ~06 ~~UJn DRAWING: WOA L-PAD FR608 WOL 02-00 SHEET: ~ ~~~OO ~a JGB NG CONDUCTOR AS-BUILT 0 2 1 0 ISSUED FOR INFORMATION TFB RFA SCALE: i OF 1 1°= 1so' WELL L-2201 N0. DATE RENSION BY CHK a+sAx un L-220 projected spud date Maunder, Thomas E (DOA) Page 1 of 1 From: Coolidge, Robert B [Robert.Coolidge@bp.com] Sent: Wednesday, April 02, 2008 10:00 AM To: Maunder, Thomas E (DOA) Subject: L-220 projected spud date Tom, As follow up to my phone msg, it Looks tike we would be ready to spud L-220 about 4/10, Thursday next week. I'll be at home this week, but on email and cell phone, ~ Feel free to contact me if needed. Regards, Bob Coolidge BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling Robert. Coolidge@bp. com Office: 907-564-5776 Cell: 907-980-7183 Fax: 907-564-4040 4/4/2008 • • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Wednesday, March 5, 2008 Bob Coolidge BP Exploration (Alaska) Inc. Schlumberger Prudhoe Bay L-220 (P4) 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 analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred 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. Survey Prooram: Instrument Type Start Depth End Depth GYD GC SS 28.50' and 1000.00' and MWD 1000.00' and 2400.00' and MWD + IFR + MS 1000.00' and 7218.55' and Close Approach Analysis results: Under method (2), note. All drilled wells pass major risk. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillings Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 03/05/2008 BP Alaska Anticollision Report Canpany: BP>~~ Date: 3/5/2008 'time: 14:32:47 Page: I Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: Plan L-220 (S-I), True North Reference Well: Plan L-220 (S-I) Vertical ('I'VD) Reference: L-220 Plan 76.6 Reference Wellpath: Plan L-220 Db: Oracle ~I GLOBAL SCAN AP PLIED: All wellpaths within 200'+ 100/1000 of reference -There are )<t@iiHoQells in thisRltild'lpal Plan & PLANNED PROGRA~ Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7218.55 ft Scan Method: Trav Cylinder North ', Maximum Radius: 919.01 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/19/2007 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 28.50 1000.00 Planned: Plan #4 V2 GYD-GC-SS Gyrodata gyro single shots 1000.00 2400.00 Planned: Plan #4 V2 MWD MWD -Standard 1000.00 3610.00 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station 3610.00 7218.55 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points M1ID 'fVD Diameter Hole Size Name .-, ..., ft ft in in 3713.71 2716.60 9.625 12.250 9 5/8" 7208.83 4787.60 7.000 8.750 7" Summary -------------- Offset Wellpath. --~- ----->' Reference Offset qtr-Ctr No-Go Allo,vablc Silc VYell Wellpath MD 119D Distance grcd Deviation Warning ft ft ft ft ft PB L Pad L-01 L-01 V14 824 25 825.00 103.03 13.79 89.24 Pass: Major Risk ~, PB L Pad L-02 L-02 V1 424.63 435.00 187.14 7.55 179.59 Pass: Major Risk ', PB L Pad L-02 L-02A V5 425.39 430.00 187.15 7.67 179.48 Pass: Major Risk ', PB L Pad L-02 L-02AP61 V2 425.39 430.00 187.15 7.67 179.48 Pass: Major Risk ~~ PB L Pad L-02 L-02P61 V21 424.63 435.00 187.14 7.66 179.48 Pass: Major Risk PB L Pad L-03 L-03 VS 477.41 480.00 130.24 8.99 121.25 Pass: Major Risk ~ PB L Pad L-04 L-04 VS 629.17 630.00 46.84 11.22 35.62 Pass: Major Risk PB L Pad L-101 L-101 V4 410.52 415.00 216.54 