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207-168
MEMORANDUM 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-216 PRUDHOE BAY UN POL W-216 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 W-216 50-029-23379-00-00 207-168-0 G SPT 4973 2071680 1500 2401 2404 2396 2394 270 288 291 291 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-216 Inspection Date: Tubing OA Packer Depth 27 1709 1636 1618IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240812202435 BBL Pumped:2.3 BBL Returned:1.5 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 12:24:47 -08'00' 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. 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN 3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV /LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$& )LHOG3RRO V 6XVS:HOO,QVS ,QVWDOO:KLSVWRFN 0RG$UWLILFLDO/LIW 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV &RLOHG7XELQJ2SV 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH $WWDFKPHQWV UHTXLUHGSHU$$& :HOO6WDWXVDIWHUZRUN ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH 2,/ *$6 :,1- :$* *,1- :'63/ *6725 6XVSHQGHG 63/8* $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $XWKRUL]HG7LWOH &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH 3%8: &RPSOHWHG3RO\PHU,QMHFWLRQ7ULDO +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH$QFKRUDJH$. &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU 1RQH 1RQH / 6WUXFWXUDO 'XDO)HHGWKUX3DFNHU 6WDQ*ROLV 6U$UHD2SHUDWLRQV0DQDJHU %URGLH:DJHV 'DYLG:DJHV#KLOFRUSFRP 358'+2(%$<32/$5,62,/ 7RWDO'HSWK (IIHFWLYH'HSWK PHDVXUHG WUXHYHUWLFDO IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO PHDVXUHG PHDVXUHG IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO 3OXJV -XQN 3DFNHU 0HDVXUHGGHSWK 7UXH9HUWLFDOGHSWK IHHW IHHW 3HUIRUDWLRQGHSWK 7XELQJ VL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 3DFNHUVDQG6669 W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHG PHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDOSUHVVXUH D5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD 2LO%EO *DV0FI :DWHU%EO &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF'DLO\5HSRUWRI:HOO2SHUDWLRQV &RSLHVRI/RJVDQG6XUYH\V5XQ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD 6XQGU\1XPEHURU1$LI&2([HPSW $'/ 3HUIRUDWLRQVIURP 6HHIRUWKFRPLQJ,QMHFWLYLW\7HVW5HVXOWV6XPPDU\7ULDOEHJDQ$SULODQGHQGHG1RYHPEHU E3RROVDFWLYHDIWHUZRUN 32/$5,62,/ 6LQJOH)HHGWKUX3DFNHUV 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 6U3HW(QJ 6U3HW*HR )RUP5HYLVHG6XEPLWLQ3')IRUPDWWRDRJFFSHUPLWWLQJ#DODVNDJRY 6U5HV(QJ 'XH:LWKLQGD\VRI2SHUDWLRQV By Anne Prysunka at 1:02 pm, Nov 23, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1 FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV RBDMS JSB 112522 WCB 11-29-2024 DSR-11/23/22 ƐƐĞƐƐŵĞŶƚZĞƉŽƌƚŽĨĨŝǀĞ;ϱͿ^ƚƵĚLJtĞůůƐǁŝƚŚ^ƵƌĨĂĐĞĂƐŝŶŐ^ĞƚŝŶWĞƌŵĂĨƌŽƐƚ WĂŐĞϵ ϭϯͲϯͬϴΗ'ƌĂǀĞů^ƚƌŝŶŐΛϭϯϬϵΖD;ϭϮϵϮΖdsͿ ϮϬΗŽŶĚƵĐƚŽƌΛϭϬϵΖ ϵͲϱͬϴΗĂƐŝŶŐ^ŚŽĞΛϰϬϮϭΖD;ϯϯϭϮΖdsͿ ϳΗĂƐŝŶŐ tͲϮϭϲ;t'Ϳ dKŝŶϳΗďĞůŽǁϵͲϱͬϴΗĂƐŝŶŐ^ŚŽĞ xϭϯͲϯͬϴΗŝƐůĂŶĚĞĚŽŶĂďƵƚƚǁĞůĚƐƵďŝŶƐŝĚĞƚŚĞ ĐŽŶĚƵĐƚŽƌǁŝƚŚĂĨůƵƚĞĚŚĂŶŐĞƌ;ƵŶĂďůĞƚŽǀŝƐƵĂůůLJ ǀĞƌŝĨLJŝĨƐƚŝůůůĂŶĚĞĚͿ͘ xϵͲϱͬϴΗŝƐůĂŶĚĞĚŽŶĐŽŶĚƵĐƚŽƌůĂŶĚŝŶŐƌŝŶŐǁŝƚŚĂ ĨůƵƚĞĚŚĂŶŐĞƌ͘EKd ͗ŶŽƚůĂŶĚĞĚĂƐŽĨϬϰͬϯϬͬϭϴ͘ xtĞůůŚĞĂĚŝƐŝŶƐƚĂůůĞĚŽŶϵͲϱͬϴΗ͘ ϰͲЪ͟džϯͲЪ͟dƵďŝŶŐ ϭƐƚ^ƚĂŐĞdKŝŶϭϯͲϯͬϴΗĂƉƉƌŽdž͘ϴϲϬΖ^ƉĂĐĞƌͬDƵĚϭϯͲϯͬϴΗdDWŽƌƚŽůůĂƌΛϭϬϮΖ ϮŶĚ^ƚĂŐĞĞŵĞŶƚŝŶϭϯͲϯͬϴΗĨƌŽŵϬͲϭϬϮΖ ƵƚƚtĞůĚ^ƵďϯΖďĞůŽǁŽŶĚƵĐƚŽƌ>ĂŶĚŝŶŐZŝŶŐ ŽŶĚƵĐƚŽƌ>ĂŶĚŝŶŐZŝŶŐ Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:207-168 6.API Number:50-029-23379-00-00 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-216 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 GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 7052 Effective Depth MD: L80 11. 7/1/2021 Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: David.Wages@hilcorp.com 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): 5398 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 6455, 4973 6591, 5068 / 6884, 5276 Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 30 - 1309 30 - 1292 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 109 Structural 5750 Proposal Summary 13. Well Class after proposed work: 3-1/2" Dual Feedthru Packer 6514 - 6754 5014 - 5183 3-1/2" 9.2#24 - 6800 Production 6708 5150 6708 None 30 - 109 13-3/8" 9-5/8" Contact Phone:907.564.5006 Date: 3090 79 20"Conductor 2270 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 1279 4930 Intermediate 3993 28 - 4021 28 - 3312 7011 7"26 - 7037 26 - 5387 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. 1955 No SSSV Installed No SSSV Installed By Samantha Carlisle at 11:24 am, Apr 26, 2021 321-214 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.26 10:47:43 -08'00' Stan Golis (880) 10-404 DSR-4/26/21SFD 4/26/2021 MGR27APR21 Polymer injection cannot begin until AIO 25 is amended to authorize this polymer injection trial. Yes Required? Comm. 4/20/21 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 -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 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 TO: Jim Regg � K E'eo,�,-' 111(2UZ DATE: Monday, August 31, 2020 SUBJECT: Mechanical Integrity P.1. Supervisor Tests BP Exploration (Alaska) Inc. W-216 FROM: Jeff Jones PRUDHOE BAY UN POL W-216 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry IJ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-216 API Well Number 50-029-23379-00-00 Inspector Name: Jeff Jones IRSp Num: mitJJ200828143834 Permit Number: 207-168-0 Inspection Date: 8/14/2020 Rel Insp Num: Packer Depth Well W-216 Type Inj W ''TVD 4973 PTD 2o716so Type Test Test psi I soo SPT BBL Pumped: 2 ',BBL Returned: 1.7 Intervvala 4YRTST P/F P Notes' I well inspected, no exceptions noted. ' Pretest Initial 15 Min 30 Min 45 Min 60 Min T-- ubing1060 1062 1061 1061 - - -�- IA 27 2265 2179 t 2166 OA 1 213 232 11 234 - 236 ' Monday, August 31, 2020 Page 1 of 1 • 277) a a7 -14V • Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Monday,April 30, 2018 1:37 PM To: Loepp,Victoria T(DOA) Subject: FW: Producer J-01B (PTD#2022010) Similar Construction Geometry to 02-03 Follow Up Flag: Follow up Flag Status: Flagged Jim Regg Supervisor, Inspections SCAM® AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. < From:AK,GWO SUPT Well Integrity AKDCWeIIlntegrityCoordinator@bp.com> Sent: Monday,April 30, 2018 1:35 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Foerster, Catherine P(DOA)<cathy.foerster@alaska.gov>; Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov>; Daniel, Ryan <Ryan.Daniel@bp.com>; Cismoski, Doug A<CismosDA@BP.com>; Romo, Louis A<Louis.Romo@bp.com>;AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: RE: Producer J-01B (PTD#2022010)Similar Construction Geometry to 02-03 Jim, Per my voicemail,we will reclassify the wells with gravel protection strings Not Operable: • Producer S-122 (PTD 2050810) • Injector W-209(PTD 2031280) • Injector W-214(PTD 2071420) Injector W-216(PTD 2071680)) Our surface casing depth verification project identified 2 other wells with surface casing set in the permafrost(both Long Term Shut Ins): • Producer E-28A(PTD 1990610)—will reclassify Not Operable • Injector M-01(PTD 1690780)—already Not Operable due to remaining shut in past its 4-year witnessed test date BPXA's Tubular Design Advisor will review all of these wells. Upon completion,we'll present the findings to the AOGCC. In the meantime,all will remain Not Operable and shut in. 1 TThanks, • • , Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 From: Regg, James B (DOA) [mailto:jim.recigftalaska.gov] Sent: Friday, April 27, 2018 2:18 PM To: AK, GWO SUPT Well Integrity Cc: Loepp, Victoria T(DOA); Foerster, Catherine P(DOA); Schwartz, Guy L(DOA); Rixse, Melvin G (DOA) Subject: RE: Producer J-01B (PTD #2022010) Similar Construction Geometry to 02-03 Thank you for the follow-up email. Just to be clear,are the S-pad and W-pad wells with gravel protection strings also going to be reclassified as"not operable"to verify they are not at risk for failure like PBU 02-03B? When BP is finished with the reviews of the wells, please arrange for a meeting to present your findings to the AOGCC. That can be coordinated with Victoria. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged informati n. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this a-mai, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 90'- 793-1236 or iim.regg@yalaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWell ntegrityCoordinator@bp.com> Sent: Friday,April 27,2018 1:51 PM To: Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Cismoski, Doug A<CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>;AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: Producer 1-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, To summarize our phone conversation today: • After the 02-03 incident,we reported to the AOGCC 14 wells with similar construction geometry; i.e.a 3-strin: casing design,and the surface casing shoe set in the permafrost. • Yesterday,we identified one additional well with similar construction geometry:1-01. • We do not believe that J-01 is at risk of an event similar to 02-03, because, unlike 02-03,all three strings of casing are anchored together with cement.We believe this eliminates the potential for differential force load ng at the wellhead. 2 However,we are going/Reclassify/Reclassi J-01 Not Operable, shut it in,an cure it, until we can perform modeling • • g g fY p , to verify. • We also identified 4 wells on S-Pad and W-Pad that have 13-3/8"gravel protection strings set in the permafro•t, and 2 casing strings within. I'm investigating the details now, but I do not believe these wells present a risk.Th- 13-3/8" is a second conductor,and not coupled to the inner casing strings at the wellhead. In the event the 13 3/8"were to subside, it would not impart a load to the inner casing strings via the wellhead. I will follow up o these wells as soon as possible. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 3 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t+- € �1 DATE: Wednesday,September 07,2016 P.I.Supervisor � (1`y SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. W-216 FROM: Chuck Scheve PRUDHOE BAY UN POL W-216 Petroleum Inspector Src: Inspector Reviewed Byy�t��, P.I.Supry Jgt2. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-216 API Well Number 50-029-23379-00-00 Inspector Name: Chuck Scheve Permit Number: 207-168-0 Inspection Date: 9/5/2016 Insp Num: mitCS160906064006 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-216 fTYP a In' TVD 4973 Tubing 1066 - 1067 - 1065- 1065 - J I g PTD 2071680 - Type Test Test psi I 1500 • IA i 6 2195 - 2130 - 2113 Interval 4YRTST P/F P / OA 285 313 - 316 317 - Notes: SCANNED JUN 2 0 2017, Wednesday,September 07,2016 Page 1 of 1 %0° 0 0 • � o l (�i+ C) cc W 1 r+ - (o❑ )N( ONZ f ' s1�w a < Y .� 3 H. Oto a1 Q1 O t _cC CO Lb ra --J c a1 O ,.. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~ ~ Well History File Identifier Qrganizing (done> ^ Two-sided III 111111 II III II III ^ Rescan Needed III 111111 II II III III RE CAN DIG AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ' ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date:. ` /s/ Protect Proofing III II IIII II III II III BY: Maria Date: ~ ~ ®~ /s/ ~~ ~ ~ =TOTAL PAGES ~~ Scanning Preparation x 30 = + (Count does not include cover sheet) BY: Maria Date: ~ 1 ~ ~ (~ (~ /s/ l J ~ IIIIIIIIIIIIII IIIII Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: aria Date: ~' ~ ~ ~~ /s/ ~~` Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO ttt BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II I) I II II I (III Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II II II III (IIIII 10!6/2005 well History File Cover Page.doc • • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Wednesday, February 1, 2012 1:59 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) e1Y L1 Subject: January 2011 AOGCC MIT Forms Attachments: January 2011 MIT -IA Forms.zip; W -216 AOGCC Well File MIT - IA.pdf Jim, Phoebe, Please find attached January AOGCC MIT forms for the following wells: MPU B -12 (PTD #1850800) MPU J -11 (PTD #1941140) MPU J -15 (PTD #1991070) PBU L -105 (PTD #2020580) PBU X -24A (PTD #1991250) PBU NGI -11 (PTD #1770800) AOGCC witnessed MIT -IA performed 01/07/2012 to evaluate TxIA communication. Apply to 4 -year AOGCC test requirement to reset testing clock. PBU 11 -26 (PTD #1861340) Initial AOGCC witnessed MIT -IA performed 01/28/2012 post rig work over operation to repair TxIA communication and PC leak. PBU Z -102 (PTD #2070500) 4 -year AOGCC MIT -IA was due while well was secured for drilling operations on Z- 116. MIT -IA performed 01/28/2012 to put well in compliance to allow injection. The following two wells on your list do not have AOGCC witnessed MIT -IA's performed: PBU W -216 PTD #2071680 / C' I J Last AOGCC MIT -IA was performed 10/02/2008 for evaluating IAx((dA communication witnessed by Mr. John Crisp. The MIT -IA form was submitted noting the interval as "0". BP will complete a 4 -year AOGCC witnessed test prior to 10/02/2012. I have attached the MIT -IA form pulled from the AOGCC website for reference. PBU PWDW1 -2A (PTD #1901180): Last 4 -year AOGCC MIT -IA was performed 01/04/2008. A non - witnessed MIT -IA was performed on 07/19/2009 at which time the test was incorrectly flagged as a witnessed test in our database. A witnessed test will be immediately scheduled (weather permitting) and the test data submitted to the AOGCC as soon as completed. Please call if you have any concerns or require further information. Thank you, aUlZ Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1 • • From: Regg, James B (DOA) [mailto:jim.reggPalaska.gov] Sent: Wednesday, February 01, 2012 11:01 AM To: AK, D &C Well Integrity Coordinator Subject: Past Due MITs Completed January review of MITs due; following tests are past due date per AOGCC records: MPU B -12 (PTD 1850800) Status= injecting (as of 12/31/11) MIT due 1/11/12 MPU J -11 (PTD 1941140) Status= injecting (as of 12/31/11) MIT due 1/11/12 MPU J -15 (PTD 1991070) Status= injecting (as of 12/31/11) MIT due 1/27/12 PBU L -105 (PTD 2020580) Status = injecting (as of 12/31/11) MIT due 1/18/12 PBU PWDW1 -2A (PTD 1901180) Status= injecting (as of 12/31/11) MIT due 1/4/12 PBU W -216 (PTD 2071680) Status= injecting (as of 12/31/11) MIT due 1/13/12 PBU X -24A (PTD 1991250) Status= injecting (as of 12/31/11) MIT due 1/22/12 If tested, please provide MIT Report; if not yet tested, provide reason for not completing tests on or before due date. