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Home My WebLink About207-051MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-213 PRUDHOE BAY UN POL W-213 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 W-213 50-029-23354-00-00 207-051-0 G SPT 4741 2070510 1500 2966 2964 2956 2952 240 252 252 252 4YRTST P Austin McLeod 8/12/2024 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-213 Inspection Date: Tubing OA Packer Depth 39 1710 1620 1591IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240812202301 BBL Pumped:1.3 BBL Returned:1.2 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 12:20:23 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-213 207051 500292335400 3 9/23/2023 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 12/01/22 Commissioner Jessie Chmielowski and Commissioner Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: AIO 25A.018 Results of Polymer Injection Trial Prudhoe Bay Unit Polaris Oil Pool W-212 (PTD# 202-066), W-213 (PTD# 207-051) and W-216 (PTD# 207-168) Dear Commissioner Chmielowski and Commissioner Wilson, On August 2, 2021, the Alaska Oil and Gas Commission (AOGCC) granted Hilcorp North Slope, LLC (HNS) administrative approval with Area Injection Order (AIO) 25A.018 to allow for a polymer injection trial into Prudhoe Bay Unit- Polaris Oil Pool (Polaris) wells W-212, W-213 and W-216. Prior to the AIO, polymers were not approved for enhanced oil recovery (EOR) injection into the Polaris Oil Pool under Area Injection Order (AIO) 25A. HNS initiated the Polymer Injection trial in W-213 starting on January 26, 2022. Next, polymer injection began in W-212 on March 31, 2022. Finally, polymer injection commenced in W-216 on April 3, 2022. Polymer injection continued in all three wells until the trial was ended on November 2, 2022. 10-404 sundry reports were submitted to the AOGCC for each affected well on November 23, 2022. Additionally, AIO 25A.018 required a “summary of the results of the injectivity test” be submitted to the AOGCC within 30 days of the completion of the trial. This summary of results of the trial is attached. If you have any questions, please call me at 907-564-5231 or Natalie Brent at 907-564-4313. Sincerely, Stan Golis PBW Operations Manager Attachment: Injection Trial Results Wellbore Schematics Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2022.12.01 16:14:32 -09'00' Stan Golis (880) Polymer Injection Trial Results 12/01/22 Scope of Work: Execute long term polymer injection trial into Polaris oil pool wells W-212 (PTD# 202066), W-213 (PTD# 207051) and W-216 (PTD# 207168) for up to 18 months. Injection Trial Results: Hilcorp has completed a polymer injectivity trial on the Prudhoe Bay Unit – Polaris pool wells W- 212, W-213, and W-216 as of November 2, 2022. The polymer injectivity trial concluded that: x We can successfully inject polymer into the Oba, Obc, and Obd Schrader Bluff layers. x The injectivity dropped by 45% while injecting polymer as compared to produced water after just ~10 weeks of injection. The goal of polymer is to increase the viscosity of the injected water to improve the mobility ratio. The improved mobility ratio results in increased sweep efficiency and higher ultimate recovery within the given pattern. Based on the results of the polymer injection pilot the increase in recovery efficiency does not overcome the loss in injectivity. Since the Schrader Bluff waterflood is relatively immature the drop in total volume being injected will directly impact the offset producer’s oil rate. This would also result in an increase in the processing time for patterns delaying the recovery of that oil. At this time Hilcorp has decided to stop the polymer injectivity trial and return the wells to WAG injectors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y Anne Prysunka at 1:06 pm, Nov 23, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV WCB 11-29-2024 RBDMS JSB 112522 DSR-11/23/22 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU W-213 (PTD 207-051) IPROF 3/18/2022 Please include current contact information if different from above. 207-051 T36489 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.27 13:09:01 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/25/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU W-213 (PTD 207-051) Injection Profile 3/18/2022 Please include current contact information if different from above. 207-051 T36435 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.29 10:18:55 -08'00' Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:207-051 6.API Number:50-029-23354-00-00 PRUDHOE BAY, POLARIS OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028263 Property Designation (Lease Number):10. 8. PBU W-213 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Polymer Injection Trial Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 5571 Effective Depth MD: L-80 11. 7/1/2021 Commission Representative: 15. Suspended Contact Name: Contact Email: Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 3-1/2" Single Feedthru Packers Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 5397 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 4907, 4741 / 5046, 4875 5174, 5001 / 5234, 5061 Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 29 - 3466 29 - 3362 14. Estimated Date for Commencing Operations: BOP Sketch 29 - 109 Structural Proposal Summary 13. Well Class after proposed work: 3-1/2" Dual Feedthru Packers 4942 - 5288 4774 - 5115 3-1/2" 9.2#24 - 5349 Production 5328 5154 5328 None 29 - 109 770 9-5/8" Contact Phone: Date: 80 228020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3437 5750 Intermediate 5536 7" 26 - 5562 26 - 5388 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. No SSSV Installed No SSSV Installed Brian Glasheen brian.glasheen@hilcorp.com 907-564-5277 1955 5 By Samantha Carlisle at 11:24 am, Apr 26, 2021 321-212 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 10:46:19 -08'00' Stan Golis (880) Polymer injection can not begin until AIO 25 is amended to allow this polymer injection trial. DSR-4/26/21 X 10-404 MGR27APR21 DLB04/26/2021 Yeson Required? Comm 4/28/21 dts 4/28/2021 JLC 4/28/2021 RBDMS HEW 4/29/2021 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Job Scope: Polaris Polymer Injection Trial Reg.Approval Req’d? Yes Regulatory Contact: Abbie Barker First Call Engineer: Brian Glasheen Second Call Engineer: Brodie Wages AFE Number: 215-00773 Well Name: W-212 Permit to Drill Number: 202066 Well Type PWI API Number: 50-029-23078-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Well Name: W-213 Permit to Drill Number: 207051 Well Type WAG API Number: 50-029-23354-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Well Name: W-216 Permit to Drill Number: 207168 Well Type WAG API Number: 50-029-23379-00 Current Status: Operable, Online Date Reg. Approval Rec’vd: TBD Estimated Start Date: 7/1/2021 Estimated Duration: 18 months Scope of Work: Execute long term polymer injection trial into Polaris oil pool wells W-212 (PTD# 202066), W-213 (PTD# 207051) and W-216 (PTD# 207168) for up to 18 months. Procedure: 1. Prep Work: a. Ensure well is set up for injection pending waterflood regulator valve testing b. Workover W-212 to install WFRVs (workover sundry to be submitted separately) c. Construct required polymer facilities 2. Inject Polymer into W-213, W-212, and W-216 for ~two months. 3. Inject MI into W-213, and keep W-212 and W-216 on Polymer injection for ~one month 4. Inject Polymer into W-213, W-212, and W-216 for ~two months. 5. Repeat steps 2-4 as needed, timeframes may vary from initial trial period based on performance. 6. Slickline Post Polymer flood work a. Return well to water injection if desired Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 Polaris Polymer Injection Trial Well: W-212, W-213, W-216 PTD: 202066, 207051, 207168 API: 50-029-23078-00, 50-029-23354-00, 50-029-23379-00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission --� DATE: Monday, August 31, 2020 TO: Jim Regg P.I. Supervisor ( It (�� SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. W-213 FROM: Jeff Jolles PRUDHOE BAY UN POL W-213 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-213 API Well Number 50-029-23354-00-00 Inspector Name: Jeff Jones Permit Number: 207-051-0 Inspection Date: 8/14/2020 Insp Num: mitJJ200828143531 Rel Insp Num: Monday, August 31, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-213 In' TVD 4741 Tubing I 1292� 1292 1293 tType iW 2248 2155 2140 - - PTD 2070510 Type Test I SPT-iTest psi II, 1500 JA 454 BBL Pumped: 1 1.2 BBL Returned: -129--1 1.2 OA 242 266 267 267 Interval 4YRTST P/F P i Notes: I well inspected, no exceptions noted. Monday, August 31, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg �r"t`( DATE: Wednesday,August 31,2016 P.I.Supervisor (R Gl ` / ' SUBJECT: Mechanical Integrity Tests f pI BP EXPLORATION(ALASKA)INC. W-213 FROM: Jeff Jones PRUDHOE BAY UN POL W-213 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv2_- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-213 API Well Number 50-029-23354-00-00 Inspector Name: Jeff Jones Permit Number: 207-051-0 Inspection Date: 8/27/2016 Insp Num: mitJJ160827150954 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-213 Type Inj W TVD L 4741 - Tubing 517 520 - 518 - 521 PTD 2070510 Type Test SPT Test psi 1500 - IA 0 2004 - 1923 1912 _ Interval 'WRIST P/F P " OA 270 470 - 406 - 372 Notes: 1.5 BBLS diesel pumped. 1 well inspected,no exceptions noted. , SCANNED JUN 2 320 fila Wednesday,August 31,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, August 14, 2016 11:31 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD W;Zoesch, Eric; 'chris.wal lace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;Grey, Leighton;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; jim.regg@alaska.gov'; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector W-213 (PTD#2070510)To Be Placed on Injection for AOGCC MIT-IA All, Injector W-213 (PTD#2070510) is a mechanically sound well that missed its AOGCC MIT-IA test date,due to being shut in for surface work.The well is now ready to be brought online,and is reclassified as Operable. Please be aware of the fluid-packed annuli when bringing the well online. Plan Forward: 1. Operations: Put on Injection 2. Downhole Diagnostics:AOGCC MIT-IA to 2000 psi Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska -r w (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegritvCoordinator@BP.com SCANNED JAN 1. 8 2017 From: AK, D&C - I Integrity Coordinator Sent: Wednesday, Sep -41 ber 23, 2015 10:34 AM To: AK, OPS GC2 OSM; AK, •, GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, GWO S " Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Zoesch, AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, GWO SUPT Well Integrity; AK, GWO ' -' Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; '.•.regg@alaska.gov' Subject: NOT OPERABLE: Injector W-213 (PTD #2070 S Due for AOGCC MIT-IA All, Injector W-213 (PTD#2070510) is due for an AOGCC MIT-IA on October 15, a 5. The well will not be on injection for the test before the due date. The well is reclassified as Not Operable until the w- 's ready to be placed on injection and will be added to the quarterly Not Operable Injector Report . A copy of the TIO plot is included for reference. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, September 23, 2015 10:34 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Zoesch, Eric; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov' Subject: NOT OPERABLE:Injector W-213 (PTD #2070510) Due for AOGCC MIT-IA Attachments: Injector W-213 (PTD#2070510)TIO Plot.docx All, Injector W-213 (PTD#2070510) is due for an AOGCC MIT-IA on October 15, 2015. The well will not be on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection and will be added to the quarterly Not Operable Injector Report . A copy of the TIO plot is included for reference. Thank you, Kevin Parks :?te: Whitney Petal:, BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 SCANNED JUN 0 1 2016 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com 1 • Injector W-213(PTD#2070510)TIO Plot CO. •M•••01% • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 17, 2011 TO: Jim Regg `� P.I. Supervisor I1 tl 1i N SUBJECT: Mechanical Integrity Tests 13P EXPLORATION (ALASKA) INC W -213 FROM: Matt Herrera PRUDHOE BAY UN POL W -213 Petroleum Inspector Src: Inspector Reviewed By: P.l. Supry ,'- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN POL W - 213 API Well Number: 50 - 029 - 23354 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111017074014 Permit Number: 207 - 051 - Inspection Date: 10/15/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j W -213 ' Type Inj. ' W' I TVD 1 4741 ` rA 90 2000 , 1925 1910 2 070510 " � 15 00 P.T.D TypeTest Test psi OA 168 372 322 287 Interval 4YRTST_ _ P/F P - Tubing 1243 1243 1243 1243 Notes: Ak M t) ' ii r t 0 Monday, October 17, 2011 Page 1 of 1 ` _. _;~ ~,. ~ "" `: ~ ~~ ~~_ . '~~~~ ~ s ~~ ~'~° ~; ~ , L'"~ ~~~ 'wad=.. ~~.:. .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc 2 ~ wl.~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070510 Weli Name/No. PRUDHOE BAY UN POL W-213 Operator BP EXPLORATION (ALASKIy INC MD 5571 ND 5397 Completion Date 6/2/2007 Completion Status 1WINJ Current Status 1WINJ API No. 50-029-23354-00-00 REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes ~ DATA INFORMATION Types Electric or Other Logs Run: / GR, MWD / GR / RES / AZI DEN / NEU / PWD I USIT-CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Dat Digital Dataset Log Log Run Interval OH / T Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ' ED D Asc Directional Survey 0 5571 Open 6l20/2007 pt Directional Survey 0 5571 Open 6/20/2007 •L%g Cement Evaluation 25 Col 1 24 5440 Case 7/3/2007 USIT, DSLT, GPIT, GR, CCL 31-May-2007 / D C Lis 15414JCement Evaluation 2 5382 Case 9/14/2007 LIS Veri, USIT, CCL, GR w/PGF Graphics D C Las 15553 ~Density 100 5571 Open 10/12/2007 DRHB, DRHO, RPM, GR, NPHI, RHOB, ROP w/EMF graphics fieid data ~g Temperature 2 Blu 1 20 5293 Case 10/26/2007 Mem Temp/Pres Survey, GR, CCL, Temp, Pres 29- Sep-2007 '~D C Lis 15658 ~duction/Resistivity 96 5568 Open 11/9/2007 LIS Veri, GR, ROP, FET, RPM, DRHO, NPHI w/PDS graphics ~Cog 15658 Induction/Resistivity 25 Blu 108 5516 Open 11/9/2007 MD Vision Services 29- May-2007 ~og 15658 Induction/Resistivity 25 Blu 108 5516 Open 11/9/2007 ND Vision Services 29- May-2007 Wel! Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070510 Well Name/No. PRUDHOE BAY UN POL W-213 Operator BP EXPLORATION (ALASFC~y INC MD 5571 ND 5397 Completion Date 6/2/2007 Completion Status 1 WINJ Current Status 1 WINJ ADDITIONAL INFORMATION Well Cored? Y ~1 Chips Received? ~^ Analysis Y71~ Received? Comments: Compliance Reviewed By: Daily History Received? ~ N Formation Tops ~ N API No. 50-029-23354-00-00 UIC Y Date: ~_ =1_ J ~- ~'~ 1 . ~ 10/30/07 ~~~~~~~~~~~~ NO. 4349 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 AI8Sk8 Oil & Gas COnS COmm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt., Pt. Mac We^ _Inh it 1 nn DPCCrintinn Date R! Cnlnr C^ L2-11 11686750 RST (y ~c 05/24/07 1 1 3-41/K-39 11873054 RST ^ 06l09/07 1 1 05-22A 11285946 MCNL ~ 10119/06 1 1 P2-22 11649964 MCNL - 'R S' 04/25/07 1 1 OWDW-SW 17211392 RST ($'(p~j" ' 04120/06 1 1 W-213 40015198 OH MWD/LWD EDIT ~ 05/29I07 2 1 YLtASE AGKNOWLEDGE REGEIPT BY SIGNING AND RETURNING ONE COPY E/~Cfl T4: 1; BP Exploration (Alaska) Inc. i~ ~.,~~ ' ~~~_ ~ ~/ ~ E' )J Petrotechnical Data Center LR2-1 y ,,_ , ~- 900 E. Benson Blvd. Anchorage, Alaska 99508 p ~'~~~ ~~~ E~_~ ~ ~'.~~~.)~ Date Delivered: q ,,a'~?~ ~ ~ ..~; ~~ P v ,: ;~~ v_, ~, ~`~e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth ' Received by: ~ ~ ~ MEMORANDUM To: Jim Regg ~~ t/ ~ ~~ ~ P.I. Supervisor ~~ ~~ FROwt: Bob Noble Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Fridly. November 02, 2007 SLIBJECT: Mechanical Integrity Tests BP EXPLORA'I'ION (ALASKA) INC W-213 PRUDFIOE BAY UN POL. W-213 Src: Inspector NON-CONFIDEIYTIAL Reviewed By: P.I. Suprv }~ Comm Well Name: PRUDHOE BAY UN POL W-213 API Well Number: ~0-029-2335a-oo-oo Inspector Name: Bob Noble lnsp Num: mitRCN071029065146 Permit Number: z~~-~51-o Inspection Date: to~25~2007 Rel Insp Num: Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. _ . _ _ _ , Welt i~w-z~3 ~Type Inj w i TVD a~39 IA ~~ »o ?ooo ~~ i9~o t i9oo ' ( ; : . f ._ '~ P.T.DI zo~osio 1TypeTest ' spT f Test psi : zooo pp zoo 3so 3so ~ 340 I ~ _ . ~ _Interval INITAL P/F P__ ~ Tubing iz~o izao I~~o i~~o ~ I _. _ ~ ~ . _ , _ .!_ _ _._ Notes: ~~~l~~ N~J~ ~ ~ 20~7 Friday, Novembf;r 02, 2007 Page I of I ScMumlerger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorege, AK 99503-2838 ATTN: Beth Well Job i! Log Description NO. 4454 Company: Alaska pil 8 Gas Cons Comm Attn: Christine Mehnken 333 West 7th Ave, Suite 100 Anchorege, AK 99501 Field: Polaris Orfon Borealis Date BL Cobr CD W-273 V•215 Z-108 S-1T4 11667175 11594497 77212828 40014242 MEM TEMP/PRESS SURVEY CM EDIT PDC GR USI OH WIRELINE PEX EDIT ` OH MWD/LWD ED17 09/29107 04/23/07 02/05/OB 11/05/06 1 2 3 1 1 1 5-725P81 40015467 OH MWDILWD EDIT ' -(~ 07I07/07 2 1 V-721 40075007 OH MWD/LWD EDIT ~ 03/24/07 2 7 V-222 W-210 40015319 40074842 OH MWDILWD EDIT OH MWDILWD EDIT . O6/08/07 02126/07 2 2 1 1 V-278 40015D68 OH MWD/I.WD EDIT 04/07/07 2 1 W204 40014637 OH MWD/LWD EDIT ~ 01f29107 2 1 W-204P67 40014637 OH MWDIIWD EDIT 01124f07 2 7 W-204L1 40074637 OH MWDILWD EDIT ' 02/07107 7 7 W-204L2 40014637 OH MWD/1_WD EDIT - 1~ 02/20/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Ezploration (Alaska) Inc. Petrofechnical Deta Cente~ .I.F~2-~1, >, r ~ ~i ~~-`~~~ 900 E Benson Blvd i~...a~ `~ :~~ ~~ ,~~~ AnchoregeAK 99508425'q ~ ,t..,.;., _.*~ t ~~ ~ Date Delivered: f~ ~' `i~ a~, ^~ ''ra oi +~~'' ~~i .. ~~A Y...~~6j~ I ~ y 1~ ~ai~:'_A ,~ ~~ ~.~. 1~ . . . '. P:^ I Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth A Received by~_~/~/~~ ~0/19/07 ~ • Saltmarsh, Arthur C (DOA) ~ Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, October 22, 2007 1:40 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU W-213 / PTD # 207-051 Hi Art, Please reference the foliowing well: Well Name: PBU W-213 Permit #: 207-Q51 API #: 50-029-23354-00-00 Top Perf MD: 4942' Bottam PerF MD: 5288' This well began Injectian on C}ctaber 13, 2007 Method of Operations is: Water Injection Na Well Test Data Available 10/23/2007 • Date l0-12-2007 Transmittal Number:92907 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) , f you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delive Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-01C ~~'~ ~a~3'ff___.___._.__ 01-08A ~ _ ~b _,-- Iq~S ~~_--- 01-08AP61 vsC ~~--_~q,~_./,~~c~~ 03-14A l--~ ~vlo oa~ ~ ~S~f t _ - - - 03-36A ~A 5 Tt ~ f~P.i ~- __ _ .__. _ .__ __ 05-36A -~=b?O~',SY1~_______. 05-36AP61 ~o~ _a-~.o ~5s-~ ~ 06-13A~ - ~ - ~.~ 06-13APB1 ~~~ _toa~~y5-^_~F_V 12-05A ~~ ~~ ~~~~T_~ 12-05APB1 s~0~-~63 . "t~Ty~__._u~_.~._.,_. C-22A__,c~C~,o.-~. i15~.K1.`1~_..__._~_r~~:_.. E-15C t G-26 :a n~ ..nc/~' tL~ S~ 6 K-02D ~blo b5(c. _ _'K,1~.5~.!___,. _._.__~. K-02DPB1: -7.O~o-05S~ ~IS~Sa ....._._,. W-21-3V.aa'3- ~si (~ - -~~___-~ -!~~~_.__ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 i a Schtumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2838 ATTN: Beth OB/30/07 NO. 4401 Company: Alaska Oil 8 Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 Field: Well Job # Log Deseription Date BL Polaris Midnight Sun Borealis Color CO E-102 71637355 PRODUCTION PROFILE U" 07128107 1 S-215 NIA USIT 08/Oi/07 1 Z-102 71637125 CH EDIT PDC GR USIT = ~(~ 05116/07 7 I W-213 11638637 CH EDIT PDC GR USIT 05131I07 1 L. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURN~NG ONE COPY EACH TO: „6P F.~cploraUqn„(Alaskd).Irtc s ,'~ k F~rot~~c~niC~l°~J~1ak~~(ec ~R2~n .~ j '_8oa E.B~nsP~s'81v~1~`~ ' _„ ~ .., ~: Anchorage AK 99508~4254 ~ ;r:D~t~eliJ~gred~ Z ~ ~ J ~ „~ ,. ,~y ~ $'~ {:a„y ~ {if1:-:. ~ t~~llfl'~!.'~"s~?~s '~,~ iC:'t l( ;; rtt't! : Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2838 ATTN Beth Received by: ~ • C~ i~'.~,C:3.4i~ICAL i?1'TEGRITY Z:PQP.T ~ ao~~o~ ~ - . - _ ~ li D S~~ p-O~ Q?EtZ c F?~?~ ~~ ~~v ~olCs~S _ _ ., . , ~~ _ ~ ~+ !\U111J~l~ h'~ V ~ _ ~J 1 ~ :._C ..`...~._,. ,.:., . ~ V - ~~ LL ~~T~ ~ . 5s~~ ~_ 53~~ 'I'VD ; ? BTD . s~~c~ ~ 5 3~a `-v~ ~~asi~g: „ ~ Shoe: 5S6a r~ 5 3~SFS ~~ ; liv : N -~ ~ ~1 ~ - =~~ -:.~e= . lJA Shoe. `~ 'I':~ ~ , =~P . '•~D _';~ ~~ - -~o~~v 3~~j Pacicer y O '~D TV7i ; Set at 53~"~ r '1 ~..~c~cc~x~-~ S :ole S-_~e S6'S~K ~nd NL. ~ Per~~ ~+-S~a~ ~o y~,s'ti ~ ~~~:~?1=C~.~.. ~NTEGR?TY - aa,RT #~ r_nr:uius ?~ess Test: _? ; 15 nin ; ~0 min C o~ e n t s: yA~~ ~S~ ~~n c~ Grra1~ S~'C ~i~ T ~' ~ , 'O ~ . ~- 1..-, as oc~ ,~~,, o r.