7.34 209.19 Pass: Major Risk PB L Pad L-104 L-104 V7 437.54 440.00 233.83 7.12 226.71 Pass: Major Risk ', PB L Pad L-105 L-105 V4 472.90 475.00 193.34 8.59 184.75 Pass: Major Risk PB L Pad L-106 L-106 V14 575.45 580.00 204.03 9.64 194.39 Pass: Major Risk PB L Pad L-107 L-107 V14 169.29 170.00 116.36 3.78 112.58 Pass: Major Risk PB L Pad L-108 L-108 V18 630.38 635.00 171.85 11.54 160.31 Pass: Major Risk ', PB L Pad L-109 L-109 V12 958.77 960.00 26.33 18.59 7.74 Pass: Major Risk PB L Pad L-110 L-110 V11 504.66 505.00 17.17 9.16 8.01 Pass: Major Risk PB L Pad L-111 L-111 V24 300.39 300.00 121.78 5.38 116.40 Pass: Major Risk PB L Pad L-112 L-112 V8 551.81 570.00 196.17 11.12 185.06 Pass: Major Risk PB L Pad L-114 L-114 V15 633.59 635.00 91.96 10.13 81.83 Pass: Major Risk PB L Pad L-114 L-114A V4 633.59 635.00 91.96 10.13 81.83 Pass: Major Risk PB L Pad L-115 L-115 V7 523.77 535.00 177.38 9.00 168.38 Pass: Major Risk PB L Pad L-116 L-116 V10 485.22 485.00 15:52 7.46 8.06 Pass: Major Risk !~ PB L Pad L-117 L-117 V11 357.67 360.00 182.04 5.73 176.31 Pass: Major Risk PB L Pad L-118 L-118 V9 204.68 205.00 184.14 3.81 180.33 Pass: Major Risk PB L Pad L-121 L-121 V14 360.09 360.00 46.67 6.54 40.13 Pass: Major Risk PB L Pad L-121 L-121A V1 360.09 360.00 46.67 6.54 40.13 Pass: Major Risk PB L Pad L-122 L-122 V6 357.77 360.00 183.19 6.26 176.94 Pass: Major Risk PB L Pad L-123 L-123 V5 170.60 170.00 186.13 3.22 182.92 Pass: Major Risk PB L Pad L-123 L-123PB1 V3 170.60 170.00 186.13 3.22 182.92 Pass: Major Risk PB L Pad L-123 Plan L-123L1 V1 Plan: 170.60 170.00 186.13 3.22 182.92 Pass: Major Risk PB L Pad L-124 L-124 V13 309.47 310.00 202.46 5.25 197.21 Pass: Major Risk PB L Pad L-124 L-124P61 V5 309.47 310.00 202.46 5.25 197.21 Pass: Major Risk PB L Pad L-124 L-124P62 V4 309.47 310.00 202.46 5.25 197.21 Pass: Major Risk PB L Pad L-200 L-200 V7 223.99 225.00 207.16 3.98 203.18 Pass: Major Risk PB L Pad L-200 L-200L1 V3 223.99 225.00 207.16 3.98 203.18 Pass: Major Risk PB L Pad L-200 L-200L2 V6 223.99 225.00 207.16 3.98 203.18 Pass: Major Risk PB L Pad L-202 L-202 V6 367.19 370.00 214.83 6.26 208.57 Pass: Major Risk PB L Pad L-202 L-202L1 V8 367.19 370.00 214.83 6.26 208.57 Pass: Major Risk PB L Pad L-202 L-202L2 V7 367.19 370.00 214.83 6.26 208.57 Pass: Major Risk PB L Pad L-202 L-202L3 V8 367.19 370.00 214.83 6.26 208.57 Pass: Major Risk PB L Pad L-204 L-204 V8 542.99 545.00 225.61 9.15 216.46 Pass: Major Risk PB L Pad L-204 L-204L1 V5 542.99 545.00 225.61 9.15 216.46 Pass: Major Risk BP Alaska Anticollision Report Compa~n~~: BP ~ Date: 3/5!2008 Time: 14:32:47 Page: 2 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate (NE) Reference: Well: Pla n L-220 (S-I), True North Reference Well: Plan L-220 (S-I) Vertical (TV D) Refere nce: L-220 Plan 76.6 Reference Wellpath: Plan L-220 Db: Oraole Summary <--------- - Offset Wellpath -- -------> Reference Offset Ctr-Ctr No-Co Allowable Site Well WeRpafh MD ~1D Distance Area Deviation Warning ft ft ft ft ft i, PB L Pad L-204 L-204L2 V7 542.99 545.00 225.61 9.15 216.46 Pass: Major Risk {I PB L Pad L-204 L-204L3 V5 542.99 545.00 225.61 9.15 216.46 Pass: Major Risk i ~, PB L Pad L-204 L-204L4 V5 542.99 545.00 225.61 9.15 216.46 Pass: Major Risk i PB L Pad L-211 L-211 V6 357.69 360.00 181.98 6.76 175.21 Pass: Major Risk ', PB L Pad L-211 L-211 P61 V6 357.69 360.00 181.98 6.76 175.21 Pass: Major Risk ', PB L Pad L-212 L-212 V11 327.92 330.00 223.33 5.58 217.75 Pass: Major Risk ' PB L Pad L-212 L-212P61 V9 327.92 330.00 223.33 5.58 217.75 Pass: Major Risk PB L Pad L-212 L-212P62 V2 327.92 330.00 223.33 5.58 217.75 Pass: Major Risk I ', PB L Pad L-213 L-213 V9 403.53 405.00 160.31 6.67 153.64 Pass: Major Risk ', PB L Pad L-214 L-214 V9 332.68 335.00 249.30 6.21 243.09 Pass: Major Risk PB L Pad L-214 L-214A V4 332.68 335.00 249.30 6.21 243.09 Pass: Major Risk PB L Pad L-217 L-217 V5 337.31 340.00 233.61 6.37 227.24 Pass: Major Risk PB L Pad L-218 L-218 V5 580.60 595.00 207.70 11.49 196.21 Pass: Major Risk I PB L Pad L-250 L-250 V4 396.28 400.00 199.61 8.29 191.32 Pass: Major Risk I PB L Pad L-250 L-250L1 V14 396.28 400.00 199.61 8.29 191.32 I Pass: Major Risk PB L Pad L-250 L-250L2 V10 381.74 385.00 199.33 7.08 192.25 Pass: Major Risk PB L Pad L-250 L-250PB1 V4 396.28 400.00 199.61 8.35 191.26 Pass: Major Risk ~ PB L Pad L-50 L-50 V1 584.69 585.00 78.62 9.88 68.73 Pass: Major Risk ', PB L Pad L-50 L-50PB1 V4 584.69 585.00 78.62 9.88 68.73 Pass: Major Risk PB L Pad L-51 L-51 V6 470.04 470.00 105.04 7.54 97.50 Pass: Major Risk I, PB L Pad NWE1-01 L-100 V2 309.38 310.00 255.56 5.44 250.12 Pass: Major Risk I ~ PB L Pad NWE1-01 NWE1-01 V5 309.38 310.00 255.56 5.44 250.12 II Pass: Major Risk ' PB L Pad Plan L-203 (N-O) Plan L-203 V6 Plan: PI 503.56 515.00 242.05 9.70 232.35 Pass: Major Risk ', PB L Pad Plan L-205 (S-G) Plan L-205 OBb V6 Plan 559.92 560.00 31.79 10.71 21.08 I Pass: Major Risk ', PB L Pad Plan L-205 (S-G) Plan L-205L1 OBc V9 PI 559.92 560.00 31.79 10.71 21.08 Pass: Major Risk I PB L Pad Plan L-205 (S-G) Plan L-205L2 OBd V7 PI 559.92 560.00 31.79 10.71 21.08 Pass: Major Risk ', PB L Pad Plan L-205 (S-G) Plan L-205L3 OBa V5 PI 559.92 560.00 31.79 10.59 21.20 Pass: Major Risk I, ', PB L Pad Plan L-205 (S-G) Plan L-205L4 OA V4 Pla 559.92 560.00 31.79 10.59 21.20 Pass: Major Risk it ~, PB L Pad Plan L-205 (S-G) Plan L-205L5 Nc V3 Pla 559.92 560.00 31.79 10.59 21.20 Pass: Major Risk I ', PB L Pad Plan L-205 (S-G) Plan L-205PB1 V5 Plan: 559.92 560.00 31.79 10.59 21.20 Pass: Major Risk I PB L Pad Plan L-221 (S-P) Plan L-221 V5 Plan: PI 543.68 545.00 146.65 10.24 136.41 Pass: Major Risk I PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 549.07 550.00 60.07 10.46 49.62 I Pass: Major Risk ~ FieldPrudhoe Bay Site PB L Pad We11:Plan L-220 (S-I) WellpathPlan L-220 -3 1 3 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t Target: L-220 Tgt 1 Nb Site: PB L Pad Well: Plan L-220 (S-1) Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 4105.00 ft below Mean Sea Level Map Northing: 5973955.00 ft Local +N{-S: -4147.47 ft Map Easting :584275.00 ft Local +E/-W: 1069.76 ft Latitude: 70°20' 19.611 N Longitude: 149° 18'58.191 W Shape: Circle - __ _- Radius: 100 ft __ _ _. __ ~~ i -~- 00 -x+200 r; Site: PB L Pad Drilling Target Conf.: 95% Description: Map Northing: 5973655.00 ft Map Easting :584300.00 ft Latitude: 70°20' 16.657N Shape: Circle Target: L-220 Tgt 2 OBd Well: Plan L-220 (S-I) Based on: Planned Program Vertical Depth: 4445.00 ft below Mean Sea Level Local +N/-S: -4447.75 ft Local +E/-W: 1091.43 ft Longitude: 149° 18'S7.559W Radius: 100 d i ~~ ~; 0 0 0 0 0 ~o 0 0 0 0 p~~~ o ~~~~ I~ ~ c~ m -~+~+00 _4-500 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) __ ' Alaska Department of Natural Resources Land Administration System Page 1 of 3 • ~~r;i '~.