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 2 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ WAG SWAP Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^ Exploratory ^ 207-1680 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-23379-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028263 ~ PBU W-216 10. Field/Pool(s): PRUDHOE BAY FIELD /POLARIS POOL 11. Present Well Condition Summary: Total Depth measured 7052 feet Plugs (measured) 6778 5/31/08 feet true vertical 5398.09 feet Junk (measured) None feet Effective Depth measured 6952 feet Packer (measured) 6455 6591 6684 true vertical 5325.23 feet (true vertical) 4973 5068 5133 Casing Length Size MD TVD Burst Collapse Structural Conductor 108 20" 91.5# A-53 SURFACE - 108 SURFACE - 108 Surface 1309 13-3/8" 68# L-80 30 - 1309 30 - 1292 4930 2270 Intermediate 4021 9-5/8" 40# L-80 28 - 4021 28 - 3312 5750 3090 Production Liner 7037 7" 26# L-80 26 - 7037 26 - 5387 7240 5410 Liner Perforation depth: Measured depth: 6514 - 6552 6624 - 6660 6704 - 6754 _ True Vertical depth: 5014.22 - 5040.73 5091.05 - 5116.35 5147.46 - 5182.97 Tukiing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# LL-80 SURFACE - 6799 SURFACE - 5215 Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" HES DUAL FEEDTHRU 6455 Pater 4973 7"X3-1/2" HES SINGLE FEEDTHRU 6591 5068 7"X3-1/2" HES SINGLE FEEDTHRU 6684 5133 ~~~~ 12. Stimulation or cement squeeze summary: ( ~ ~p~~ Intervals treated (measured): ; r ` alt s=-';; f, i- ` ~ ~,~jU ~'~D~ a 4° ~ } ~~~` Treatment descriptions including volumes used and final pressu re: ~ ., ; ~!~' ,y,~r.;. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 649 1274 Subsequent to operation: 1484 1484 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^/ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 inn IV-YVY ~~cvracu ~iwvo ~ ~-~~~ a RBDMS JUL 0 8 ~0 ~( 7"~ 3 ~~~ QQ" /(y/` • • W-216 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/14/2010 ""*WELL INJECTING ON ARRIVAL"** RU SWCP #10, STANDBY FOR LRS } PUMP TRUCK UNAVAILABLE, JOB POSTPONED I i***LEFT WELL INJECTING, INFORM PAD OP*** j ,~.~.. 5/16/2010""*WELL INJECTING ON ARRIVAL"**(pre swap to MI) ! LRS FREEZE PROTECT FLOWLINE 1 PUMPED 58 BBLS DIESEL TO DISPLACE WELL AS PER PROGRAM SET 3 1/2" WHIDDON C-SUB @ 6744' SLM PERFORM INJECTIVITY TEST AS PER PROGRAM (GOOD) PULLED RK-WFR FROM ST#1 (c7 6706'SLM/6728'M IB&F W/ LRS, PUMPED 70 BBLS AWAY, USING 3-1/2" BLB, 2.50"G-RING TO 6720 SLM (no issues) OOH W/BRUSH, R/D FOR WEATHER (high winds 40+) ,""*CONT WSR ON 5-17-10""' ~.~ 5/16/2010 T/I/O 1100/20/240 Assist slick-line with WFR redesign (Prep for WAG swap) Freeze 6 Protect FL and S-riser. Pumped 6 bbls neat methanol down FL and into S-riser to freeze protect. Pumped 2 bbls neat, followed by 58 bbls of 30* dsl down TBG to displace water. TP fell to 1600 psi after shutting down pump. SSL to RIH and set 'catcher. Perform SRT. Pumped a total 8.3 bbls during infectivity test. Pump rates and pressure .10 bpm. @ 1300 psi. for 5 mins .32 bpm. @ 1500 psi. for 5 mins .58 bpm. @ 1700 psi. for 5 mins. SSL pulled WFR from GLM#1. Pumped 70 bbls 180* diesel during brush and flush. I'""*Continue AWGRS on 5/17/10**'' ~. ~ m__~ .._._.~ ~ ~ ___~~~.. 5/17/2010***Continued AWGRS from 05-16-10*** Job postponed due to high winds • 5/18/2010 i I /I/V= SUU/1U/1 SU 1 emp= 51 Assist wireline pump as directed- Pumped 16 bbls diesel down tubing through WFR in sta. #1 to capture rates at .20 bpm @ 1300 psi, .45 bpm @ 1500 psi and .76 bpm @ 1700 psi each for 5 min test without change. Turn well over to SSL. Final WHP's= 1000/20/180 "Slickline has control of well at departure" 5/18/2010*"*CONT WSR FROM 5-16-10**'' - -~~________ -~_-~~ „SET RK- P-15 WFR IN STA #1 @p6706WSLM/ 6728' MD [PULL C-SUB FROM 6740' SLM 'PERFORM INJECTIVITY TEST AS PER PROGRAM, GOOD TEST SET 3 1/2" MCX (SER-# BP-327) W/.50" BEAN IN SVLN @ 2786' SLM/ 2809' MD PERFORMED GOOD DRAW DOWN TEST ON INJ VALVE, RDMO ***WELL LEFT S/I, TURNED OVER TO PAD OP TO POI/ GAS*'"* FLUIDS PUMPED BBLS 8 MEOH 153 diesel 161 Total TREE = 4-118" CNV WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 81.9' BF. ELEV = 56.7" KOP = 300' Max Angle = 50° @ 5667' Datum MD = 6611' Datum TV D = 5000. SS ~ W-216 20" CONDUCTOR, 91.5#, A-53, ID = 19.124" 80~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 1309 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 4021' 7" LNR, 26#, L-80 TC11 XO TO L-80 BTGM -~ f Minimum ID = 2.750" @ 6778' 3-112" HES XN NIPPLE 3-1 /2" MA RKER JOINT w ! RA TA G ~ 6435' 24' I~ 4-112" X 3-1 /2" XO, ID = 2.992" 102' 13-318" TAM PORT COLLAR, ID = 12.259" ~ 1255' 9-518" TAM PORT COLLAR, ID = 8.835" 2809 ~ 3-112" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6344 4897 47 MMG DMY RK 0 06/02/08 WATER IN.IFC:TInN MANnRFI c ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 6480 4991 46 MMG- DMY RK 0 01109/08 4 6542 5034 46 MMG- P-15 RK 11 06/23/09 3 6617 5086 46 MMG- DMY RK 0 01 /09108 2 6655 5113 45 MMG- P-15 RK 13 06123/09 1 6728 5165 45 MMG- P-15 RK 18 06123/49 6434' I-) 3-112" HES X NIP, ID = 2.813" I7" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" PHOENIX PRESS(fEMP SENSOR SUB, ID = 2.992" 7" MARKER JOINT w! RA TAG I-I 6487' PERFORATION SUMMARY REF LOG: USIT LOG ON 01111!08 ANGLE AT TOP PERF: 46° @ 6514' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OBa 6514 - 6552 O 01/10/08 4-1i2" 5 OBc 6624 - 6660 O 01/10!08 4-112" 5 OBd 6704 - 6754 O 01/10108 3-112" TBG, 9.2#, L-80 TCII, .0087 bpf, !D = 2.992" PBTD 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 3-112" HES X NIP, ID = 2.813" 6591 ~ -17" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 6605' PHOENIX PRESSITEMP SENSOR SUB, ID = 2.992" 7" X 3-112" SINGLE FEEDTHRU PKR, ID = 2.965" 3-112" .HES X NIP, ID = 2.813" 6757' ~-~ 3-112" HES X NIP, ID = 2.813" 6778' 3-112" HES XN NIP, ID = 2.750" 6778 -i3-1/2" PXN PLUG (05131/08 6800' 3-i12" WLEG, ID=2.992" POLARIS UNIT WELL: W-216 PERMIT No: 2071680 API No: 50-029-23379-00 SEC 21, T11 N, R12E, 376' FNL & 1176' FEL BP Exploration (Alaska} ~~ ~~ ~ ,~~ i ~` ,..,,~` ~'~ ~~ .~- ~ ' 01~' `s f1~ r ~. t ~ MICROFILMED 6/30/2010 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • ~~Q~~ 0~ Q~Q~~{a /,E..a,~...ao~.~. ALAS~A OIL ~ t7[t>U7 333 W. 7th AVENUE, SUITE 100 COI~TSERQA'1`IO1~T COMI~TISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ADMINISTRATIVE APPROVAL NO. IO 25AEC~t05 (907) 276-7542 Ms. Diane Richmond GPB West Subsurface Resource Manager BP Exploration (Alaska) Inc. ~, ~~~',-..Y~ ~p~{ °, I~ ~_Q~ „.., P.O. Box 196612 Anchorage, AK 99519-6612 Re: Request to Allow Enriched Hydrocarbon Gas Injection PBU W-216 (PTD 2071680) Polaris Oil Pool Dear Ms. Richmond: By letter dated March 29, 2010, BP Exploration (Alaska) Inc. (BPXA) requested approval to allow enriched hydrocarbon gas injection in Well PBU Polaris W-216 (PTD 2071680)). The Alaska Oil and Gas Conservation Commission (Commission) GRANTS BPXA's request in accordance with Rules 2 and 13 of AIO 25A.000. An Application for Sundry Approval (Form 10-403) is not required; however a Report of Sundry Well Operations (Form 10-404) should be submitted documenting the commencement of enriched gas injection. DONE at Anchorage, Alaska and dated April 14, 2010. ~~ ~~ '?~• a~ E,~/` ~~~"°- Daniel T. Seamount, Jr. Cathy . Foerster a~~~-'~` Commissioner, Chair Commissioner ~, p . z y ~.~,. ~; r., , ' " " ~ _~,~~ RECONSIDERATION AND APPEAL NOTICE ~ ` tt3 m AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission ~_ r good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration aze FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days afrer the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "(t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. by March 29, 2010 Daniel T. Seamount Chairman Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.0. Box 196612 Anchorage, Alaska 99519-6612 (9071561-5111 REC~I`VEC~ MAR ~ 1. 2010 Anchorage, AK 99501 OY$G~CglaCanlmissbn RE: Administrative Approval for Enriched Hydrocarbon Gas Injection in well PBU W-216 Dear Chairman Seamount: BP Exploration (Alaska), Inc. (BPXA), operator of the Prudhoe Bay Unit (PBU), on behalf of itself and the other the PBU Working Interest Owners, requests administrative approval under Area Injection Order No. 25A (AIO 25A) to allow for the injection of enriched hydrocarbon gas into injection well W-216. The following wells are approved for enriched hydrocarbon gas injection under AIO 25A Rule 2: 5-215i, W-2091, and W-215i. The rule also states that upon "proper application" additional water injecting wells can be reclassified as WAG injectors. W-2161 was drilled in January 2008 and is currently approved for water injection. Figure 1 provides data on the zonal isolation status of the wellbore. There are no offset injectors present within aone-quarter mile radius of W-2161 as depicted by Figure 2. The plugback leg of W-204 is 665' from the W-2161 wellbore. The top of cement (TOC) in W-216i was determined by a cement bond log to be 3500' MD, providing 2609' MD of coverage above the top of the pool. BPXA believes that injected fluids will be confined within the appropriate receiving intervals. Should you have any questions regarding this request, please contact Maggie Orlando at 564 - 4741. Thank you for timely consideration of this request. Sincerely, ~ ~? %~ ~~ ~~ Diane Richmond GPB WEST, Resource Manager CC: Mark Agnew (ExxonMobil) Dan Kruse (CPAI) Glenn Frederick (Chevron) Alan Mitchell (BPXA) David Lenig (BPXA) Claire Sullivan (BPXA) Attachments: Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of W-2161 Figure 2: W-216i '/ mi Radius Map • March 18, 2010 Page 2 Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of W-216i Well Dist from TOC, TOC Determination Top Pool (MC Top Injection Coverage injector, ft MD Method sand), MD Sand (Oba), MD W-216i 0 3500 Cement Bond Log 6109 6514 2609' MD Dated 111Jan~2008 W-204PB1 665' NA NA NA NA Plugback 2: W-216i '/ mi Radius M 5,968,000 5,966,000 5,964,000 5,962,000 5,960,000 610,000 612,000 614,000 616,000 Schrader Bluff OBa Depth Structure Map 20' Contour Interval. '/< mile circle around SB_OBa injection zone for W-214, W-216, W-217, W-218 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071680 Well Name/No. PRUDHOE BAY UN POL W-216 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23379-00-00 MD 7052 TVD 6398 REQUIRED INFORMATION Completion Date 2/14/2008 Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / RES / AZI-DEN / PWD, LWD GR /CCL, USI Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Ty~ Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 'ICED D Asc Directional Survey 0 7052 Open 1/16/2008 G,;~2'pt Directional Survey 0 7052 ~+O~pen 1/16/2008 Some ~ ~,.~- (~~~ 5 Col 203 6923 'i~pcr~t 2/13/2008 USIT- CBL, USIT -D and ~ DSLT 11-Jan-2008 t/ED C Lis 15939 '`~C~antr~rtrRay C ~t,w.~.