~oc '~ C'r~ N~ C~ ~, ~ NTEGRIT`~ _ PART # 2 ~ S3bh~ Ce~ent Vol~es :~ ~~t. ~iner tJp, ; ~SQ aS~gV ~~V N~ C.~.t -ral to cover ~er=s ~~~o`I.S 3~ ~~~5 S~Ys'r\G.~~c~'"~ ~c~ Gpv2.C"~t'O c'~ ~v SO~I =:eoretical TOC C 30~0 7-S ~O C. ~~10y~ loc~`O~ o~ ~oc~C C~'~~~' yOSC~ ~ . ~ 1~•o"t Cement Bond Log (Yes ar No) ~~S ; In AOGCC Fi1e~_ CBL ~valuation, ~one aoove perfs ~Q`tiEil\.~~A1~L~~~'. ~~~ ~~ ~1~~- ?roduction Log: Tpve ; Evaluat~ on ~;UN4LJS~ONS: ?3i ~ il : ~ci ~ tL: ~ ~ /`~~ ` - l 1 ~ 6'O`~ ~ ~ ~ . S~M~~erge~ NO. 4320 Schlumberger-DCS n ~y g~~ I~ °" ~~~"-°~ Company: Alaska Oil 8. Gas Cons Comm 2525 Gambell St, Suite 4W ~ ~ Attn: Christine Mahnken Anehorage, AK 99503-2838 ~{ ~ ~ 333 West 7th Ave, Suite 700 ATTN: Beth ~19 ~9~~~ ~!~ ~ ~~ ~~, ~ 4 Anchorage, AK 99501 ,~~ Field: Prudhce Bay Orion Borealis Well Job # Log Description Date BL Color CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorege AK 99508-4254 Date Delivered: d~0`~ - ~S~ 4 ,. Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 9950&2838 ATTN: Beth Received 06/29/07 ~ STATE OF ALASKA ~ ALASKA Oll. AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~.~~~iv~r~ .QI~1N 2 7 20Q~ .=~ia~~a ~if ~ Gas Cans. Commissiorr 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zonACZS.~os soa+css.~,o ^ GINJ ~ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: Ao~C ~r~~e ^ Development ^ Exploratory ~ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 6/2/2007 ,d~ 12. Permit to Drill Number 207-051 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 5/20/2007 ~ 13. API Number 50-029-23354-00-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/29/2007 ~ 14. Well Name and Number: PBU W-213 ~ FSL, 1176 FEL, SEC. 21, T11N, R12E, UM 4874 Top of Productive Horizon: 5198' FSL, 2334' FEL, SEC. 21, T11 N, R12E, UM 8• KB (ft above MSL): 81.3' ' Ground (ft MSL): 52.8' 15. Field / Pool(s): _ Prudhoe Bay Field / Polaris Pool Total Depth: 5189' FSL, 2405' FEL, SEC. 21, T11 N, R12E, UM 9. Plug Back Depth (MD+~/D) 5476 ~ 5302 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 612049 y- 5959851 Zone- ASP4 10. Total Depth (MD+1'~/D) 5571 ~ 5397 16. Property Designation: ADL 028263 ` TPI: x- 610886 y- 5960158 Zone- ASP4 Total Depth: x- 610815 y- 5960148 Zone- ASP4 11. SSSV Depth (MD+~/D) None 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No Submit electronic and rinted informa ion r 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1908' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR, MWD / GR / RES / AZI DEN ! NEU / PWD, USIT-CBL ZZ. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH ND HOLE ~~u~' ` WT. PER FL GRADE TOP BOTTOM ' TOR BOTTOM SIZE CEMENTING RECbRU F'~ULLED 20" x 34" 215.5# A53 urface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3466' 29' 3361' 12-1/4" 864 sx AS Lite 367 sx Class 'G' 188 sx AS Lite To Job: 682 sx ASL 7" 26# L-80 26' 5562' 26' 5388' 8-3/4" 254 sx lass'G' 23. Open to production or inject ion? ~ Yes ^ No 2q. : TueiN~ t~ecoao If Yes, list each i (MD+ND of Top & Bottom; Pe nterval open rforation Size and Number): Size ~EPTH SET MD PACKER .SET MD 4-1/2" Gun Diameter 5 spf 3-1/2", 92#, L-80 5349' 4907', 5046', , MD TVD MD TVD 5174', 5234' 4942' - 4954' 4774' - 4786' 5125' - 5148' 4952' - 4975' 25. ' lECib, Fw4CruRE, GEMENT SQUEEZE, ETC. 5194~ - SZZO~ 5OZ'I ~- 504~~ DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED 5248' - 5288' S075' - 5115' Freeze Protect w/ 91 Bbls of Diesel Z6. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N!A Date of Test: Hours Tested: PaooucrioN FoR TEST PERI00 OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Cn~cuu,reo 24-HouR Rnre• OIL-BBI: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: Z7. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND 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 pe~4.E~eA~,c~}~~1. COf~PLETtuPi ~ None ~_ ~ ~~ JUL 0 61D~7 " ~~; ` ~~~ Form 10-407 Revised 02/200Z CONTINUED ON REVERSE SIDE ~~RI~ ~-~~~. ~~~io~ G ZH. GEOIOGIC MARKERS ~LIST ALL FORMATIONS AN RS ENCOUNTERED~: 29. FORMATION TESTS NAME MD ND Well Tested? ^ Yes ~ No Permafrost Top 28.5' 2g.5~ ~f yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1987' 1936' detailed test information per 20 AAC 25.071. Ugnu 3535' 3427' None Ugnu MA 4690' 4533' Ugnu M61 4739' 4580' Ugnu M62 4787' 4626' Ugnu MC 4847' 4683' Scrader Bluff NA 4918' 4751' Scrader Bluff NB 4942' 4774' Scrader Bluff NC 4977' 4808' Scrader Bluff NE 4986' 4816' Scrader Bluff NF 5037' 4866' Scrader Bluff OA 5078' 4906' Scrader Bluff OBa 5125' 4952' Scrader Bluff OBb 5151' 4978' Scrader Bluff OBc 5194' 5021' Scrader Bluff OBd 5246' S073' Scrader Bluff OBe 5313' S140' Scrader Bluff OBf 5353' 5179' Base Schrader Bluff / Top Colville 5400' S226' Formation at Total Depth (Name): Colville Mudstone 5400' 5226' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~ ~ Signed Terrie Hubble Title Technical Assistant Date 0 ~~7 0 7 PBU W-213 207-051 PreparedByName/Number. TerrieHubble, 564-4628 Well Number Drilling Engineer: Ken ANen, 564-4366 Permit No. / A roval No. INSTRUCTIONS GeNew-~: 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. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irem 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multipte stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irenn 27: Provide a listing of intervals cored and the conesponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 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 ~ ~~ Printed: 6/4/2007 6:51:51 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/19/2007 ~ 03:00 - 08:00 I 5.00 I MOB I N I WAIT I PRE 08:00 - 09:00 I 1.001 MOB I P I I PRE 09:00 - 10:00 1.00 MOB P PRE 10:00 - 12:00 2.00 MOB P PRE 12:00 - 16:30 4.50 MOB P PRE 16:30 - 22:00 5.50 MOB P PRE 22:00 - 00:00 2.00 DIVRTR P PRE 5/20/2007 00:00 - 00:30 0.50 DIVRTR P PRE 00:30 - 01:30 1.00 MOB P PRE 01:30 - 02:30 I 1.00 I MOB I P I I PRE 02:30 - 03:30 I 1.00 I RIGU ~ P I I PRE 03:30 - 04:30 I 1.001 RIGU I P I I PRE 04:30 - 08:00 3.50 DIVRTR P PRE 08:00 - 09:00 1.00 RIGU P PRE 09:00 - 09:30 0.50 RIGU P PRE 09:30 - 12:00 2.50 RIGU P PRE 12:00 - 16:00 4.00 RIGU P PRE 16:00 - 17:30 1.50 RIGU P PRE 17:30 - 19:30 2.00 RIGU P PRE 19:30 - 20:00 0.50 RIGU P PRE 20:00 - 21:00 1.00 DIVRTR P PRE 21:00 - 22:00 I 1.00 I RIGU I P I I PRE 22:00 - 22:30 I 0.501 RIGU I P I I PRE 22:30 - 23:30 I 1.001 DRILL I P I I SURF Wait on security. Security busy on Nordic rig and crane moves. Prepare truck shop and satellite camp for move. Peak trucks here @ 03:00 hr. Release trucks. Remobilize trucks ~ 06:00 hr. Back on location ~ 08:00 hr. PJSM with POS. Raise pits and move off Z-102i to entrance to pad. Install jeep for move. Move mechanic shops and satellite camp to W-pad. 'Security on location ~ 08:30 hr. Install jeep on mud pits 5th wheel. Laydown derrick. Position and secure surface stack in cellar. Raise rig. Remove rig mats. Stage rig to edge of Z-pad. Move sub base from Z-pad to W-pad. Position rig in front of W-213i. Install surface stack on W-213i. Continue nipple up diverter spool. Position rig over W-213i conductor. Place matting boards under rig. Position mud pits to sub base. Place' matting boards under pits. PJSM. Inspect and raise derrick. Raise pipe skate chute. Make up kelly hose to topdrive. Make up lines at interconnect. Unbridle from blocks. Pin blocks and torque tube. Secure bridle lines in derrick. `Rig accepted for operations on W-213i ~ 02:00 hr, 5/20/2007. Time rolled back due to 2.5 hrs spent on diverter. Nipple up diverter system. Rig up rig floor tools and equipment. Change out topdrive quill. Load drill pipe and prep pipe shed. Pick up enough drill pipe to TD 8.75" hole. 150 singles, rack back 50 stands in derrick. 24 joints of 4" HWDP, rack back 8 stands in derrick. Make up JAR and collar stand, rack back in derrick. Make up BHA #1: New 1225" HTC MXL-1 bit, 1.5 deg PDM, NM lead DC, NM STAB, MWD, NM STAB, NM XO, orienting sub, 3 ea NM DC. Hold Pre-Spud meeting. PJSM. Rig up Sperry wireline and Gyro Data. Function test and inspect surface diverter system. Test witnessed by AOGCC rep Jeff Jones, WSL R. French, NAD TP Randy Axness. Function test Accumulator. Test PVT's, flow indicator. Check electricians log book for gas monitor calibrations. Per AOGCC rep Jeff Jones: Thaw snow out of diverter line. Build and replace hydraulic hose on diverter knife valve. Reposition Mud Engineer shack and diverter warning signs. Fill hole and check for leaks - OK. Pressure test high pressure mud lines and kelly hose to 3,000 psi - OK. Spud W-213i surface hole @ 22:30 hr, 5/20/2007. Drill from 108' to 185'. 550 gpm, 530 psi off, 650 psi on. 80 rpm, .5k TQ off, 1 k TQ on. PU - 50k, SO - 50k, RWT - 50k. ART - .7 hrs Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-213 W-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Spud Date: 5/20/2007 Start: 5/19/2007 End: Rig Release: 6/2/2007 Rig Number: 5/20/2007 23:30 - 00:00 0.50 DRILL P SURF POH 60' and install NM STAB 5/21/2007 00:00 - 00:30 0.50 DRILL P SURF Continue drilling surface hole from 185' to 272'. 00:30 - 02:00 1.50 DRILL P SURF POH 1 stand to pick up JAR stand. Unable to get stand back to bottom. Pick previous stand back up and wash back to bottom. Tried again with JAR stand without success. Made it back to bottom on second wash 02:00 - 02:30 0.50 DRILL P SURF Drilled appx 3 feet and started getting peanut butter mud back. Stopped drilling and slowed pump rate to get thick mud out of hole. Mud returned to normal. No high PH. 02:30 - 07:00 4.50 DRILL P SURF Start kick-off and directional drill from 275' to 640'. Gyro surveyed to 500'. 560 gpm, 1,000 psi off, 1,230 psi on. 80 rpm, 1.7k TQ off, 2.5k TQ on. PU - 56k, SO - 54k, RWT - 55k, WOB - 15k. *Brief thick mud @ 370'. 07:00 - 07:30 0.50 DRILL P SURF Rig down survey equipment. 07:30 - 12:00 4.50 DRILL P SURF Directional drill from 640' to 1,104'. 650 gpm, 1,730 psi off, 1,900 psi on. 80 rpm, 1.5k TQ off, 3.5k TQ on. PU - 66k, SO - 64k, RWT - 64k, WOB - 15k. AST - 4.88 hrs, ART - 1.82 hrs. 12:00 - 16:00 4.OQ DRILL P SURF Directiona! drill irom 1,104' to 1,773'. 700 gpm, 2,400 psi off, 2,600 psi on. 80 rpm, 1.6k TQ off, 5.5k TQ on. PU - 85k, SO - 75k, RWT - 80k, WOB - 15k. 16:00 - 19:00 3.00 DRILL P SURF Circulate bottoms up 11 times. Pea gravel and sand running throughout circulation. Did not quit, but improved moderately when @ 550 gpm, 40 rpm. 700 gpm, 2,500 psi, 80 rpm, 1.5k TQ for 19,000 pump strokes. Reduce rate to 650 gpm, 2,150 psi, 50 rpm. to 23,000 pump strokes. Reduce rate to 600 gpm, 1,900 psi, 40 rpm. to 28,600 pump strokes. Reduce rate to 550 gpm, 1,700 psi, 40 rpm. to 42,900 pump strokes. 19:00 - 21:00 2.00 DRILL P SURF Pump out of hole (planned) from 1,773' to JARs C 272'. 2.5 to 3 bpm, 450 psi, no rotation. Wiped out minor tight spots (10-20k). 1,126' & 555' 21:00 - 22:00 1.00 DRILL P SURF Run in hole without problem from 272' to 1,055'. Set down hard C~ 1,055'. Attempted to work through without pumping - No progress. (No drag on up strokes), Attempt to work through with 2- bpm with and without rotation - No progress. Attempt to work through staging up to 240 gpm, 40 rpms and made appx 5 ft to 1,060'. Reduce rate back to 2 bpm, 20 rpms and work through at various pipe speeds from 1,055' to 1,060'. Increase pump rate to 250 gpm, 35 rpms and able to work through free to 1,080'. Shut down pumps and lower remaining stand without problem. 22:00 - 23:00 1.00 DRILL P SURF Continue running in hole to 1,677' without problem. 23:00 - 23:30 0.50 DRILL P SURF Precautionary wash last stand from 1,677' to bottom @ 1,773'. No fil~. Continue circulating prior to connection for 1 bottoms up. 600 gpm, 50 rpm, 1,900 psi. Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/21/2007 I23:30 - 00:00 I 0.50I DRILL I P 5/22/2007 ~ 00:00 - 12:00 I 12.00 ~ DRILL I P 12:00 - 13:00 I 1.001 DRILL I P 13:00 - 14:00 1.00 DRILL P 14:00 - 15:15 125 DRILL P 15:15 - 15:45 0.50 DRILL P 15:45 - 16:15 0.50 DRILL P 16:15 - 16:45 0.50 DRILL P 16:45 - 18:00 125 DRILL P 18:00 - 21:00 I 3.001 DRILL I P 21:00 - 22:30 I 1.50I DRILL I P 22:30 - 00:00 I 1.50 ~ DRILL I P 5/23/2007 100:00 - 07:30 I 7.501 DRILL I P 07:30 - 07:45 I 0251 DRILL I P SURF Directional drill from 1,773' to 1,869'. 600 gpm, 1,930 psi off, 2,200 psi on. (Reduced rate for gravel and sand control) 80 rpm, 2k TQ off, 5.5k TQ on. PU - 86k, SO - 72k, RWT - 78k, WOB - 30k. AST - 0.18 hrs, ART - 3.42 hrs. SURF Directionai drill from 1,869' - TD @ 3,476'. 650 gpm, 3,225 psi off, 3,440 psi on. 80 rpm, 3.1 k TQ off, 5.5k TQ on. PU - 110k, SO - 75k, RWT - 97k, WOB - 35k. AST = 2.00 hrs, ART = 6.43 hrs Pea gravel and sand returning at same rate as before wiper trip. SURF Circulate bottoms up 3 x at 700 gpm while reciprocating pipe. 60 rpm, 3350 psi, 2.8k TQ, PU - 110k, SO - 75k, RWT - 97k. Saw no increase or decrease in sand and pea gravel, still returning at steady rate. SURF Pull out of the hole from 3,476' to 2,930', no major overpulls or swabbing. SURF Pump out of hole from 2,930' - 1,790' @ 250 gpm, 800 psi, PU - 90k. SURF Pull 4 more stands out of hole w/ pumps off to 1,400'. PU - 95k. SURF Pump out of hole from 1,400' - 1,236' (~ 250 gpm, 660 psi. SURF Working pipe in tight hole from 1,236' - 1,199'. Jarring and working pipe until free. SURF Continue to pump out of hole from 1,199' - 823'. 530 gpm, 1400 psi, PU - 70k. 80% increase in sand and gravels over shakers. SURF Circulate to clean hole while recipricating stand of pipe 823' - 916' md. Still seeing gravels and sand over shakers 2-3 inches thick. Cuttings box filling quickly. Mobilize additional trucks and reduce circulation rate from 530 gpm to 150 gpm C~ 320 psi until cuttings box empty and trucks standing by. SURF Bring pumps back to full rate and continue to circulate CBUx6 while reciprocating 823' - 916'. 530 gpm, 1350 psi, PU - 67k, SO - 60k. After 3 bottoms up, gravels and sand across shakers reduced by 40% and remained steady. SURF Wash and Ream from 9i 6' to 1102'. At 1055' hit obstruction and work down hole. Worked hole repeatedly using pump rates from 105gpm ~ 370psi - 525gpm @ 1410 psi and 0-80 rpm. RTW - 70k. Each time obstruction moved downhole, BHA picked up above and made to pass w/ pumps off. SURF Continue to wash and ream from 1,102' to 3,399'. Washed each stand down ~ 300 gpm, 750 psi, 25 rpm, then increased pump rate to 510 gpm, 1650 psi to pull stand, then shut down pumps & rotary and RIH for next connection. CBUx2 in 30 min every 5 stands. Returns over shakers still -2 inches deep and split -70% sand, 30% pea gravel w/ small amounts of wood. SURF Wash down last stand from 3,399 - 3,476' md. No fill seen. 525 gpm, 2480 psi, 45 rpm, 3.2k TQ, PU - 100k, SO - 85k, RTW - 90k. Printed: 6/4/2007 6:51:55 AM ~ ~, Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/23/2007 07:45 - 10:15 2.50 DRI~L P SURF CBU x4 while reciprocating and rotating last stand. 525 gpm, 2480 psi, 45 rpm, 3.2k TQ, PU - 100k, RTW - 90k Steady stream of gravel up to pea size, sand, and wood in returns. Prior to POOH, shut down pumps and rotary and RIH to TD ~ 3,476' md. 10:15 - 12:00 1.75 DRILL P SURF Pump out of hole without rotation from 3,476' to 2,729' md. PU - 110k, 525 gpm, 2245 psi. ' 12:00 - 15:30 3.50 DRILL P SURF Pump out of hole without rotation from 2,729' to top of BHA ~ 272' md. PU - 60k, 525 gpm, 1300 psi. 15:30 - 17:30 2.00 DRILL P SURF Pull out of the hole from 272', Standing back jars & drill collars. , Break bit and lay down UBHO sub, MWD, NM stab, NM lead I collar, and 1.5 degree motor. Bit grade 4-6-WT-A-E-2-RG-TD. I 17:30 - 18:30 1.00 CASE P SURF Make dummy run with 9 5/8" madral casing hanger. Hanger on seat w/ landing joint 28' in and 7' out. 18:30 - 20:00 1.50 CASE P SURF Rig up Nabors casing equipment. Change out bails and make ' up franks fill up tooL , 20:00 - 21:00 1.00 CASE P SURF PJSM. Run 9-5/8" 40# BTC surface casing. Baker Loc shoe I track. Check floats. Run bow spring centralizer on joint 1 10' I back from shoe. Average make up tq 9000 Wibs. Able to run 7 joints in with pumps off until -300' md before setting down. Attempt to work pipe and lost 18 inches. 21:00 - 00:00 3.00 CASE P SURF Begin circulating 9-5/8" casing down from 300' to 1,023' md. ! 250 gpm, 365 psi. Flow line temp 58 degrees. Taking 5-7k I weight intermittantly, but no problem to slowly work through. I No over pull while working casing on the up stroke or indication of pack off on the down stroke. Sand, Pencil eraser sized gravel and small pieces if wood coming across shale shakers. 5/24/2007 00:00 - 02:30 2.50 CASE P SURF Continue circulating 9-5/8" casing down from 1,023' to 1,454'. 250 gpm, 365 psi, SO - 70k. Flow line temp 56 degrees. i Taking 5-7k weight intermittantly, but no problem to slowly I work through. No over pull while working casing on the up stroke or indication of pack off on the down stroke. Sand, Pencil eraser sized gravel, and small pieces of wood coming across shale shakers. 02:30 - 03:00 0.50 CASE P SURF Hole taking solid weight at 1,454' md. Attempt to pass w/ ' pumps off, pumps ~ 150, 250, 300 gpm. After setting weight down hard, eventually made 6 feet with pumps ~ 300 gpm to 1,460'. Between 1,454' & 1,460', hole took 20k weight on first pass through before setting down again at 1,460'. Subsequent passes showed full SO of 70k until setting down at 1,460'. 03:00 - 06:00 3.00 CASE P SURF Continue to work 9-5/8" casing from 1460 - 1463'. PU - 90k, ' SO - 70k, 300 gpm, 420 psi. Making slow progress. No I change in returns across shale shakers. I 06:00 - 12:00 6.00 CASE P SURF Continue to work 9-5/8" casing from 1,463' - 1,478'. PU - 90k, SO - 72k. Vary pump rates between 245 gpm, 345 psi and 300 gpm, 345 psi. Still making slow progress pushing a solid obstacle downhole bit by bit. Returns across shale shakers , have reduced significantly. Returns still have sand, small gravel, & small wood pieces. 12:00 - 23:30 11.50 CASE P SURF Continue to work 9-5/8" casing from 1,478' - 1,790'. PU - 95k, SO - 75k. Vary pump rates between 200 gpm, 325 psi and 315 Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRIL.LING i Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/24/2007 12:00 - 23:30 11.50 CASE P SURF gpm, 495 psi. Still pushing a obstacle downhole at different times until -1,750'. After 1,750' md, fought and washed through built up debris until 1,790'. 23:30 - 00:00 0.50 CASE P SURF Circulating 9-5/8" casing down from 1,790' to 1,830'. 260 gpm, 410 psi, PU - 98k, SO - 70k. No losses to tormation for the day. 5/25/2007 00:00 - 06:00 6.00 CASE P SURF Continue circulating 9-5/8" casing down from 1,830' to 2,700' md. 260 gpm, 450 psi. Casing washing down smoothly. Shale shakers showing small amount of sand, gravel, & wood. MU TAM Port collar in string to land ~ 723' md. 06:00 - 10:30 4.50 CASE P SURF Continue circulating 9-5/8" surface casing down from 2,700' to 3,466'. Wash fill off of bottom from 3,458' to TD. SO - 92k, did not record PU. Land 9 5/8" surface casing on ring ~ 3,466' with mandral hanger. Pump rate 250 gpm, 440 psi. 10:30 - 12:00 1.50 CEMT P SURF Circulate and condition mud at 280 gpm 550 psi while reciprocating pipe in 8' strokes. PU - 161 k, SO - 95k. 12:00 - 15:30 3.50 CEMT P SURF Circulate and condition mud at 286 gpm 427 psi while reciprocating pipe in 5' strokes. Land casing back on ring to RU for cementing. PU - 164k, SO - 114k. 15:30 - 16:00 0.50 CEMT P SURF Rig down franks fill up tool. Blow down lines. Make up cement head and manifold. 16:00 - 17:00 1.00 CEMT P SURF Stage up pumps to 203 gpm, 496 psi. 8egin to reciprocate pipe. Pipe took 375k up weight to move. Continue to circulate and work pipe in 5-7 foot strokes until up weight was 225k and down weight was 85k - 95k, but PU began increasing and SO decreasing as mud thinned. Sand beginning to run and seen on shakers 1/2" thick on 2 shakers. Landed casing back on hanger. 17:00 - 21:45 4.75 CEMT P SURF PJSM w/ Schlumberger cementers. Batch up cement. Pump 5 bbls water, test lines to 3500 psi. Pump 79 bbls of 10.5 ppg mud push. Drop bottom plug, pump 691 bbls of lead 10.7 ppg cement. 5.9 bbl/min with full returns until cement turned the corner at the shoe. After lead went around the shoe (250 bbls away), returns slowly began falling off to -40% ot full returns. Pumped 57 bbls 15.8ppg G cement and 20 bbls 15.8ppg G w/ durastone at 5 bpm. After tail pumped and dropped top plug returns went to 0%. Wash up with 10 bbls of water. Switch to rig pumps and displace cement ~ 5 bpm. Good lifting pressure gradually built up from 460 psi to 1067 psi. Saw good indication w/ pump pressure of 15.8ppg tail cement turning comer and moving up hole. C~ 110 bbls into displacement, fluid level in riser started to drop C-6" per minute. Slow rate to 2 bbl/min and bump plug and hold at 1680 psi. Bleed off and check floats. CIP @ 21:37. 