~c;r ~ ~~~,slats ~~enreie~~'W ~:;.~,~~h StateGabins ~~tu~l Ups __, y, o4.a~ka Nt Case ~umary- File Type ADL File Number: 2$239 ~ Prntabie Case Fi(e_Summ. a.ry See Township, Range, Section and Acreage? New Search~~ ~' Yes ~ No ____~_.___~~ i_A~ 1Uten~~ ~ Case Abstract ~ Case Detail ~ Lund Abstract File: :~UL 28230 ''~~'~' ~ Se<~rch fir Status Plat J ri<at~?s ~s cif 0=1'01 WOOS Cuslo~nef°: 000107377 BP EXPLORATION (ALASKA) INC PO BOX ] 966 t 2/900 E. BEN SON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99519661.2 Case Type: ;~~~ OIL & GAS LEASE COMP DNR Unit: 780 O1L AND GAS Filc Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Dute Initiated: 05/28/1965 Office ofPrimayyResponsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~ NORTH,SLOPF, Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian. U To~rn.~lrij~: O L 2N Rai~~~~: 01 I E .~~°c~ti~>n: ~7 :ti'eclir~it ,'l~r~~s: h-ll) Search Plats Meridiafr: U Toirr~~s~i~i/~~ (.ll ~N Range: 011E ~'cc~r~uz~ ~8 ,St~~~lfur7 icr~~.,~: (i~0 Meridian: U Tulrrlehr~~: Q1~'N Range: 011E ~~e'c~ir,~t.~ 33 .ti's°c~liut7:Icr~~~r. (;-11) [1~feridiara: lJ lrnrns{~rl,. 012N Range: 01.1E ,C~>~lr~~r~: 3~t ,5'~~ctroir;lcrc~s. 6-10 Legal Dcscripiiou OS- 28-196 * * SALE NOTICE LEG 4L DESCRIPTION''` CI ~-17 012N-011 E- UM 27, 28, 33.34 2560.00 04-01-1977 * ~` UNITI7ED, LEASE AND PARTICIPATIlI'G ARFA LEG 4L DESCRIPTION* LEASE CONINIITTED IN ENTIRETI' TO PRUDHOE PAY UNIT AND OIL RNLI GAS CAP PA'S PRU-HOE BAY UNIT http://www.dnr. state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=2823 9&... 4/ 112008 Alaska Department of Natural Resources Land Administration System Page 2 of 3 • • TRACT 18 OIL RIMAND GAS CAP PARTICIPATING AREAS T. 12 N. R. 11 E.. UMIAT MERIDIAN. ALASKA SECTION 2?: ALL, 640.00 ACRES, SECTION 2S: ALL, 6=10.00 ACRES, SECTION 33: ALL, 640.00 ACRES, SECTION 34: ALL, 640.00 ACRES: CONTAINING APPROXIILIATELY 2, 560. DO.ACRES, MORE OR LESS. ~~:k~**~:~*~~=:~*~~*~~x~~~:k:k~~~*~~:~~~~~**:k**~******x**~x*:k~:~~:k~::~*~=****~*~* I I -01-2001 * *FORMATION OF BOREALIS PARTICIPATING AREA LEG_4L DESCRIPTION LEASE INCORPORATED IN ITS ENTIREY INTO THE PA * ~` * * * * * * ~~ PRUDHOE I3AY UNIT BOREALIS PARTICIPATING AREA TRACT I8 T.12N., R.11 E., UMIAT MERIDIAN, ALASKA SECTION 27: ALL. 640.00 ACRES: SUCTION 28: ALL, 640.00 ACRES, SUCTION 33: ALL, 640.00 ACRES: SUCTION 34: ALL. 640.00 ACRES, .THIS' TRACT CONTAINS 2,560.00 ACRES, MORE OR I,E.SS. *~:<>;<;k>:~:;kx:k>;:xY~;k~k*~=k~~x%k**~k~k*>;<*******#**#~k**~k~k;k~e~*x~*;'r-~:*~k~k~*~k*~>;:*#***x 02-01-2004 *'kI'ORMATION OF ORIDN PARTICIPATING ARIi'A LEGAL DESCRIPTION* LEASE C'OAIMITTED IN PART TO ORION PARTICIPATING AREA PR UDHOE I3AY UNIT TR4CT 18 ORIONPARTKIPATING AREA T. 12 N., R. 11 E., U~17IAT MERIDIAN, ALASK~I http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28239&... 4/1 /2008 ~-Alaska Department of Natural Resources Land Administration System Page 3 of 3 • SECTION 27: ALL, 6=10.00 ACRES, SECTION 28: ALL, 6-10.00 ACRES, SECEION 33: EI/2, NI/2NW1/~1, =100.00 ACRES; SECTION 3-1: ALI,, 610.00 ACRES; CONTAINING APPRO_XI~L~ITELY 2,3?0.00 ACRES, MORE OR LESS. ~:xxx*~k~k*x*~*x*~~:=k~F~F*~**~**#;g~~:~*:~~**x***~kxx:k;<;~:~x:~~~~~~xkx~k:t;~:k~kx=k~~k~#~:t Last updated on 04/01/2008. 