~' E~aj, 205 9834 psi 2/22/2008 LIS Veri, GR, CCL w/PDS and Tif graphics ','~ED C Lis 15955~uction/Resistivity 101 7057 Open 2/28/2008 LIS Veri, GR, ROP, RPM, ~ DRHO, NPHI w/PDS ~ ', graphics Cog Induction/Resistivity 25 Blu 100 7010 Open 2/28/2008 MD Vision Service 7-Jan- 2008 I; og Induction/Resistivity 25 Blu 100 7010 Open 2/28/2008 TVD Vision Service 7-Jan- 2008 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y71Q'~ Analysis Y~- Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops Completion Status 1WINJ Current Status 1WINJ DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071680 Well Name/No. PRUDHOE BAY UN POL W-216 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23379-00-00 MD 7052 TVD 6398 Completion Date 2!1412008 Completion Status 1WINJ Current Status 1WINJ UIC Y Compliance Reviewed By: Date: __~ ~~~ • LJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Thursday, October 09, 2008 To: Jim Regg ~ v~24 l p v P.I. Supervisor ~ ~~ SUBJECT: Mechanical Inte~•ity Tests BP EXPLORATION (ALASKA) INC W-216 FROM: Jalm Crisp PRUDHOE BAY LiV POL W-216 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN POL W-216 Insp Num: mitJCr08 1 008 1 1 3206 Rel Insp Num: API Well Number: 50-029-23379-00-00 Permit Number: 207-168-0 Inspector Name- John Crisp Inspection Date: 10/2/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well w-zI6 Type Inj. ! W TVD 4973 i IA 0 2480 ~~ 2390 i 2370 ~ P.T. ~ 2071680 ~ TypeTest SPT Test pSl ~ 1500 "Y QA ~ ]70 ~ 480 i 470 ~ 460 Interval oT~R p/F P ~ Tubing ~ loao Joao I Joao i loao ! j Notes: 2.6 bbl's pumped for test. MIT IA to demonstrate casing integrity. Thursday, October 09, 2008 Pale 1 of 1 ~~+ M®~1~~~~ To: Jim Regg P.I. Supervisor kp~JJ ~~j~~L~°V l~ FRONt: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 09, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-2(6 PRUDHOE BAY UN POL W-216 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UN POL W-216 API Well Number: 50-029-23379-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS080609080322 Permit Number: 2o7-tbs-o / Inspection Date: bi7i2oo8 Rel Insp Num: Packer - --- Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -~ Well I W-216 ~ Type Inj. W I TVD 4973 IA sao T zsoo / zaloTzaoo T _-__ -- :-_-_--- P.T zo716so TypeTest SPT ;`Test psi 1500 I- i OA X00 420 ~----- ---- -1- -- 410 400 I i --- - INITAL P Interval --- P/F Tubin ~ g - -_ 1380 1320 - - - - 1320-~ 1380 -~ ~ ------ I Notes: - - ---- -- -- --- - _ Monday, tune 09, 2008 Page 1 of I o2i2~/os ~C~Illtllb~t'I~~' N0.4599 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Betn 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Polaris,Lisburne Wall _Inh $ 1 nn rln~r nf:.... n.~f.. of n_1..- nn W-216 40016312 OH MWD/LWD EDIT - i- 01/07/08 2 1 LGI-04 11970706 RST S(_p q 12/31/07 1 1 W-45 40016146 OH MWD/LWD EDIT '}_ '~ 12/18/07 2 1 15-04B 12005202 CH EDIT PDC GR (SCMT) ~- ~ 12/28/07 1 C-16B 11209604 MCNL ~Q(o-ps ~ / ~ 05/19/06 1 1 B-18 11962779 RST -d 01/05/08 1 1 ~~~~~~vr~,YV YYL.GVVG nGV GlrI G~ JIV1\II`,V NIYV RCIlJR1Y1rYV VIYC VVri CAl.r1 IV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ' "' 900 E. Benson Blvd. - ~ ` ( :_ _ Anchorage, Alaska 99508 Date Delivered: ;,~ ~s~ , A ~}, ,; t~ Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 4 Anchorage, AK 99503-28 8 ~ ATTN: Beth ,n / W Received by: u • c . Page 1 of 1 Maunder, Thomas E (DOA From: Hubble, Terrie L [Terrie.Hubble@bp.com} Sent: Thursday, February 21, 2008 10:18 AM To: Maunder, Thomas E (DOA) Subject: RE: W-216 (207-168) Thanks! From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 21, 2008 9:07 AM To: Hubble, Terrie L Subject: W-216 (207-168) Terrie, I am reviewing the completion report for this well. WAG is checked in the top box. According to AIO 25A, WAG is only on approval according to the AIO. The correct designation is WINJ. At #his time there are only 3 weds in Polaris that have been approved for WAG; S-215, W 215 and W 209. I will be changing the status to WINJ. You should make the same change to your copy. Gall or message with any questions. Tom Maunder, PE AOGCC 2/21 /2008 ~-~~~~ j"`~C=iANICAL INTEGRITY REPORT • .: UD u:.._ : ~a~~~--~~ QPER ~ FIELD ~~ ~ ~7~ ~~ .G ~ E~~~ .. ~ . ~~1,b -O chi i;~LL NUMBER ~U_ ~~~ ~,~ ~ LL SAT ~ TD . '1~05~ .~.. ~3;.~ TvD ; : ~T~ . ~,~5 ~ ~n ~ ~~-~~TvD ~~~ Casi^g: Shoe:'Zd3~MD Jc-~~ TVD; liV: ~~ ?~ 1~~-?'4~i =,:~e= . ~ ~ Shoe : '~ ?'VD ; .~C~ . ?13 ~';~ ole Sice ~~~~ end ~` ~ C'r'..e1?~ _C~=.~,_NTEGRITY - ? ArRT # T'~i Set et ~ ~~~ ~ ~~.~> ~' eris ~~ to ~,~' ~~ `~ ~ ~ ~~ ~~~~ ~~~~ rnnul.4s ?ress Test: _? ?5 nin \~.p,_ :,fl min -~~ C OQ2n t S . ~J~ i 1/~~` ~ ~ ~ p ~ /J'C~C \c:- /~~ ~ ~~~1.~/~+j`~ 3 '~ CHIC N I C?i. 1NTEGR?'TY - PART_ # 2 Cement Vol~es:_ r~1nt_ Liner~~_; Csa~~~~j\S; DV ~~-- C.ut Jol to cove, oer~s ~ ~~o`~S ~~ ~~~,~ fro ~©~a ~® ~`~5 SOCK' ecretlcal TOC ~ ~~~~~~ ~ D ~ ~, ~cro~~~4~ ~ 4`~U' ,~--- ~. - ~- rfE ~ti nc~ c~~, cc~ ~ ~~ ,~ ~ ~ t ~ c .~v ~-~ ~ Cement Bond Log (Yes yr No) C9L Evaluation, zone above perks t~rOC111Ct20n LOg: ~'p"De ` ~ ''b ~t,-~ ~' ~ In AOGCG File - r ~ t.V$1L'at3.On ooN~LJSIOi~s ~ art # 1 : ~~ L-~c~~~2a-~ ~~~~~~ _ ~ .~~~ ~ v fl~ ~~~~~ STATE OF ALASKA ~/~ ~~ ~~~~~~~ ALASKA~L AND GAS CONSERVATION COMNRSSION DEB X ~ X008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil $~ ~8S Cars. Cotnfnissian 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended y~o~ ~~~..~y~ zoAACZS.~os zoAACZS.~~o ^ GINJ ' NJ a WDSPL ^ Other No. of Completions One 1b. Well Class: "`" ~' ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: ~~~~~~p~ ~ BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 1/16/2008 12. Permit to Drill Number 207-168 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded d~' 12/27/2007 13. API Number 50-029-23379-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/6/2008 14. Well Name and Number: PBU W-216 4904 FSL, 1176 FEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 3004' FSL, 320' FWL, SEC. 15, T11 N, R12E, UM 8. KB (ft above MSL): 81.9' ' Ground (ft MSL): 53.4' 15. Field /Pool(s): , Prudhoe Bay Field /Polaris Pool Total Depth: 3384' FSL, 283' FWL, SEC. 15, T11 N, R12E, UM 9. Plug Back Depth (MD+TVD) 6952 5325 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 612049 y- 5959881 Zone- ASP4 10. Total Depth (MD+TVD) 7052 ~ 5398 16. Property Designation: ADL 028263- TPI: x- 613487 y- 5963282 Zone- ASP4 Total Depth: x- 613443 y- 5963662 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.05 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (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 / PWD, LWD GR / CCL, USIT / CBL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH'MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT._ GRADE TOP BOrrOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# A-53 Surface 108' Surface 108' 34" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 30' 1309' 30' 1292' 16" 616 sx AS 154 sx AS Lite 9-5l8" 40# L-80 28' 4021' 28' 3312' 12-1/4" 492 sx Dee Crete 373 sx Class'G' 7" 26# L-80 26' 7037' 26' 5387' 8-3/4" 360 sx Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter 5 spf 3-1/2", 9.2#, L-80 6799' 6455', 6591' & 6684' , MD TVD MD TVD 6506' - 6544' 5009' - 5035' 6616' - 6652' 5085' - 5111' 25. ACIQ, FRACTURE, CEMENT SQUEEZE, ETC. 6696' - 6746' 5142' - 5177' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 2843' Freeze Protected with 100 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BdL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OiL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. pia ; k None ~$"' E ~^'j `~ Qp ~' ~ . ~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE fir; !L~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED: 29. FORMATION TESTS NAME TVD Well Tested . Yes ®No Permafrost Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2039' 1941' detailed test information per 20 AAC 25.071. Ugnu 4120' 3380' None Schrader Bluff NA 6210' 4805' Schrader Bluff NB 6243' 4828' Schrader Bluff NC 6292' 4862' Schrader Bluff NE 6306' 4871' Schrader Bluff NF 6381' 4922' Schrader Bluff OA 6432' 4957' Schrader Bluff OBa 6506' 5009' Schrader Bluff OBb 6551' 5040' Schrader Bluff OBc 6613' 5083' Schrader Bluff OBd 6695' 5141' Schrader Bluff OBe 6784' 5204' Schrader Bluff OBf 6840' 5244' Base Schrader Bluff OBf / 6914' 5298' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 6914' 5298' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / ~~ / Signed Terrie Rubble Title Drilling Technologist Date 'I ~ ~~ PBU W-216 207-168 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Bob Coolidge, 564-5776 Permit No. / A royal 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple 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). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only gp Page 1 of 1 Leak-Off Test Summary Legal Name: W-216 Common Name: W-216 .- Test Date Test Type 1/5/2008 ~ FIT Test Depth (TMD) 4,021.0 (ft) Test Depth (TVD) 3,312.0 (ft} AMW __ 8.80 (PP9) -- - _ __ _ ~ Surface Pressure Leak Off Pressure (BHP) ' EMW 525 (psi) 2,039 (psi) 11.85 (PP9) Printed: 1/24/2008 2:46:37 PN BP Operations Summary Report Page 1 of 15 Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPL ETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: I D ti i i f O Date From - To ~ Hours Task - it Code NPT Ph pera ons escr pt on o ase 12/25/2007 - _ 18:00 - 19:00 __ 1.00 _ RIGD P PRE Rig down and prep for rig move. 19:00 - 00:00 5.00 MOB P PRE Move pits away from sub base. Jack rig up and remove malts. Move rig off of W-45. Move sub around pad. 12/26/2007 00:00 - 01:00 1.00 MOB P PRE Continue moving rig around pad near W-216. 01:00 - 03:00 2.00 DIVRTR P PRE Nipple up diverter stack. 03:00 - 04:30 1.50 MOB P PRE Spot rig over W216 conductor. Place rig mats under rig. 04:30 - 06:00 1.50 MOB P PRE Spot mud pits to rig. Place mats under pits. 06:00 - 07:00 1.00 RIGU P PRE Hook up pit /rig interconnect. Rig ready for acceptance. "Rig accepted ~ 05:00 hr, 12/26/2007. (Time rolled back 2 hrs spent on diverter) 07:00 - 08:30 1.50 RIGU P PRE Take on water in mud pits. Secure cellar. Berm around rig. Work on Pre-Spud Checklist. 08:30 - 15:30 7.00 DIVRTR P PRE Ni le u diverter system, riser and flowline. 15:30 - 17:00 1.50 RIGU P PRE Change out saver sub on topdrive. 17:00 - 20:30 3.50 RIGU P PRE PJSM. Prep floor for picking up 5" drill pipe. Pick up 25 singles and rack back in derrick. (Tagged top of ice ~ 52') 20:30 - 21:30 1.00 RIGU P PRE Pick up BHA subs and tools to rig floor. 21:30 - 00:00 2.50 RIGU P PRE Pick up 5" HWDP singles and rack back in derrick. Make up Jar stand and rack back. 12/27/2007 00:00 - 01:00 1.00 RIGU P PRE Complete Pre Spud Checklist. (Crew held Pre-Spud Meeting during Pre Tour Safety Meeting) 01:00 - 02:00 1.00 DIVRTR P PRE Perform surface Diverter function and accumulater draw down tests. Witnessing of test was waived by AOGCC rep Jim Rigg. Test witnessed by BP WSL R. French and NAD TP T. Leigh. 02:00 - 03:00 1.00 RIGU P PRE Fill lines and hole with spud mud. Check for and fix leaks. Pressure test surface lines to 3,000 psi - OK. Stand back jar stand. 03:00 - 04:30 1.50 RIGU P PRE Make up new MX1 16" bit to 1.83 deg motor, crossed back over to HWDP for ice plug cleanout. 04:30 - 05:00 0.50 RIGU P PRE Clean out ice plug from 52' to 70'. 600 gpm, 400 psi. 05:00 - 06:00 1.00 RIGU N RREP PRE Trouble shoot pumps. Clean out clogged suctions screens on mud pumps. 06:00 - 06:30 0.50 RIGD P PRE Continue clean out ice plug from 70' to 108'. 06:30 - 07:00 0.50 RIGU P PRE Stand back 1 stand of HWDP. 07:00 - 08:00 1.00 RIGU P PRE Make up NM lead DC, NM Stab, MWD and orient. Run back in hole to 108'. 08:00 - 08:15 0.25 DRILL P COND2 Spud in W-216i @ 08:00 hr, 12/27/2007. Drill 16" hole from 108' to 118'. 500 gpm, 280 psi (pumps not acting right) 40 rpm, .5k TO oft, 1 k TO on. PU - 46k, SO - 46k, RWT - 44k, WOB - 5k. 08:15 - 11:30 3.25 DRILL N RREP COND2 Trouble shoot pumps. Go through valves & seats, check suction screens. Did not find anything wrong. 11:30 - 12:00 0.50 DRILL P COND2 Drill 16" hole from 118' to 167'. 716 gpm, 715 psi 45 rpm, .5k TO off, 1.3k TO on. PU - 46k, SO - 46k, RWT - 44k, WOB - 6-8k. ART - .84 hrs 12:00 - 13:00 1.00 DRILL P COND2 Drill 16" hole from i 67' to 260'. 716 gpm, 775 psi 45 rpm, .5k TO off, 1.3k TO on. PU - 49k, SO - 49k, RWT - 47k, WOB - 8-10k. Printed: 7/24/2008 2:46:45 PM g P Page 2 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number; Date From - To !Hours ' Task Code I'I NPT '', Phase Description of Operations 12/27/2007 13:00 - 15:00 2.00 DRILL P COND2 POH 2 stands to 75'. Rig up SWS E-line and Gyro Data. 15:00 - 17:00 2.00 DRILL P COND2 Pick up remaining BHA #1: UBHO, NM Stab, NM DC, NM XO, 2 NM DC, saver sub, Jar stand. 17:00 - 17:30 0.50 DRILL P COND2 Run Gyro surve . 17:30 - 00:00 6.50 DRILL P COND2 Drill 16" hole from 260' to 492'. Gyro survey every 100'. 595 gpm, 830 psi off, 1,025 psi on 45 rpm, .7k TQ off, 2k TQ on. PU - 64k, SO - 62k, RWT - 61 k, WOB - 10k. ART - .95 hrs, AST - 3.75 hrs 12/28/2007 00:00 - 05:00 5.00 DRILL P COND2 Continue directionally drill 16" 2nd conductor hole from 492' to 724'. 600 gpm, 1,050 psi off, 1,165 psi on 40 rpm, 1 k TQ off, 2.5k TQ on PU - 76k, SO - 74k, RWT - 75k, WOB - 25k. 05:00 - 05:30 0.50 DRILL P COND2 Run last Gyro survey. Rig down SWS and Gyro Data. 05:30 - 12:00 6.50 DRILL P COND2 Directionally drill 16" 2nd conductor hole from 724'to 1,113'. 