21:45 - 00:00 225 CEMT P SURF Rig down cement head. Blow down lines. Back out and lay down upper section of split landing joint. Change out bails and handling equipmeni. Clean & clear rig floor. 5/26/2007 00:00 - 02:00 2.00 CEMT P SURF PJSM w/ PES for remedial cement job. Pick up Tam port shifting tool and run in the hole w/ 4" HW DP to 720'. RU to open Tam collar. 02:00 - 02:15 0.25 CEMT P SURF Take parameters prior to latching into collar. PU - 49k, SO - 48k. Slowly RIH to 726' md. 1 k slack off spike indicates dogs Prinied: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILL)NG I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/26/2007 02:00 - 02:15 0.25 CEMT P SURF engaged in collar. Pull up 15k over PU to confirm latch. Mark collar closed position on DP. Pressure test sleeve and shifting tool cups to 1000 psi - OK. Bleed pressure to 300 psi. Slack off 10k below string weight and shift collar open 7". 300 psi bled down to 100 psi after 3 inches of down travel. After sleeve open, PU to neutral weight. 02:15 - 02:30 0.25 CEMT P SURF Break circulation and pump mud through Tam cotlar @ 3 bpm. Pressure built to 725 psi before breaking over to 530 psi after 30 bbls away and slowly falling off afterwards to 400 psi. Initial fluid on backside was below surface hanger and out of sight. No sign of fluid returning to surface. Shut down pumps w/ 50 bbls mud away. 02:30 - 03:00 0.50 CEMT P SURF Regroup and consult w/ anchorage drilling engineer. 03:00 - 03:30 0.50 CEMT P SURF Close Tam collar. Pick up to 5k over string weight and shift collar closed. Pressure up to 1000 psi to confirm closed - OK. Maintaining 5k overpull, rotate to release dogs from collar. After overpuil dropped off and dogs released, Pressure test again to 1000 psi to confirm still closed - OK. PU string 20' and standby. 03:30 - 06:00 2.50 CEMT P SURF Mobilize equipment for 1" top job. Send cementers for rest prior to next attempt at remedial cementing. Notified AOGCC Rep. Bob Noble of upcoming remedial cementing operations. 06:00 - 13:30 7.50 CEMT N WAIT SURF Waiting on a fresh cementing crew. Continue to arrange equipment for 1" top job. Prepare 7" casing string for later running. 13:30 - 14:00 0.50 CEMT P SURF PJSM w/ rig crew, TAM port collar, and cementing personel. Slowty RIH to 726' md. Saw weight indication of dogs engaged in collar. Pull up 15k over PU & confirm latch. Pressure test sleeve and shifting tool cups to 1000 psi - OK. Bleed pressure to 320 psi. Slack off 10k below string weight and shift collar open 7". 320 psi bled down indicating sleeve open. After sleeve open, PU to neutral weight. 14:00 - 14:30 0.50 CEMT P SURF Break circulation and pump 20 bbis 9.2 ppg mud through Tam collar. Initial pump rate 35 gpm. Pressure built to 655 psi before breaking over to 490 psi. Increase rate to 84 gpm until 20 bbls away. Initial fluid on backside was below surface hanger and out of sight. ' 14:30 - 19:00 4.50 CEMT N SFAL SURF Drilling Fluid observed in adjacent cellars from prior operation. i Shut down pumps. Close TAM collar. Notified 5700. ACS Vic Richards arrived on site for spill evaluation. Clean in & around cellars for wells W-200, W-204, W-224 w/ ACS and super suckers. Attempt to diagnose leak source. Fill 20" x 9-5/8" annulus w/ water and fluid level falling. Observe water level rising in cellar of W-204. Leak path not from TAM port collar. Drain riser, consult Anchorage on plan forward. Note: -1730 discussed situation in detail with Jim Regg of AOGCC in Anchorage. 19:00 - 21:00 2.00 CEMT P SURF PJSM w/ rig crew, TAM port collar, and cementing personel. , Pump 15 bbls water to fill lines. Pressure test lines to 2500 psi. ' Pump 150 bbls 10J ppg cement with 2 Ib/bbl Cem-Net at 4 bbl/min 310 psi. Chased cement w/ 10 bbls water to clear lines Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: W -213 W-213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Spud Date: 5/20/2007 Start: 5/19/2007 End: Rig Release: 6/2/2007 Rig Number: 5/26/2007 19:00 - 21:00 2.00 CEMT P SURF and drillpipe. No returns during entire job - 20" x 9-5/8" fluid level remained below fluted hanger. 21:00 - 21:15 0.25 CEMT P SURF Close Tam collar. Pick up to 5k over string weight and shift collar closed. Pressure up to 1400 psi to confirm closed - OK. Maintaining 5k overpull, rotate to release dogs from collar. After overpull dropped off and dogs released, Pressure test again to 1400 psi to confirm still closed - OK. PU string 20', pressure up to 2170 psi and burst rupture disk in choke sub on shifting tool. 21:15 - 22:00 0.75 CEMT P SURF Pump 50 bbls 1.5 annular volumes mud down drillstring and up 9-5/8" casing to clear casing of any cementing debris. 5% of returns were thickly gelled contaminated mud. Took returns over split landing joint and out of 4" valves in conductor to cellar. 22:00 - 23:00 1.00 CEMT P SURF Pulf out of the hoie with tam running tool and lay down the same. 23:00 - 00:00 1.00 CEMT P SURF Prepare shed and tools for running in hole with 1-3/8" hydril pipe for top job. 5/27/2007 00:00 - 01:00 1.00 CEMT P SURF Rig up 1-3/8" CS Hydril top job pipe and run it through diverter stack and through fluted hanger to'130' without resistance. Tag up ~ 130' and RU to circulate pipe down. 01:00 - 02:00 1.00 CEMT P SURF Pump at 2 bbl/min 600 psi 9.2 ppg 100 vis mud to bring fluid level up to flowline. ~luid level at flowline at 78 bbls away. Shut down pumps and fluid level falling through riser. In 5 minutes, fluid level dropped 10 feet. RU to take returns to cellar via 4" valves to minimize hydrostatic on formation. 02:00 - 02:45 0.75 CEMT P SURF Bring pumps online at 2 bpm, 600 psi pumping down 1" pipe and taking returns to 4" valves in cellar. RIH w/ 1" pipe and rotate through obstructions while pumping. Able to feel gravels on pipe as working pipe downhole. Pump pressure gradually built up to 760 psi. Work pipe down to 200' below rotary table. Unable to work pipe past. 02:45 - 04:15 1.50 CEMT N WAIT SURF Wait on fresh cementing crew to arrive on location. Pick cementing string up to 180' md rkb. to keep from packing off. Break circulation every 30 minutes for .5 bbls @ 1 bpm, 300 psi. 04:15 - 05:00 0,75 CEMT P SURF RU Dowell cementers. Continue to break circulation every 30 minutes to ensure no packoff. 05:00 - 06:00 1.00 CEMT P SURF PJSM w/ rig crew and cementers. Break circulation wl rig and work pipe back down to 192' md rkb. Cementers pressure testing lines and prime pumps and begin to batch cement. Ready cellar for cementing returns. Note: AOGCC Rep. Bob Noble on location to witness remedial cementing. 06:00 - 12:00 6.00 CEMT P SURF Begin pumping cement job. Pump 130 bbis 10.7# ASL cement w/ 2#/bbl CemNet followed by 415 bbis 10.7# ASL cement w/o CemNet @ 1.5 bpm, 370 - 420 psi. Cement returns to surface after total of 545 bbls cement pumped. Wash out lines and top job pipe w/ 5 bbls H2O. Maintained full returns through entire job. 555 bbls of returns hauled off from cellar. 12:00 - 13:00 1.00 CEMT P SURF Attempt to work 1-3/8" cementing pipe out of annulus but unable. Blind back off top joint of pipe w/ wrenches from rig floor. Connection backed off was 8' below rig floor. Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/27/2007 I 13:00 - 14:30 I 1.501 CEMT I P I I SURF 14:30 - 16:00 I 1.50I CEMT ( P I I SURF 16:00 - 17:30 1.50 DIVRTR P SURF 17:30 - 19:00 1.50 WHSUR P SURF 19:00 - 22:00 3.00 BOPSU P SURF 22:00 - 22:30 0.50 BOPSU P SURF 22:30 - 00:00 1.50 BOPSU P SURF 5/28/2007 00:00 - 02:30 2.50 BOPSU P SURF 02:30 - 06:00 I 3.501 DRILL I P I I PROD1 06:00 - 07:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 07:30 - 08:30 1.00 DRILL P PROD1 08:30 - 10:30 2.00 DRILL P PROD1 10:30 - 11:00 0.50 DRILL P PROD1 11:00 - 13:00 2.00 DRILL P PROD1 Schlumberger powell cementers leaked 2 bbls of cement rinsate to pad. Galled 5700 and notified Bill Richards. Clean up under & around cementing unit as per ACS rep. Rig down Dresser sleeve and turnbuckles from between rig floor nipple and drilling riser. After sleeve removal, top joint of 1-3/8" pipe can be handled. Using two 36" pipe wrenches, crew backed out next two joints of 1-3/8" pipe. Top stub of cemented pipe now in the hole at -38' below ground level. Lay down drilling riser. Change out pitcher nipple. Remove diverter stack from wellhead. Prepare tubing spool & wellhead. Position spool on wellhead. Run in set screws to 450 ft-Ibs. Test metal to metal seal to 1000 psi for 10 minutes - OK. Position BOP stack on tubing spool. Nipple up stack. Make up turnbuckles, riser, casing & tubing working valves. Flush stack. Make up BOPE floor equipment. Install test plug. Fiil all testing lines. Test BOPE & Floor manifold to 250 psi low and 4000 psi high . Test Annular preventer to 250 psi low and 3500 psi high. W itness of test waived by AOGCC representative Bob Noble. Test witnessed by BP WSL Matt Martyn & NAD Toolpusher Brian Tiedemann. Continue to test BOPE & Floor manifold to 250 psi low and 4000 psi high . Test Annular preventer to 250 psi low and 3500 psi high. Witness of test waived by AOGCC representative Bob Noble. Test witnessed by BP WSL Matt Martyn & NAD Toolpusher Brian Tiedemann. Pick up BHA #2 consisting of 8-3/4" MX2022-B1 Hycalog PDC bit, Powerdrive 675 rotary steerable unit, slow speed, 0 degree, motor, ARC, MWD, ADN. Load nuclear source in ADN. Run in the hole with remaing BHA from the derrick to 723'. Rotate past TAM Port collar from 723' to 995' w/ 25 rpm and no pumps. Pressure test casing to 1000 psi for 5 minutes after BHA past TAM collar - OK. Shallow test MWD ~ 995'. 585 gpm, 1950 psi - OK. MU Ghost reamer. RIH w/ drilipipe from derrick 995' to 3,212' md. Cut and slip 72' drilling line. Clean & inspect under drawworks. Service rig. Lubricate top drive. Rig up test equipment and test casing to 3500 psi for 30 minutes. Recording pressure. Wash down. Begin drilling cement at 3,368'. Drill cement, landing collar, shoe, and rathole to 3,476'. Tag collar on depth at 3,383' md and shoe on depth at 3,466'. 555 gpm, 2635 psi. 50 rpm, 4k tq. on 3 tq off. 3-5k WOB. PU - 110k, SO - 85k, RTW - 96k. 13:00 - 14:00 I 1.001 DRILL I P I I PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 00:00 9.00 DRILL P PROD1 Drill 20' of new hole to 3,496' MD. Begin displacement to new 9.Oppg LSND mud at 3476' MD. Mud weight in = mud weight out = 9.0 ppg. Perform leak off test to 1050 psi EMW of 15.0 ppg. Take benchmark ECD readings. Calculated & actual clean hole ECD at 60 rpm = 9.41 ppg correction factor was -0.13ppg. Drill 8-3/4" hole from 3,496' to 4,360'. 585 gpm, 2200 psi on, Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5/28/2007 ~ 15:00 - 00:00 5/29/2007 ~ 00:00 - 06:00 06:00 - 12:00 12:00 - 15:30 15:30 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 23:30 W-213 W -213 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 9.00 I DRILL I P 6.001 DRILL I P 6.00 DRILL P 3.50 DRILL P I 0.50 DRILL P 2.00 DRILL P 0.50 DRILL P 1.50 DRILL P 3.50 DRILL P Start: 5/19/2007 Rig Release: 6/2/2007 Rig Number: PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 23:30 - 00:00 0.50 DRILL P PROD1 5/30/2007 00:00 - 01:00 1.00 BOPSU P RUNPRD 01:00 - 02:00 1.00 BOPSU P RUNPRD I 02:00 - 02:30 0.50 BOPSU P RUNPRD 02:30 - 03:45 I 1251 BOPSUq P I I RUNPRD 03:45 - 05:30 I 1.75I CASE I P I I RUNPRD Spud Date: 5/20/2007 End: 2065 psi off. 60 rpm - 40 rpm, 3.9k tq on, 3.4k tq off. Up wt. 123k. S/O 99k. Rot wt. 110k. ART = 6.47 Hrs. Actual ECD = 9.61 Calculated ECD = 9.58 Drilled 1 st stand down after LOT at 0 surface rpm. Drilled 3,580 - 4,140 f~ 60 surface rpm & tool building in hold mode. Reduce rpm and drill 4,140 - 4,360 C~3 40-45 surface rpm and steering improved. Pumped High Vis sweep @ 4000' md. 50% increase in cuttings once back at surface. Drill 83/4" hole from 4,360' - 4,780'. 585 gpm, 2290 psi on, 2180 psi off. 40 rpm, 4.2k tq on, 3.6k tq off. Up wt. 127k. S/O 104k. Rot wt. 115k. Drilled from 4,600' - 4,630' @ 70 surface rpm for testing purposes prior to turn and drop section. Drill 8-3/4" hole from 4,780' - 5,150'. 585 gpm, 2480 psi on, 2365 psi off. 40 rpm, 5.Ok tq on, 4.Ok tq off. Up wt. 135k. S/O 110k. Rot wt. 121 k. 15k WOB. ART = 9.63 Hrs. Actual ECD = 9.55 Calculated ECD = 9.45 Drill 8-3/4" hole from 5,150' - TD @ 5,571'. 585 gpm, 2,760 psi on, 2365 psi off. 60 rpm, 5.4k tq on, 4.5k tq off. Up wt. 141 k. S/O 115k. Rot wt. 124k. 10k WOB. ART = 3.06 Hrs. Actual ECD = 9.76 Calculated ECD = 9.44 Circulate one open hole volume C~3 585 gpm, 2539 psi, 60 rpm, 4k TQ. CECD = 9.44, AECD = 9.65. Shut down, monitor well - OK. RIH tag bottom C 5,571' md without pumping. PU - 150k, SO - 117k with no pumps. Backream Ghost reamer into casing shoe and bit to 4,456' md (above deepest ghost reamer depth). 585 gpm, 80 rpm, 2380 psi, 4.5k TQ. CBU C~ 4,456'. 585 gpm, 2315 psi, Initial ECD = 9.67, final ECD = 9.62. Monitor well - OK. MW in 9.Oppg, MW out 9.Oppg. Pump dry job. POH to BHA. No overpulls or probiems seen while POOH. PJSM. Lay down BHA #2. Powerdrive tool is worn over 1/8" within 5 feet of bottom and at paddles. Bit grade: 3-2-BT-A-O-I-RO-TD. Clean and clear rig floor of all BHA handling equipment. Puli wear bushing, flush BOP stack and install BOPE test plug. Change out upper pipe rams from 3.5" x 6" VBRs to 7". Rig up and test 7" ram door seals to 3,500 psi - OK. Rig down test equipment. Make dummy run with 7" hanger and landing joint. Rig up to run casing. PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 BTC-M casing to 900'. 21 jts of BTC-M pups, 1 marker jt. w/ 2-pip RA tag. Make up casing to mark with average make-up torque of 9,200 ft/Ibs. Used BOL-2000 M pipe lubricant. Fill each joint and break circulation Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: ; #3~te ~rom - Tc~ ~(c~urs ~T'a~k Cc~c~e N~7 F~h~~e ~ ~~s~ri~t'rc~r~ c~f;C3~eratic~r~s '`°~~ , ,~ 5/30/2007 03:45 - 05:30 1.75 CASE P RUNPRD every 20 joints for 3 minutes. 05:30 - 06:30 1.00 CASE P RUNPRD Rig up Torque turn equipment for TCII casing. 06:00 - 12:00 6.00 CASE P RUNPRD Continue running in hole C~2 1.5 minutes per joint with 7" 26# L-80 TC-II casing from 900' to 4,125'. Fill each joint and break circulation every 10 joints for 3 minutes. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 79 joints of TC-II casing run so far. 12:00 - 15:00 3.00 CASE P RUNPRD Continue running in hole @ 1.5 minutes per joint with 7" 26# L-80 TCII casing from 4,125' to 5,562'. Torque Turn casing to make-up torque of 10,100 fUlbs. Fill each joint and break circulation every 10 joints for 5 minutes. Pick up 7" hanger, landing joint and land casing on depth ~ 5,562', Up wt 185k Dn Wt 135k. Used JetLube Seal Guard pipe lubricant. 113 total joints of TC-II casing. HES Float Shoe - Bottom @ 5,562' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Landing Collar - Top @ 5,476' 8 Jts 7", 26#, L-80 BTC-Mod (#3-10) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA C~ 5,130' 11 Jts 7", 26#, L-80 BTC-Mod (#11-21) 7", 26#,L-80 TC-II X BTC-Mod Crossover Pup. 113 Jts 7", 26#, TC-II (#1-113) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Total of 60 - 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers: 2-locked back to back 5' from shoe. BTC-M jts 4-21, XO jt, & TC-11 jts 1-9 have 2 free floating per joint separated by stop ring in middle. 20' BTC-M marker jt & TC-11 jt #10 have one free floating. 15:00 - 15:30 0.50 CEMT P RUNPRD Rig down Frank's tool. Make up cementing head. 15:30 - 17:00 1.50 CEMT P RUNPRD Break circulation. Stage pumps up to 5 bpm, 480 psi. Condition mud for cementing. Held cementing PJSM while circulating. Reciprocate casing 8 ft strokes. PU - 174k, SO - 130k. 17:00 - 18;00 1.00 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 20 bbls 10.8 ppg of MudPush II viscosified spacer ~ 5 bpm, 550 psi. Batch mix and pump 53 bbls of Class "G" 16.0 ppg cement C~ 5 bpm avg, 1125 - 560 psi. Wash out cementing lines through T. Drop plug swap to rig pumps. 18:00 - 18:30 0.50 CEMT P RUNPRD Switch to rig and dispiace cement with 210 bbls of seawater. 1st 190 bbls ~ 5 bpm, 171 psi ICP, 759 psi FCP. Stopped reciprocating and landed casing with 200 bbis away. PU - 142k, SO - 105k. Last 20 bbls @ 2 bpm, 759 psi ICP, 1,170 psi FCP. Bumped plug at calculated strokes with 95% pump efficiency to 1,700 psi. CIP @ 18:30 hr. Bleed off pressure, check for flowback - OK. 18:30 - 20:00 1.50 CEMT P RUNPRD Pressure test casing to 4,000 psi. Pressure bled off 300 psi on 1 st attempt. Bump pressure back up to 4,000 psi, and pressure bled down 100 psi. Good pressure test on 3rd attempt. 20:00 - 22:00 2.00 CEMT P RUNPRD Lay down all casing and cementing equipment Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/30/2007 I 22:00 - 23:00 1 1.001 CASE I P 23:00 - 23:30 0.50 CASE P I 23:30 - 00:00 0.50 BOPSU P 5/31/2007 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:00 ~ 0.50I PERFOB~ P 02:00 - 03:30 I 1.501 PERFO~ P 03:30 - 05:00 1.50 PERFO P 05:00 - 05:30 0.50 PERFO P 05:30 - 07:30 2.00 PERFO P 07:30 - 09:30 2.00 PERFO P 09:30 - 09:45 I 0.25 09:45 - 11:00 1.25 P 11:00 - 14:30 3.50 P P P P RUNPRD Install 7" Packoff and run in lock down screws. Torque to 450 ft-Ibs. Test to 5000 psi for 10 min., Good Test. RUNPRD Perform LOT Down OA = 13.Oppg assuming 9.Oppg mud on backside. -Pump rate @ 10 spm , ICP - 100 psi -Pump 2.7 bbl, FCP 680 -Shut in pressure after 5 min = 500 psi Top of 10.8 ppg mudpush unknown. LOT may be higher than 13ppg if mudpush in OA. OTHCMP Change Upper Pipe Rams to 3 1/2 x 6 variables OTHCMP Change Upper Pipe Rams to 3 1/2 x 6 variables & test door seals to 3500 psi. OTHCMP RU equipment for DPC perforating. Note: Continuing to injected 1 bbls of 9.0 ppg mud every 1 hours @ 1/2 bpm: 700 psi, 560 SIP 700 psi, 600 SIP 705 psi, 550 SIP 710 psi, 600 SIP 705 psi, 600 SIP. OTHCMP PJSM. Pick up and make up 4.5" HSD Power Jet Omega 4505 5 SPF DPC perforating guns (8 ea loaded or partial guns, 10 ea blanks, including 7 ea blank punchers), XO, 1 jt 3.5" HWDP, bumper sub, MWD, XO, 1-stand 4" HWDP, 10 ft pup joint. OTHCMP Run in hole with DPC perf assembly from 580' to 2,155'. 'Note all depths reported are to bottom nose. G/R sensor is 453 ft up from bottom nose. OTHCMP Test MWD ~ 290 gpm, 585 psi - OK. OTHCMP Continue to RIH w/ DPC guns and tag f(oat collar on depth C~3 5,476'. PU 133k, SO - 105k. OTHCMP Log to correlate depth to reference log - MWD Realtime field print 29-May-2007. 230 gpm, 475 psi while displacing well from seawater to 9.0 ppg brine . GR log found BHA on depth to casing pipe tally. No depth correction needed. Log confirmation pass - OK. Log into position & set on depth w/ Top shot @ 4,942, 8ottom nose ~ 5,289'. "UCA compressive strength - 500 psi @ 08:00, 1030 psi @ 09:00. OTHCMP Perforate well. Initiate firing sequence by pump and bleed. Wait 5 minutes for guns to fire. Good indication of guns firing. Well initially lost 7 bbls then went on a 6 bph loss rate. Perforation intervals: Nb - 4942 - 4954' OBa-5125-5148' OBc - 5194 - 5220' OBd - 5248 - 5288' OTHCMP POH from 5,289' to 4,860' (above top per~ and circulate surface to surface 264 gpm, 585 psi. Shut down, monitor well - static. Total losses to perforations 14 bbls 9.0 ppg brine. OTHCMP POH laying down drill pipe from 4,860' to perforating BHA ~ 565'. Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common Well Name: W-213 Spud Date: 5/20/2007 Event Name: DRILL+COMPLETE Start: 5/19/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 9ES Rig Number: 5/31/2007 11:00 - 14:30 3.50 PERFO P OTHCMP Note: 1230-1345 Sim Ops - OA injection and freeze protection: Inject 105 bbls 9.0 ppg mud C~3 1/2 bpm, 710 ICP, 800 FCP. RU Little Red & pump 70 bbls 80 deg dead crude C~ 1 bpm, 850 ICP, 1000 FCP, 900 SIP. 14:30 - 17:00 2.50 PERFO P OTHCMP PJSM. Lay down perf gun assembly. All guns fired. 17:00 - 17:30 0.50 PERFO P OTHCMP Clean rig floor of gun residue and rig down all perforating tools. 17:30 - 18:00 0.50 PERFO P OTHCMP Run in hole with remaining drili pipe out of derrick to 1,807'. Monitor well - static. 18:00 - 19:00 1.00 PERFO P OTHCMP POH laying down drill pipe from 1,807' to surface. 19:00 - 20:00 1.00 EVAL P OTHCMP PJSM. Rig up SLB E-line and GR/JB assembly. 20:00 - 22:00 2.00 EVAL P OTHCMP RIH and log w/ 6.125" gauge ring / junk basket / Gamma Ray/ CCL. Tag fill or obstruction C~ 5,462'. Tag not sticky, and didn't move after several tags. POOH. Recovered 1/2 cup of sand. 22:00 - 00:00 2.00 EVAL P OTHCMP RD from junk basket, RU for USIT/CBL run. 6/1/2007 00:00 - 03:30 3.50 EVAL P OTHCMP Log USIT-CBL in 7" casing from 5,441' to surface. Top of cement found stringer C~3 3,780'. Top of good cement C~ 3,920'. Logs indicated excellent cement and perfs on depth as reported on 5/31/2007. 0145 - Transmit initial log pass to APE Taylor West and confirm cement and perf depths OK for completion. 