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Resaurces LAS Nome Capyright Privacy System_Status http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28239&... 4/1 /2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~S'L/ ~ ~ PTD# ~o~~'~ ~ Development / Service Exploratory Stratigraphic Test Non-Conventional Well ~~ ~b® FIELD: Q,PG//~~o~' ,~Ay,~"/~ POOL: _ Q.~°~/ ~c~'~~~ ~!~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throw h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 WELL PERMIT C HECKLI8T Field & Pool PRUDHOE BAY, ORION SCHR BL Ott - 649135 Well Name: PRUDHOE BAY UNIT L-220 Program SER Well bore seg PTD#:2080470 Co mpany BP EXPLORATION~ALASKA) INC initial Classlfype SER ! PEND GeoArea $90 Unii 11650 OnlOff Shore ~_ Annular Disposal ^ Admtnistration 1 Permit-fee attached- - - - - - - - - ~ - - - - NA - - - - - - - - - - - - - - - - - - - 2 Lase number appropriate - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Uniqueweunameandnumbe[--- -- - - -- -- -Yes - -- - -- ---- - - --- -- - - -- -- -- 4 Well located ina_definedpool________________--_-------- --------Yes------ -OrionlSchraderBluff___-___-_-___-__-_------------- -- -- ' 5 Well locatedptoperdistancef[omdriliingunit-boundary------------- ---------Yes----- ------~--------- - -- -- - -- - -- - - -- -- -- 8 Weli lRCated p[oper distance from other wells - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 SutfiCient acreage ayaila4le in dtiUing Snit- - - - - - - - - - - - Yes - - - 2560 - - - - - - - - - - - - - - - - - - - - - - 8 If-deviated, iswellborepiat_included----------------------- -------Yes----- ------------------- -- -- -- 9 Opsrakoronlyaffectedparty_______-_--_-_----------- Yes-- -- - -- - - - - --- -- - -- --- - -- --- -- - -- --- - -- - ~ 10 Ope[atorhas-appropriateboi~diniQrGe---------------------- --------Yes----- -QlanketBond_#fi194193----------------------- - -- --- 11 Pe[mitcaB:be'tssuedwithoutrAnsBrvati9n4rder------------------- ---------Yes------ ---------- -- - - - -- -- Appr Date 92 Permitcanbeissuedwithouladmirristrativ_e_approval---------------- --- -----Yes-.--- ------------------ ---- ~- - - -- -- - -- -- - - -- --- - - 13 Can permit be spRroved before 15-daywait - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - ACS 41212008 14 Welllocated within area and strata authorized by-Injection 0[der- # (put10# in_cammenis)(For_ Yes _ - - _ - _ AIO-26_ . - _ - - _ - _ _ - - - - - _ . _ _ - _ _ - - _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - 15 A1lwelis-within1l4_milearea-ofreyiewidentified(Fotserviceweilgnly)_.--_ -__-__-_Yes------ ------------------------------------ - - -- 16 Pre-produced injector; duration of proProduction less than 3 mor?ths (Forse[vrce well only) - - I~o_ - - - - - ---- - - - - - - - - - - - _ - _ - - _ - - - - _ - - - - - - - - - - - - - - - - - - - 47 Nonconven, gas conforms io AS31.05,03QQ.1,A),(~2.A•D) _ _ _ _ - _ - - - - . - - - _ _ - - - No_ _ _ _ - - . . - - - - - - - - - - - - - - - - - - Engineering 18 Conductor strigg_Rrouided - - - - - - - - - - - - - Y~ - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Aliaquifersexempted 4QCFR147.102_(b)(3)andAE01----------------------------------- 19 Surfacecasingpr4tectsallkn4wn_USDW9_____-._-_-__-__-_--- __--___ ------- - 20 CMT_v-ol adequateto circulate_on conductor & surf-csg _ _ - - - - - - - - - - - - - - - - - - - - -Yes - - - - - - - _ - - - - - - - - 21 CMT_v_oladequate_tofie•inlongstnngtosurfcsg ------------------ ----- - - N0- -- -- - - - - -- - ----- - ---- -- - - - - -- - - 22 CMT-willooveraliknawn_productiyehorizons--------------------- --- -- --Yes------ -----.