600 gpm, 1,140 psi off, 1,380 psi on 40 rpm, 1.3k TO off, 4.5k TQ on PU - 92k, SO - 81 k, RWT - 86k, WOB - 25-35k. ART - 0.68 hrs, AST - 5.43 hrs 12:00 - 17:30 5.50 DRILL P COND2 Directionally drill 16" 2nd conductor hole from 1,113'to TD C~? 1,315' MD, 1,298' TVD. 650 gpm, 1,150 psi off, 1,365 psi on 45 rpm, 2.1 k TQ off, 4.7k TQ on PU - 92k, SO - 81 k, RWT - 86k, WOB - 25-35k. ART - 0.12 hrs, AST - 3.72 hrs 'Did NOT hav 'n thi Running gravels or sands Surface broaching Lost mud down hole Tight hole problems 17:30 - 19:00 1.50 DRILL P COND2 Stand back one stand and pick up single joint. Circulate 3 1/2 times bottoms up C~ 700 gpm, 1,380 psi 55 rpm, 2.4k TQ. MW - 9.0+ppg. 19:00 - 20:00 i.00 DRILL P COND2 POH from 1,215' to 203' without problem. 20:00 - 20:30 0.50 DRILL P COND2 Run in hole from 203' to 1,150' without problem. Set down hard ~ 1,150. Attempt to work by without pumping - No go. 20:30 - 22:00 1.50 DRILL P COND2 Wash and ream from 1,150' to 1,220' Q 200 gpm, 330 psi, 20 rpm, 3-7.6k TO. Increase rate to 700 gpm, 1,380 psi and backream full stand up. Shut down pump and run in to 1.220' without problem. Work full stand up and down again without pumping and without drag. Make connection and wash last stand down to bottom C~3 200 gpm, 325 psi. No rotating. Tagged 5' high. Increase rate and wash last 5' with 700 gpm, 1,305 psi, 45 rpm, 2.8k TQ. 22:00 - 23:00 1.00 DRILL P COND2 Circulate 3 times bottoms up C~ 700 gpm, 1,320 psi ICP, 1,285 psi FCP. 50 rpm, 2-3k TO, PU - 92k, SO - 81 k, RWT - 86k. 9.0+ ppg MW 23:00 - 00:00 1.00 DRILL P COND2 POH to run 13 3/8" casing from 1,315' to 172' without problem. 12/29/2007 00:00 - 02:30 2.50 DRILL P COND2 Stand back jar and drill collar stands. Laydown remainder of BHA. Printed: 1/24/2008 2:46:45 PM BP Operations Summary Report Page 3 of 15 ~ Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date I! From - To Hours .Task 'Code NPT Phase Description of Operations 12/29/2007 00:00 - 02:30 2.50 DRILL P COND2 Bit grade: 4-3-WT-A-E-1-No-TD. Motor in good condition. 02:30 - 03:30 1.00 DRILL P COND2 Clear and clean rig floor. 03:30 - 07:30 4.00 CASE P COND2 Make casing hanger dummy run. 07:30 - 09:00 1.501 CASE P COND2 09:00 - 11:30 2.501 CASE N HMAN COND2 11:30 - 15:00 3.50 CASE P 15:00 - 16:30 1.50 CASE P 16:30 - 17:00 0.50 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 18:30 1.00 CASE P 18:30 - 19:00 0.50 CEMT P 19:00 - 19:30 I 0.501 CEMT I P 19:30 - 21:30 I 2.001 CEMT I P 21:30 - 00:00 2.501 CEMT P 12/30/2007 100:00 - 01:30 1.501 CEMT P 01:30 - 02:30 1.00 i CEMT P PJSM. Rig up to run casing. Make up, Baker-Lok shoe track and check floats - OK. Continue running in hole with 13 3/8" 68# L-80 BTC casing to 246'. Make up TO - 10,500 fUlbs, used BOL 2000 NM pipe dope. Fill every joint with Frank's fill-up tool. Discovered mud spill in cellar area from a valve that was left open. Appx 35 bbls with a small amount out of containment outside. `See Remarks. Clean up spill. Continue running in hole with 13 3/8" casing from 246' to 1,245' COND2 COND2 Wash from 1,245'to bottom @ 1,275'. 3.2 bpm 285 psi. COND2 Rig crown Frank's tool, rig up circulating swedge. COND2 Wash landing joint down from 1.275' to bottom C~3 1,309' @ 4 bpm, 180 psi. PU - 114k, SO - 97k. COND2 Circulate and reci rocate casin .Stage up from 3 bpm, 135 psi to 6 bpm 270 psi. COND2 Rig down circulating swedge. Rig up cementing head and lines. COND2 Circulate and reciprocate casing C~3 10 bpm, 520 psi. PU - 112k, SO - 102k. COND2 Switch over to Dowell. Cement 1st stage: Pump 5 bbls of fresh water. Pressure test lines to 3,500 psi - OK. Mixon the fly and pump 52 bbls of 10.0 ppg MudPush II spacer. Drop bottom plug. Mix on the fly and pump 102 bbls of AS1 15.7 ppg cement. Drop top plug and kick out with 5 bbls of fresh water. Switch to rig and displace cement until catching plug @ 6.8 bpm, 200 psi. Slow to 5 bpm, 130 psi with MudPush going around shoe. Slow pump to 3 bpm and land casing with cement going around shoe. 40 psi ICP, 160 psi FCP. Bumped plug with 1,050 psi. CIP ~ 21:30 hr. Good returns through out cement 'ob. Pumped total of 179 bbls to bump @ 97% effc. Check floats - OK. COND2 Rig down casing equipment and cement head. Back out top pup of split landing joint. Change out bales. COND2 Make up TAM combo tool. Run in hole to 100' and en age TAM collar. Pressure test between cups to 800 psi - OK. ` Rotate tool 1/4 turn to open collar. Pump 25 bbls around tool ~ 5 bpm, 80 psi. COND2 Switch to Dowell. Cement 13 3/8" 2nd stage. Pump 5 bbls of fresh water. Test lines to 3,000 psi - OK. Mix on the fly and pump 32 bbls of 10.0 ppg MudPush II spacer Mix on the fly and pump 44 bbls of 10.7 ppg ASL cement. Wash up cement lines to Tee. Pump 1 bbl of fresh water down DP. CIP ~ 02:12 hr Printed: 1/24/2008 2:46:45 PM BP Operations Summary Report Legal Well Name: W-216 Page 4 of 15 'I Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABORS 9ES Rig Number: Date From - To ,Hours ', Task Code I NPT Phase - __ 12/30/2007 01:30 - 02:30 1.00 CEMT P COND2 02:30 - 03:00 0.50 CEMT P COND2 03:00 - 03:30 0.50 CEMT P COND2 03:30 - 06:30 3.00 CEMT P COND2 06:30 - 09:30 I 3.001 CEMT I P I I COND2 09:30 - 11:00 I 1.501 CEMT I P I I COND2 11:00 - 14:00 3.00 CEMT P COND2 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 20:30 6.00 DRILL P SURF 20:30 - 23:00 I 2.501 DRILL I P I I SURF 23:00 - 00:00 1.001 DRILL P ~ SURF 12/31/2007 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 01:00 0.50 DRILL P SURF 01:00 - 02:30 1.50 DRILL N MISC SURF 02:30 - 03:45 i 1.25 ~ DRILL ~ P ~ ~ SURF 03:45 - 04:15 I 0.501 DRILL I P I I SURF 04:15 - 04:45 0.50 DRILL P SURF 04:45 - 12:00 7.25 DRILL P SURF 12:00 - 23:30 I 11.501 DRILL I P I I SURF Description of Operations 'Returned 25 bbls of sidewalk cement back to surface. Close TAM collar. Pressure test TAM to 2,300 psi - OK. irculate 3 DP annular volumes @ 13 bpm, 860 psi. Stand back stand. Break out and laydown TAM combo tool. Rig down casing and cement equipment. Make up split landing joint top pup. Backout and laydown landing joint. Clean surface equipment of cement residue. Run in hole with 5" HWDP to 460' and laydown same back to surface. Run in hole with 5" DP to 736' and laydown same back to surface. Held "Safety Standown" meeting. Meeting attended by Pat Stewart's crew and facilitated by BP HSE rep Herb Williams, BP WSL Tom Anglen, NAD HSE rep Rick Dufek, and NAD TP Mark Ashley. Discussed previous HSE events and how they can be prevented. Service topdrive and drawworks. Change out lower TIW valve from 5" to 4" HT-40. Change out topdrive quill sub from 5" to 4" HT-40. Adjust pipe handler grabber. Pick up BHA tools and equipment to rig floor. Pick up 108 joint of 4" HT-40 drill pipe and stand back in derrick. Make up BHA #2: Used 12 1/4" HTC MXL-1 bit, 1.5 deg PDM, NM lead DC, NM Stab, MWD, NM DC, NM XO, 2ea NM DCs, saver sub, 1 5" HWDP, Jar, 1 5" HWDP, XO. Run in hole with BHA #2 picking up single joints of 4" HT-40 HWDP from 263'to 998'. Continue running in hole with BHA #2 from 998'to 1,187'. Service topdrive and crown. Hook up topdrive blower hose. Make up topdrive and fill pipe. Both pumps lost prime. Trouble shoot problem. Wash down and tag cement ~ 1,219'. Drill out cement, float co ar, shoe track, float shoe and rathole to 1,315'. 600 gpm, 1,445 psi off, 1,550 psi on 60 rpm, 2.9k TO off, 5.8k TO on. PU - 84k, SO - SO - 70k, RWT - 77k. Displace well with new 8.7 ppg spud mud. 600 gpm, 1,650 psi, 60 rpm, 5k TO. Clean out from under shakers. Top off pits with new mud. Directionally drill 12 1/4" surface hole from 1,315' to 2,620'. 700 gpm, 2,800 psi off, 3,150 psi on 70 rpm, 5k TO off, 8k TO on PU - 93k, SO - 74k, RWT - 80k, WOB - 30k. ART - 1.98 hrs, AST - 2.78 hrs Directionally drill 12 1/4" surface hole from 2,620' to TD ~ 4,031' MD, 3,318' TVD. 700 gpm, 3,500 psi off, 3,650 psi on 80 rpm, 6k TO off, 8k TO on PU - 110k, SO - 88k, RWT - 98k, WOB - 40k. ART - 4.47 hrs, AST - 0.62 hrs 'Encountered a fair amount of hydrates ~ 3,698'. None @ TD. 'After hydrates were encountered, lowered viscosity from Printed: 1/24/2008 2:46:45 PM BP Operations Summary Report Page 5 of 15 Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABORS 9ES Rig Number: i Date From - To '. Hours Task Code NPT Phase Description of Operations _ --- I - _ _ ---- 12/31/2007 23:30 - 00:00 0.50 DRILL P I SURF Circulate and condition hole. 1/1/2008 100:00 - 01:30 I 1.501 DRILL I P I I SURF 01:30 - 04:30 ~ 3.00 ~ DRILL ~ P ~ ~ SURF 04:30 - 06:30 2.00 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 14:30 6.50 DRILL N SFAL SURF 14:30 - 17:00 2.50 DRILL P SURF 17:00 - 19:00 I 2.001 DRILL I P I I SURF 19:00 - 22:00 3.001 DRILL P SURF 22:00 - 00:00 2.00 DRILL P SURF 1/2/2008 00:00 - 01:30 1.50 DRILL P SURF 01:30 - 03:00 1.50 DRILL P SURF 03:00 - 04:00 1.00 CASE P SURF 04:00 - 07:00 3.00 CASE N RREP SURF 07:00 - 08:30 1.50 CASE P SURF 08:30 - 12:00 3.50 CASE P SURF 12:00 - 19:30 I 7.501 CASE I N I SFAL I SURF 19:30 - 20:30 I 1.001 CASE I P I I SURF 700 gpm, 3,500 psi ICP, 3,480 psi FCP C~3 end of tour. 80 rpm, 5.5k TO. Continue circulating for total of 3 1/2 times bottoms up. Shakers clean. 700 gpm, 3,480 psi ICP, 3,370 psi FCP. 100 rpm, 5.5k TO. 'No hydrates while circulating. MW - 9.3 PP9 Monitor well - OK, no hydrates breaking out. W iper trip to shoe. POH from 4,031' to 2,230'. Started pulling tight. Attempt to work through. Backream from 2,230' to 1,282'. 500 gpm, 1,420 psi, 80 rpm, 4-7k TO. Monitor well -Static. Blow down topdrive. Clean rig floor. Clean out possum belly. Service topdrive, crown, drawworks. Wait on parts and change out turbocharger on #1 catepillar motor. Trip in hole from 1,282'to 1,910' md. Wipe tight spot ~ 1,910' until smooth. Continue trip in hole to 3,935' md. Wash to 4,031'. No fill found on bottom. Circulate and recipricate 3+ bottoms up. 700 gpm, 3550 psi, 100 rpm, 5k TO, RTW - 95k. MW in 9.5ppg. Shakers progressively cleaned up by CBUx3. Shut down pumps, monitor well -static. POH slick to above 13-3/8" casing shoe C 1,309' md. No more than 5-10k overpulls entire trip out. PU / SO @ TD - 125k / 87k, PU C~ Shoe - 85k. Continue POH to top of BHA @ 263'. PJSM. Pull out of the hole standing back jars & drill collars. Lay down MWD. Continue laying down BHA. Break bit and lay down NM stab, NM lead collar, and 1.5 degree motor. Bit grade 1-1-WT-A-E-1-NO-TD. Clean and clear rig floor of all BHA components. Make dummy run with 9 5/8" mandrel casing hanger. Remove and replace failed solenoid on topdrive backup wrench. Rig up Nabors casing equipment. Change out bales and make up franks fill up tool. PJSM. Begin running 9-5/8" 40# BTC surface casing. Baker Loc shoe track. Check floats. Run 21 joints of 9-5/8" casing to 855' md. Average make up tq 10,500 ft-Ibs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every joint. Install bowspring centralizer over collars on joints #1 - #21. Noticed leak on franks tool body. Break out and lay down Franks tool. Blow down top drive. Mobilize GBR and tighten leaking connection as per GBR service hand. Make up Franks tool to top drive and attempt to pump but same connection still leaking. Mobilize second Franks tool to location. Rig move delayed arrival. RU new Franks tool & Test - OK. Continue running 9-5/8" casing from 851' - 1,341' and Qoints Printed: 1/24/2008 2:46:45 PM ~ r gP Page 6 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date~I From - To I' Hours Task Code NPT 1/2/2008 119:30 - 20:30 1.00 CASE P 20:30 - 21:00 I 0.501 CASE I P 21:00 - 00:00 ~ 3.00 ~ CASE ~ P 1/3/2008 100:00 - 02:30 I 2.501 CASE I P Spud Date: 12/27/2007 Start: 12/25/2007 End: 1 /16/2008 Rig Release: 1/16/2008 Rig Number: Phase Description of Operations SURF 22-33). Average make up tq 11000 ft-Ibs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every joint. Install bowspring centralizer over collars on joints 22-25. SURF Circulate one casing volume (100 bbls) C~3 13-3/8" shoe. Stage up to 214 gpm, 345 psi. PU - 98k, SO - 60k. SURF Continue running 9-5/8" casing from 1,341' - 3,053' and Qoints 34-75). Average make up tq 11 k ft-Ibs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every joint. Install bowspring centralizer over stop rings on joints 68 & 69. Install TAM Port Collar in between 68 & 69. SURF Continue running 9-5/8" 40# BTC surface casing ~ 2 minutes per joint from joint number 76 ~ 3,053' and shoe depth to joint 98 ~ 3,990' md. Average make up tq 10,500 Wlbs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every 02:30 - 03:30 I 1.001 CASE I P 03:30 - 04:30 I 1.00 I CEMT I P 04:30 - 07:30 I 3.001 CEMT I P SURF SURF SURF 07:30 - 08:30 I 1.001 CEMT I N I SFAL I SURF 08:30 - 12:30 I 4.001 CEMT I P I I SURF 98 joints of BTC casing run. Pick up 9-5/8" hanger, split landing joint, wash down and land casing on depth C~ 4,021', w/fluted hanger. Up wt 185k Dn Wt 120k. No problems at all running in hole. HES Float Shoe - Bottom ~ 4,021' 2 Jts 9-5/8", 40#, L-80 BTC (#1-2) HES Landing Collar -Top C~ 3,937' 66 Jts 9-5/8", 40#, L-80 BTC (#3-68) 9-5/8" TAM port collar 30 Jts 9 5/8" 40# L-80 BTC (#69-#98) 9 5/8" 40# L-80 BTC Hanger P x P Pup Jt. FMC fluted casing hanger Total of 27 - Bowspring Centralizers and 3 stop rings: Jts 2-25 have 1 per joint clamped across collars. Float joint has 1 centralizer clamped 10' from float shoe. Joints 68 & 69 have a centralizer clamped 15' above and below TAM collar. Circulate one casing volume w/franks tool. Stage pumps up to 8 bpm, 617 psi. Full returns. Rig down franks fill up tool, casing tongs, & slips. Blow down lines. Make up cement head and manifold. Stage up pumps to 340 gpm, 630 psi. Reciprocate pipe in 10' , strokes. Circulate and condition mud back in preparation for cement job. Initial Parameters: PU - 170k, SO - 125k, 340 gpm, 630 psi, YP - 42, Funnel Vis - 200 Final Paramteres: PU - 185k, SO - 130k, 340 gpm, 400 psi, YP - 15, Funnel Vis - 60 Troubleshoot and work around Dowell batch mixer fuel pump problem. ,Continue to circulate and reciprocate while waiting on cementers. PJSM w/ Schlumberger cementers. Batch up cement. Pump 5 bbls water, test lines to 3500 psi. Pump 85.9 bbls of 10.0 Printed: 1/24/2008 2:46:45 PM gp Page 7 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date I, From - To Hours Task !Code NPT Phase Description of Operations 1/3/2008 08:30 - 12:30 4.00 CEMT P SURF ppg mud push (add dye to initial MudPush). Drop bottom plug, pump 338 bbls of lead 10.7 ppg DeepCrete cement. 