03:30 - 04:15 0.75 EVAL P OTHCMP USIT-CBL tool at surface. Rig Down SLB E-Line. 04:15 - 05:15 1.00 W HSUR P RUNCMP Pull wear bushing. Make dummy run with tubing hanger and landing joint. 05:15 - 07:30 225 RUNCO RUNCMP Pick up tubing running equipment, SLB and HES equipment to rig floor. 07:30 - 14:30 7.00 RUNCO RUNCMP PJSM. Pick up and make up 3.5" 92# L-80 TCII Quad-HES packer, Dual I-wire completion jewelry and tubing to top X-Nipple @ 526'. Torque turn and make up connections to 2,300 ft/Ibs TQ. Used JetLube Seal Guard pipe lubricant. *All connections below bottom packer were Baker-Lok'd. Installed 2 Phoenix pressure sensors, splicing I-wires at packers. Test I-wire lines and connections to 5,000 psi - OK. 14:30 - 00:00 9.50 RUNCO RUNCMP Continue running in hole with completion assembly from 526' to 3,743'. Check I-wire integrity every 2 hours - OK. Torque turn and make up connections to 2,300 ft/Ibs TQ. Used JetLube Seal Guard pipe lubricant. 6/2/2007 00:00 - 02:30 2.50 RUNCO P RUNCMP Continue running in hole with completion assembly from 526' to 3,743'. Check I-wire integrity every 2 hours - OK. Torque turn and make up connections to 2,300 ft/Ibs TQ. Used JetLube Seal Guard pipe lubricant. 02:30 - 03:00 0.50 RUNCO RUNCMP PJSM. Rig up SLB E-line. 03:00 - 05:30 2.50 RUNCO RUNCMP Run in hole with GR/CCL tools to 5,280' and log up. Tie in tubing to gamma ray on realtime MWD log dated 29-May-07. No depth or pipe tally corrections. Log out of hole to surface. 05:30 - 06:00 0.50 RUNCO RUNCMP Rig down SLB E-line. 06:00 - 06:30 0.50 RUNCO RUNCMP Laydown 1 joint of tubing. Pick up landing joint and tubing hanger. 06:30 - 08:00 1.50 RUNCO RUNCMP Terminate I-wire equipment. RD tubing running equuipment, I-Wire spools, and all related equipment. 08:00 - 08:30 0.50 RUNCO RUNCMP Land tubing. PU - 80k, SO - 67k. Run in lock-down screws on tubing spool. TQ Gland nuts to 350 ft-Ibs, and LDS to 450 ft-Ibs Printed: 6!4/2007 6:51:55 AM • ~ Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 6/2/2007 I 08:00 - 08:30 W-213 Hours Task Cc~de NPT PFi~~~ ~~° f ~~sc~ipti~n vf fl~r~~fc~~i~ 0.50 RUNCO RUNCMP ITEM 3.5" 9.2 # WLEG, 3.5" TC-II - Bottom @ 5,349'. Tops: 3.5" HES 'XN' Nipp~e: ID 2.750 No-Go ~ 5,328'. 3.5" HES 'X' Nipple: 2.813" ID w/ RHC-M Plug @ 5,307'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 5,278'. 3.5" HES'X' Nipple: 2.813" ID C~3 5,257'. 3.5" x 7" HES single feedthru Packer (1 port) #1 packer ~ 5,234'. GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 5,216'. GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 5,187'. Phoenix Sensor sub ~ 5,182'. 3.5" x 7" HES single feedthru Packer (1 port) # 2 packer @ 5,174'. 3.5" HES'X' Nipple: 2.813" ID C~ 5,163'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 5,144'. 1 jt 3.5" 9.2# L-80 TC-I I Tubing (# 1) GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 5,084'. 3.5" 9.2# L-80 TC-II Pup RA TAG in Upper Collar C~2 5,074'. 3.5" x 7" HES Dual feedthru Packer (2 ports) # 3 packer @ 5,046'. 2 jts 3.5" 92# L-80 TC-II Tubing (# 2- 3) 3.5" HES'X' Nipple: 2.813" ID ~ 4,964'. GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 4,935'. Phoenix Sensor sub ~ 4,920'. 3.5" x 7" HES Dual feedthru Packer (2 ports) # 4 packer ~ 4,907'. 3.5" HES'X' Nipple: 2.813" ID ~ 4,886'. GLM #7 - 3.5" x 1.5" MMG w/ DCR-1Shear & RKP latch ~ 4,832'. 72 jts 3.5" 9.2# L-80 TC-I I Tubing (# 4- 75 ) 3.5" HES 'X' Nipple: 2.813" ID @ 2,561'. 79 jts 3.5" 9.2# L-80 TC-II Tubing (# 76 - 154 ) 2 ea Space out pup jts 3.5" 9.2# L-80 TC-II (9.71' - 7.78') 1 jt 3.5" 92# L-80 TC-II Tubing (# 155 ) 3.5" 9.2# L-80 TC-il Hanger Pup 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads Nabors 9-ES RKB - 23.77' 08:30 - 10:00 Ran a total of 87 full cannon clamps, 18 Half clamps 1.50 RUNCO RUNCMP PJSM. Drop 1 5/16" rod and ball assembly, laydown landing joint. Pressure up tubing to 4,000 psi to set packers. Hold pressure for tubing test - 30 min - OK. Bleed tubing pressure to 2,500 psi. Pressure up annutus to 4,000 psi. Hold annulus test for 30 minutes - OK. Bleed annulus to 0 psi, bleed tubing Printed: 6/4/2007 6:51:55 AM ~ ~ Legal Well Name: W-213 Common W ell Name: W-213 Spud Date: 5/20/2007 Event Nam e: DRILL+C OMPLE TE Start : 5/19/2007 End: Contractor Name: NABOR S ALASK A DRI LLING i Rig Release: 6/2/2007 Rig Name: NABOR S 9ES Rig Number: ~ate = Fr~ - l"i~ Hc~urs . ~'~sk ~ticc~e ~IPT Ph~se ; ~,. ° . Descriptit~n c~f C~p~rat~~~:s i„ , 6/2I2007 08:30 - 10:00 1.50 RUNCO RUNCMP pressure to 0 psi. Re-pressure the annulus to shear ihe DCR valve in the #7 GLM, pinned for 2500 psi / sheared at 2,350 psi. Establish circulation through valve both ways to confirm shear - OK. 10:00 - 10:30 0.50 RUNCO RUNCMP Install TWC, Pressure test from below to 1000 psi for 10 min, Tested O.K. 10:30 - 12:30 2.00 BOPSU P RUNCMP PJSM, Nipple down and set back BOP Stack 12:30 - 14:30 2.00 W HSUR P RUNCMP Bring tree adapter and double master valve tree into cellar. Nipple up adapter, terminate I-wires. Test I-wire integrity and adapter to 5,000 psi - 15 min - OK. 14:30 - 15:30 1.00 WHSUR P RUNCMP Nipple up double master valve. 15:30 - 16:00 0.50 WHSUR P RUNCMP Test double master valve tree to 5,000 psi for 15 minutes - Good. 16:00 - 16:30 0.50 W HSUR P RUNCMP RU drill site maintenance lubricator and pull 2-way check valve. 16:30 - 17:00 0.50 WHSUR P RUNCMP Rig up to reverse circulate and U-Tube. 17:00 - 18:30 1.50 WHSUR P RUNCMP Reverse circulate 120 bbls of clean 9.0 ppg brine, followed by 59 bbls of corrosion inhibited brine ~ 3 bpm, 310 psi. 18:30 - 21:00 2.50 WHSUR P RUNCMP PJSM with LRHOS. Pressure test lines to 3,500 psi - OK. Reverse circulate 91 bbls of 50 deg diesel ~ 2 bpm, 700 psi ICP, 1010 psi FCP. U-tube diesel back to tubing. 0 psi SIP on tubing and inner annulus. 21:00 - 22:30 1.50 WHSUR P RUNCMP Install BPV with lubricator. Test valve from below to 1,000 psi - OK. Install VR plugs in IA. 22:30 - 23:00 0.50 WHSUR P RUNCMP Rig down DSM and LRHOS. 23:00 - 00:00 1.00 WHSUR P RUNCMP Remove secondary annulus valves. Secure cellar and double valve tree. Remove remaining fluid in mud pits. "Release rig for move to V-222i ~ 23:59 hr, 6/2/2007. Printed: 6/4/2007 6:51:55 AM bp ~ ch~um e W-213 Survev Reaort Client: BP Exploration Alaska Field: Prudhoe Bay Unit • WOA Structure / Slot: W-PAD / W-213 Well: W-213 Borehole: W-213 UWI/API#: 500292335400 Survey Name / Date: W-213 / May 29, 2007 Tort / AHD / DDI / ERD ratio: 68.237° / 1276.04 ft/ 4.954 / 0.236 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.29925752, W 149.09253375 Location Grid WE Y/X: N 5959851.090 ftUS, E 612049.050 flUS Grid Convergence Angle: +0.85435692° Grid Scale Factor: 0.99991426 Survey / DLS Computation Method: Minimum Curvature / Li Vertical Section Azimuth: 284.390° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reterence Datum: Rotary Table ND Reference Elevation: 81.30 ft relative to MSL Sea Bed / Ground Level Elevation: 52.80 ft relative to MSL Magnetic Declination: 23.577° Total Field Strength: 57631.358 nT Magnetic Dip: 80.864° Declination Date: May 23, 2007 Magnetic Declination blodel: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.577° ~ Comments Measured ~nclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Langitude Depth Section Departure ft de de ft ft n n ft ft ft de 00 ft itUS ftUS ~"{~~ ~J.(J(J ~J.~JV ~J.VU 'Z51.~7U ~J.VV V.VV V.VV V.VV V.UU U.VV V.UV J.7J.70.71.V.`7 OIGV'~.7.Va IV /V.L.7.7G.7/.7G VV IY.`7.V.7GJJJ/.7 GYD GC MS 100.00 0.03 239.52 18.70 100.00 0.02 0.03 0.03 -0.01 •0.02 0.03 5959851.08 612049.03 N 70.29925749 W 149.09253393 200.00 0.10 245.26 118.70 200.00 0.10 0.14 0.14 -0.06 -0.12 0.07 5959851.03 612048.93 N 70.29925735 W 149.09253475 300.00 0.47 285.18 218.70 300.00 0.58 0.62 0.60 0.01 -0.60 0.40 5959851.09 612048.45 N 70.29925755 W 149.09253860 400.00 2.60 284.38 318.66 399.96 3.26 3.30 3.26 0.68 •3.19 2.13 5959851.72 612045.85 N 70.29925938 W 149.09255960 Last Gyro 500.00 4.98 280.50 418.43 499.73 9.86 9.91 9.87 2.03 -9.66 2.39 5959852.98 612039.36 N 70.29926308 W 149.09261196 First MWD+IFR+MS 578.43 6.67 278.95 496.45 577.75 17.79 17.87 17.83 3.36 -17.51 2.16 5959854.19 612031.50 N 7029926671 W 149.09267550 670.66 8.08 286.59 587.92 669.22 29.60 29.69 29.63 6.05 -29.01 1.86 5959856.70 612019.96 N 70.29927404 W 149.09276866 762.43 10.48 288.85 678.48 759.78 44.37 44.49 44.37 10.58 -43.09 2.64 5959861.03 612005.81 N 70.29928644 W 149.09288269 854.19 12.82 288.88 768.35 849.65 62.84 63.01 62.85 16.58 -60.62 2.55 5959866.76 611988.19 N 70.29930281 W 149.09302466 946.84 14.66 288.31 858.34 939.64 84.79 85.02 84.83 23.59 -8i .48 i.99 5959673.46 611967.23 N 70.29932196 W 149.09319357 1041.82 16.60 284.95 949.81 1031.11 110.35 110.60 110.40 30.86 -106.00 2.25 5959880.37 611942.61 N 70.29934184 W 149.0933 1136.91 16.47 285.65 1040.96 1122.26 137.41 137.66 137.46 38.00 -132.11 0.25 5959887.12 611916.40 ~ N 70.29936134 W 149.0936 1232.49 16.26 285.17 1132.67 1213.97 164.33 164.59 164.39 45.16 -158.07 026 5959893.88 611890.34 N 70.29938089 W 149.093813 1328.87 16.29 285.49 1225.19 1306.49 191.34 191.60 191.40 52.30 -184.12 0.10 5959900.64 611864.19 N 70.29940040 W 149.09402469 1424.88 15.87 285.69 1317.44 1398.74 217.93 218.20 217.99 59.45 -209.73 0.44 5959907.40 611838.47 N 70.29941992 W 149.09423211 1519.91 15.69 285.85 1408.89 1490.19 243.76 244.04 243.84 66.47 -234.60 0.19 5959914.05 611813.50 N 70.29943911 W 149.09443351 1615.71 16.77 282.85 1500.87 1582.17 270.53 270.81 270.59 73.08 -260.54 1.43 5959920.27 611787.47 N 70.29945717 W 149.09464354 1711.98 16.41 281.70 1593.14 1674.44 297.99 298.30 298.04 78.93 -287.40 0.51 5959925.72 611760.53 N 70.29947314 W 149.09486103 1806.08 19.16 279.97 1682.73 1764.03 326.67 327.03 326.69 84.30 -315.63 2.98 5959930.67 611732.23 N 70.29948780 W 149.09508963 1903.01 17.21 284.04 1774.82 1856.12 356.88 357.27 356.88 90.53 -345.21 2.40 5959936.46 611702.56 N 70.29950483 W 149.09532918 1998.23 16.87 284.82 1865.86 1947.16 384.78 385.17 384.78 97.48 -372.23 0.43 5959943.00 611675.44 N 70.29952382 W 149.09554801 2094.42 16.67 284.61 1957.96 2039.26 412.53 412.93 412.54 104.53 -399.07 0.22 5959949.65 611648.50 N 70.29954307 W 149.09576539 2189.72 16.32 285.31 2049.34 2130.64 439.59 439.99 439.60 111.52 -425.22 0.42 5959956.25 611622.26 N 7029956215 W 149.09597708 2285.32 15.97 285.17 2141.17 2222.47 466.17 466.57 466.18 118.51 -450.86 0.37 5959962.85 611596.51 N 7029958123 W 149.09618478 2380.62 15.93 285.30 2232.80 2314.10 492.35 492.76 492.36 125.39 -476.13 0.06 5959969.35 611571.14 N 70.29960003 W 149.09638940 SurveyEditor Ver SP 2.1 Bld( doc40x_100 ) W-213\W-213\W-213\W-213 current Generated 6/27l2007 7:39 AM Page 1 of 2 Comments Measured ~nclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft n n tt ft ft de 00 ft ttUS ftUS t4 /b.:it5 2572.09 2668.22 2763.56 2859.27 2955.01 3050.67 3146.02 3242.01 3338.11 3417.46 3511.94 3607.98 3703.61 3800.13 3895.63 3991.12 4086.33 4181.93 4277.96 4372.65 4468.56 4564.03 4660.12 4756.41 4851.13 4947.39 5043.13 5138.68 ~a.ia 15.49 15.36 15.36 15.17 15.01 14.93 14.56 14.39 14.12 15.83 18.33 18.13 18.06 15.32 16.46 16.85 18.77 16.17 16.78 17.16 15.90 15.72 15.72 16.02 17.66 17.11 12.51 7.80 L84. / Z 284.97 284.94 285.17 285.04 284.93 285.38 284.92 285.19 285.55 285.70 284.64 285.64 286.57 283.68 283.96 285.99 288.93 286.86 288.91 289.70 289.99 287.69 290.41 290.45 287.66 274.45 262.75 259.72 Z3Z4. y l 2417.08 2509.75 2601.68 2694.01 2786.45 2878.87 2971.08 3064.02 3157.16 3233.81 3324.12 3415.34 3506.24 3598.68 3690.53 3782.02 3872.66 3963.85 4055.93 4146.50 4238.45 4330.30 4422.80 4515.42 4606.08 4697.98 4790.53 4884.56 Z4VO.L I 51 iS.~Z b125.`JJ 51 iS.DS I SL . I/ -DU I.41 2498.38 544.32 544.73 544.34 138 .78 -526.35 2591.05 569.89 570.30 569.91 145 .37 -551.05 2682.98 595.14 595.55 595.16 151 .93 -575.44 2775.31 620.34 620.75 620.36 158 .50 -599.77 2867.75 645.26 645.68 645.28 164 .94 -623.84 2960.17 669.97 670.39 669.99 171 .40 -647.69 3052.38 694.24 694.65 694.26 177 .75 -671.12 3145.32 718.23 718.65 718.25 183 .98 -69429 V.LL oaoayia.i~ OI1.747.// IV /V.Lyy016J4 VV 14~.U70~~4V~ 0.32 5959981.99 611520.74 N 70.29963660 W 149.09679607 0.14 5959988.22 611495.94 N 70.29965462 W 149.09699611 0.06 5959994.41 611471.46 N 70.29967253 W 149.09719360 0.20 5960000.62 0.17 5960006.70 0.15 5960012.80 0.41 5960018.80 0.19 5960024.68 611447.04 611422.87 611398.93 611375.41 611352.16 611329.25 611309.43 611282.54 611253.43 611224.77 611197.94 611172.46 611145.93 611118.04 611090.62 611064.59 611038.38 611012.58 610987.85 610963.12 610938.32 610912.25 610884.13 610859.79 610843.18 610833.74 610828.05 610822.84 610819.37 610815.13 N 70.29969047 W 149.09739061 N 70.29970807 W 149.09758559 N 7029972571 W 149.09777873 N 70.29974304 W 149.09796843 N 70.29976006 W 149.09815606 N 70.29977718 W 149.09834084 N 70.29979227 W 149.09850073 N 70.29981205 W 149.09871~ N 70.29983347 W 149.0989 N 70.29985597 W 149.0991 N 70.29987586 W 149.09940008 N 7029989292 W t 49.09960569 N 70.29991225 W 149.09981975 N 70.29993620 W 149.10004454 N 70.29996037 W 149.10026557 N 70.29998323 W 149.10047541 N 70.30000819 W 149.10068663 N 70.30003348 W 149.10089450 N 70.30005642 W 149.10109382 N 70.30007962 W 149.10129305 N 70.30010472 W 149.10149288 N 70.30012909 W 149.10170295 N 70.30014419 W 149.10193004 N 70.30014359 W 149.10212720 N 70.30013685 W 149.10226207 N 70.30013181 W 149.1023~ N 70.30012805 W 149.1023 N 70.30012451 W 149.10242736 N 70.30012223 W 149.10245553 N 70.30011938 W 149.10249003 3238.46 741.89 742.31 741.91 190.25 -717.11 0.30 5960030.61 3315.11 762.39 762.81 762.42 195.77 -736.85 2.16 5960035.84 3405.42 790.13 790.56 790.16 203.02 -763.64 2.67 5960042.68 3496.64 820.17 820.60 820.20 210.86 -792.64 0.39 5960050.09 3587.54 849.86 850.30 849.90 219.10 -821.17 0.31 5960057.91 3679.98 877.57 878.02 877.61 226.39 -847.91 2.97 5960064.79 3771.83 903.71 904.16 903.75 232.63 -873.30 1.20 5960070.66 3863.32 931.07 931.53 931.11 239.71 -899.73 0.73 5960077.34 3953.96 960.14 960.64 960.19 248.48 -927.49 2.23 5960085.69 4045.15 988.78 989.34 988.85 257.33 -954.78 2.80 5960094.14 4137.23 1015.96 1016.57 1016.05 265.70 -980.69 0.88 5960102.12 4227.80 1043.49 1044.20 1043.61 274.84 -1006.77 0.47 5960110.87 4319.75 1070.66 1071.49 1070.82 284.10 -1032.44 1.32 5960119.74 4411.60 1096.58 1097.50 1096.78 292.50 -1057.05 0.68 5960127.78 4504.10 1122.52 1123.53 1122.75 301.00 -1081.65 0.77 5960135.90 4596.72 1148.71 1149.86 1148.99 310.19 -1106.33 0.31 5960144.72 4687.38 1176.05 1177.30 1176.38 319.12 -113227 1.93 5960153.26 4779.28 1204.59 1205.94 1204.87 324.65 -1160.31 4.13 5960158.37 4871.83 1228.12 1230.33 1228.28 324.43 -1184.66 5.71 5960157.79 4965.86 1243.64 1247.17 1243.71 321.97 -1201.31 4.96 5960155.08 5234.28 3.79 257.45 4979.65 5060.95 1252.35 1256.82 1252.39 320.12 -1210.78 4.20 5960153.10 5329.53 3.28 255.36 5074.72 5156.02 1257.54 1262.69 1257.56 318.75 -1216.49 0.55 5960151.64 5425.06 3.19 256.81 5170.10 5251.40 1262.29 1268.08 1262.29 317.45 -1221.72 0.13 596015026 Last MWD+IFR+MS 5490.14 3.11 256.26 5235.08 5316.38 1265.45 1271.66 1265.45 316.62 -1225.20 0.13 5960149.38 TD ( Projected ) 5571.00 3.11 256.26 5315.82 5397.12 1269.32 1276.04 1269.32 315.58 -1229.46 0.00 5960148.27 Survey Type: Definitive Survey NOTES: GYD GC MS -( Gyrodata - gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys ( RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination. ) MWD + IFR + MS -( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leaal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4874 FSL 1176 FEL S21 T11 N R12E UM 5959851.09 612049.05 BHL : 5189 FSL 2405 FEL S21 T11 N R12E UM 5960148.27 610815.13 SurveyEditor Ver SP 2.1 Bld( doc40x_100 ) W-213\W-213\W-213\W-213 current Generated 6/27/2007 7:39 AM Page 2 of 2 iKEG = tt1~LLHE.Ad = AGT1JATt7R = EC6. ELEV = ~F. ~~.~v = 'iCOP _ ~t Ar~e = [Ydtu~n MD = E7atUn1 NL) _ • ~~~ ",~w ~ ~ ~ ~ ° ~~ ~ ~l$" Tarn Poat C~I~r $!#8` _._... ~.._. 95f8" GSG, 4(3~, L-8t1, fQ = 8,8~a" --~~4~~• 7a ~T{'~1, x TC-!I 2~, ~.-k3t}. G~osrnt+~r~. ~39~ IlNltltit1U171 IC1 = 2.7rJ#~•• ~-'~~~'~ ~E~ ~~ ~M~~~~ AFEf Y [~TES: C~t.M'~ ~ STA #1-#~6 ,AR~ -if2" X 1=11~" MiVIG'wW 11V F~t;ti AF~ bitAT~i~Ft,.OCf~1 NlANaFtELS. 2~0' s-trz- r~~s x~i~. ~o ~ 2.$~ts° ' GAS LIFf MANDRELS D TV D DEV TY PE V LV LATCH PORT DATE 33 4670 17 MMG FS RKP 0 06l01l07 WATER ~NJECTION MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 6 4935 4768 17 MMG-W DUM RK 0 O6/01107 5 5084 4912 11 MMG-W DUM RK 0 06/01107 4 5144 4~J79 8 MMG-W DUM RK 0 06/01l07 3 51$7 5014 6 MMG-W DUM RK 0 06/01 /07 2 5216 5042 5 MMG-W DUM RK 0 06l01/07 1 5278 5105 4 MMG-W DUM RK 0 06I01/07 s~~' --~ ~-ar~- ~€s x n~~~. ic~ ~ x,s~~w f ~~~~. ~~ ~j~' ~~ ~ ~~~. 4906~ 7" X 3-1l2" HES AHR Packer, ID = 2.965" ~19~3~ ~" ^^~ 3-1f2" t1ES X NIP, IG = 2.$13" I ~Al~f ~-WIFC ti? $ll!'~~Gi3 +W~l.~ ....... .. . ..... ...... .__. . . _ ..~~~~..~~~~~..... -`-- ~~` 7" X 3-1/2" !-#ES AtiR Paaker, IT7 = 2.~65" 3-112" TBG WIRA Fag ~~~' S162' 3-1t2" HE3 XNIF, 10! = 2.~13° 7" 20' Maricer jt w/RA Ta9 5130' S"173' T' X 3-tf2" HES AHi2 Packer, ID -= 2.~'i" l~RFL?RA'~7QT~+I St~141~Y f~~ lt~: 52~9' PFua~r~x Serrsar ~e~, ~ 2,99~ ANGLEATTi~P 6~F: i'7* ~ #~d2* -~t~: ' ~~~'~ 7" 7t3-112` tt~~ ~;HR P8Ck~. ID ~ 2.955" S~ZE ~F~ 11u1 T'E~tA~. C~rtiSqz I?ATE ~4.5" 5 2- ~1 tJ 06101 t07 4:5" 5 ~12~ -~i~s C7 t~ft)11U7 ~257" 3-~rz~ HES ~+r ~~P. -o~= 2.~sa~ ~t:~" S z~~*3 - ~ C3 t16JtT1t07 4:5" 5 52 m~a~~3 £! tMiftIilt~7 --_,. ~{M~-'~ 3-tt2" HES X N~P, ID = 2,813" wIRMG m p[u J~~T 3-1/2" H@S ~UI NIP. E~ 2.750« ' S3A~9' - ~ ~--ttz- ~v~.~~, in ~ a.oo- ~ ~-~tz~ rco ~e~, s.az~. ~-~o. tr~ = 2:s~~~ ~48 PBTp ~4~6" 7" GSG, :Z#~> L-£~I, IC} = 6.276" -~{~ DATE REV BY COMMENTS DATE REV BY COMMEPtT'S 06/01/07 BJB Original Qrill & Co~lete 06/07/07 /PAG DRLG DRAFT CORRECTIONS Polaris UNff WELL: W-213i PERMIT No: 207-0510 API No: 50-029-233354-00-00 4874' FSL, 1176' FEL, Sec 21, T11N, R12E, UM BP Eupioration (Alaska) ~ • ~ ~ EIVI O R/~-N DlJ IVI Alaska Oil and Gas Conservation Commission TO: Jim Regg P. I. Supervisor FR011N: Bob Noble Petroleum Inspector ,-~ jt~j~;,~~ i ~~~~5/ ~~ i State of ~4laska DATE: May 26, 2007 SUBJECT: Surface Casing Top Job PBU W-213 BPXA PTD 207-051 Mav 26, 2007: ( got a call from Matt Martin / Alan Madsen telling me that they didn't get cement back to surface. I told them to keep me posted on the timing of the top job. They told me that they had lost circulation when the cement turned the corner. We talked later in the day and they were telling me that drilling mud had breached surface in and around wells W-201, W-200, W-24. I called Jim Regg and went to location. They pumped 165 bbl's out of the TAM port collar and did not get any returns. They said they think they wer~ bridged off somewhere befinreen the TAM port collar (723'} and surface. They went forward with a top job. 190' of 1" tubing was installed. It went 90' below the cond~c±or bottom. They pumped 550 bbl's of 10.7# cement until they got cement to weight at surFace. I was told that the well next to this well (PBU W-204; 15' away) had a lot of problems with the surFace pipe. They pumped 1500 bbl's of cement in 4 cement jobs to get cement to surface in W-204. The picture is of mud that breached surFace and was in one of the cellars in a near by wellhouse [PBU W-200]. Most of the mud on the ground between the wellhouses had been cleaned up as they had 6 Super suckers. It looked as if the mud had run from the wellhouse's to or near the reserve pit. Summarv: I witnessed a successful top job at PBU W-213 Attachments: Mud in Cellar at PBU W-200 Confidential 2007-0~26 Surf csg_topjob_PBU_W-Z 13_bn.doc ~ ~ • ~~~ `~m~~~, 9~~~9 ~a~~~~~ ~~ ~9~10 ~~~8~~ ~hofia by Bob ~ob~e IP~~G~~) I~~ay 26, 2007 2007-0~?6_Surf_csg_topjob_PBU _W-2 I3_bn.doc ~ Q ~ ~ '~ . ~ SCHLUMBERGER Survey report Client ...................: Bp Exploration (Alaska) Inc. Field ..................... Polaris Well .....................: W-213 API number ...............: 50-029-23354-00 Engineer .................: Franco 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.......: 52.80 ft KB above permanent.......: 81.30 ft DF above permanent.......: 81.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 5,959,851.09 ft Departure (+E/W-)........: E 612,049.05 ft Azimuth from Vsect Origin to target: 0.00 degrees 29-May-2007 18:09:24 Page 1 of 3 Spud date ................: 20-May-07 Last survey date.........: 29-May-07 Total accepted surveys...: 60 MD of first survey.......: 0.00 ft MD of last survey........: 5571.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 20-May-2007 Magnetic field strength..: 57643.23 GAMA Magnetic dec (+E/W-)...... 