--------------- --- -- - -- - - - -- - - ---_-- 23 Casirrg desgns adequate for C,_T, 6 &_permafrost - - - - - - - - Yes - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - Rig equiped with steelpits. _No resen!e_pit planned,_ Ali waste reapproved disposatweli(s)- - - - - - - - - - - - - - - 24 _ _ Adequate tankage_or reserve pit - - _ _ - _ _ - - - _ _ _ - - _ - _ _ _ _ _ - - 25 a10.403forgbandon_menlbeenapRrQved------------- has re-drill Jfa ---------~A------- ---- -- -- - - --- - - - - - ---- -- -- -- 26 , _ _ Adequate wellbore separakionproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ _ - _ Proximity analysis performed. Traveling cylinder path calculated, Gyros likely-in surface hole. - _ - _ _ - - - _ _ 27 If djverter required, does rt meet regulations- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling tlwidprogram schematic_8~ equip list adequate- - - - - - - - - - - - - - - - - - - -Yes _ _ _ _ _ _ _ Maximum expQCted formation pressure 8,7_EMW._ PI_anned MW up to 9.2 ppg. _ - - - _ - - - - - - - _ _ _ - TEM 4~~12008. ! rylf~ 29 0 _ 130P~s;_do theymeet regulation! - _ - -- -- BOPE_press ratiflg appropriate; tflst to_(put psig in cemmQnts)_ _ - _ _ Yes - - - - Yes _ _ - - - - - - - - - - - - - - - _ - MASP salCulaied at 1$43psi. 4Q00_psi BOP testplanned, _ _ - - - - _ _ - - _ _ _ - - - - - - - - - ~' ~ 31 Chgke-manifold ccmpties wlAPl_ RP-53 (May 84)- - - - - - - - - - - Yes - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - 32 Wodc will occur without operation shutdown - - - - - - - - - - - - Yes - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - H2S is presen4 inyarious flour streams on L pad. H2S is not reported in SB. - Rig equ)pp~ with, sensarslalerms _ - 33 Is presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - _ _ _ - - - - - - _ 34 I+nechanicatcondftion of welts within AQR yerted (.For service weUonly) - _ - - - _ _ - - - . - Yes - - _ _ - _ There are no wells within 114 mile of L-222 BHL-- - - - - - - - - - - - - - - - - Geology 35 Permit can be issuedwfo hydrogen_sulfide measu[es - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ - H2S levels: L•120=90ppm, L-1Q7=20ppm, L-110=74ppm, L-116=14Qppm, L-01=25ppm. _ - _ _ - _ _ _ - _ _ _ - _ _ - 36 Data-presented on potential overpnsssurelones- - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - ~ - - - - - - - Appr Date 37 Seismic analysis of shallow gas zones - - - ~ - - - - - - - - Y~ - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 4!2!2006 36 Seabed conditionsun!ey_(if4ffshore)--_------------------- NA - ----- --- - - - - - - - - - - - - - - - - - - - - - 39 Contactnamelphoneforweekly_P-~gressrep4ds_(exploratoryo0~1------- ----------Yes----- --Bab_CAOlidge-564-5776----------------------------------- -- - -- - Geologic Commissioner: Engineering Date Date: Commissioner: issi r Date