5-4 bbl/min with full returns. Pumped 62 bbls 15.8ppg G cement and 15 bbls 15.8ppg G w/ durastone at 5 bpm. Drop top plug. Wash up with 10 bbls of water from Dowell. Switch to rig pumps and displace cement C~3 8 bpm. Good lifting pressure & saw good indication w/pump pressure of 15.8ppg tail cement turning corner and moving up hole. Slow rate to 3 bbl/min and bump plug at 1550 psi 4140 strokes = 95% efficiency. CIP @ 12:20. Full returns throughout job. 75 bbls cement back to surface. Reciprocated pipe in 7' strokes until 270 bbls of lead awa .Set back on ring & stop reciprocation. 12:30 - 13:00 0.50 CEMT P SURF Pressure u casin to 3500 si & hold for 15 minutes -Slight leak at cement head crossover. Bleed off pressure & check floats - OK. 13:00 - 16:00 3.00 CEMT P SURF Rig down cementing head, & casing equipment. Change out bails and handling equipment. Drain stack. Back out landing joint. Clean & clear rig floor. 16:00 - 23:00 7.00 DIVRTR P SURF Flush stack. Lay down drilling riser. Nipple down diverter & remove diverter stack from wellhead. 23;00 - 00:00 1.00 WHSUR P SURF Prepare tubing spool & wellhead. 1/4/2008 00:00 - 02:00 2.00 WHSUR P SURF Position spool on wellhead. Run in set screws to 450 ft-Ibs. Test metal to metal seal to 1000 psi for 10 minutes - OK. 02:00 - 10:00 8.00 BOPSU P SURF Break and rotate BOP stack on adapter flange. Pick and position BOP stack on tubing spool. Nipple up stack. Make up turnbuckles, riser, casing & tubing working valves. 10:00 - 12:00 2.00 BOPSU P SURF Make up BOPE floor equipment. Install test plug. Fill all testing lines. 12:00 - 18:00 6.00 BOPSU P SURF 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 Lou Grimaldi. Test witnessed by BP WSL Tom Anglen & NAD Toolpusher Ronnie Dalton. 18:00 - 19:00 1.00 BOPSU P SURF Rig down BOPE floor equipment. Remove test plug. Install wear ring. Blow down lines. 19:00 - 23:30 4.50 DRILL P PROD1 PJSM. Pick up BHA #3 consisting of 8-3/4" DSX619M Hycalog PDC bit, 1.15 degree PDM motor, NM Stab, ARC, MWD, ADN, tea NM DC, Jars. Load nuclear source in ADN. Run in the hole with remaining BHA from the derrick to 989'. 23:30 - 00:00 0.50 DRILL P PROD1 RIH on drillpipe singles from shed from 989' - 1,084' md. 1/5/2008 00:00 - 04:00 4.00 DRILL P PROD1 RIH from 1,084' - 3,745' and on drillpipe singles from shed. Rotate past TAM Port collar w/ BHA and ghost reamer C~? 10 rpm and no pumps. Shallow test MWD ~ 1,311'. 450 gpm, 1170 psi - OK. MU Ghost reamer 1,568' back from bit. 04:00 - 05:00 1.00 DRILL P PROD1 Pressure test 9-5/8" casing to 3,500 si - OK. 05:00 - 08:30 3.50 DRILL P PROD1 Cut & Slip 110' of drilling line. Inspect under drawworks. Service rig. Lubricate top drive. 08:30 - 10:45 2.25 DRILL P PROD1 Wash down from 3,745'. Begin drilling cement at 3,917'. Drill cement, landing collar, and shoe track to 4,017'. Tag collar on depth at 3,936' md. 550 gpm, 2600 psi. 60 rpm, 6k tq. on 5k tq off. 3k WOB. PU - 125k, SO - 80k, RTW - 95k. Shoe track drilled fast and cement returns at surface resembled drilling cement not completely set up. Printed: 1/24/2008 2:46:45 PM • ! g P Page 8 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABORS 9ES Rig Number: Date 'From - To Hours Task ,Code NPT Phase Description of Operations 1/5/2008 10:45 - 11:30 0.75 DRILL P PROD1 Begin displacement to new 8.8 ppg LSND mud while drilling last few feet of shoe track. 11:30 - 12:30 1.00 DRILL P PROD1 Shut down and clean shaker system, possum belly and troughs of cement contaminated mud. 12:30 - 13:30 1.00 DRILL P PROD1 Drill 20' of new hole to 4,051' md. 13:30 - 15:30 2.00 DRILL P PROD1 Perform leak off test to 525 si EMW of 11.85 .Take benchmark ECD readings. Calculated & actual clean hole ECD at 100 rpm = 9.47 ppg correction factor was -0.29 ppg. 15:30 - 00:00 8.50 DRILL P PROD1 Directional drill 8-3/4" hole from 4,051' - 5,790'. 585 gpm, 2450 psi on, 2250 psi off. 100 rpm, 7k tq on, 6k tq off. PU - 130k, SO - 87k. RTW - 105k. 20-30k WOB. CECD - 9.47ppg, AECD - 10.12ppg. AST - .98, ART - 3.82 30 bbl Hi-Vis Sweep C~ 5,100' brought 30% increase in cuttings, 30 bbl Hi-Vis Sweep C~3 5,700' brought 10% increase in cuttings. 1/6/2008 00:00 - 06:00 6.00 DRILL P PROD1 Directional drill 8-3/4" hole from 5,790' - 6,230'. 585 gpm, 2430 psi on, 2340 psi off. 100 rpm, 7-9k tq on, 4-6k tq off. PU - 135k, SO - 95k. RTW - 105k. 20-30k WOB. CECD - 9.65 ppg, AECD - 9.82ppg. 06:00 - 11:30 5.50 DRILL P PROD1 Directional drill 8-3/4" hole from 6,230' - 7,032'. 585 gpm, 3250 psi on, 2950 psi off. 100 rpm, 7k tq on, 6k tq off. PU - 135k, SO - 115k. RTW - 115k. 20-30k WOB. CECD - 9.78 ppg, AECD - 10.30 ppg. 11:30 - 13:00 1.50 DRILL P PROD1 Circulate bottoms up. 585 gpm, 2920 psi, 100 rpm, 6k tq. PU - 135k, SO - 115k. RTW - 115k. 13:00 - 13:30 0.50 DRILL P PROD1 Directional drill 8-3/4" hole from 7,032' - TD C~ 7,052' MD. 585 gpm, 3100 psi on, 2885 psi off. 95 rpm, 9k tq on, 7k tq off. PU - 145k, SO - 120k. RTW - 120k. 10k WOB. CECD - 9.68 ppg, AECD - 10.10 ppg. AST - 2.78, ART - 3.63 13:30 - 14:00 0.50 DRILL P PRODi Circulate one open hole volume. 585 gpm, 2925 psi, 90 rpm, 7k tq. PU - 140k, SO - 120k. RTW - 115k. 14:00 - 17:45 3.75 DRILL P PROD1 Backream Ghost reamer into casing shoe and bit to 5,453' and (above ghost reamer depth ~ TD). 585 gpm, 80 rpm, 2800 psi, 7k TO. 17:45 - 18:15 0.50 DRILL P PROD1 Circulate bottoms up while backreaming last stand slowly. 585 gpm, 80 rpm, 2693 psi. PU - 130k, SO - 95k. 18:15 - 22:00 3.75 DRILL P PROD1 Monitor well - OK. MW in 9.1 ppg, MW out 9.1 ppg. POH from 5,433' to top of BHA C~ 254'. No overpulls or swabbing seen while POOH. Pump dry job ~ 4,963'. 22:00 - 00:00 2.00 DRILL P PROD1 PJSM. Lay down BHA #3 from 254' to 100' 1/7/2008 00:00 - 02:00 2.00 DRILL P PROD1 Continue to lay down BHA #3 from 100'. Bit grade: 1-3-WT-A-X-2-NO-TD. 02:00 - 03:00 1.00 DRILL P PROD1 Clean and clear rig floor of all BHA handling equipment. Printed: 1/24/2008 2:46:45 PM • g P Page 9 of 15 i Operations Summary Report Legal Well Name: W-216 Common W ell Name: W-216 Spud Date: 12/27/2007 Event Nam e: DRILL+C OMPLE TE Start : 12/25/2007 End: 1/16/2008 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 1/16/2008 Rig Name: NABOR S 9ES Rig Number: Date ' From - To Hours Task ~! Code NPT Phase ' Description of Operations ' 1/7/2008 03:00 - 04:30 1.50 BOPSU P RUNPRD Pull wear bushing and install BOPE test plug. 04:30 - 06:00 1.50 BOPSU P RUNPRD Change out upper pipe rams from 3.5" x 6" VBRs to 7". 06:00 - 08:00 2.00 BOPSU P RUNPRD Ri u and test 7" rams to 4 000 si - OK. Rig down test equipment. Test witnessed by NAD TP Ronnie Dalton. 08:00 - 13:00 5.00 CASE P RUNPRD Make dummy run with 7" hanger and landing joint. Rig up to run casing. 13:00 - 16:30 3.50 CASE P RUNPRD PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole C~ 1.5 minutes perjoint with 7" 26# L-80 BTC-M casing to 1,524'. 36 jts of BTC-M, 1 marker jt. w/ 2-pip RA tag, and 1 crossover joint. Make up casing to mark with average make-up torque of 9,800 ft/Ibs. Used BOL-2000 M pipe lubricant. Fill each joint and break circulation every 20 joints for 5 minutes. PU - 69k, SO - 65k ~ 1,524' 16:30 - 18:30 2.00 CASE P RUNPRD Rig up Torque turn equipment for TCII casing. Continue running in hole C~ 1.5 minutes per joint with 7" 26# L-80 TC-II casing from 1,524' to 2,154'. Fill each joint and break circulation every 20 joints for 5 minutes. Torque Turn casing to make-up torque of 10,100 fUlbs. Used JetLube Seal Guard pipe lubricant. 15 joints of TC-II casing run so far. PU - 80k, SO - 71 k C~? 2,154'. 18:30 - 19:30 1.00 CASE P RUNPRD Change out torn Franks tool cup. 19:30 - 23:00 3.50 CASE P RUNPRD Rig up Torque turn equipment for TCII casing. Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 TC-II casing from 2,154' to 4,012'. Fill each joint and break circulation every 20 joints for 5 minutes. Torque Turn casing to make-up torque of 10,100 Wlbs. Used JetLube Seal Guard pipe lubricant. 60 joints of TC-II casing run so far. 23:00 - 00:00 1.00 CASE P RUNPRD CBU x 1.5 w/ Franks tool - 210 gpm, Initial Circulating Pressure = 530 psi, Final Circulating Pressure = 430 psi. No losses to well so far. 1/8/2008 00:00 - 07:00 7.00 CASE P RUNPRD Continue running in hole ~ 2 minutes perjoint with 7" 26# L-80 TC-II casing from 4,012' to 7,012'. Fill each joint and break circulation every 10 joints for 3 minutes. Torque Turn casing to make-up torque of 10,100 fVlbs. Used JetLube Seal Guard pipe lubricant. 134 joints of TC-II casing run. 07:00 - 07:30 0.50 CASE P RUNPRD Pick up 7" hanger, landing joint and land casing on depth @ 7,037', Up wt 195k Dn Wt 110k. No problems at all running in hole. HES Float Shoe -Bottom C~ 7,037' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Landing Collar - Top ~ 6,952' 11 Jts 7", 26#, L-80 BTC-Mod (#3-13) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ 2 pip RA tag ~ 6,487' 24 Jts 7", 26#, L-80 BTC-Mod (#13-36) 7", 26#,L-80 TC-II X BTC-Mod Crossover Pup. 7", 26#, L-80 TC-II Marker Pup 134 Jts 7", 26#, TC-II (#1-134) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Printed: 1/24/2008 2:46:45 PM gp Page 10 of 15 Operations Summary Report 'Legal Well Name: W-216 Common W ell Name: W-216 Spud Date: 12/27/2007 Event Nam e: DRILL+C OMPLE TE Start : 12/25/2007 End: 1/16/2008 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 1/16/2008 Rig Name: NABOB S 9ES Rig Number: Date From - To it Hours Task Code NPT Phase Description of Operations 1/8/2008 07:00 - 07:30 0.50 CASE P RUNPRD Total of 99 - 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers and 49 stop collars: 2 centralizers on shoe joint w/ stop ring 5' from shoe. BTC-M jts 2-36, XO jt, & TC-I I jts 1-12 have 2 free floating per joint separated by stop ring in middle. 20' BTC-M marker jt has one free floating. 07:30 - 08:00 0.50 CASE P RUNPRD Rig down Frank's tool. Make up cementing head. 08:00 - 10:30 2.50 CEMT P RUNPRD Break circulation. Stage pumps up to 5 bpm, 625 psi. Condition mud for cementing. Held cementing PJSM while circulating. Reciprocate casing_ PU - 195k, SO - 110k. 10:30 - 11:30 1.00 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,500 psi - OK. Pump 41 bbls 11.0 ppg of MudPush II viscosified spacer ~ 5 bpm, 550 psi. Batch mix and pump 75 bbls of Class "G" 15.8 ppg cement ~ 5 bpm avg, 550 - 250 psi. Drop plug and wash up through 'T' w/ 10 bbls H2O. Swap to rig pumps. Reciprocate pipe in 15' strokes. 11:30 - 13:30 2.00 CEMT P RUNPRD Switch to rig and displace cement with 266 bbls of seawater. 1st 200 bbls ~ 5 bpm, 167 psi ICP, 430 psi FCP. Reduce rate to 3 bpm @ 200 bbls away - 458 psi ICP, 945 psi FCP. Reduce rate to 1 bpm (~? 234 bbls away - 840 psi ICP, 1328 psi FCP. Bumped plug at 4,711 strokes. Stopped reciprocating and landed casing C~ plug bump. PU - 146k, SO - 78k. CIP Q 12:55 hr. Pressure test to 4,000 psi - OK. Bleed off pressure, check for flowback - OK. Full returns during all of circulating, cementing, and displacement. 13:30 - 16:30 3.00 CEMT P RUNPRD Lay down all casing and cementing equipment. 16:30 - 17:30 1.00 WHSUR 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. 17:30 - 18:00 0.50 CEMT P RUNPRD Conduct LOT down 9-5/8" x 7" annulus to 15.3 ppg. Leak off pressure at 1050 psi. *Note: Outside of critical path, inject 2 bbls used LSND mud into OA ~ 1900 hrs. No increase in leak off pressure. 