23.74 degrees Magnetic dip .............: 80.90 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 57643.00 GAMA 80.90 degrees (+/-) 2.50 mGal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.74 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.74 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 • u _ t SCHLUMBERGER Survey Report 29-May-2007 18:09:24 Page 2 of 3 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 0.00 285.20 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.03 239.52 100.00 100.00 -0.01 -0.01 -0.02 0.03 239.52 0.03 BP GYD GC MS 3 200.00 0.10 245.26 100.00 200.00 -0.06 -0.06 -0.12 0.14 243.11 0.07 BP GYD GC MS 4 300.00 0.47 285.18 100.00 300.00 0.01 0.01 -0.60 0.60 270.75 0.40 BP GYD GC MS 5 400.00 2.60 284.38 100.00 399.96 0.68 0.68 -3.19 3.26 282.00 2.13 BP GYD GC MS 6 500.00 4.98 280.50 100.00 499.73 2.03 2.03 -9.66 9.87 281.89 2.39 BP GYD GC MS 7 578.43 6.67 278.95 78.43 577.75 3.36 3.36 -17.51 17.83 280.87 2.16 BP MWD+IFR+MS 8 670.66 8.08 286.59 92.23 669.22 6.05 6.05 -29.01 29.63 281.77 1.86 BP MWD+IFR+MS 9 7b2.43 10.48 288.85 91.77 759.78 10.58 10.58 -43.09 44.37 283.80 2.64 BP MWD+IFR+MS 10 854.19 12.82 288.88 91.76 849.65 16.58 16.58 -60.62 62.85 285.29 2.55 BP MWD+IFR+MS 11 946.84 14.66 288.31 92.65 939.64 23.59 23.59 -81.48 84.83 286.14 1.99 BP MWD+IFR+MS 12 1041.82 16.60 284.95 94.98 1031.11 30.86 30.86 -106.00 110.40 286.23 2.25 BP MWD+IFR+MS 13 1136.91 16.47 285.65 95.09 1122.26 38.00 38.00 -132.11 137.46 286.05 0.25 BP MWD+IFR+MS 14 1232.49 16.26 285.17 95.58 1213.97 45.16 45.16 -158.07 164.39 285.94 0.26 BP MWD+IFR+MS 15 1328.87 16.29 285.49 96.38 1306.49 52.30 52.30 -184.12 191.40 285.86 0.10 BP MWD+IFR+MS ~6 1424.88 15.87 285.69 96.01 1398.74 59.45 59.45 -209.73 217.99 285.83 0.44 BP MWD+IFR+MS 17 1519.91 15.69 285.85 95.03 1490.19 66.47 66.47 -234.60 243.84 285.82 0.19 BP MWD+IFR+MS 18 1615.71 16.77 282.85 95.80 1582.17 73.08 73.08 -260.54 270.59 285.67 1.43 BP MWD+IFR+MS 19 1711.98 16.41 281.70 96.27 1674.44 78.93 78.93 -287.40 298.04 285.36 0.51 BP MWD+IFR+MS ~ 20 1806.08 19.16 279.97 94.10 1764.03 84.30 84.30 -315.63 326.69 284.95 2.98 BP MWD+IFR+MS 21 1903.01 17.21 284.04 96.93 1856.12 90.53 22 1998.23 16.87 284.82 95.22 1947.16 97.48 23 2094.42 16.67 284.61 96.19 2039.26 104.53 24 2189.72 16.32 285.31 95.30 2130.64 111.52 25 2285.32 15.97 285.17 95.60 2222.47 118.51 26 2380.62 15.93 285.30 95.30 2314.10 125.39 27 2476.38 15.79 284.72 95.76 2406.21 132.17 28 2572.09 15.49 284.97 95.71 2498.38 138.78 29 2668.22 15.36 284.94 96.13 2591.04 145.37 30 2763.56 15.36 285.17 95.34 2682.98 151.93 90.53 -345.21 97.48 -372.23 104.53 -399.07 111.52 -425.21 118.51 -450.86 125.39 -476.13 132.17 -501.41 138.78 -526.35 145.37 -551.05 151.93 -575.44 356.88 284.70 384.78 284.68 412.54 284.68 439.60 284.70 466.18 284.73 492.36 284.75 518.53 284.77 544.34 284.77 569.90 284.78 595.16 284.79 2.40 BP MWD+IFR+MS 0.43 BP MWD+IFR+MS 0.22 BP MWD+IFR+MS 0.42 BP~MWD+IFR+MS 0.37 BP`MWD+IFR+MS 0.06 BP_MWD+IFR+MS 0.22 BP MWD+IFR+MS 0.32 BP MWD+IFR+MS 0.14 BP MWD+IFR+MS 0.06 BP MWD+IFR+MS • • /' ; SCHLUMBERGER Survey Report 29-May-2007 18:09:24 Page 3 of 3 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 2859.27 15.17 285.04 95.71 2775.31 158.50 158.50 -599.77 620.36 284.80 0.20 BP MWD+IFR+MS 32 2955.01 15.01 284.93 95.74 2867.75 164.94 164.94 -623.84 645.28 284.81 0.17 BP MWD+IFR+MS 33 3050.67 14.93 285.38 95.66 2960.16 171.40 171.40 -647.69 669.99 284.82 0.15 BP MWD+IFR+MS 34 3146.02 14.56 284.92 95.35 3052.37 177.75 177.75 -671.12 694.26 284.83 0.41 BP MWD+IFR+MS 35 3242.01 14.39 285.19 95.99 3145.32 183.98 183.98 -694.29 718.25 284.84 0.19 BP MWD+IFR+MS 36 3338.11 14.12 285.55 96.10 3238.46 190.25 190.25 -717.11 741.91 284.86 0.30 BP MWD+IFR+MS • 37 3417.46 15.83 285.70 79.35 3315.11 195.77 195.77 -736.85 762.42 284.88 2.16 BP MWD+IFR+MS 38 3511.94 18.33 284.64 94.48 3405.42 203.02 203.02 -763.64 790.16 284.89 2.67 BP MWD+IFR+MS 39 3607.98 18.13 285.64 96.04 3496.64 210.86 210.86 -792.64 820.20 284.90 0.39 BP MWD+IFR+MS 40 3703.61 18.06 286.57 95.63 3587.54 219.10 219.10 -821.17 849.90 284.94 0.31 BP MWD+IFR+MS 41 3800.13 15.32 283.68 96.52 3679.98 226.39 226.39 -847.91 877.61 284.95 2.97 BP MWD+IFR+MS 42 3895.63 16.46 283.96 95.50 3771.83 232.63 232.63 -873.30 903.75 284.92 1.20 BP MWD+IFR+MS 43 3991.12 16.85 285.99 95.49 3863.32 239.71 239.71 -899.73 931.11 284.92 0.73 BP MWD+IFR+MS 44 4086.33 18.77 288.93 95.21 3953.96 248.48 248.48 -927.49 960.19 285.00 2.23 BP MWD+IFR+MS 45 4181.93 16.17 286.86 95.60 4045.15 257.33 257.33 -954.78 988.85 285.08 2.80 BP MWD+IFR+MS 46 4277.96 16.78 288.91 96.03 4137.23 265.70 265.70 -980.69 1016.05 285.16 0.88 BP MWD+IFR+MS 47 4372.65 17.16 289.70 94.69 4227.80 274.84 274.84 -1006.77 1043.61 285.27 0.47 BP MWD+IFR+MS 48 4468.56 15.90 289.99 95.91 4319.75 284.10 284.10 -1032.44 1070.82 285.39 1.32 BP MWD+IFR+MS 49 4564.03 15.72 287.69 95.47 4411.60 292.50 292.50 -1057.05 1096.78 285.47 0.68 BP MWD+IFR+MS 50 4660.12 15.72 290.41 96.09 4504.10 301.00 301.00 -1081.65 1122.75 285.55 0.77 BP MWD+IFR+MS 51 4756.41 16.02 290.45 96.29 4596.72 310.19 310.19 -1106.33 1148.99 285.66 0.31 BP MWD+IFR+MS • 52 4851.13 17.66 287.66 94.72 4687.38 319.12 319.12 -1132.27 1176.38 285.74 1.93 BP MWD+IFR+MS 53 4947.39 17.11 274.45 96.26 4779.28 324.65 324.65 -1160.31 1204.87 285.63 4.13 BP MWD+IFR+MS 54 5043.13 12.51 262.75 95.74 4871.83 324.43 324.43 -1184.66 1228.28 285.32 5.71 BP MWD+IFR+MS 55 5138.68 7.80 259.72 95.55 4965.86 321.97 321.97 -1201.31 1243.71 285.00 4.96 BP MWD+IFR+MS 56 5234.28 3.79 257.45 95.60 5060.95 320.12 320.12 -1210.78 1252.39 284.81 4.20 BP MWD+IFR+MS 57 5329.53 3.28 255.36 95.25 5156.02 318.75 318.75 -1216.49 1257.56 284.68 0.55 BP MWD+IFR+MS 58 5425.06 3.19 256.81 95.53 5251.40 317.45 317.45 -1221.72 1262.29 284.57 0.13 BP MWD+IFR+MS 59 5490.14 3.11 256.26 65.08 5316.38 316.62 316.62 -1225.20 1265.45 284.49 0.13 BP MWD+IFR+MS 60 5571.00 3.11 256.26 80.86 5397.12 315.58 315.58 -1229.46 1269.32 284.40 0.00 Projection to TD • . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc. W-213 Nabors-9ES Dispatched To: Christine Mahnken (AOGCC) Date Dispatched: 20-May-07 Dispatched By: Franklin Medina Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: ~ames H.,lonnson RBCeIVed By: BP Exploration (Alaska) Inc. Petrotechnical Data CenterlLR2-1) a~ ~ t...,.., 900 E. Benson Blvd. ~ w ~~ Anchorage,Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com LWD Log Delivery V1.1,10-02-03 a~~- ~~ ~ ~ ~ ~ AOGCC Memorandum Date: May 31, 2007 To: PBU W-213 Well File PTD 207-051 ~~ ~ ~1~~1~7 From: Jim Regg, Petroleum Engineer ~ Subject: Surface Casing Cement I received a call from AOGCC Inspector Bob Noble May 26, 2007 at 4:30 pm regarding problems encountered with the PBU W-213 surface casing cement job. He was notified by personnel on Nabors 9ES a short time before contacting me. The casing-formation annulus apparently bridged off preventing cement returns to surface and resulting in what appeared to drilling mud to broach in 3 nearby well houses on PBU W-pad. I dispatched Mr. Noble to the well to inspect the site, to follow up with the rig supervision about what will be done to get the surface casing cemented properly, and what has or will be done to clean up mud released in adjacent well houses. I placed a call to Mr. Alan Madsen (BP; Nabors Rig 9ES; 907-659-4831) at 4:40 pm and left a message for a call back. Mr. Madsen returned my call at 5:42 pm. A summary of information he provided follows: - Surface casing cement job occurred during late night/early morning of May 25-26, 2007; - Cement job was planned with 250% excess cement; - Drilling encountered "running gravel" that is extremely unconsolidated; other wells drilled on W-pad have encountered same gravel zone and have experienced problems with cementing surface casing; most recent well drilled took 4 cement jobs and 1500 bbls of cement to get good cement returns to surface; - PBU W-213 surface casing includes a TAM port collar at 723 feet; - Annular space between surface casing and formation appears to have bridged off somewhere between the TAM collar and surface (were able to pump into TAM but not circulate to surface); - Found drilling mud in 3 nearby well cellars; - 3 additional attempts to circulate through TAM collar to surface; well houses were monitored during circulation attempts subsequent to primary cement job; - Vacuum trucks are at location to clean up mud in well houses; - Next step is to pump cement into TAM port collar and shift it closed, then run 1" Hydril pipe into the surface casing annulus to do a top job (pump cement in annulus from apparent bridge to surface); have 1000 bbls of dry cement at location if needed. I told Mr. Madsen that an AOGCC Inspectar was on his way to the location to witness operations. I asked him to coordinate with the Inspector. Mr. Madsen indicated they were ready to pump into the TAM collar and shift it closed and asked if he should wait for the Inspector to witness. I told them to proceed and to brief inspector when he arrives. Inspector will look at adjacent well houses and witness top job. • ~ ~IEI~IORA~IDUM State ~f Alaska ~ ~~'~ ~ ~~ TO: Jim Regg ~~~~~'~ ~ P. I. Supervisor ~ Alaska Oil and Gas Conservation Commission FROM: Bob Noble Petr~leum Inspector DATE: May 26, 2007 SUBJECT: Surface Casing Top Job PBU W-213 BPXA PTD 207-051 Mav 26, 2007: I got a call from Matt Martin / Alan Madsen telling me that they didn't get cement back to surface. I told them to keep me posted on the timing of the top job. They told me that they had lost circulation when the cement turned the corner. We talked later in the day and they were telling me that drilling mud had breached surface in and around wells W-201, W-200, W-24. I called Jim Regg and went to location. They pumped 165 bbl's out of the TAM port collar and did not get any returns. They said they think they were bridged off somewhere between the TAM port collar (723') and surface. They went forward with a top job. 190' of 1" tubing was installed. It went 90' below the condt~ctor bottom. They pumped 550 bbl's of 10.7# cement until they got cement to weight at surFace. I was told that the well next to this well (PBU W-204; 15' away) had a lot of problems with the surface pipe. They pumped 1500 bbl's of cement in 4 cement jobs to get cement to surFace in W-204. The picture is of mud that breached surface and was in one of the cellars in a near by wellhouse [PBU W-200]. Most of the mud on the ground between the wellhouses had been cleaned up as they had 6 Super suckers. It looked as if the mud had run from the wellhouse's to or near the reserve pit. Summarv: I witnessed a successful top job at PBU W-213 Attachments: Mud in Cellar at PBU W-200 Confidential 2007-0526_Surf csg_topjob_PBU_W-213_bn.doc • • PBU V11-200: ~ud Broa~h in 'V~tell Cellar Photo by Bob Nobie (AOGCC) IViay 26, 2007 2007-0526_Surf_csg_topjob_PBU_W-213 bn.doc ~ ~ ~ ~ ~ ~ ~ SARAH PAUN, GOVERNOR ~7~~ Da~y ~a-as ~S 333 W. 7thAVENUE, SUITE 100 COlYSERQ~~'I011T COrII~IISSI01~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU W-213 BP Exploration (Alaska) Inc. Permit No: 207-051 Surface Location: 4874' FSL, 1176' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 5191' FSL, 2413' FEL, SEC. 21, T11N, R12E, 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. The Area of Review analysis conducted for this injection well indicates that the top of cement behind the 9-5/8" casing in PBU W-31 (188-154) and W-32 (189-091) are likely not above proposed Schrader injection zone. Both wells are about 750' distant. PBU W-29 (188-071) is about 210' distant, however during a recent workover it was determined that annulus isolation was likely better than expected. In order to confirm that injected fluids are isolated to the intended Schrader intervals, BP should design a monitoring plan, possibly similar to that proposed for PBU Z-06, to assess performance in the wells proximate to W-213. A copy of the plan should be sent to the Commission when available. 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. Fa.ilure 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). ' ce 1 Dan T. Seamount Commissioner DATED this ~~day of April, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - ~~~./ -- --- - STATE OF ALASKA ~ ~~~~ ~E~EIV~ ALAS~IL AND GAS CONSERVATION COMMI~ . 4,( ~, APR 1 3 2007 PERMIT TO DRILL ~ ~~ 20 AAC 25.005 Alaska Oil & Gas Cons. Commission 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. Specify if well is pro o. ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU W-213 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 5542 TVD 5370 12. Field / Pool(s): Prudhoe Bay Field / Polaris Pool 4a. Location of Well (Governmental Section): Surface: 4874' FS~ 1176' FEL SEC 21 T11N R12E UM 7. Property Designation: ADL 028263 , , . , , , Top of Productive Horizon: 5190' FSL, 2348' FEL, SEC. 21, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: May 15, 2007 Total Depth: 5191' FSL, 2413' FEL, SEC. 21, T11N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,050' 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y-5959851 Zone-ASP4 10. KB Elevation Plan (Height above GL): 81,7 feet 15. Distance to Nearest Well Within Pool: 213' 16. Deviated Wells: Kickoff Depth: 3g2 feet Maximum Hole An le: 16 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2265 SurFace: 1757 18; Casin Pr ram: S ~catio n T'- Settin h- Bo ttom u nt. f e .f. or sa Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 42" 20" x 34" 215.5# A53 Welded 80' Surface Surface 100' 100' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3443' SurFace Surfa 3443' 3337' 556 sx A Lite 378 sx Class'G' 8-3/4" 7" 26# L-80 BTC-M 542' Surface Surfa 5 42' 7' 22 x CI ss 'G' ~ g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations~ ; Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing Length Size Cement Volume MD Conductor ! Structural Surface Intermediate Pr duction Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments ~ Filing Fee, $100 ^ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ken A~~en, 564-4366 Printed Name Robert Tirpack Title Senior Drilling Engineer ~ Prepared By Name/Number: Si nature ~~~.:~r ~~.~"' Phone 564-4166 Date ~~~ ~" Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~~~Ot$'/O API Number: 50- Ov?J a2.3.~5~0000 Permit Appro al See cover letter for ~ Date: '~ ' C~ other r uirem n ConditionsofApproval: ~~'~~~~-~~~~~}~ Ljpc ,~/ If box is checked, well may not be used to explore for~test, or produce coalbed methane, gas hydrates, or gas contained shales: L) ~PSr~O~-~~,t-O~S P~C~ht~.~ ~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No ~t ., C~~~~~ ~~ ~.,~M~v~ ~~ ` HZS Measures: ~Yes ^ No Directional Survey Req'd: ~( Yes ^ No c~~.,l, ~ r~ Qn .~ ~ e~z, ~~ ~,~ c io~o~ "~r.svr~.c~ hQ~ Other: l~ \~~+~c~.~ ~:pEC-e~.~Zcc~ '~~~~~oc~ ~-' l AlO S~. T--a~~~c~-zohi~or:~ '~, ~.,a~~c-~~\~ APPROVED BY THE COMMISSION Date , COMMISSIONER Form 10-401 Revised 12/2~05< ~ '`r Submit In DupliCate Q~1~ ~ ~ ~T1 ~_ • ! Well Plan Summarv Well Name: W-213 T e of Well roducer or in'ector : USH Injector Surface Location: 406' FNL, 1,176' FEL, Sec. 21, T11N, R12E As Built X= 612,049.00 Y= 5,959,851.00 Top OA: 90' FNL, 2,348' FEL, Sec. 21, T11 N, R12E WP06 X= 610,872.5 Y= 5,960,149.6 Z= 4,800' TVDss Top OBd: 89' FNL, 2,371' FEL, Sec. 21, T11N, R12E WP06 X= 610,849 Y= 5,960,150 Z= 4,970' TVDss TD: 89' FNL, 2,413' FEL, Sec. 21, T11 N, R12E WP06 X= 610,807 Y= 5,960,150 Z= 5,288' TVDss AFE Number: N/A Ri : Nabors 9ES Estimated Start Date: May 15 2007 Operatin days to complete: 21.75 Data Below Based on Data from Directional Plan 06 WP06 MD: 5,542' TVD: 5,370' Max Inc: 17° GL: 53.2' KB: 28.5' KBE: 81.7' Well Design: USH Grassroots Schrader Bluff Injector 3-'/2", L-80, TC-II, multi packer, zonal injection, and zonal monitorin completion General Distance to Nearest Property: Distance to Nearest Well in Pool API Number: Well Type: Current Status: BHP: BHT: Mechanical Condition ~16,050' at TD to the nearest PBU property line 213' from W-213 to W-29 at the OA top 50-029-XXXXX Development - Polaris Schrader Injector New well, 20" X 34" insulated conductor 2,265 psi @ 5,130' TVDss 105°F C«~ 5,130' TVDss W-213: Ground Level above MSL = 53.2' -"As Staked Survey' Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW has not been set yet. W-213 Permit to Drill Page 1 ~ ~ '/a Mile Welibore Near Wellbore Mechanical Integrity Summary: A more comprehensive document was sent to the AOGCC detailing the well conditions in the table below. A follow up conversation has taken place between Tom Maunder, Taylor West and Egor Makarov using the previously mentioned documentation. ~~..~/ 17 ~f Dist. to nearest well within pool, ft: 211' from W-29 C~closest a roach. 213' at To OBa shallowest in'ection oint . Wells within 1/4 mi. of this injection well @ Top of Pool (=Mc) Well Name Dist, Ft. Annulus Inte rit Comments " ~ 258' at Mc, 238' at SB_Na, 211' at Top OA, 213' at Top OBa. ov~d woC~ Top of cement calculated to be in SB_N_Sands - within ~a jp ~ Polaris Pool W -29 258 Top of cement calculated to be in SB~A Sand - within W-31 615 Polaris Pool Top of cement calculated to be in SB_~BA Sand which is W-32 677 one of our tar et in'ection sands } Top of cement calculated to be in SB_N_Sands - within W-3 732 Polaris Pool ~~ Top of cement calculated to be in SB_N_Sands - within W-2 743 Polaris Pool Top of cement calculated to be in SB_NA_Sands - within W-19 815 Polaris Pool \k W-3 1161 To of cement calculated to be in U nu Mc. Top of cement calculated to be in SB_NA_Sands - within W-23 1204 Polaris Pool Top of cement calculated to be in SB_NC_Sands - within W-24 1213 Polaris Pool Top of cement calculated to be in the UG_MB2 interval, W-22 1226 above the Schrader Bluff. ~ Top of cement calculated to be in the UG_MB2 interval, W-2 1293 above the Schrader Bluff. Top of cement calculated to be in SB_N_Sands - within W-18 1299 Polaris Pool Top of cement calculated to be in SB_OBB Sand which is W-21 1302 one of our tar et in"ection sands Well Status C Completion Schrader Bluff In'ection Well Note that top of cement for offset wells was based upon cement volumes pumped with a Comments 30% excess assumed. W-213 Permit to Drill Page 2 ~ ~ Formation Markers _. t G1 382' 300' 135 8.7 No SV6 1291' 1195' 538 8.7 No SV5 1963' 1835' 826 8.7 No Base Permafrost 1973' 1845' 830 8.7 rvo SV4 2119' 1985' 893 8.7 Poss. Free Gas or Gas H drates SV3 2667' 2510' 1130 8.7 Poss. Free Gas or Gas H drates SV2 2864' 2700' 1215 8.7 Poss. Free Gas or Gas H drates SV1 3161' 2985' 1343 8.7 Poss. Free Gas or Gas H drates UG4 3526' 3335' 1501 8.7 Thin coal UG4A 3568' 3375' 1519 8.7 Hea Oil between 3375 - 3525' ssTVD UG3 3911' 3705' 1667 8.7 Thin coals UG1 4396' 4170' 1877 8.7 No, water UG_Ma 4646' 4465' 2009 8.7 No, water UG_Mbl 4698' 4525' 2036 8.7 No, water UG_Mb2 faulted out n/a n/a Fault #1 4792' 4560' 2052 UG Mc 4818' 4578' 2060 8.7 Heavy Oil possible between 4578' - 4620' ssTVD SB_Na 4886' 4640' 2065 8.7 No, water SB Nb 4912, 4665' 2100 8.7 Poss. heavy oil between 4665 - 4680' ssTVD SB Nc 4942' 4695' 2113 8.7 Yes SB Ne 4953' 4705' 2117 8.7 Yes SB OA 5050' 4800' 2100 8.6 Yes SB OBa 5100' 4850' 1985 8.0 Yes SB OBb 5125' 4875' 2020 8.0 Yes SB OBC 5171' 4920' 2150 8.5 Yes SB OBd 5221' 4970' 2025 7.9 Yes SB OBe 5292' 5040' 2230 8.6 Yes SB OBf 5332' 5080' 2245 8.6 Yes Base SB OBf 5383' 5130' 2265 8.6 No ''*TD is based on 250' MD below the top OBe marker.** Mud Program 12'/a" Surface Hole Mud Pro erties: Spud - Freshwater Mud Interval Densit Funnel vis YP PH FL Initial 8.5 - 9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm 9.0 - 9.5 >250 30-45 8.5-9.0 8.0 Interval TD 9.6 max >250 30-40 8.5-9.0 5.0-7.0 8 3/a" Intermediate Hole Mud Properties: Freshwater LSND Mud PH: 9.0-9.5 <600 Chlorides Interval Densit YP PV API Filtrate MBT ~3,442' to ~5,542' MD 9.0 20-28 12-18 4-6 < 20 W-213 Permit to Drill Page 3 ~ ~ Survey and Logging Program 12-'/a" Hole Section: Surface Gyro will be utilized until MWD surveys are clear of Magnetic interference estimated ~1000' . O en Hole: MWD / GR 9-5/8" Cased hole: None „ 8-3/a" Hole Section: ; . ,„ MWD / GR / Res / Azimuthal Den / Neu / PWD (All real-time) 7" Cased Hole: USIT Bond Lo Prima De th Control Mode Cement Calculations: Casin Size: 9 5/e-in 40-Ib/ft L-80 BTC - Single Stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead 70C: Surface Lead TOC: Surface Tail: 1,000' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2,443' MD Total Cement Volume: Spacer 75 bbls of Viscosified Spacer weighted to 10.0 ppg (Mud Push II) Lead 424 bbls, 2379 ft , 556 sks 10.7 Ib/ al ASL G+ adds - 4.28 ft /sk Tail 79 bbls, 442 ft , 378 sks 15.8 Ib/ al Class G+ Durastone -1.17 ft /sk Temp BHST ~70° F, BHCT ~60° F estimated bv BP RP - confirm with SLB model. In the event that cement is not circulated to surface during the initial surFace casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size: 7" 26 Ib/ft L-80 BTC-M - Single Stage Basis: Lead: None Lead TOC: N/A Tail: 1,396' of open hole with 30% excess, plus 80' shoe track Tail TOC: 4,146' MD 500' MD above lanned Ma to at 4,646' MD Total Cement Volume: Wash 30 bbls CW100 S acer 30 bbls of Viscosified S acer Mud ush II Desi n Wei hted to 10.3 Tail 49 bbls, 273 ft , 228 sks 15.8 Ib/ al G+ Gasblok - 1.20 ft /sk Temp BHST ~105° F, BHCT --88° F estimated bv BP RP - confirm with SLB model. Centralizer Recommendations 9 5/8" Casing Centralizer Placement a) Run (25) 9 5/e" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to ~2,443' MD (~1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change due to actual hole conditions. Consult with the Drilling Engineer before changing the program. W-213 Permit to Drill Page 4 CasinglTubing Program ~ ~ 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, Run two Halliburton straight vain centralizer (7-1/8" ID x 8-1/2" OD) per joint from the casing shoe to 500' MD above the top of the Ma (~4,152' MD). Lock down one stop ring in the middle of each joint placing a centralizer on each side. Zonal isolation with cement is required across the Schrader Sands. The centralizer program is subject to change pending modeling and hole conditions. Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well W-204 Distance to W-204 15' W-204 will require surface shut-in and wellhouse removal in order to move over well W-213. ~--~ Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation while drilling directional profile (WP) 06. See attached Anti-~~Ilision scan in the directional plan package for sub-surface close approach wells and associated distances. All wells pass BP's Major Risk anti-collision scan. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceedin , ps~ ~t will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency will be 14 days. ~~(~ ` Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. /~,'~ 1`t~~~ Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: Disposal 2,265 psi - Base of Schrader (8.6 ppg @ 5,080' TVDss) 1,757 psi - Based on a full column of gas C~ 0.10 psi/ft 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi /' 10.4 ppg EMW LOT 20' from 9-5/8" shoe 27 bbls with an 10.4 ppg EMW LOT Estimated 9.0 ppg Brine / 6.8 ppg Diesel No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. W-213 Permit to Drill Page 5 ~ ~ 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 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 any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. 1r.~~-~-c~, ~ ~. ~C~Q~ ' ~~ y~ . ~~ W-213 Permit to Drill Page 6 ~ ~ Drillinq Hazards and Continqencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this Polygon fault block is expected to be normal pressured at 8.5-8.7 ppg EMW. This pressure is estimated based on offset well pressures. II. Hydrates and Shallow gas A. Gas Hydrates: Gas Hydrates are possible at W-pad from the SV5 thru the SV1 sands below the base of the permafrost. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole although there are previous instances of gas from the SVi into the Ugnu on W-pad. Recommended practices and precautions for drilling hydrates should be followed in the surface and intermediate hole sections. B. Shallow Gas: Shallow gas has been interpreted from surrounding offset well bore logs in the SV1 formation. Ensure Mud Weight is not reduced below the planned 9.0 ppg. If hydrates are excessive do not drill into the SV1 (predicted shallow gas) until the hydrostatic weight can be controlled with Mud Weight and is not being reduced do to the hydrates breaking out of the fluid column. This gas is not expected to be over pressured. III. Close Approach A. All wells passed the major risk scan for the surface hole interval. Review and follow the traveling cylinder / no-go plot per established procedures. III. Lost Circulation/Breathing A. Lost circulation is a possibility due to the close proximity to W-204. W-204 experienced losses while pumping their 1S~ stage cement job on their surface hole. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/e" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma sand ~4,146' MD. C. The Kick Tolerance for the surface casing is 27 bbls with 9.0 ppg mud, 10.4 ppg LOT, and an 8.7 ppg pore pressure. V. Stuck Pipe A. Stuck pipe issues are not expected if current drilling practices are followed. VI. Hydrogen Sulfide W-Pad will be considered an HZS site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL Well H2S Level W-201 20 m 11/1/2005 #2 Closest SHL Well H2S Level W-200 15 m 8/21/2006 #1 Closest BHL Well H2S Level W-31 10 m 11/4/2006 #2 Closest BHL Well H2S Level W-32A 20 m 10/8/2006 Max. Recorded H2S on Pad/Facilit W-01 60 m 8/16/2005 All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range as a result of usin PBU as lift as. VII. Faults A. One fault is expected to be crossed at W-213. This fault has been crossed by at least three other wells. No losses or other hole problems are expected to be associated with this fault. Details are listed below for reference: Fault 1(Ugnu): 4,800' MD 4,641' TVD 4,560' TVDss Throw: 90' Southwest CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-213 Permit to Drill Page 7 ~ ~ W-213 Operations Summarv Pre-Rig Work: 1. Weld an FMC landing ring and "Butt Well Sub" for the FMC Gen 5 Wellhead on the 20" conductor. The Butt Weld Sub is a contingency that would allow running a short 13-3/8" surface casing string. 2. If necessary, level the pad and prepare location for rig move. 3. Prepare neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-Ya" drilling assembly with MWD/GR and directionally drill surface hole to approximately 80' TVD above UG4. The actual surface hole TD is planned at 3,443' MD / 3,255' ssTVD. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the permafrost. POOH and laydown BHA. 3. Run and cement the 9 5/e", 40.0-Ib/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency. If serious hole problems arise a 16" hole with 13-3/8" casing is available as a contingency. 4. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi / 2500 psi annular. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den-caliper/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 5/e" casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9-5/e" shoe and perform LOT. 7. Drill ahead to production hole target TD at 5,540' MD / 5,288' ssTVD (250' MD below Top OBe marker). CBU ix while reciprocating and rotating at maximum RPM, back-ream out of hole to run casing. 8. Run and cement the 7", 26#, L-80, BTC-M x TCII production casing. Note: Torque turn 7" TC-II threaded casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze proteciing. Freeze protect the 7" x 9-5/a" annulus. 9. PU DPC guns and Schlumberger LWD GR. RIH w/ 4.5" Power Jet 5 spf, perf guns utilizing Schlumberger LWD GR for gun correlation. Tag PBTD, Circulate over to 9.0 brine. Depths to be determined from actual LW D logs. 10. Space out perf. guns utilizing GR and RA tags in 7" casing. Once correlated correctly, gently tag TD w/ guns on bottom. Pull back to shooting depth & confirm cement compressive strength is at least 1,000 psi. Perforate zones as determined from actual LWD logs. POOH standing DP back. 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 (OBd perfs planned at 5,220'- 5,260' MD). f 12. Run USIT/GR log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-'/z", 9.2#, L-80 TCII completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II tubing. Note: Do not circulate inhibited brine down the /A af this time. 14. Run in the lockdown screws and set the packers. Test the IA and tubing to 4,000 psi each individually while recording on a chart. Shear the DCR shear valve and pump both ways to confirm circulation ab+lity. 15. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 16. Freeze protect the IA and Tubing to 2,200 ssTVD. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/z" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. W-213 Permit to Drill Page 8 ~ i W-213 Detailed Drilling Procedure MIRU Critical Issues: - Confirm Landing ring height and riser modifications needed prior to MIRU. Confirm this requirement prior to the rig moving over the well. - Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. - A total of one well will require well house removal for the rig move onto W-213. The one well house is on the South (W-204). This well (W-204) will require surface shut-in for the rig move onto W-201. The closest neighboring well is spaced as follows: W-204 ~15' to the South. Care should be taken while moving onto the well. Spotters will be used at all times. o As per SOP, any wells requiring well house removal will need to be shut-in and depressurized via the SSSV for MIRU. The wells can be brought back on line once the rig is set in place and done moving. ^ Ensure there is good communication with the Pad operator when the wells are shut in and when they may or may not be brought back on production. - W-Pad wil/ be considered an HZS site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL Well H2S Level W-201 20 m 11/1/2005 #2 Closest SHL Well H2S Level W-200 15 m 8/21/2006 #1 Closest BHL Well H2S Level W-31 10 m 11/4/2006 #2 Closest BHL Well H2S Level W-32A 20 m 10/8/2006 Max. Recorded H2S on Pad/Facilit W-01 60 m 8/16/2005 All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range as a result of usin PBU as lift as. - Post Pad Data Sheet and Drilling Hazards Sheet in the dog house and camp. Reference SOP: •"Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. • "Hydrogen Sulfide"SOP. • "ADW Rig Move" RP. Operational Specifics • See the As-Built for the W-213 conductor location on W Pad. • Post Drilling Permit with Summary of Drilling Hazards in doghouse prior to spud. • A Diverter is required on W Pad. • Review the W Pad data sheet and post in the dog house and field office. W-213 Permit to Drill Page 9 ~ ~ Drill 12-1/4" Surface Hole Critical Issues: - The well 15' to the South (W-204) was drilled in January 2007. The well encountered the worst "running gravel" seen in GPB in quite some time. Every attempt to ensure all the recommended practices for surface hole drilling is followed as outlined in the recently created Surface Hole Drilling RP. - Surface Hole Problems: Swabbing, tight hole, gas hydrates, lost returns, running gravels, 3' wood interval and casing and cementing problems have been experienced at W Pad on previous wells. Hydrates are present at W Pad from the SV-5 through the Ugnu formations and should be treated with conventional practices: pre-treating mud, maintaining cool mud, and drilling through the hydrate section as quickly as practical. - Gas Hydrates: Gas Hydrates are possible at W-pad from the SV5 thru the SV1 sands below the base of the permafrost. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole although there are previous instances of gas from the SV1 into the Ugnu on W-pad. Recommended practices and precautions for drilling hydrates should be followed in the surface and intermediate hole sections. - Shallow Gas: Shallow gas has been interpreted from surrounding offset well bore logs in the SVi formation. Ensure Mud Weight is not reduced below the planned 9.0 ppg. If hydrates are excessive do not drill into the SV1 (predicted shallow gas) until the hydrostatic weight can be controlled with Mud Weight and is not being reduced do to the hydrates breaking out of the fluid column. This gas is not expected to be over pressured. - Close Approach: All wells passed the major risk scan for the surface hole interval. Review and follow the traveling cylinder / no-go plot per established procedures. - Directional: Every effort should be made to ensure a`smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Objective is to keep DLS <_1.5° over planned. o A Gyro survey will be required per the directional plan to 1000' MD or until the magnetic interference on the MWD surveys has dissipated. o The well can be drilled to 300' with "inclination onl~' surveys as per attached surface A/C package. This interval will be surveyed (at minimum) every 100' with a gyro on the first run in the hole with a Gyro. - Hole Cleaning: Surface rotary speeds should be maximized wherever possible. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back reaming across initial tight spots only if washing does not alleviate the problem. - Faults: There are no planned fault crossings in the surface hole. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" W-213 Permit to Drill Page 10 ~ ~ Run 9-5/8" Surface Casinq Critical Issues: - Casing drift: 9-5/8" 40# is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3/4" bit, i.e. casing, float equipment, casing hanger, etc. - Casing Running: Previous surface casing jobs on W-Pad have had difficulty running casing due to Thawed permafrost, running gravels, high concentrations of wood and sticky clays. - Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar may be placed at ~1,000-ft MD as a contingency if hole conditions warrant. The well 15' to the South took four cement jobs in order get cement to the surface. The total volume of cement pumped was ~1,500 bbls. o Durastone will be added to the tail cement for strength around the shoe of the 9-5/8" casing. - Losses during cement job: Lost circulation has been experienced on W-Pad while running and cementing surface casing on past wells. The well 15' South lost circulation during final stages of 1S'stage. The expected fracture gradient for the shale below the SVi sands should be above a 12.7-Ib/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. - Cement "slump": CemNET will be added to the lead cement slurry as a trial to reduce the need to perform a small top job. Reference RPs: :• "Surface Casing and Cementing Guidelines" :• "Surface Casing Port Collar Procedure" Drill 8-3/4" Intermediate Hole Critical Issues: - Fibrous LCM / Super-sweep: There are no plans to run MDT logs on this well. There are no LCM restrictions while drilling this well. Follow the GPB Lost Circulation Decision Tree if needed. - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. - LOT: Perform a LOT following the LOT SOP guidelines. The Kick Tolerance for the surface casing is 27 bbls with 9.0 ppg mud, 10.4 ppg LOT, and an 8.7 ppg pore pressure. Based upon off-set drilling data on W Pad, a minimum leak-off of 12.5 ppg is expected at the 9-5/8" shoe. ECD's are expected to be in the 10 ppg range while drilling. Note: The well W-204 received a 14.6 ppg EWM LOT. - Screen Blinding: Add EMI-697 as per MI mud program while drilling the Ugnu/heavy oil sands. - 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the top OBe marker. After seeing the top OBe, TD will be picked based on drilling 250' MD past this marker. This footage is critical for future well work. If the tops are coming in 50' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. - Faults: There is one planned fault crossing in this section at an estimated depth of 4,800' MD / 4560' ssTVD. This fault should be crossed in the Ugnu formation. There are no anticipated problems associated with this fault crossing since it has been previously crossed by at least 3 other wells. - Directional Constraints: There are two faults to the South and West of the target location. Stay within the target polygons to avoid drilling two close to these faults. This section will require hold a relatively low inclination and then a slight drop near TD. Design the BHA to hold angle, minimizing the inclination and walking tendencies which will minimize "maintenance slides". W-213 Permit to Drill Page 11 ~ ~ - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. If a tight spot is encountered, run back in the length of the BHA and circulate for at least 30 minutes at max rotation speed and max flow rate while reciprocating at max allowable speed without exceeding the ECD limit. Reference RPs: •"Standard Operating Procedure for Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" •"Lubricants for Torque and Drag Management" • "ERD Operating Practices" Run and Cement 7" Intermediate Casinq Critical Issues: - Cement Job: A high quality cement job is required for zonal isolation. Reciprocate pipe as long as possible whife cementing. Note when reciprocation is stopped in DIM's daily report. - Freeze Protection: Establish circulation early, before cement reaches 500 psi compressive strength, to ensure a successful freeze protect. After freeze protecting the 7" x 9-5/8" casing outer annulus with diesel to 2,200' TVD, the hydrostatic pressure will be 6.8 ppg vs 8.6 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the diesel as the hydrostatic pressure of the mud and diesel could be 200 psi under balance to the open hole. - Differential Sticking: Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period of time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: Top OBd sand - Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. - Well Control: Ensure that two TIW valves with crossovers are on the rig floor prior to picking up the 7" casing. One with a crossover to 7" BTC and one with a crossover to 7" TCII. Install 7" pipe rams and test. - Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. Reference RPs: • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" • "ERD Operating Practices RP" W-213 Permit to Drill Page 12 ~ DPC Perforate Well ~~ Critical Issues - Barriers: A wireline BOP with double downward rams should be used in conjunction with a packoff or stuffing box attached to a riser joint for wireline operations. While running DPC guns the well will be contain kill weight fluid and SOPs wifl be in place. After perforating, up to freeze protecting this will be adequate to provide two barriers. - The well will be perforated ±100 psi over-balanced. Ensure all personnel are well briefed on Shlumberger's perforating procedures and that all responsibilities are understood. - It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. - Contact Schlumberger to prepare for approximately 100' of 4-1/2" Power Jet guns at 5 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. - Be prepared for fluid losses to the formation after perforating. Have ample seawater and brine on location and be prepared with LCM if necessary. Losses are not expected to be severe based on past perforation jobs. It is expected that the formation will take a little drink due to the extra pressure induced by the detonation of the perf guns. - It is planned to utilize LWD GR to correlate to the formation and casing RA tags to position the perforation assembly. The GR tool will be placed above the perforating assembly, the assembly is then RIH past the perf depth, the well will be logged up to correlate DP depth, and then the guns can be brought on depth and fired. The LWD GR tool requires a 150-260 gpm flowrate to establish a signal. Modeling indicates a maximum pressure of 2,400 psi will be seen when pumping @250 gpm. The previous USIT/GR will be used as the primary depth control. Reference RPs • "Wireline Pressure Control SOP" •"Alaska Wells Group Standard Operating Procedure: Perforating" • Follow Schlumberger perforating practices and recommendations Run USIT (E-line Conveved): Running the USIT Log: Prior to running the USIT, make GR/JB runs as necessary on wireline to clean any debris from wellbore down to 50' below the bottom perforation. It is critical to have a clean hole for the USIT program and to run this completion in with the production packers. Run USIT in primary depth control mode (PDC), as it will be use for future well work. Log USIT up inside surface shoe or to TOC, which ever is higher. Reference RPs • "Wireline Pressure Control SOP" • Follow Schlumberger logging practices and recommendations W-213 Permit to Drill Page 13 ~ ~ Run 3-'h" 9.2# L-80 TC-II Completion: Critical Issues: - Pressure Testing: Contact the Field AOGCC Rep with 24 hours of notice to witness the tubing and annulus pressure tests. - Packers: Four HES pressure set packers will be run on this completion. They are set for pull to release at 90,000#. Please confirm the setting on these packers before RIH as they come pre-set for 75,000# pull to release. The release rating is increased by changing out the (15) 5k # shear screws and replacing them with 6k # shear screws. This should have been done before the packers were sent to location. IA pressure tests will act to release these packers, however the maximum differential pressure rating is 5400psi. These packers are pressure set and do not require tubing movement to set. - I-Wire: There will be two i-wires run to surface from the top packer. Use hand slips when running jewelry and air slips when running tubing. Be careful to not crush any i-wire or control line. There will be several spools of I-wire and control line on the rig floor. Take into consideration the timing of events and spacing requirements of the spools when rigging up to run the completion. Follow the running procedures provided by Schlumberger. - Pressure Gauges: The max pressure is 5000 psi. Tubing and IA pressure tests to 4000 psi will not affect the gauges because they will be isolated behind the packers and tubing. - Injection Mandrels: Ensure the check valves are removed from the MMG-W mandrels. This allows the circulation between mandrels if necessary. - RA Tag Location: Place RA tag in the tubing at the top of the OA (5,050' MD / 4,882' TVD). This will help with the depth correlation when logging the completion onto depth. Reference RP: • "Completion Design and Running" RP • "Casing and Tubing connections" RP Job 9: ND/NU/Release Riq Critical /ssues - See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. - Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RPs •"Freeze Protecting an Inner Annulus" RP W-213 Permit to Drill Page 14 ~P Schlumberger W-213 (P6) Proaosal Report Date: March 12, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA StructurelSlot: W-PAD/W-213 '~~ Well: ~~~~ Plan W-213 Borehole: ~~ ~ Plan W-213 UVN/API#: 50029 Survey Name 1 Date: W-213 (P6) / March 12, 2007 Tort I AHD I DDI 1 ERD ratio: 25.471 ° 11279.89 ft / 4.527 / 023E Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LatlLong: N 7017 57.32620845, W 149 5 33.12298594 Location Grid NIE YIX: N 5959851.000 ftUS, E 612049.000 ftUS Grid Convergence Angle: +0.85435653° Vertical Section Azimuth: 284.390° ~ Y Vertical Section Origin: N 0.000 ft, E 0 000 ft ND Reference Datum: Rotary Table TVD Reference Elevation: 81.70 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.20 ft relative to MSL Magoetic Declinffiion: 23.742° Total Field Strength: 57642.843 nT Magnetic Oip: 80.897° Declination Date: May 20, 2007 Magnetic Declination Model: BGGM 2006 ~ North Reference: True North ToWI Corr Mag North -> True North: +23.742° Measured Vertical ~~~~ty Comments Inclination Azimuth Sub•Sea ND TVD NS EW DLS Build Rate Walk Rate Northing Easting Latftude Longitude Depfh Section Tool Face R d de ft ft ft ft ft de d 1100 k d 100 ft de 700 ft ftUS ftUS Klt U .UU U.UU Ltlb.ZV -tll./U U. VU U.VU V.VV V.VV --- V.VV KOP Bld 1.5/100 300 .00 0.00 285.20 218.30 300. 00 0.00 0.00 0.00 HS 0.00 G1 381. 71 1.23 285.20 300.00 381. 70 0.87 0.23 -0.84 HS 1.50 Bid 2.25/100 400 .00 1.50 285.20 318.29 399. 99 1.31 0.34 -1.26 HS 1.50 500 .00 3.75 285.20 418.18 499. 88 5.89 1.54 -5.68 HS 2.25 600 .00 6.00 285.20 517.81 599. 51 14.38 3.77 -13.88 HS 2.25 700 .00 8.25 285.20 617.03 698. 73 26.79 7.02 -25.85 HS 2.25 800 .00 10.50 285.20 715.69 797. 39 43.07 11.30 -41.57 HS 2.25 900 .00 12.75 285.20 813.63 895. 33 63.22 16.58 -61.01 HS 2.25 1000 .00 15.00 285.20 910.71 992. 41 87.20 22.87 -84.15 HS 2.25 End Bld 1058 .63 16.32 285.20 967.16 1048. 86 103.02 27.02 -99.43 --- 2.25 SV6 1290. 83 16.32 285.20 1190.00 1271. 70 168.26 44.13 -162.39 --- 0.00 SV5 1962. 90 16.32 285.20 1835.00 1916. 70 357.08 93.65 -344.62 --- 0.00 Base Perm 1973. 32 16.32 285.20 1845.00 1926. 70 360.01 94.42 -347.45 --- 0.00 SV4 2119. 20 16.32 285.20 1985.00 2066. 70 401.00 105.17 -387.00 --- 0.00 S V3 2666. 24 16.32 285.20 2510.00 2591. 70 554.69 145.48 -535.33 --- 0.00 SV2 2864. 22 16.32 285.20 2700.00 2781. 70 610.32 160.07 -589.02 --- 0.00 SV1 3161. 18 16.32 285.20 2985.00 3066. 70 693.75 181.95 -669.54 --- 0.00 9-5/8" Csg Pt 3442. 51 16.32 285.20 3255.00 3336. 70 772.80 202.68 -745.83 --- 0.00 UG4 3525. 87 16.32 285.20 3335.00 3416. 70 796.22 208.82 -768.43 --- 0.00 UG4A 3567. 55 16.32 285.20 3375.00 3456 J0 807.93 211.89 -779.73 --- 0.00 UG3 3911. 41 16.32 285.20 3705.00 3786. 70 904.54 237.23 -872.97 --- 0.00 , UG1 4395. 93 16.32 285.20 4170.00 4251. 70 1040.67 272.93 -1004.35 --- 0.00 U.VV V.UV oy~yao i.vv O ILV4y.VV V 1/~/.3LOLV04~4~ ~ JJ. ILGyOJy4 0.00 0.00 5959851.00 612049.00 0 17 57.3262084~ 49 5 33.12298594 1.50 0.00 5959851.22 612048.15 0 17 57.32846176 49 5 33.1475688b 1.50 0.00 5959851.32 612047.73 0 17 57.3295836~ 49 5 33.15980859 2.25 0.00 5959852.46 612043.30 0 17 57.34139377 49 5 33.28864096 2.25 0.00 5959854.56 612035.06 0 17 57.3633093C 49 5 33.52769519 2.25 0.00 5959857.64 612023.05 0 17 57.3952963~ 49 5 33.87660285 2.25 0.00 5959861.67 612007.27 0 17 57.4373053` 49 5 34.33482625 2.25 0.00 5959866.67 611987.75 0 17 57.4892713749 5 34.90165921 2.25 0.00 5959872.61 611964.52 0 17 57.55111397 49 5 35.57622817 2.25 0.00 5959876.53 611949.19 0 17 57.5919281 C 49 5 36.021 46 0.00 0.00 5959892J0 611885.99 0 17 57J601908G 49 5 37.85 0.00 0.00 5959939.50 611703.05 0 17 58.2471907~ 49 5 43.16 ° 0,00 0.00 5959940.22 611700.21 0 17 58.25474077 49 5 43.25186105 0.00 0.00 5959950.38 611660.51 0 17 58.3604403G 49 5 44.40500046 0.00 0.00 5959988.47 611511.60 0 17 58.75679535 49 5 48J293028~ 0.00 0.00 5960002.25 611457.71 0 17 58.9002310~ 49 5 50.2942999L 0.00 0.00 5960022.93 611376.88 0 17 59.11537746 49 5 52.6418069~ 0.00 0.00 5960042.52 611300.30 0 17 59.3191926~ 49 5 54.86577364 0.00 0.00 5960048.32 611277.61 0 17 59.37958085 49 5 55.5247291G 0.00 0.00 5960051.23 611266.27 0 17 59.40977465 49 5 55.85420725 0.00 0.00 5960075.17 611172.67 0 17 59.65886761 49 5 58.57241214 0.00 0.00 5960108.91 611040.78 70 18 0.00984308 149 6 2.4026431 b WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) W-213\Plan W-213\Plan W-213\W-213 (P6) Generated 3/12/2007 5:58 PM Page 1 of 2 Measured ~ert~~~ Gravity Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude LongiWde Depfh Section 7001 Face ft de d ft ft ft ft ft d de 1100 ft de 100 ft d 100 ft ftUS ftUS 4646. UU 7ti.:i1 ZBb."lU 447R UU 4491 J0 717Q 93 Zy1.36 -7U/Z. 76 --- U.UU UAO 0.UU by6U7'L6.3'L 67U9/Y./7 /U 1tf U.79U9tiZ/b 749 6 4.3/yb4986 4698. 10 16.32 285.20 4460. 00 4541. 70 1125. 57 295. 20 -1086. 28 --- 0.00 0.00 0.00 5960129.95 610958. 53 70 18 0.22871946 149 6 4.79140664 4744. 99 16.32 285.20 4505. 00 4586. 70 1138. 74 298. 66 -1099. 00 --- 0.00 0.00 0.00 5960133.21 610945. 77 70 18 0.26268225 149 6 5.1620781 G 4791. 88 16.32 285.20 4550. 00 4631. 70 1151. 91 302. 11 -1111. 71 --- 0.00 0.00 0.00 5960136.48 610933. 01 70 18 0.29664485 149 6 5.53274991 4817. 93 16.32 285.20 4575. 00 4656. 70 1159. 23 304. 03 -1118. 77 --- 0.00 0.00 0.00 5960138.29 610925. 92 70 18 0.31551284 149 6 5.73867884 4871. 42 16.32 285.20 4626 .34 4708 .04 1174. 26 307 .97 -1133 .28 168.13L 0.00 0.00 0.00 5960142.01 610911 .35 70 18 0.35425805 149 6 6.16155380 4885. 64 15. 76 284.77 4640. 00 4721. 70 1178. 19 308. 99 -1137. 07 167.71 L 4.00 -3.91 -3.03 5960142.97 610907. 55 70 18 0.3642461 ~ 149 6 6.2721817G 4900. 00 15.20 284.31 4653 .84 4735 .54 1182. 02 309 .95 -1140 .78 167.26L 4.00 -3.91 -3.25 5960143.88 610903 .82 7018 0.37370959 149 6 6.38037945 4911. 55 14.75 283.91 4665. 00 4746. 70 1185. 01 310. 68 -1143. 68 166.88L 4.00 -3.90 -3.46 5960144.57 610900. 92 70 18 0.3808618b 149 6 6.46478236 4942. 49 13.55 282.71 4695. 00 4776. 70 1192. 57 312. 42 -1151. 04 165.71L 4.00 -3.89 -3.88 5960146.20 610893. 53 70 18 0.39800255 149 6 6.6793427E 4952. 77 13.15 282.26 4705. 00 4786. 70 1194. 94 312. 94 -1153. 36 165.28L 4.00 -3.87 -4.34 5960146.68 610891. 21 70 18 0.40304565 149 6 6.74 5000. 00 11.33 279.82 4751 .16 4832 .86 1204. 94 314 .87 -1163 .18 162.89L 4.00 -3.85 -5.17 5960148.46 610881 .36 70 18 0.42203813149 6 ~ 7.03 5049. 66 9.45 276.26 4800. 00 4881. 70 1213. 84 316. 15 -1172. 04 159.39L 4.00 -3.79 -7.17 5960149.61 610872. 47 70 18 0.4345814G 149 6 7.29173384 5100. 00 7.60 270.89 4849 .78 4931 .48 1221. 17 316 .65 -1179 .48 154.08L 4.00 -3.68 -10.66 5960150.00 610865 .03 70 18 0.43951257 149 6 7.50862046 5100. 22 7.59 270.86 4850 .00 4931 .70 1221. 20 316 .65 -1179 .51 --- 4.00 -3.60 -13.23 5960150.00 610865 .00 70 18 0.43951692 149 6 7.50946909 5100. 23 7.59 270.86 4850. 01 4931. 71 1221. 20 316. 65 -1179. 51 --- 0.00 0.00 0.00 596015Q.00 610865. 00 70 18 0.43951711 149 6 7.50950704 5125. 44 7.59 270.86 4875. 00 4956. 70 1224. 44 316. 70 -1182. 85 --- 0.00 0.00 0.00 5960150.00 610861. 67 70 18 0.44000581 149 6 7.6066248b 5170. 84 7.59 270.86 4920. 00 5001. 70 1230. 28 316. 79 -1188. 84 --- 0.00 0.00 0.00 5960150.00 610855. 67 70 18 0.44088577 149 6 7.78150525 5221. 28 7.59 270.86 4970 .00 5051 .70 1236. 76 316 .89 -1195 .51 --- 0.00 0.00 0.00 5960150.00 610849 .00 70 18 0.44186346 149 6 7.97581676 5221. 29 7.59 270.86 4970. 01 5051. 71 1236. 76 316. 89 -1195. 51 --- 0.00 0.00 0.00 5960150.00 610849. 00 70 18 0.44186365 149 6 7.97585471 5291. 90 7.59 270.86 5040 .00 5121 .70 1245. 83 317 .03 -1204 .84 --- 0.00 0.00 0.00 5960150.00 610839 .67 70 18 0.44323212 149 6 8.24785292 5291. 91 7.59 270.86 5040. 01 5121. 71 1245. 83 317. 03 -1204. 84 --- 0.00 0.00 0.00 5960150.00 610839. 67 70 18 0.44323231 149 6 8.24789087 5332. 26 7.59 270.86 5080. 00 5161. 70 1251. 01 317. 11 -1210. 17 --- 0.00 0.00 0.00 5960150.00 610834. 34 70 18 0.44401416 149 6 8.40330216 5382. 70 7.59 270.86 5130. 00 5211. 70 1257. 50 317. 21 -1216. 84 --- 0.00 0.00 0.00 5960150.01 610827. 67 70 18 0.44499166 149 6 8.59761371 5541. 90 7.59 270.86 5287 .81 5369 .51 1277. 95 317 .53 -1237 .87 --- 0.00 0.00 0.00 5960150.01 610806 .64 70 18 0.44807642 149 6 9.21088992 ~ WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) W-213\Plan W-213\Plan W-213\W-213 (P6) Generated 3/12/2007 5:58 PM Page 2 of 2 bp ~ ~ Schlumberger VrELL FIELD STRUCTURE W-213 (P6) Prudhoe Bay Unit - WOA W-PAD MeqnNK Panmeters Surlaw Loca4on NND2] Nlaska S~a~e Fanes. Zone 00. US Feat M~ecellarneus MoOel~. BGGM10p6 pD~ ~~~' Oate May20.200] N]OiiS)J36 Natlyip 59°.BBS100M15 GrMLOnv ~OB513565J' Sbf~ W-213 NDReI RMaryTade~B110~aEavaMSL~ ma9a~~ ~~?~a2• FS~. 5]fid28nT Lon Wt<95y.12J EaErp'. 61XIa8WflU5 ScakFacl 099991JN33 Plan W-2131P61 SrvyDate Mar<~11,]OD] 0 800 1600 2400 ~ 800 1600 ~ °0 2400 ~ C ~ N U ~ ~> ~ 3200 4000 4800 5600 RTE .......................... ~ .......................:..................................~..................................:.............. KOP Bld 1.5/100 Bld 2.25/100 ...........................:. ................................:...................................:..................................:.............. End Bltl ~..~..~..~..~..~..~ ' .vs '~"~..~..~..~ ~..~..~..~..~..~..~..~..~ ..~..~..~..~..~..~..~. ~. _.._.._. ...........................j.......... ......................~...................................j..................................j.............. ^~........~.........d.......... w...~..~...i..............~..~.~~..~.i~.~..~...~........~..~.~.~.~..~...... ..........................:: ..................................s.............. ..._........_..-• -;•-••-••-••-••-••-•._.._..K.._.._.._ .~..~..~..~..~..~. ~i.~..~..~..~..~..~..~..~. ..~..~ .~..~..~..~..~..~. ~_.~..~..~..~..~..~..~..~. ~..~..~ 'ss~a^ csg ai . .. .. .. .. .. .. .. .. .. .. .. .. .. . .. .. .. _i._ ~~..~. ~..~..~..~..~~.~..~..~..~..~..~..~..~..K..~..~..~ .r..~..~..~..~..~. ..~..~..~..~..~..~..~. ~..~..~ J ..........................n..................................~.............. i ~` i . _.. _.. _.. _.. _ ~. _.. _..... _.. _.. _.. _.. _.. K.. _.. _.. _.. \ . . d Tn i r~ csy w Y~-213 (PB) 0 800 1600 2400 Vertical Section (ft) Azim = 284.39°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E!-V ~ 8~~ ~6~~ 2400 3200 4~~0 4800 5600 ~ ~ 0 0 0 0 ° (p V N O N O ` ~ C ~ ~ ~ ~ ~ ~ ~ a 3 ~ 8 ~8 z~ rc~ rc o ~ ~ ~ ~~3 ~~ F usi O N V O O ~ ~ ~ ~ Q Ssc Q ~ ~~ °~g ~ ~„I _ - ~ ~ ~ O O c0 ~ $ ~ ~ m g€ d $ w ~ Z ~ ~ N R O O a` ;_~ ~ - ;~~ 8~ o ~a N oLL ~^ o ° L` s " v ~. d v a°3 ~ M N ~ ~ p~ ~~ o 0 ~ fg a s ~ ~ O O O N O O V O ~ n A W ~ ~ O O o~p N C N c0 U ~ O ~ O O V ,~ 0 a ~ °v °o ~ O O O O O (~O 7 N N «< N (u)OOZ:(w) ~ = a~e~g g »> ~ ~ BP Alaska Anticollision Report Company: , ' BP Ar~oco Date: 3/12/2Q07 Time: 18:01:20 Fage: 1 ^`I Field: Prudhoe Bay , Reference Site: PB W Pad Go-ordinate(lVE) Reference: ; Weli: Plan W-213, True North Reference Well: Plart W-213 Vertical (TVD) Reference: W-213 Pian 81c7 Reference Wellpath: Plan W-213 ! Dh: Oracle - - --_. --- -- --__ __. ', NO GLOBAL SCAN: Using user defined selection & scan criteria __ --- -- - Reference: -- -- - - PrinCipal Plan & PLANNED PROGRAM , Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse ~, I Depth Range: 28.50 to 5541.90 ft Scan Method: Trav Cylinder North ', I Maximum Radius:10000.00 ft ~ _ _ _ _ _ Error Surface: _ _ _ _-- Ellipse + Casing ' - _ _- ._ - - ~-- - -__-_ ___ __ ' Surve Pro ram for Definitive Well ath Y g P --- -- -- - ~ ~ Date: 3/5/2002 Validated• No Verswn• 7 I Planned From To Survey Toolcode Tool Name ', ft ft ', i 28.50 1400.00 Planned: Plan #6 V1 MWD MWD - Standard ', I 28.50 3380.00 Planned: Plan #6 V1 MWD+IFR+MS MWD + IFR + Multi Station I ' 3380.00 5541.90 Planned: Plan #6 V1 MWD+IFR+MS MWD + IFR + MuRi Station I Casing Points - ---- ----- -_ _ _ - -- - - - MD TVD - - Di~meter Aole Size Name , -- -- , ft ft - - -___ -- - in in _ , , - = , . j 3442.51 3336.70 _. __.... .- _ _ _ - 9.625 12.250 9 5/8" -__ _ . . _ _ , i, 5541.90 5369.51 ~ --- -- - - -- -- - 7.000 8.750 7" ----- --____ I _ _ - Summary ~, <----- ---- Offset Wellpath --- ---> Reference OfYset , Ctr-Ctr No-Go Alloweble % i Site Well Wellpath ' MD MD Distance Area-- DeviaCion Warning ! ~ _-- -- -- ft ft ft -_ ft R I - I PB W Pad Plan W-209 - _ Plan W-209 V4 Plan: PI _ - - - 476.12 - ---- 485.00 - 722.37 - 8.74 _ __ 713.63 - _ Pass: Major Risk I I PB W Pad Plan W-214 Plan W-214 V5 Plan: PI 434.95 435.00 15.25 7.48 776 Pass: Major Risk ', ' PB W Pad Plan W-401 Plan W-401 V1 Plan: PI 1965.19 2225.00 96.86 42.99 53.87 Pass: Major Risk ' PB W Pad Plan W-45 Plan W-45 V3 Plan: Pla 914.36 930.00 1161.93 16.93 1145.00 Pass: Major Risk ' PB W Pad W-01 W-01 V3 454.64 465.00 753.48 8.49 744.99 Pass: Major Risk , PB W Pad W-01 W-01A V4 454.64 465.00 753.48 8.49 744.99 Pass: Major Risk PB W Pad W-01 W-01APB1 V1 454.64 465.00 753.48 8.49 744.99 Pass: Major Risk ' ', PB W Pad W-02 W-02 V4 486.93 500.00 787.21 7.47 779.74 Pass: Major Risk ', PB W Pad W-02 W-02A V20 483.40 494.99 787.17 7.44 779.73 Pass: Major Risk , PB W Pad W-03 W-03 V4 514.20 530.00 822.98 9.26 813.72 Pass: Major Risk ' ' PB W Pad W-03 W-03A V1 514.20 530.00 822.98 9.26 813.72 Pass: Major Risk ' i~ PB W Pad W-04 W-04 V1 413.63 430.00 856.75 7.18 849.57 Pass: Major Risk ~I PB W Pad ~ W-05 W-05 V3 418.37 435.00 891.57 7.87 883.70 Pass: Major Risk ' ~, PB W Pad W-05 W-05A V2 418.37 435.00 891.57 7.87 883.70 Pass: Major Risk I PB W Pad W-06 W-06 V5 444.40 455.00 962.28 8.56 953.72 Pass: Major Risk ', ~, PB W Pad W-07 W-07 V1 486.89 510.00 929.35 10.97 918.38 Pass: Major Risk !i I PB W Pad W-07 W-07A V7 486.00 500.00 929.33 10.95 918.38 Pass: Major Risk ', PB W Pad W-08 W-08 V1 485.74 510.00 997.53 8.30 989.23 Pass: Major Risk ', PB W Pad W-08 W-08A V12 482.04 500.00 997.48 7.98 989.50 Pass: Major Risk ', ~ PB W Pad W-09 W-09 V1 315.03 325.00 1031.67 6.63 1025.03 Pass: Major Risk '~, ~~ PB W Pad W-09 W-09A V4 31222 310.00 1031.66 6.68 1024.97 Pass: Major Risk !, , PB W Pad W-09 W-09AP61 V9 312.22 310.00 1031.66 6.62 1025.03 Pass: Major Risk '~ PB W Pad W-10 W-10 V3 474.83 490.00 1068.45 9.37 1059.08 I Pass: Major Risk ~ ', PB W Pad W-10 W-10A V4 474.83 490.00 1068.45 9.37 1059.08 Pass: Major Risk ! ' PB W Pad W-11 W-11 V1 479.49 505.00 1102,89 8.41 1094.48 Pass: Major Risk I ', PB W Pad W-12 W-12 V5 447.80 470.00 1137.78 9.29 1128.49 Pass: Major Risk , , PB W Pad W-15 W-15 V1 498.84 515.00 431.42 8.89 422.54 Pass: Major Risk I , PB W Pad W-15 W-15A V10 498.84 515.00 431.42 8.89 422.54 Pass: Major Risk ', ', PB W Pad W-15 W-15P61 V6 498.84 515.00 431.42 8.89 422.54 Pass: Major Risk ' ' PB W Pad W-15 W-15PB2 V1 498.84 515.00 431.42 8.89 422.54 Pass: Major Risk ' PB W Pad ' W-16 W-16 V3 461.13 475.00 39679 8.44 388.35 Pass: Major Risk ' PB W Pad W-16 W-16A V3 461.13 475.00 396J9 8.28 388.51 Pass: Major Risk , , PB W Pad W-16 W-16AP61 V1 461.13 475.00 396.79 8.28 388.51 Pass: Major Risk ', PB W Pad W-16 W-16L1 V3 461.13 475.00 396.79 8.44 388.35 Pass: Major Risk ; ~ PB W Pad W-17 W-17 V4 455.65 460.00 362.97 7.96 355.01 Pass: Major Risk I ! PB W Pad W-17 W-17A V9 452.80 460.00 362.93 7.92 355.01 Pass: Major Risk ~ PB W Pad W-18 W-18 V1 484.67 490.00 327.45 8.32 319.13 Pass: Major Risk I PB W Pad W-19 W-19 V2 404.15 415.00 291.30 7.19 284.11 Pass: Major Risk I I PB W Pad ~ W-19 W-19A V1 406.19 410.00 291.33 7.22 284.11 Pass: Major Risk ' i PB W Pad W-19 W-19AL1 V3 406.19 410.00 291.33 7.22 284.11 Pass: Major Risk ', I PB W Pad W-19 W-19AL1 PB1 V1 406.19 410.00 291.33 7.06 284.26 Pass: Major Risk I I PB W Pad W-19 W-19AL1 P62 V1 406.19 410.00 291.33 7.06 284.26 Pass: Major Risk ! ~ ~ BP Alaska Anticollision Report Company: - BP Am4co Date: 3/12/2007 ~ Time: 18;01:24 -~~~ ~ Page: ~ 2~ ~ Field: Prudhoe Bay ~ Reference Site: PB W P~d Co-ordinate(AIE) lteference: ' Weil: Plan W-2f3~, True North- ~ ReferenCe Weil: Ptan W-213 - VerCical (TVD) Reference: r W-213 Platr 81:7 J ~ Reference Wellpath: Plan W-213 ,:_ . _ _: . .... - - --------- --------- - ~_ ._ - - _.:: . _ -- - ~ _~ Db: Oracle ' I ~ ~ - - .~ ~ _ _.: --~ Summary <-------~----- -- Offset Wellpath --> Reference Offset Gtr-Ckr Nq-Go Apawable Site Well ' Wellpath MD MD Distance Area Deviation Warning ~ -- - -- -~ - - - ::- -- - = ft -- - ft '_ ft - - ft` -- ft =- -_ ,. -~- - PB W Pad - - - - W-200 _ . --- -- W-200PB1 V11 - 457.56 _ 460.00 81.11 = 7.75 ~ - 73.36 .__ .. ~ . _ 1 Pass: Major Risk PB W Pad W-201 W-201 V4 375.12 375.00 46.36 6.11 40.25 Pass: Major Risk i ! PB W Pad W-203 W-203 V10 373.79 385.00 1206.54 5.96 1200.57 Pass: Major Risk ', PB W Pad W-203 W-203L1 V8 37379 385.00 1206.54 5.75 1200.79 Pass: Major Risk 'I ', PB W Pad W-203 W-203L2 V4 37379 385.00 1206.54 5J5 1200.79 Pass: Major Risk ~, ' PB W Pad I W-205 W-205 V6 451.02 465.00 1169.08 7.73 1161.35 Pass: Major Risk ~' ~ PB W Pad W-205 W-205L1 V2 451.02 465.00 1169.08 7J3 1161.35 Pass: Major Risk i~ I PB W Pad W-205 W-205L1 P61 V4 451.02 465.00 1169.08 773 1161.35 Pass: Major Risk ~ ~; PB W Pad W-205 W-205L2 V4 451.02 465.00 1169.08 7.73 1161.35 Pass: Major Risk ' PB W Pad W-207 Plan W-207A V2 Plan: P 300.74 300.00 592.55 5.05 587.50 I Pass: Major Risk PB W Pad W-207 W-207 V10 300.74 300.00 592.55 5.05 587.50 Pass: Major Risk PB W Pad W-207 W-207P61 V2 300.74 300.00 592.55 5.05 587.50 Pass: Major Risk I PB W Pad W-209 W-209 V9 483.32 495.00 720.03 8.32 711.72 Pass: Major Risk I ~I PB W Pad W-209 W-209P61 V6 483.32 495.00 720.03 8.16 711.87 Pass: Major Risk I I PB W Pad W-20 W-20 V1 441.93 445.00 256.04 7.45 248.59 Pass: Major Risk I '~, PB W Pad W-210 W-210 V14 492.87 500.00 532.60 8.75 523.84 Pass: Major Risk I ', PB W Pad W-211 W-211 V9 904.24 900.00 530.80 16.67 514.14 Pass: Major Risk !, ', PB W Pad W-212 W-212 V12 530.94 545.00 500.25 7.84 492.41 Pass: Major Risk I ' PB W Pad W-215 W-215 V7 745.74 785.00 558.12 13.26 544.85 Pass: Major Risk !, PB W Pad W-215 W-215PB1 V2 745.74 785.00 558.12 13.26 544.85 Pass: Major Risk j ' PB W Pad W-21 W-21 V3 565.16 580.00 223.04 12.62 210.42 Pass: Major Risk ', '; PB W Pad W-21 W-21A V12 569.33 575.00 223.15 12.74 210.42 Pass: Major Risk ', I PB W Pad W-22 W-22 V1 476.66 480.00 187.62 8.72 178.89 Pass: Major Risk ~ PB W Pad W-23 W-23 V3 483.62 495.00 15273 8.49 144.24 Pass: Major Risk ', ', PB W Pad W-23 W-23A V5 483.12 485.00 152.72 8.48 144.24 Pass: Major Risk ' i PB W Pad W-24 W-24 V1 502.45 505.00 117.30 8.57 108.73 Pass: Major Risk ! PB W Pad W-25 W-25 V1 5540.30 5720.00 417.08 98.49 318.59 Pass: Major Risk ; I PB W Pad W-26 W-26 V3 2612.40 2700.00 359.58 65.87 293J2 Pass: Major Risk I, PB W Pad W-27 W-27 V3 1271.75 1275.00 561.63 25.42 536.22 Pass: Major Risk ' PB W Pad W-27 W-27A V3 1271.75 1275.00 561.63 25.42 536.22 Pass: Major Risk I, PB W Pad W-29 W-29 V1 5055.83 5280.00 210.63 81.12 129.51 Pass: Major Risk , ; PB W Pad W-30 W-30 V1 1332.26 1330.00 456.55 28.10 428.45 Pass: Major Risk I PB W Pad ~ W-31 W-31 V1 4664.17 4850.00 563.14 178.25 384.90 Pass: Major Risk , PB W Pad W-32 W-32 V6 1391.47 1385.00 389.57 26.91 362.65 Pass: Major Risk ~ PB W Pad W-32 W-32A V3 1394.16 1385.00 389.63 26.97 362.65 ~ Pass: Major Risk I ', PB W Pad W-32 W-32AP61 V13 1394.16 1385.00 389.63 2672 362.91 Pass: Major Risk , ' PB W Pad W-34 W-34 V1 1203.80 1225.00 857.24 24.55 832.69 Pass: Major Risk I , PB W Pad W-34 W-34A V1 1203.80 1225.00 857.24 24.55 832.69 Pass: Major Risk I PB W Pad W-34 W-34AP61 V1 1203.80 1225.00 857.24 24.40 832.85 Pass: Major Risk I ' PB W Pad W-35 W-35 V1 1116.27 1135.00 888.43 22.83 865.59 Pass: Major Risk , ' PB W Pad W-36 W-36 V1 1031.14 1050.00 925.64 18.93 906J1 Pass: Major Risk 'I ', PB W Pad W-37 W-37 V3 1024.77 1045.00 959.58 20.77 938.81 Pass: Major Risk ', ', PB W Pad W-37 W-37A V3 1024.77 1045.00 959.58 20.77 938.81 Pass: Major Risk I ' PB W Pad W-38 W-38 V2 456.49 465.00 992.45 7.88 984.57 I Pass: Major Risk , PB W Pad W-38 W-38A V10 459.15 465.00 992.49 7.81 984.67 Pass: Major Risk ~ '~ PB W Pad W-39 W-39 V1 968.53 990.00 1027.73 21.05 1006.68 Pass: Major Risk 'i ' PB W Pad W-39 W-39A V2 968.53 990.00 102773 21.21 1006.52 Pass: Major Risk I , PB W Pad W-400 W-400 V5 880.54 900.00 1077.25 15.15 1062.10 Pass: Major Risk ' , PB W Pad W-40 W-40 V1 103978 1070.00 1062.84 21.09 1041 J4 Pass: Major Risk ~~, ' PB W Pad W-42 W-42 V4 939.32 965.00 1130.53 16.96 1113.56 Pass: Major Risk I ' PB W Pad W-44 W-44 V1 958.08 990.00 1195.56 16.46 1179.09 Pass: Major Risk I • s FieldPrudhoe Bay Site PB W Pad We11:Plan W-213 wellpathPlan W-213 313 300 200 100 0 2 100 200 300 313 n 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t ~ Site: PB W Pad Drilling Target Conf.: 95% Description: Map Northing: 5960150.00 ft Map Easting : 610865.00 ft Latitude: 70° 18'00.440N Shape: Circle Target: W-213 Tgt l OBa __ `\ __ _ _ . _ ~~ ' 0 0~ O~t D ~ ~ 0~ ~~ } ~ WeIL• Plan W-213 Based on: Planned Program Vertical Depth: 4850.00 ft below Mean Sea Level Local +N/-S: 316.65 ft Local +E/-W: -1179.51 ft Longitude: 149°06'07.509 W Radius: 50 ft _ __- - _ _ _ ___ _. ~ _ . ; _ %~ 4-50 ~+00 350 300 250 O O o ~n cv i - i ~ Target: W-213 Tgt 1 OBd ~ ' Site: PB W Pad Well: Plan W-213 Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 4970.00 ft below Mean Sea Level Map Northing: 5960150.00 ft Local +N/-S: 316.89 ft Map Easting : 610849.00 ft Local +E/-W: -1195.51 ft Latitude: 70° 18'00.442N Longitude: 149°06'07.976W Shape: Circle Radius: 50 ft , ~ ~ ~ ~ ~ ' , , / / / ~ , ~ ~ ~ ~ ~a ~ O ~ (1 ~ ~ ~ ~ ~ 0 ~ ~ ~ ~~ ~ ~ ;EE=~ 4-1/8" 1NELLHEAD= FMC ACTUATOR = Leo Ks. ~EV = Zs.s BF. ELEV = xxx' KOP = 300' Max Angle = xx° ~ xxxx' Datum N~ = xxxx' DatumTVD= xxxx'SS • W-213 DRAFT Proposed Completion AFETY NOTES: GLM'S ~ STA #1-#6 ARE ~-1/2" X 7-1/2" MMGW WHICHARE WATERROOD MANDRELS. 