18:00 - 00:00 6.00 BOPSU P RUNPRD Change Upper Pipe Rams to 3 1/2 x 6 variables & prepare to test w/ 3.5" and 4" test joints to 4,000 psi. *Note: Sim Ops - OA injection and freeze protection: Inject 105 bbls 9 2 ppg LSND mud total 3 C~ bom to flush annulus After UCA indicates 500+ comoresive strength. RU Little Red & pump 68 bbls 90 deg dead crude C~ 1.5 bpm, 1000 ICP, 1240 FCP. 1/9/2008 00:00 - 01:00 1.00 BOPSU P RUNPRD Test upper pipe rams w/ 3.5" and 4" test joints to 4,000 psi & , annular oreventer w/ 3.5" test joint only. 01:00 - 02:30 1.50 PERFO P OTHCMP RU equipment for DPC perforating. 02:30 - 05:00 2.50 PERFO P OTHCMP PJSM. Pick up and make up 4.5" HSD Power Jet 4505 5 SPF DPC perforating guns (9 ea loaded or partial guns, 3 ea blanks, including 1 ea blank punchers), Firing head, XO, bumper sub, MWD, XO, 1-stand 4" HWDP, 5 ft pup joint, 1-stand 4" HWDP. Shallow test Slimpulse MWD - OK. 05:00 - 09:00 4.00 PERFO P OTHCMP Run in hole with DPC pert assembly & tag up on float collar at 6,944'. *Note all depths reported are to bottom nose. G/R sensor is 292 ft up from bottom nose. 09:00 - 10:00 1.00 PERFO P OTHCMP Displace well over from 8.5 ppg seawater to 9.0 ppg brine. 5 Printed: 1/24/2008 2:46:45 PM gp Page 11 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To ~', Hours ',I Task Code ICI NPT ; Phase Description of Operations 1/9/2008 09:00 - 10:00 1.00 PERFO P OTHCMP bpm, 420 psi. 10:00 - 14:00 4.00 PERFO N DFAL OTHCMP Troubleshoot MWD tool malfunction. Tool appeared to reset anytime pipe was moved. Good communication with tool when stationary, but signal lost each time pipe movement started. Varied flowrates, adjusted pulsation dampener pressure, and switched pumps in attempt to remedy but no success. 14:00 - 18:00 4.00 PERFO N DFAL OTHCMP POH with uns from 6,820' to Slimpulse MWD tool. 18:00 - 19:00 1.00 PERFO N DFAL OTHCMP At surface w/ Slimpulse MWD. Remove Slimpulse and lay down. Change out for 4-3/4" Impulse MWD tool. 19:00 - 20:00 1.00 PERFO N DFAL OTHCMP RIH w/ Perforating guns and Impulse MWD to 1,149' md. Shallow hole test MWD - 220 gpm, 325 psi - OK. Continue RIH to 2,009'. 20:00 - 21:00 1.00 PERFO N DFAL OTHCMP Iron roughneck failure. Inspect & replace hydraulic fitting. 21:00 - 00:00 3.00 PERFO N DFAL OTHCMP Continue RIH with perforating guns on drillipipe from derrrick from 2,009' to 6,643' md. PU - 150k, SO - 95k. 1/10/2008 00:00 - 00:30 0.50 PERFO N DFAL OTHCMP RIH from 6,643' until tag up on landing collar at 6,944' md. 00:30 - 01:00 0.50 PERFO P OTHCMP Confirm tag and pull up hole to bottom nose depth of 6,860' to begin correlation pass. 01:00 - 01:45 0.75 PERFO P OTHCMP Log to correlate depth to reference log -MWD Realtime field print 6-Jan-2008. 215 gpm, 640 psi. GR log found exactly on depth. No depth correction needed. Log into position & set on depth w/ Top shot ~ 6,506', Bottom nose @ 6,747;. DPM 01:45 - 02:30 0.75 PERFO P OTHCMP PJSM with all hand prior to firing guns. Perforate well. Initiate firing sequence by pump and bleed. Wait 5 minutes for guns to fire. Good indication of puns firing`_W_ ell initially lost 3 bbls then went on a 1-2 bph loss rate. Perforation intervals: OBa - 6506 - 6544' OBc - 6616 - 6652' OBd - 6696 - 6746' 'Pert depths as per Realtime LWD log 02:30 - 03:30 1.00 PERFO P OTHCMP POH from 6,746' to 6,453' (above top pert) and circulate surface to surface 250 gpm, 795 psi. Brine returns smelled of perforations, but no other debris on bottoms up. Shut down, monitor well -losses very slow. Less than 2 bph. Blow down top drive. 03:30 - 06:30 3.00 PERFO P OTHCMP Slip and Cut 53' of drilling line. 06:30 - 12:00 5.50 PERFO P OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 6,453' - 1,054' md. 12:00 - 13:00. 1.00 PERFO P OTHCMP POH Laying down HWDP to pipeshed 1x1 from 1,054' - 315' md. 13:00 - 16:00 3.00 PERFO P OTHCMP PJSM. Lay down all guns, crossovers & firing head. All shots fired er desi n. No shots seen outside of scallop. No trapped pressure in any guns. 16:00 - 17:15 1.25 PERFO P OTHCMP Clean and clear rig floor of perforating equipment. 17:15 - 18:30 1.25 PERFO P OTHCMP RIH with remaining stands of drillpipe from derrick and lay down to pipeshed 1 xi . 18:30 - 20:00 1.50 EVAL P OTHCMP PJSM. Rig up Schlumberger E-Line unit and 6.12" OD Gauge rin /Junk basket tools. 20:00 - 21:00 1.00 EVAL P OTHCMP RIH on E-Line to perforations. 21:00 - 22:30 1.50 EVAL P OTHCMP Tool hanging up at -6,515' (10 feet into top perforations) work tool down and able to fall past after several tries. Continue in hole and find another tight spot at 6,627'. Work tool past after Printed: 1/24/2008 2:46:45 PM ~ ~ BP Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To 'Hours Task Code NPT Start: 12/25/2007 Rig Release: 1/16/2008 Rig Number: Phase 1/10/2008 21:00 - 22:30 1.50 EVAL P OTHCMP 22:30 - 00:00 1.50 EVAL P OTHCMP 1/11/2008 00:00 - 02:30 2.50 EVAL P OTHCMP 02:30 - 05:30 3.00 EVAL P OTHCMP 05:30 - 06:30 1.00 EVAL P OTHCMP 06:30 - 13:00 6.50 EVAL P OTHCMP 13:00 - 14:00 1.00 EVAL P OTHCMP 14:00 - 14:30 0.50 BUNCO RUNCMP 14:30 - 18:30 4.00 BUNCO RUNCMP 18:30 - 00:00 5.50 BUNCO RUNCMP 1/12/2008 00:00 - 01:00 1.00 BUNCO RUNCMP 01:00 - 02:00 1.00 BUNCO DFAL RUNCMP 02:00 - 03:30 1.50 BUNCO DFAL RUNCMP 03:30 - 06:00 2.50 BUNCO DFAL RUNCMP 06:00 - 07:30 1.50 BUNCO DFAL RUNCMP 07:30 - 08:30 1.00 BUNCO RUNCMP 08:30 - 11:30 3.00 BUNCO MISC RUNCMP 11:30 - 00:00 12.50 BUNCO RUNCMP 1/13/2008 00:00 - 01:30 1.50 BUNCO RUNCMP Page 12 of 15 Spud Date: 12/27/2007 End: 1 /16/2008 Description of Operations several tries, and tag up at 6,724' md. Work tool for -45 minutes and tag still at 6,724'. Pulling as high as 1,500 Ibs overpulls to free from tag. Stopped trying to work tool deeper, and pull up and wipe areas ~ 6,627' and 6,515' until passing through easily. POH on E-line to surface. Empty junk basket - no debris from. hole in basket. Change out gauge ring to 5.74" OD ring. RIH on E-Line w/ 5.74" OD gauge ring without any problems to top of landing collars at 6,944' md. POH to surface. Empty junk basket at surface and recover 1-2 gallons of ccra Pr .d , cement sheath and pert debris. , Change out gauge ring back to 6.12" OD gauge ring. Run back in hole to 6,685' md. No problems running in hole. Did not tag TD. No debris in junk basket. Rig down gauge ring tools. Rig up USIT. Run in hole with USIT logging tools to 6,820'. Log Hi-Res pass from 6,900' and to 6,400' md. Log standard resolution pass from 6,900' to surface for primary depth control..Logs indicated, top of channeled cement stringers C~3 -3,980', with unchanneled cement top C~3 -4,310'. (Note: 9-5/8" casing shoe ept ,0 0 Rig down Schlumberger E-Line unit. Pull wear bushing. Make dummy run w/ tubing hanger. Rig up tubing running and I-wire equipment. PJSM. Run in hole with completion jewelry to 338'. Baker Lok'd all 5 connections below bottom packer. Test line connections to 5,000 psi - OK. Test I-wire continuity - OK. PJSM. Run in hole with completion jewelry to 530'. Troubleshoot what appears to be a failed gauge. Output from sensor that reads pressure below bottom packer seems to be reading double what other 3 gauges are reading. Run in hole 2 joints while monitoring gauges closely to help identify problem. POH to pressure gauge to troubleshoot and change out gauge. Change out pressure gauge and test. Continue running completion jewelry & tubing joints to 530' where problem was initially discovered. Gauge still okay. Run in hole to joint number 14 of 3.5" tubing. Depth is 818' md. Noticed smell of smoke on rig. Investigate & discover pickup truck fire on pad. Notify emergency response (2222) and respond with fire extinguishers. Replace any used fire extinguishers on rig and wait on crew memebers to return from preventative checkup at medic before proceeding. PJSM. Continue running in hole with 3.5" 9.2# L-80 TCII 3 packer completion from 818' and to planned depth setting depth of 6,791'. Space out with extra joint in preparation for E-Line correlation log and set in slips. Check I-wire continuity every 1,000'. Made up TCII connections to 2,300 ft/Ibs torque. Used Jet Lube Seal Guard pipe dope. PU - 90k, SO - 65k. Once completion in position on extra joint, cut I-Wires and leave extra slack for spaceout if needed. Rig down I-Wire spools and sheaves prior to rigging up E-line to allow Schlumberger to mobilize spools to Nabors 7ES as soon as Printed: 1/24/2008 2:46:45 PM • gp Page 13 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date li From - To Hours Task Code ~I NPT Phase Description of Operations : 1/13/2008 00:00 - 01:30 1.50 - BUNCO _ __ RUNCMP - possible. 01:30 - 03:00 1.50 BUNCO RUNCMP Rig up Schlumberger E-Line w/ pack-off and pump-in sub for pressure control. Make up GR/CCL/Press/Temp tool. 03:00 - 05:00 2.00 BUNCO RUNCMP Run in hole with GR/CCL tool to 6,735'. Log up and correlate RA tags and packers. 9.83' foot down adjustment needed. with logging tools recording well temperature. 05:00 - 06:00 1.00 BUNCO RUNCMP Rig Down Schlumberger E-Line. 06:00 - 07:00 1.00 BUNCO RUNCMP S ace out tubin .Lay down spare joint, and joint 202. Make up 9.83' pup above 3.82' pup already installed. Make up joint 202. 07:00 - 08:30 1.50 BUNCO RUNCMP Make up tubing hanger and landing joint. Terminate I-wire and test connections to 5,000 psi - OK. Test I-wire continuity - OK. Land tubing. Item: - 5" TC-tl set ~ 6 2 #WLEG 800' Bottom of 3 5" 9 3 ~ , . . . , . Tops: 3.5" 9.2 #WLEG, 3.5" TC-II ~ 6,799'. 3.5" HES 'XN' Nipple: ID 2.750 ~ 6,778'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug C~3 6,757'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,728'. 3.5" HES 'X' Nipple: 2.813" ID ~ 6,708'. -~ 3.5" x 7" HES single feedthru Packer #1 packer @ 6,684'. GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,655'. GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch C~3 6,617'. Phoenix Sensor sub ~ 6,605'. ---1~ 3.5" x 7" HES Dual feedthru Packer #2 packer ~ 6,591'. 3.5" HES 'X' Nipple: 2.813" ID ~ 6,570'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,542. 1 joint tubing. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,480'. Phoenix Sensor sub ~ 6,468'. °-~---~ 3.5" x 7" HES Dual feedthru Packer #3 packer Cud 6,455'. 3.5" 9.2# L-80 TC-II Pup (Centralizer w/PIP tag anchored on pup (~ 6,436' just below nipple). 3.5" HES 'X' Nipple: 2.813" ID ~ 6,434'. 2 jts 3.5" 9.2# L-80 TC-II Tubing (#2 - 3) ~ 6,362'. GLM #6 - 3.5" x 1.5" MMG w/ DCR-1 Shear- RKP latch - 6,344'. 111 jts 3.5" 9.2# L-80 TC-I I Tubing (#4 - 114) C~3 2,819'. 3.5" HES 'X' Nipple: 2.813" ID ~ 2,809'. 81 jts 3.5" 9.2# L-80 TC-II Tubing (# 115 - 201) C~ 88' 2 ea 3.5", 9.2#, L-80 TC-II Space out Pups (9.83' & 3.82') 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 202 ) 3.5" 9.2# L-80 TC-II Hanger Pup 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads Up wt = 90k, Dn wt = 67k Printed: 1/24/2008 2:46:45 PM g p Page 14 of 15 Operations Summary Report (Legal Well Name: W-216 ;Common Well Name: W-216 Spud Date: 12/27/2007 'Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours ' Task 1 /13/2008 1 /14/2008 07:00 - 08:30 08:30 - 09:00 09:00 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 22:30 22:30 - 00:00 Code NPT Phase Description of Operations i I --- - - 1.50 BUNCO RUNCMP 116 full Cannon clamps, 14 Half clamps 0.50 BUNCO RUNCMP Drop rod and ball. Laydown landing joint. 2.50 BUNCO RUNCMP PJ M. Rig up circulating lines. Pressure up on tubing, set packers and test to 4,000 psi - 30 min -Good test. Bleed off tubing pressure to 2,600 psi. Pressure up inner annulus and test to 4 000 si - 30 min -Good test! Test witnessed by Lou Grimaldi, AOGCC representative. (tubing pressure f~ 3,100 psi during IA test). Bleed off annulus pressure to 0 psi, bleed off tubing pressure to 0 psi. Pressure up oh annulus to shear DCR valve. Sheared at 2,750 psi. Establish circulation briefly both ways - OK. 0.50 WHSUR P RUNCMP Dry rod 2 way check valve. Test valve from below to 1,000 psi 1.00 WHSUR P 3.50 BOPSU P 1.50 WHSUR P 1.00 WHSUR P 3.00 WHSUR P 0.50 WHSUR P 1.50 WHSUR P 00:00 - 00:30 0.50 WHSUR P 00:30 - 00:00 23.50 WHSUR N 1/15/2008 100:00 - 19:00 I 19.001 WHSUR I N 19:00 - 22:30 I 3.50 I W HSUR I N 22:30 - 00:00 1.50 WHSUR N 1/16/2008 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:30 i.50 WHSUR P 02:30 - 05:30 3.00 WHSUR P 05:30 - 07:30 2.00 WHSUR P - vr.. RUNCMP Drain BOP stack, blowdown lines and prepare to nipple down BOPE. RUNCMP PJSM. Nipple down BOPE. RUNCMP PJSM. Nipple up tree adaptor. Test same to 5,000 psi - OK. RUNCMP Terminate I-wires on tree adaptor. Test connections to 5,000 psi - OK. Test I-wire continuity - OK. RUNCMP Nipple up tree with hydraulic actuator valve. RUNCMP PJSM. Rig up and test tree to 250 psi low, 5,000 psi high - OK. RUNCMP PJSM. Rig up DSM lubricator. Test same to 500 psi - OK. Pull 2-way check valve. RUNCMP Lay down DSM lubricator. WAIT RUNCMP Perform misc. tasks while waiting on temperature to warm up above -40 degF (currently -45). Unable to arrange pump truck until -40. Once freeze protect complete, unable to lower derrick until -35. Once derrick down, Z-112 pad is not prepped until heavy equipment prepares pad (no heavy equipment operations until above -35 degF). Pump 213 bbls old brine around surface to surface to warm well every 3 hours @ 167 gpm, 590 psi. Lowest temperature seen while E-Line in hole was 33 degF @ 1,500' md. Freezing point of 9.0 ppg brine = -6 degF. WAIT RUNCMP Perform misc. tasks while waiting on temperature to warm up above -40 deg F. Unable to arrange pump truck until -40. At 19:00 hr, temperature C~? -34 on W-pad, still -40 on DS-15 where LRHOS equipment is staged. WAIT RUNCMP Continue waiting on temperature to warm upon DS-15. LRHOS got OK from the Wells Group to mobilize C~ 10:30 hr. -28 deg F on W-pad. Call for Vac trucks. WAIT RUNCMP Wait on LRHOS and Vac trucks. RUNCMP PJSM and rig up LRHOS. RUNCMP Reverse circulate 120 bbls of clean 9.0 brine through shear valve, followed by 93 bbls of 9.0 ppg inhibited brine ~ 3 bpm, 340 psi. RUNCMP Switch over to LRHOS. Pressure test lines to 2,500 psi - OK. Freeze rotect IA and tubin .Reverse circulate 100 bbls of 80 . deg F diesel C~3 1.5 bpm, 100 psi ICP, 400 psi FCP. U-tube diesel back to tubing. Freeze protected well to 2,843' MD, 2,512' TVD. RUNCMP Rig up DSM lubricator and test same to 1,000 psi - OK. Set Printed: 1/24/2008 2:46:45 PM gp Page 15 of 15 Operations Summary Report Legal Well Name: W-216 Common Well Name: W-216 Spud Date: 12/27/2007 Event Name: DRILL+COMPLETE Start: 12/25/2007 End: 1/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/16/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To I Hours I Task I Code I NPT ~ Phase ~ Description of Operations 1/16/2008 05:30 - 07:30 2.00 WHSUR P RUNCMP BPV and test from below to 1,000 psi - OK. 07:30 - 09:00 1.50 WHSUR P RUNCMP nstall VR plugs in IA & OA. Rig down lubricator. 09:00 - 16:00 7.00 WHSUR P RUNCMP Secure tree and cellar. Clean out cellar and mud pits. 'Rig released from W-216i operations @ 16:00 hr, 1/16/2008 for rig move to Z-112. Printed: 1/24/2008 2:46:45 PM by ~~ ....,_ ~ ~ ~ Schlumherger ~ vv-~ i o au Client: BP Expkxation Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: W-PAD / W-216 Plan Well: W-216 Borehole: W-216 UWUAPI#: 50029233790( Survey Name I Date: W-216 /January 6, 200f Tort 1 AHD 1 DDI 1 ERD ratio: 112.795° / 4118.39 ft / 5.783 / 0.76: Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Location LaflLong: N 7017 57.620, W 149 5 33.11; Location Grid NIE YIX: N 5959880.870 ftUS, E 612048.880 ftU: Grid Convergence Angle: 10.85435944° r~epvrt Vertical Section Azimuth: 20.770° Vertical Section Origin: N 0.000 ft, E 0.000 fl ND Reference Datum: Rotary Table ND Reference Elevation: 81.90 ft relative to MSL Sea Bed I Ground Level Elevation: 53.40 $ relative to MSL Magnetic Declination: 23.242° Total Fieid Strength: 57646.532 nT Magnetic Dip: 80.871 ° Declination Date: January 03, 200E Magnetic Declination Model: BGGM 2007 North Reference: TNe NOrth Total Corr Mag North •> TNe North: +23.242° Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longhude Depth Section Departure ft d d k K ft k k k k d H00 ft ftUS ftUS Rlt U.W U.W U.UU -tsl.tlU U.W U.VU V.VV V.VV U.VV V.uu V.uu asr~~oov.or oicuYO.oo r~ rv it ar.ocv rr WD.7 JJ.I IJ GYO CT DMS 100.00 0.33 88.70 18.10 100.00 0.11 0.29 0.29 0.01 0.29 0.33 5959880.88 612049.17 N 7017 57.620 W 149 5 33.105 179.00 0.45 129.54 97.10 179.00 0.09 0.80 0.78 -0.19 0.75 0.37 5959880.70 612049.64 N 7017 57.618 W t49 5 33.092 271.00 1.17 80.65 189.09 270.99 0.45 2.04 1.98 -0.26 1.96 1.02 5959880.64 612050.84 N 7017 57.617 W 149 5 33.056 363.00 1.70 49.08 281.06 362.96 2.12 4.29 4.00 0.78 3.92 1.01 5959881.71 612052.79 N 7017 57.628 W 149 5 32.999 456.00 3.49 36.03 373.96 455.86 6.07 8.48 7.73 3.98 6.63 2.01 5959884.94 612055.45 N 70 17 57.659 W 149 5 32.920 548.00 5.06 32.27 465.70 547.60 12.75 15.34 14.23 9.67 10.44 1.73 5959890.70 612059.17 N 7017 57.715 W 149 5 32.809 572.00 5.15 31.39 489.61 571.51 14.84 17.47 16.30 11.49 11.57 0.50 5959892.53 612060.27 N 70 17 57.733 W 149 5 32.776 640.00 6.74 28.86 557.24 639.14 21.79 24.51 23.17 17.59 15.08 2.37 5959898.68 612063.70 N 70 17 57.793 W 149 5 32.674 MWD+IFR+MS 664.20 7.21 27.90 581.26 663.16 24.70 27.45 26.05 20.17 16.48 2.00 5959901.28 612065.05 N 7017 57.818 W 149 5 32.633 758.16 8.04 25.32 674.39 756.29 37.11 39.92 38.30 31.32 22.05 0.96 5959912.52 612070.46 N 7017 57.928 W 149 5 32.471 852.76 9.88 26.69 767.83 849.73 51.77 54.65 52.90 44.56. 28.52 1.96 5959925.84 612076.73 N 70 17 58.058 W 149 5 32. 945.91 11.95 25.97 859.29 941.19 69.33 72.29 70.46 60.37 36.34 2.23 5959941.77 612084.31 N 70 17 58.214 ~ W 149 5 32. 1040.11 13.47 22.59 951.18 1033.08 90.01 93.01 91.06 79.27 44.82 1.80 5959960.79 612092.51 N 70 1758.400 W 149 5 31. 1133.53 14.68 19.82 1041.80 1123.70 112.72 115.72 113.58 100.45 53.01 1.48 5959982.09 612100.39 N 7017 58.608 W 149 5 31.568 1225.53 16.65 20.99 1130.38 1212.28 137.56 140.56 138.25 123.72 61.69 2.17 5960005.49 612108.71 N 7017 58.837 W 149 5 31.315 1256.72 16.74 21.89 1160.25 1242.15 146.52 149.52 147.18 132.06 64.96 0.88 5960013.88 612111.86 N 7017 58.919 W 149 5 31.220 1316.63 17.39 20.99 1217.52 1299.42 164.10 167.10 164.70 148.43 71.39 1.17 5960030.33 612118.04 N 70 17 59.080 W 149 5 31.032 1411.96 21.39 25.69 1307.43 1389.33 195.68 198.73 196.30 177.41 84.03 4.50 5960059.50 612130.25 N 70 17 59.365 W 149 530.664 1507.44 23.58 26.06 1395.65 1477.55 232.05 235.24 232.82 210.26 99.97 2.30 5960092.58 612145.70 N 7017 59.688 W 149 530.199 1603.44 25.12 26.63 1483.11 1565.01 271.44 274.82 272.39 245.72 117.54 1.62 5960128.30 612162.74 N 7018 0.037 W 149 5 29.687 1700.04 26.76 28.16 1569.97 1651.87 313.40 317.07 314.62 283.23 137.00 1.83 5960166.09 612181.63 N 70 18 0.406 W 149 5 29.120 1785.47 29.15 28.69 1654.26 1736.16 357.74 361.81 359.31 322.56 158.30 2.52 5960205.73 612202.34 N 70 18 0.792 W 149 5 28.499 1889.91 31.40 27.68 1735.82 1817.72 404.95 409.41 406.89 364.53 180.77 2.44 5960248.03 612224.18 N 70 181.205 W 149 5 27.843 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-216 PIan1W-216\W-216\W-216 Generated 2/13/2008 11:15 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting Latftude Longitude Depth Section Departure ft d d ft ft ft ft k ft ft d 100 ft ftUS ftUS 1`JC3.4tS 3D.Sb Ltl.ZC 1tS73.L~4 laaa.a4 4~U. T1 4tlU.t58 40b.3U 47U.41 LU4.U`J 4.JU Yy000:1'i.L4 UIGG9U.01 Ir lV 10 t.oJV vv 19.7J Gl. l[Yf 2080.59 36.56 26.89 1892.55 1974.45 512.83 517.89 515.37 461.40 229.61 1.30 5960345.60 612271.56 N 70 18 2.158 W 149 5 26.420 2175.39 39.89 26.45 1967.01 2048.91 571.17 576.54 574.02 513.81 255.93 3.52 5960398.39 612297.09 N 70 18 2.673 W 149 5 25.652 2269.04 41.77 27.62 2037.87 2119.77 632.03 637.77 635.24 568.34 283.77 2.17 5960453.33 612324.12 N 70 f 8 3.209 W 149 5 24.841 2367.63 44.06 27.72 2110.07 2191.97 698.67 704.89 702.36 627.79 314.94 2.32 5960513.23 612354.40 N 7018 3.794 W 149 5 23.932 2464.97 46.65 26.90 2178.47 2260.37 767.47 774.14 771.60 689.32 346.70 2.73 5960575.22 612385.23 N 7018 4.399 W 149 5 23.006 2558.10 49.11 26.32 2240.92 2322.82 836.18 843.22 840.67 751.08 377.63 2.68 5960637.43 612415.24 N 7018 5.007 W 149 5 22.104 2653.79 48.53 25.99 2303.93 2385.83 907.89 915.24 912.69 815.73 409.38 0.66 5960702.54 612446.02 N 70 18 5.642 W 149 5 21.178 2748.04 47.82 25.51 2366.78 2448.68 977.85 985.47 982.91 878.98 439.89 0.84 5960766.24 612475.58 N 70 18 6.265 W 149 5 20.288 2843.43 47.41 25.28 2431.08 2512.98 1048.08 1055.93 1053.36 942.63 470.11 0.47 5960830.32 612504.84 N 70 18 6.891 W 149 5 19.407 2939.14 47.15 25.21 2496.01 2577.91 1118.18 1126.24 1123.66 1006.23 500.10 0.28 5960894.36 612533.88 N 70 18 7.516 W 149 518.533 3031.04 46.54 25.25 2558.87 2640.77 1185.02 1193.28 1190.68 1066.88 528.68 0.66 5960955.42 612561.54 N 70 18 8.112 W 149 517. 3123.39 48.28 27.31 2621.37 2703.27 1252.69 1261.27 1258.66 1127.83 558.78 2.50 5961016.80 612590.74 N 7018 8.712 W 149 516.8 3216.20 47.76 27.64 2683.45 2765.35 1321.21 1330.26 1327.64 1189.04 590.62 0.62 5961078.48 612621.65 N 7018 9.314 W 149 5 15.893 3306.92 47.25 27.19 2744.73 2826.63 1387.65 1397.15 1394.53 1248.41 621.42 0.67 5961138.30 612651.56 N 70 18 9.898 W 149 5 14.995 3399.67 46.91 26.79 2807.89 2889.79 1455.17 1465.07 1462.44 1308.94 652.25 0.48 5961199.27 612681.48 N 701810.493 W 149 5 14.096 3495.51 46.41 26.74 2873.67 2955.57 1524.49 1534.78 1532.15 1371.17 683.63 0.52 5961261.96 612711.94 N 70 1811.105 W 149 5 13.181 3591.09 48.03 27.31 2938.58 3020.48 1594.22 1604.93 1602.29 1433.66 715.51 1.75 5961324.91 612742.88 N 70 1811.720 W 149 5 12.251 3685.48 47.31 26.77 3002.15 3084.05 1663.59 1674.71 1672.07 1495.81 747.24 0.87 5961387.53 612773.67 N 701812.331 W 149 5 11.326 3780.36 46.87 26.51 3066.74 3148.64 1732.71 1744.20 1741.56 1557.93 778.40 0.51 5961450.09 612803.89 N 70 1812.942 W 149 510.417 3876.07 46.63 26.22 3132.32 3214.22 1802.09 1813.91 1811.27 1620.39 809.36 0.33 5961513.00 612833.92 N 701813.556 W 149 5 9.514 3967.62 48.07 27.85 3194.35 3276.25 1869.02 1881.24 1878.60 1680.35 839.97 2.05 5961573.41 612863.63 N 701814.146 W 149 5 8.621 4053.57 47.22 27.39 3252.26 3334.16 1932.08 1944.76 1942.11 1736.63 869.42 1.07 5961630.12 612892.23 N 70 1814.699 W 149 5 7.762 4153.82 46.40 27.54 3320.87 3402.77 2004.67 2017.85 2015.19 1801.48 903.13 0.83 5961695.46 612924.97 N 70 1815.337 W 149 5 6.779 4248.50 45.67 28.30 3386.60 3468.50 2072.29 2085.99 2083.32 1861.70 935.03 0.96 5961756.14 612955.97 N 70 1815.929 W 149 5 5.849 4344.25 45.94 26.86 3453.35 3535.25 2140.45 2154.64 2151.95 1922.55 966.81 1.11 5961817.45 612986.84 N 701816.527 W 149 5 4.922 4440.44 46.69 26.07 3519.78 3601.68 2209.67 2224.20 2221.51 1984.82 997.81 0.98 5961880.17 613016.90 N 70 1817.140 W 149 5 4.018 4535.68 45.48 26.50 3585.84 3667.74 2277.95 2292.81 2290.12 2046.33 1028.19 1.31 5961942.12 613046.35 N 70 1817.745 W 149 5 3.132 4630.51 46.70 25.97 3651.61 3733.51 2345.96 2361.12 2358.43 2107.61 1058.38 1.35 5962003.84 613075.63 N 70 1818.347 W 149 5 2.251 4723.64 46.78 25.79 3715.43 3797.33 2413.51 2428.95 2426.25 2168.63 1087.99 0.16 5962065.29 613104.32 N 701818.948 W 149 51.~ 4819.23 45.61 26.24 3781.60 3863.50 2482.21 2497.93 2495.23 2230.63 1118.24 1.27 5962127.73 613133.64 N 701819.557 W 149 5 0. 4913.34 47.66 27.22 3846.21 3928.11 2550.25 2566.34 2563.64 2291.72 1149.02 2.31 5962189.27 613163.51 N 70 18 20.158 W 149 4 59.607 5006.37 47.77 27.22 3908.81 3990.71 2618.64 2635.17 2632.46 2352.93 1180.50 0.12 5962250.93 613194.07 N 70 18 20.760 W 149 4 58.689 5100.49 46.62 27.97 3972.76 4054.66 2687.20 2704.22 2701.50 2414.12 1212.49 1.35 5962312.59 613225.13 N 7018 21.362 W 149 4 57.756 5194.80 45.77 28.26 4038.04 4119.94 2754.71 2772.28 2769.54 2474.16 1244.56 0.93 5962373.09 613256.30 N 7018 21.952 W 149 4 56.820 5287.61 46.83 28.87 4102.16 4184.06 2821.18 2839.38 2836.61 2533.09 1276.64 1.24 5962432.49 613287.50 N 70 f 8 22.532 W f 49 4 55.884 5382.57 49.13 28.62 4165.72 4247.62 2891.04 2909.92 2907.11 2594.94 1310.57 2.43 5962494.83 613320.50 N 7018 23.140 W 149 454.895 5476.85 48.67 28.33 4227.70 4309.60 2961.45 2980.97 2978.12 2657.39 1344.44 0.54 5962557.77 613353.43 N 7018 23.754 W 149 4 53.907 5572.74 49.10 26.71 4290.76 4372.66 3033.19 3053.21 3050.36 2721.45 1377.81 1.35 5962622.32 613385.85 N 7018 24.384 W 149 4 52.933 5667.45 50.22 26.01 4352.07 4433.97 3105.03 3125.40 3122.54 2786.14 1409.86 1.31 5962687.47 613416.92 N 70 18 25.020 W 149 4 51.998 5761.86 48.56 23.99 4413.52 4495.42 3176.50 3197.06 3194.17 2851.08 1440.16 2.39 5962752.85 613446.25 N 70 18 25.659 W 149 4 51.114 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-216 Plan\W-216\W-216\W-216 Generated 2/13/2008 11:15 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de ft ft ft ft ft ft k de 100 ft ftUS ftUS 5858.02 46.83 19.43 4478.26 4560.16 3247.57 3268.16 3264.98 2917.10 1466.49 3.94 5962819.25 5947.52 44.65 13.41 4540.75 4622.65 3311.42 3332.23 3328.02 2978.51 1484.65 5.40 5962880.92 6041.99 45.90 7.15 4607.26 4689.16 3377.35 3399.31 3392.44 3044.49 1496.58 4.89 5962947.07 6135.42 46.20 4.58 4672.11 4754.01 3442.34 3466.57 3455.59 3111.39 1503.45 2.01 5963014.06 6228.16 46.67 359.20 4736.05 4817.95 3505.87 3533.75 3517.08 3178.51 1505.65 4.23 5963081.19 6324.14 47.25 354.87 4801.57 4883.47 3570.05 3603.88 3578.96 3248.53 1502.01 3.35 5963151.15 6418.24 46.43 354.32 4865.94 4947.84 3631.65 3672.52 3638.44 3316.86 1495.55 0.97 5963219.37 6513.75 45.80 354.15 4932.15 5014.05 3693.24 3741.36 3698.19 3385.35 1488.64 0.67 5963287.74 6608.79 45.63 354.02 4998.51 5080.41 3754.03 3809.39 3757.47 3453.03 1481.62 0.20 5963355.30 6701.98 44.85 354.46 5064.12 5146.02 3813.23 3875.56 3815.49 3518.86 1474.98 0.90 5963421.02 6795.92 44.47 354.82 5130.94 5212.84 3872.51 3941.59 3873.86 3584.60 1468.81 0.49 5963486.66 6890.79 43.83 353.77 5199.01 5280.91 3931.66 4007.67 3932.33 3650.35 1462.25 1.02 5963552.30 Last Survey 6981.89 43.20 354.35 5265.08 5346.98 3987.69 4070.40 3987.94 3712.74 1455.75 0.82 5963614.58 TD (Projected) 7052.00 43.20 354.35 5316.19 5398.09 4030.67 4118.39 4030.74 3760.50 1451.03 0.00 5963662.26 Survey Type: Detinitive Survey NOTES: GYD CT DMS - (Gyrodata - cont. driUpipe m!s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) In drill-pipe.) MVVD + IFR + MS - (In-field referenced MVYD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) l.eaal Descriution: Northing lY) [ftUS] Easting (X) [ftU3] Surface : 4888 FSL 1176 FEL S21 711 N R12E UM 5959865.97 612049.02 BHL : 1488 FSL 461 5 FEL S15 T11N R12E UM 5961773.03 613857.13 613471.59 N 7018 26.308 W 149 4 50.346 613488.83 N 7018 26.912 W 149 4 49.816 613499.77 N 70 18 27.561 W 149 4 49.467 613505.64 N 70 18 28.219 W 149 4 49.267 613506.84 N 70 18 28.879 W 149 4 49.202 613502.16 N 70 18 29.568 W 149 4 49.308 613494.68 N 70 1830.240 W 149 4 49.496 613486.75 N 70 18 30.913 W 149 4 49.697 613478.73 N 70 18 31.579 W 149 4 49.901 613471.10 N 7018 32.226 W 149 4 50.095 613463.96 N 70 18 32.873 W 149 450. 