2343' ~~ 3-1/2" HES X NIP, ID = 2.813" 9-5/8" CSG, 4QI~, L-80, ID = 8.835" 3443' 7" XO from TGB to BTGM 4646' Minimum ID = 2.813" 3-1t2" HES X NIPPLE T' MARKER JOINT W/ RA TAG 4646' CTS gauge 10.~cx TBA 3-1 /2" TBG W/ RA Tag in Centralizer ~ TBA FWire run from surface T~ CTS gauge ID=xx 'j'~ T' MARKER JOINT W! RA TAG TBA ~ 7 TBA MMG DCR-1 RKP 1.5" 6 TBA N~1AG-W DUM RK 1.5" 5 TBA MMG-W WM RK 1.5" 4 TBA MMG-W WM RK 1.5" 3 TBA MMG-W DUM RK 1.5" 2 TBA MMG-W DUM RK 1.5" 1 TBA MAAG-W DUM RK 1.5" TBA ~--1 3-1/2" HES X NIP, ID = 2.813" TBA U 7" X 3-1/2" HES AHR Packer, ID = 2.921" TBA 3-1/2" HES X NiP, ID = 2.813" TBA T' X 3-1/2" HES AHR Packer, ID = 2.921" TBA ~~ 3-1/2" HES X NIP, ID = 2.813" TBA LJ T' X 3-1 /2" HES A HR Packer, ID = 2.921" PERFORATION SUMMARY REF LOG: A NGLE AT TOP PFRF: Note: SQE SPF IM1ffERVAL OpnlSqz DATE 4.5" 5 N~ TBA 4.5" 5 OBa TBA 4.5" 5 OBc TBA 4.5" 5 OBd TBA 3-1/2" TBG, 8.2#, L-80, .0087 bpf, ID = 2.992" ~ 5340' ~ 5460' 7" CSG, 26#, L-80, ID = 6.276" 5542' TB~- CTS gauge ID = xx" TBA ~ J T' X 3-1l2" HES AHR Packer, !D = 2.929" T~ CTS gauge ID = xx" TBA 3-i/2" HES X NIP, ID= 2.813" TBA 3-1 /2" HES X NIP, ~= 2.813" w/RHGm plu~ TBA -~ 3-1/2" HES X NIP, ID = 2.813" 5340' 3-1 /2" WLEG, ID = 3.00" V1fELL: IN-213 PERNNT No: API No: Sec Tw p Rge BP F~cploration (Alaska) ! SEC 16 _ _ SEC 21 - - - - N N w _._... ..........~~N 2904 .... ... N 2822 - ~ ~=?r~ ~204 ^ 20~ ~' ^ 200 m ^ 24 W ^ 23 I ~ 22 ' . 2, N 2414.5-,- " ^ 20 33 ^ ^ 19 523 32 ^ ^ 18 31^ ^17 s~' 30 ^ ^ 16 29 ^ ^ 15 z~i^ .,4 s°~ 27. .2i2 ' ^21Hi M~ ~l7 25 ^ ^ 215 - _ : . ; ^ 207 m ~, ~ Z _ N W 209 ~ ~ i W I 2 34 ~ 3 35 ~ 4 36 ~ 5 ~ 37} 7 38 ~ ~ 6 39 ^ g 40 ~ ~9 400~ 1g 42 ~ 11 SPARE ~ *~2 44 ~ } 205 ~ ~, ' '. ,' ~ 203 ' FA Orwk M74.1D K FFl 6rwnJ 11]0.]! R ~. ~ i 16 -. '7s,,~ 15 p , W ~ ~ ~ W PA ~ --- -- n- Q WESTEND -- NO. 1 ~ 2~~ - N I KUP UK SfA Zz N0.7 STAGING AREA W-PAD VICINITY MAP N.T.S. ~ OF q~q ~ ~~`~ ,~F' °° °S,r 1~ ~0 ~09 ~ ~ 49 ~ ~~ 000oooooeooosooseaoeoeaooooaooo ~ `~o Richord F. Allison ~s ~° 1 PJ608 0~~ ~o ~ O ' ,c ~ .^,~eso e° ~ ~"A'ESSI~NAL ~' SURVEYOR'S CERTIFICATE l 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 UNOER MY DIRECT SUPERVfSION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 8, 2007. NOTES: 1. ALASKA STATE PLANE COORD[NATES ARE ZONE 4, NAD27 ~ 2. BASIS OF LOCATION IS W PAD MONUMENTS W-t & W-2. 3. BASIS OF ELEVATION IS W PAD MONUMENT W-2. ~p ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODET[C POSITIONS ARE NAD27. ~ AS-BUILT CONDUCTOR 5. PAD MEAN SCALE FACTOR IS 0.99991426. 6. DATE OF SURVEY: APRIL 8, 2007. ^ EXISTING CONDUCTOR 7. REFERENCE FIELD BOOK: W007-05 PGS. 29-31. LOCATED WITHIN PROTRACTED SECTION 21, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS W-213 Y= 5,959,851.09 N= 2,657.14 70'17'57.327" 70.2992575' 52 8 4,874' FSL ' X= 612,049.05 E= 2,130.06 149'05'33.122" 149.0925339' ' FEL 1,176 r. n~ u ci~ ~ JACOBS CHECKED: ~ a ~ HACKELMAN DATE ~ ~ ~ e ~ : 4/9/07 ` DRAWING: FRBe~ WaW e,-a0 SHEET: J~B N~: WOA W-PAD ~ 141~~ BO~o AS-BUILT CONDUCTOR 0 4 9 0 ISSUm FOR INFORMAT[ON ~ K~ m+s ~x ~ SCALE: WELL W-213 ~~ ~ NO. DA7E REV1510N BY piK ~~. ~ 1"=309• ~~ ~ Alaska Department of Natural Resources Land Administration System Page 1 of 4 • ~ ~ E~ ~ a,`a ~ `~ ~~'~ a~~~ ~ ~~ ; ~ ~. ~ ~~~f~~c~~t~~'~; ~~qrcl~r`s Search State Cabins ~~tt~e"~1 5+~~1M~5 , , ~ ....~.. .~,,,,,~~~ ~~~~,. - AC~~ka D R ~ase 5ummar~ File Type AD~ ; File Number: 28263 ; ~ Printable Case Fite_Summary See Township, Range, Section and Acreage? ~,~~ ~ ~` Yes ~"" No ~ ~~~~~~Cu ~~ http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263&... 4/18/2007 Page 2 of 4 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263 &... 4/18/2007 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263 &... 4/18/2007 RE: Proposed W-213i AOR Thanks Torn. ! know w~`ve been sending you several '°rush" applications lately, so I figured you were ~ven mar~ haoked-up than normal (which is saying something). I laok forward t~ you yaur note. Tayior _ __ _ _ _ From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, March 28, 2007 8:13 AM To: West, Taylor Subject: Re: Proposed W-213i AOR Taylor, Wanted to get back to you. I should have my review of the information you left completed in a day or so. Nice piece of work. My compliments to Egor and condolences on having to look through so many old files, but that is how it has to be done. So far, I have not seen a show stopper. The recent information on the workover/squeeze does help your case. One thing I find interesting in the "report" material provided is that in most wells no leak off test or integrity test is mentioned after drilling out of the 9-5/8" casing. I will get back to you. Tom Maunder, PE AOGCC West, Taylor wrote, On 3/13/2007 2:15 PM: Tom: Thank your for meeting with Egor and me last week to discuss the cement integrity review for proposed injector W-213i. It was very useful for us to see some of your thought process in reviewing these requests. I have passed on to our drilling team your request for additional information on complicated applications. Any feedback from you in the future will make the process more efficient for all of us. We look forward to your thoughts on the W-213i AOR. Thx Taylor West Production Engineer BP Exploration (Alaska), Inc. Greater Prudhoe Bay - Polaris / Orion Viscous Oil 907.564.4647 1 of 2 4/26/2007 3:16 PM ~ ~ ~ ~ bp D ~~~~~~~ BP Exploration (Alaska) Inc. ~ ~ 900 East Benson Boulevard P.O. Box 196612 ~ ~ ~ ~ ~ ~ ~ (~ 7 Anchorage, Alaska 99519-6612 (907)561-5111 Ala:k~ ~~1 ~ ~~~ C~n~R ~~'ni~s~4r~ March 8, 2007 ~"'~~i°r~~"~ Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Area of Review for Proposed Polaris tnjector, W-2i3i Dear Tom: As a follow-up to our discussion a few weeks ago, BP is proposing to drill a Polaris grass-roots injector W-213i. At issue is the annular cement integrity of a large number of legacy W-pad Ivishak producers that lie within a'/a mile radius of W-213 at the Schrader Bluff injection interval. We felt that due to the number of wells to be evaluated and limited availability of cement bond logging data, it would be prudent to obtain an Area of Review (AOR) screening prior to extensive well planning. Attached to this letter are supporting drilling records, well placement and cross section, and our analysis of the data. W-213i is proposed as a Polaris water injector scheduled to spud in May 2007. W-213i will be located updip of and will provide injection support for the existing W-200 conventional frac'ed production well and the heel section of the recent W- 204 multilateral production well. Injection is planned into three sands with offset production: OBa, OBc, and OBd. W-213i will be the second Schrader Bluff injector drilled in the upstructure W Pad area and the 6th Schrader Bluff injection weli drii(ed in the W Pad Schrader Bluff oil accumulation. Analvsis of suaaortina data There are a total of thirteen (13) Ivishak wells within a'/a mile radius of W-213 as measured at the to~ of the injection pool of which nine (9) are within the'/a mile radius at the top injection interval (OBa sand). Our analysis focuses on these nine wells. When these W-pad wells were drilled, the Schrader Bluff resenroir was not under active consideration for development, and as such, the cementing programs were not designed to cover the Schrader under worst-case hole washout conditions. ~qendix A contains a list of these wells, along with ~ ~ applicable distance data, and a summary of cement integrity data gathered from the drilling reports. Appendix B and C show AOR wells on a structure map at the top injection interval. Analysis of the data in ~pendix A shows that most wells had successful cement jobs with good returns, bumped the plug, and floats held. In all cases, the cement height calculations in the table are based on actual cement volume displaced to the annulus, so those few jobs that did not bump the plug are properly adjusted. None of the AOR wells have cement bond logs across the Schrader interval, except W-29 which was logged in December 2006 during a RWO. W-29 RWO results are discussed below. Appendix D is a graphical representation of the data presented in the summary table. It shows that al! wells within the AOR have a calculated cement top well above the Schrader injection interval if assuming gauge hole, and most have cement tops above the injection intervals assuming 30% excess hole volume. W-31 and W-32 have calculated cement tops within 14' of the top of the OBa sand when using 30% excess. W-21 has a 30% excess cement top in the middle of the O sands, although the well is just outside the ~/a mile OBa radius. W-29 RWO: During initial well planning on W-213i, W-29 cement integrity was identified as a potential problem due to the uncertainty in the actual cement top and its proximity to W-213 (213' away at the OBa). W-29 was scheduled for a RWO, so we elected to add a Schrader-intenral bond log and possible squeeze to the job scope. A USIT was run on December 18, 2006 during the RWO, which showed bond across the Schrader interval was a mix of cement stringers, and areas of low compressive strength. The rig then attempted to establish circulation between squeeze perfs ~370' apart at the top and bottom of the injection interval, but was not able circulate nor inject into the formation through either set. Additional perfs were added uphole ~50' below the top perf set in an attempt to establish circulation over a much shorter path. Circulation was established after breaking down the interval and displacing heavy drilling mud from the annulus. Again, the rig was not able to inject into the formation through any of the perf sets at pressures below fracture gradient, so despite the apparent lack of high compressive strength cement, it was not possible to establish an iniection natLi throuqh the annulus to the high perm Schrader sands The , pressure and circulation testing suggested to us that there were probably sufficient annular barriers to prevent out-of-pool injection even without the squeeze. Cement was subsequently circulated between the upper perfs, and a post-squeeze USIT showed the presence of more cement that wil! add additional barriers to annular flow. 2 ~ ~ It is interesting to note that the injection results on this well are similar to other squeeze attempts in Prudhoe Bay where although the bond log shows very patchy cement, the combination of small cement stringers and old drilling fluids prevent squeezing the zone. From this anecdotal experience, one might infer that these annular barriers could also prevent offset injection from migrating out of zone. The structural cross section through the AOR (Appendix E) highlights the down- thrown fault to the south west of W-213. Note that four of the nine AOR wells cross the Schrader injection interval in this fault block. Possibly relevant to the AOR analysis is that offset logs show that the sands in this block are wet which implies that this fault is sealing, so these four wells are neither in sand juxtaposition nor hydraulic communication with proposed W-213i. Conclusion Based on the analysis of the cement integrity data, structural location, and learnings from the W-29 logging and squeeze, we believe that there is sufficient annular integrity in offset wells to allow permitting W-213 as a water injector. At this time, only three existing Polaris wells are approved for MI injection (AIO 25A), so any future request for MI injection service in W-213 would be contained in a separate application. ~---~ ___.---------, Thank you for your review of this data. Please feel free to contact me or Egor Makarov if you have any questions or would like additional documentation. Sincerely, ~~~~ Taylor West Production Engineer Taylor.west ~ bp.com 564-4647 , ~------ Egor Makarov Production Engineer egor.makarovC~3 BP.com 564-5687 3 Greater Prudhoe Bay W Pad Area Schrader Bluff Structure and Fluid Cross Section Feet TVDSS -4400 - -4450 = -4500 = -4550 = -4600 = -4650 = -4700 = -4750 = -4800 = -4850 = -4900 = -4950= -5000= -5050= -5100= -5150= -5200= Appendix E 0 500 ieee isee ~ High API Gravity Oil Sands (> 16 API) 0 Low Permeability Oil Sands (< ~30 md.) 2000 2500 3000 3500 - Low API Gravity Oil Sands (< 15 API) 0 Water Bearing Sands (Sw > .65) 4eee 4see seee Feet ~ W-213i Proposed Perforation/Injection Interval s ~ W-213 ~I~.~aI~ 1A/ AAA ... ~~ .~ . lA/ Ar' \A/ r1A 3000 3500 4000 ~ m m 0 4500 ~ 5000 5500 6000 Proposed W-213i Quarter-Mile Radius Wells Appendix D (distance @ OBa from proposed W-213i, ft) W-29i W-25 W-30 W-31 W-32 W-19 W-34 W-24 W-22 W-23 W-18 W-21 W-27 (213 ft) (609 ft) (747 ft) (751 ft) (754 ft) (969 ft) (1207 ft) (1275 ft) (1287 ft) (1322 ft) (1358 ft) (1364 ft) (1458 ft) Well Name W-24, 22, 18. 21 ~ - ~ _ ~~ ~- --' ~ '/a mile radius circle ,~ ~ ~ ~ ~ : ~ , 1 _ , / ~ / ,r ~i~/ ,'~ l s r- ~ i ~ ----- - ~' i' ~: 4 J ~; ~'°j ° ~/ ~~~ ~ ~ ~ ,,'~ :- __ : _ ~ ~- , ~ - ~, - , ~~ _ ; ~ , __ ~ ~ W-23 , f _ - - Q - -_ - ~__.~-` ~ 1 _---- *~ ~ .- W-19 W-32 ~ _ -_- ----- - ~; _ .~ / ~ , , ~ _ --_~~_=~ ~ w-25 ___~; __ -_,_-- --~ ~.`----,' .` W-30 W-35 ~_ ~ .~ W-34 \ ~ / / ., W-27 ~ ~' ;- ~ W-31 ~% ~---~~ ' /" /~ ,~ _/ _ _r- / ~ ..- f--J`~ i ~ / - % ~ ~~~ ~ ~---_"~ tn - ~ aJ ~ ` ~~ w ~ ~ Y ~ N >s- / ~ ~_ r ~ ; ~ ~' _---"~._~--~ ~----~- / ~ W-213i Area - Top OBa 3D Structure with Nearbv Wells s ~ Appendix C 1/4 mile radius welis listed by distance from proposed Injector: W-213 Distance at Top Cement hei ht above OBa sand, ft 1/4 mile Current Distance at OBa from ~op of Pool Casing Total Cement Annular Fuli Bumped Floats Pressure TOC ND, TOC ND, Bond Log redius status PfOPOS~ Mc) from completion Volume pumped Cement Retums Reciprocated plug Held? Tested gauge hole 30% over ND, gauge hole ND, 30% over across SB wells (2/21/07) injector, ft. proposed date (cu ft) Volume (cu ft) 98U9e gauge ~njector, ft. WAG - on W-29i line 213 258 8/9/1988 2195 2147 Y no info Y Y Y 3513 4795 1435 153 PAL - SI since W-25 5/7/OS 609 743 11/6/1988 2113 2064 Y ~o info Y Y Y 3488 4E46 1445 87 no PAL - SI since W-30 9/1/05 747 732 11/25/1988 1887 1836 Y no info Y Y Y 3531 4734 14fi0 257 no Oil- producer - W-31 oMine 751 615 1/8/1989 2421 2294 Y no info N Y Y 3808 4978 1163 -7 no PAL - on- W32 line 754 677 9/9/1989 2017 1802 Y no info N Y Y 3833 4969 1123 -13 PAL - SI since W-19 7/26/06 969 815 1/28/1990 2392 2341 Y no info Y Y Y 3465 4765 1496 196 no PAL - on- W-34 line 1207 1161 10/11/1988 2134 2060 Y no info N Y Y 3517 4751 1469 235 no WAG - on- line; on MI since W-24 1/7/06 1275 1213 8/13/1988 1792 1743 Y no info Y Y Y 3582 4867 1385 100 no PAL - on- W-22 line 1287 1226 11/4/1988 1931 1855 Y no info N Y Y 3260 4627 1705 338 no PAL - SI since W-23 4/22/O6 1322 1204 1/8/7990 2018 1969 Y no info Y Y Y 3467 4761 1507 213 no PAL - on- W-18 line 1358 1299 11/24/1988 1772 1721 Y no info Y Y Y 3509 4777 1455 187 no PAL - on- W-21 line 1364 1302 4/10/1989 2122 2073 Y no info Y Y Y 3500 5022 1467 -55 no AL- since W-27 5/24/O6 7458 1293 12/17/1988 2341 2291 Y no info Y Y Y 3434 4695 1546 285 no KEY: NOTE: WAG - water altemating gas For welis where plug was not bumped, cement height calculate use annular cement only PAL - producer artificial lift SI - shut-in . Appendix A Greater Prudhoe Bay W Pad Area Structu re Contou r Map on Top OBa Sand • Appendix B ~ W Pad 1/4 Mile -4ges Well Location and Surface Radius • Depth at Top OBa Location Circle W-201 Sand (Depth - TVDSS) 0 1000 2000 3000 4000 Feet 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 ~ ~ ~ ~ ~ J w ~~ .~ ' r ..: ~~ ~'.. "F.. . ~~• ~ ~~'- ~` ` ... ; ~..~~~~~~~~ .. ~ J ~~, /~ ~~« ~ •• .,~ ~ ~, ~ ~ w~4" a . ' 4 . , ~ . ; _• . . ~, j: s .r~'.,, . ~. '4 ,1'~ ~. . Terri`~t::~Hubble ss-s~~ Zsz 330 BP,~x{~loration AK Inc. "Mastercard Check" P~`$ox 196612 MB 7-5 /'~ ' ' 7 Anchorage„ AK 99519 ~ . ~ATE v ~ PAY TO THE . ~ ~ I ~ , ~ ORDEF2 0~ O ~ 11c~n L~. .~_.. rr n DOLLARS First National Rank Alaska Anchorage, AK 99501 MEMO~~~ ~~~3 i:~25200060~:99L46227L556~~' 0330 ~ ~ T'RAYSI~I~"I'AL LE'I'1'Elt CH~CKLIS'i' w~~,~ d~Nt~ ~r~Ld ,GI~ v?/3 P~'D# o.?O~O~S/O Devetopment / Service Expioratory Stratigraphic ~'est Non-Conventional We!! Circle Appropriate Letter / Paragraphs to be Included in Transmittad L.etter I ~ ~ Cf-~CK I ADD-Oi~tS ; T'EXT' FOR APPROV!AL LfiTTER ~ ,' Vb'EiAT ~ (OPTIONS) ! ' ~ APPL[ES ~ ! ; ! ~ ; ~ MliLTI LATERAL ~ T'he permit is for a new weilbore segment of existino ~ ! i i ~ well ; ~(If last two digits in I ~qp[ ~(o. ~0- i API number are ; Permit ~(o. , - - ; between 60-69) Production shouid continue to 6e reported as a function of the ~I ~ original API number stated above. , ~ , ~ PILOT HOLE ~[n accordance with 20 A.AC 2~.00~(~, all records, data and togs ; ; ! acquired for the pilot hole must be cleacly differentiated in both ' i ; ~vell name ( Pf-n and API aumber ~ ~ '(50- - -_) from records, data and logs ~ ~ ~ ~ acquired for well ~ ~ SPACING The permit is approved subject to fult compliance with 20 AAC ~ ' EXCEPTION ~ 2~.0». Approval to perfora.te and produce / inject is contingent ~ ; ! upon issuance of a conservation order approving a spacing j i ~ exception. assumes the ~ ~ I i liability of any protest to the spacing exception tha[ may occur. ~ ~ ; DRY D[TCH ; ~ All dry ditch samp(e sets submitted to the Commission must be in ; i SA!NIPLE I no greater than 30' sample intervals fcom be(ow the permafrost or I ! I from where samples are fint caught and 10' samp(e intervals j ,' ~ ~ through taroet zones. ; I ;' Please note the fo(Iowing special condition oP this permir: ~ Non-Conventional ' ' production or production testing of coal bed methane is not allowed i W zll ~ for (name of welll until after (Companv lv`ame) has desi;ned and ! ~ imp(emented a water well testing program to provide baseline data ' ; on water quality and quantity. (Comnanv Name) must contact the ~ Commission to obtain advance approval of such water well testing ! _ ~ pro~ram. ~ Rev: 1.'2~i06 C `jody~transmittaf_chec(c[ist ~ ^ m , , y , , a, o , , , a~ Q , , ~ ~ ~ ~ , , ~ , ~~ ~~ , ~~ ~o ~ ~ , , ~ , ~ , , ~ ~ Q , , , , ~ ~ ~ ~ ~ , ~ . , , ~ ~ , N , ~ , ~ ~ ~ ~ ~ . ~ ~ , o , ~ t , ~ ~ O ; , , ~ O~ ~ , ~ o , , °' ; ; ~ ~ ~ ~ ~ ~ ~ ~, ~ , ~ ~ ~ ~~ ~ ~ ~ ~ ~ , ~ ~ ~ , , ~ N~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ' ' ' ' ' ~' ' ' ' ! ~' ' n.; ~ , ? ~ ~~ ~ _~ ~ , ~ ~ ~ ~ . , 1 f ~ , ~ ~ ~ ~ ~ ~ ~~ ~ , ~ ~ ~ , ~, ~ .~ ~ ~ ~ ~ ~ . , ~ ~ S S ~ , ! , ; ~ s ~ s , ; , , ~ ; ~ ~ ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ < ~ ~ ~ ~ ~ , ~ ~ , f ~ C, ~ ~ ~ ~ ~ ~ ~ f '~~ S an , i y, ~ ~ ' ~ ~ ~ , ,• ~ 1 n ~ ~ s ~, ~ ~, , i , 0~ ~ ,, ~ ~ . ~ , ~ , ~. ~ i . ~ ~ ~ , , ~ ~ , , I , ~j , ~ , , , , a, , ~ ~ ~ ~ ~ ~ ~ ~ , ~ N, , ~ ~ , ~~ ~ ~ ~ ~ ~ ~ ~ , , ~, , ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , N, , , , ~ . ~ ~ ~ , , , . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ N, ~) ~ , ~ ~ ~ ~ 3 ~ ~ . ~ , ~ 0 , , ~ f0~ ~ , , ~ ~ ~ , ~~ ~ , ~ , , ~ ~ ~ ~ , ~ ~ ~ .. 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