613456.41 N 70 18 33.520 W 149 450. 613448.99 N 70 1834.133 W 149 4 50.6 613443.55 N 701834.603 W 149 4 50.792 i SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-216 Plan\W-216\W-216\W-216 Generated 2/13/2008 11:15 AM Page 3 of 3 TREE = 4-1 t8"' vVELL;-iEAD= FMC AC~JATOR Baked-tydraulic KB. ELEV = w~m~ _ 81 9 BF. ELEV = KaP = 56.7. 300' Max Angle = 49. i deg [3atum MD = ~ ~ 13-318" CSG, 68#, L-8d, BTC, ID - 12,.415"' 9-518" CSG, 44#, L-8d, BTG, } = 8.835" 7" CSG, 26#, L-Bd, TC-11, .4383 bpf, li3 = 8.' ?.+`~-~ 4-1 J2" XO 3-912", ID = 2.952" GQ9' 3-1i<~:. HES X NIP. ID ~ 2.893" --a taAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PC3FtT LATE 6 ~i44 4897 47 MMG DCK RK _ 41114148 WATER INJEGTtQN MANDRELS I 5.513' f ..Minimum IQ = 2.75" ~ X778' 3-112"' HEM XN NIPPLE RICER .IpINT w / RA TA G~ _ OA 6435 E MA RKER J[31NT w I RA TAG ] PERFC)RATIQN SUMMARY REF LqG: SLR Rea~ime LWD A NGLE AT TOIL PERF: 46 ~ 6546' Note: Refer to Production PB far historical perf data SIZE SPF' INTERVAL tJpnlSgz DATE 4-1/2" 5 f?ba G5t~6 - 6544 fl 4111 4148 4-112" 5 Ubc fs616 - 6652 O 41114108 4912" 5 qbd 6S9& - fi745 C) 41110/48 ST Ml) TVD DEV TYPE VLV LATCH P(3RT I14TE 5 '' 6480 4951 46 M1114AU-W tom' FtK 0 f 414.!08 4 ' 6'542 5434 48 IvisJIG-W C?I~hY K t~1 J1 ff/a6 3 6617 5486 4E A~VIIG-W €JN1' RK 41114;08 2 6&56 5193 45 It+~tfG-V4J Cam'' RK £I11141d8 1 6728 5165 45 A111tfG-V4i I~itY RK 4111414& &43__.~_`~.~- ~3-112" HES X NiP ID = 2.813" fi4S5' 7" IiES AF+R PKR w i 114" FEEr7 THRU, ID - 2.920" 6,4$9" PFIC7ENGC PRESIf'EI+AP SENSt?R SUB, IC1= 2.992•' ,'~' 3-112" 1^I>=S X h~P, IC = 2.813.' 6,92' 7" EiES A HR PKR w f 114" FEED ThiRU, 117 = 2.924" 6f~5' PHC}ENBC PRESIT81AP5ENSC?F2 SUB, ID-2.992"_...... ~~i$~' 7" HES A HR RKR w 1114" FEED THRU, IE3 = 2.924" 67#I~ 3-112" HIwS X NIP, ID = 2.813" 3-112'" HES X N~? ID = 2.813.. 3-112" IiES XN NiP, ~3 a 2.75" ~3-if2'" TBG, 9.2#, L=84, Ttrif..0©87 b{~f, (D = 2.992" PBTD 7" GSt"; 7Fi# 1,Rtt R7'C M IS.3R_4 hnf lrt .-. {i 27fi [ 8,51' f ~--{3-112'" WLEG, ID ~ 2.997` DA'Ti= REV BY C()NENI'S DATE REtI BY COM@AENTS CIRION UNfr t11I18108 N9ES i31~GIN14L CflMPLETiCJN WELL: tN-216i A1f20-G8 ITCH CmRREC7IC?NS PE#~Mff IVo: 2471684 API No: 54-029-379' Sec 21, Tw R 11 N, Rge 12E 8P Exploration (Alaskay SAFEf 7ES: *'"[-1ES PKf2 EBBS' 1~ "PEILL Tt~ FLEA CAN ALSt3 fBEE RI:LEASEb 8Y PF~SSURE. ^~ ~ I]{I Nt37 EXGFB} 43QD PSI. TEST PRE.S~'URE PKR 1 ~ f~4TINC~ = 5413 PSI {d3~2 P5~ fS Sd °l. ~ PR RATING}"'"' °°~ a • Page 1 of 1 Regg, James B (DOA) ~ ~j ~ ~~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 17, 2008 7:31 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; NSU, ADW Drlg Rig 9es Subject: RE: MITs -PBU W-216 Attachments: Daily Drilling Report.pdf; W-216 MITs chart 01-13-08.pdf Hi Jim. AOGCC Inspector Lou Grimaldi witnessed the pressure test on the tubing to set the packer and the pressure test of the IA on W-216 during the completion. I`ve attached a copy of the chart and the DIMS repork. As (am unfamiliar with the documentation submitted by the rig so please let me know if you require any further documentation. Thank you, ,Anna ~u6e, ~'.~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, February 15, 2008 11:56 AM To: NSU, ADW Well Integrity Engineer Subject: MITs -PBU W-216 Could you send the MITs for PBU W-216 done 1/13/2008? Inspector says he witnessed 2 tests on that date. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 2/22/2008 ,Z' F . „jo ~~+`. f ~: ~~,~ '~ ' 1`"~ -'_. • ~:-_~ __ _:s ..~---- ~,, ~ i ``l _, _'-~-SLb _____v f -'~ ~. .~ - ~ i :% %s' ~i .- ,.~~~ <~ ``~. :I i ~. ~h~ jy ~ ~t ,.ia f .t J, ~ r ~ p~ l ! ~' ~ f `. l~ J r` ~a --a • BP Daily Operations Report Page ~ of4 Operator: BP Rig: NABORS 9ES Report: 20 Well: W-216 Event: DRILL+COMPLETE Date: 1/13!2008 Field: POLARIS __ __ -- Well Type: DEVELOPMENT Current Well Status Depth MD: 7,052.0 (tt) _ Casing Size: 9.625 (in) Costs in: USD ~ Rig Accept: 05:00 12/26/2007 Est. TVD: 5,398.0 (ft) Casing (MD): 4,020.9 (ft) Daily Mud: 2,146 Rig Release: 1/16/2008 Progress: (ft) Next Casing Size: (in) Cum. Mud: 174,504 Spud Date: 12/27/2007 Auth Depth: 7,081.0 (ft) Next Casing (MD): (ft) Daily Well: 414,120 WX Date: Hole Size: 8.750 (in) Next Casing (TVD): (ft) Cum. Well: 4,856,382 Elev Ref: SEA LEVEL DOL/DFS/Target: 18.79/17.67/19.33 Liner Size: 7.000 (in) Geologist: Liner (MD): 7,037.0 (ft) KB Elev: 81.90 (ft) Engineer: Bob Coolidge Liner Top (MD): 25.5 (ft) Tot. Personnel: 30 Supervisor: LeB1anGMartyn Program: Cost Ahead: 0 USD, Days Ahead: -1.50 Weather: Clear & Cold w/Ice Fog Current Status: Circulate brine for temperature in hole. 24hr Summary: Land 3.5" comple tion, Set & Test Packers, ND BOP, NU Tree. 24hr Forecast: Prepare for rig move while waiting on warmer weather. Comments: No Accidents, No Incidents, No Spills Temp -45 deg, Winds @ 4 mph, Wind chill -63 deg, Visibility 2 miles 0.0 hr Billable Rig Repair NPT, 10.5 hrs total for Well, 10.5 hrs total year to date _- -- - HSE & Well Control Days Since Last DAFVvi,: 1519 --- - All Free Days: i9 Last Csg Test Press.: 4,000 (psi) Last Envir. Incident: 11/9/2007 Last BOP Press. Test: 1/4/2008 Last Abandonment Drill: 12/18/2007 Last Trip Drill (D1): 1!10/2008 Next BOP Press. Test: 1/18/2008 Last Accum. Drill (D4): 1/4/2008 Last Safety Meeting: 1/13/2008 Last Divertor Drill (D3): 1/1/2008 Last Spill Drill: 1/13/2008 No. Stop Cards: Regulatory Agency Insp: N Non-compliance Issued: N FIRE: 1 /1 212 0 0 8 KICK WHILE DRILL (D2)1/6/2008 MAN DOWN: 1/10/2008 LOST CIRC U L A T ION: 1/4/2008 SHALLOW GAS: 1/1/2008 WELL KILL (D5): 1/13/2008 _ _ _ _ _ __ Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) LOT TVD: 3,312.0 (ft) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() LOT EMW: 11.85 (ppg) MAASSP: 491 (psi) Test Pressure: 525 (psi) Kick Tolerance: (ppg) Kick Volume: (bbD ! I Operational Parameters - - RUP Daily: Rotating Weight: Daily Bit Hrs: (hr) Pump Status -Drilling and Riser ROP Cum.: Pick Up Wt.: Daily Sliding Hrs:0.00 (hr) Pump Type Eff. Strokes Liner Size Circ. Rate WOB (min): Slack Off Wt.: Cum. Bit Hrs: b 0 0 () WOB max : Circ. Rate Riser: I RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (ft/min) j RPM DH: Circ. Off Bottom: Ann. Vel. DC: 165.3 (ft/min~ Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: 128.0 (ft/min~ i Torq. off Bottom: Jar Hrs since Inspect: 11 (hr) ~i i i __ , Drillin Ffuid Type: 9.0 ppg NaCI br 10 sec gels: (Ib/100ftz) Ca: (mg/L) ES: (mV) Time/Loc: 22:00/IN 10 min gels: (Ib/100ft=) K+: (mg/L) Solids: (%) Depth: 7,037.0 (ft) Fluid Loss: (cG30min) CaCl2: (%) Oil: (%) Temp: (°F) HTHP Temp: (°F) NaCI: (%) Water: (%) Density: 9.00 (ppg) HTHP WL: (ccl30min) CI-: (mg/L) Oil/Water: / Funnel Visc.: 28 (s/qt) Cake: (/32") Sand: (%) Daily Cuttings: (bbl) ECD: (ppg) MBT: (ppb) HGS: (ppb) Cum. Cuttings: (bbl) PV: (cp) Lime: (ppb) LGS: (ppb) Lost Downhole: (bbl) YP: (Ib/100ftZ) PM: (mL) Pf/Mf: / (mUmL) Lost Surface: (bbl) pH: _ _ Operations Summary - _ __ From-To Hrs it Phase Tas Op. Depth (hr) k ! Activity ,code ' NPT ~ Operation i I 00:00-01:30 1.50 _ RUNC ___ __ RUNCO RD P __ Once completion in position on extra joint, cut 1-Wires and leave extra ~ 6,791 !, I ~ sl spaceout if needed. Rig down I-Wire spools and sheaves prior to rigging up E-line to allow Schlumberger to mobilize spools to Nabors 7ES as soon as possible. Printed: 2/17/2008 7:20:04 PM • • ~, ~r Daily Operations Report Page 2 of 4 - ------- -- - ---- Operator: BP Rig: NABORS 9ES Report: 20 Well: W--216 Event: DRILL+COMPLETE Date: 1/13/2008 Field: POLARIS Well Type: DEVELOPMENT __ - - - ', _ _ Operations Summary From-To Hrs Phase '~ Task Activity I, Code NPT Operation Op. Depth (hr) I ~ 01:30-03:00 1.50 RUNC RUNCO RU j P Rig up Schlumberger E-Line w/ pack-off and pump-in sub for pressure 6,791 _ ~ 1 control. Make up GR/CCUPress/Temp tool. 03:00-05:00 2.00 RUNCMRUNCO i LOG P ~ Run in hole with GR/CCL tool to 6,735'. Log up and correlate RA tags 6,791 ~ and packers. 9.83' foot down adjustment needed. POH with logging I___ tools recording well temperature. 05:00-06:00 1.00 RUNCMRUNCO __ F2D P _ Rig Down Schlumberger E-Line. 6,791 __ 06:00-07:00 1.00 RUNCMRUNCO RUN P Space out tubing. Lay down spare joint, and joint 202. Make up 9.83' 6,800 - pup above 3.82' pup already installed. Make up joint 202. 07:00-08:30 1.50 RUNCMRUNCO RUN P Make up tubing hanger and landing joint. Terminate I-wire and test 6,800 connections to 5,000 psi - OK. Test I-wire continuity - OK. Land tubing. Item: Bottom of 3.5" 9.2 # WLEG, 3.5" TC-II set @ 6,800'. Tops: 3.5" 9.2 # WLEG, 3.5" TC-II @ 6,799'. I ~ ~ 3.5" HES 'XN' Nipple: ID 2.750 @ 6,778'. ~ ~, 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug @ 6,757. 'i % GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,728'. 3.5" HES 'X' Nipple: 2.813" ID @ 6,708'. 3.5" x 7" HES single feedthru Packer #1 packer @ 6,684'. ' GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,655'. GLM #3 - 3.5" x 1.5" MMG-W w! RD Dummy- RK latch @ 6,617'. i~ j Phoenix Sensor sub @ 6,605'. 3.5" x 7" HES Dual feedthru Packer #2 packer @ 6,591'. i ~ 3.5" HES 'X' Nipple: 2.813" ID @ 6,570'. ' GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,542. 1 joint tubing. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,480'. I. Phoenix Sensor sub @ 6,468'. i 3.5" x 7" HES Dual feedthru Packer #3 packer @ 6,455'. 3.5" 9.2# L-80 TC-II Pup (Centralizer w/PIP tag anchored on pup @ '; i 6,436' just below nipple). ~~ i ~ ~ 3.5" HES 'X' Nipple: 2.813" ID @ 6,434'. ' ~ i 2 jts 3.5" 9.2# L-80 TC-II Tubing (#2 - 3) @ 6,362'. ~ ~ ~ GLM #6 - 3.5" x 1.5" MMG w/ DCR-1 Shear- RKP latch @ 6,344'. j 111 jts 3.5" 9.2# L-80 TC-II Tubing (#4 - 114) @ 2,819'. i 3.5" HES 'X' Nipple: 2.813" ID @ 2,809'. I ~ 81 jts 3.5" 9.2# L-80 TC-II Tubing (# 115 - 201 j @ 88' 2 ea 3.5", 9.2#, L-80 TC-II Space out Pups (9.83' & 3.82') I ~ ~ 1 jt 3.5" 9.2# L-80 TC-I I Tubing (# 202 ) I ~ 3.5" 9.2# L-80 TC-II Hanger Pup I ; . 4.5" X 3.5" TC-II Crossover I FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads ~~ i i Up wt = 90k, Dn wt = 67k ~ 116 full Cannon clamps, 14 Half clamps 08:30-09:00 I~ 0.50 'RUNCMiRUNCO PKRST P Drop rod and ball Laydown landing joint. 6,800 ' '' ~ 2.50 RUNCMIRUNCO 09:00-11:30 ~ PKRST P _ _ PJSM. Rig up circulating lines. Pressure up on tubing, set packers 6,800 !~ '~, and test to 4,000 psi - 30 min -Good test. Bleed off tubing pressure to ~ ~ 2,600 psi. Pressure up inner annulus and test to 4,000 psi - 30 min - ~, Good test! Test witnessed by Lou Grimaldi, AOGCC representative. ', (tubing pressure @ 3,100 psi during IA test). Bleed off annulus I ' ~ ! pressure to 0 psi, bleed off tubing pressure to 0 psi. Pressure up on ', annulus to shear DCR valve. Sheared at 2,750 psi. Establish j circulation briefly both ways - OK. ~~ ~ S Printed: 2/17/2008 7:20:04 PM --- - -- B P _ - _~ Daily Operations Report Page s of4 Operator: BP Rig: NABORS 9ES Report: 20 Well: W-216 Event: DRILL+COMPLETE Date: 1/13/2008 Field: PO LARIS _ Well Type: DEVELOPMENT - - Operations Summary _ -_ From-To Hrs ~ Phase Task Activity Code NPT Operation Op. Depth (hr) 11:30-12:00 0.50 RUNCM HSU ' PLUG P Dry rod 2 way check valve. Test valve from below to 1,000 psi - OK. 12:00-13:00 1.00 RUNCM SUI~ RU P Drain BOP stack, blowdown lines and prepare to nipple down BOPE. 13:00-16:30 3.50 RUNC BOPSU~ I ND i P PJSM. Nipple down BOPE. 16:30-18:00 1.50 RUNCf~ II WHSU NU P PJSM. Nipple up tree adaptor. Test same to 5,000 psi - OK. 18:00-19:00 1.00 RUNC ~FISU INSTAL - I P Terminate I-wires on tree adaptor. Test connections to 5,000 psi - OK. Test I-wire continuity - OK. 19:00-22:00 3.00 RUNC SU ' NU P Nipple up tree with hydraulic actuator valve. 22:00-22:30 0.50 i RUNC HSU TSTPF2S P PJSM. Rig up and test tree to 250 psi low, 5,000 psi high - OI<. 22:30-00:00 1.50 RUNC SU PLUG P ~ PJSM. Rig up DSM lubricator. Test same to 500 psi - OK. Pull 2-way check valve. 06:00 U pdate From-To Hrs Phase Task Activity code NPT ___ Operation Op. Depth (hr) 00:00-00:30 0.50 RUNC SUF~ RD I __ _ P Lay down DSM lubricator. 00:30-00:00 23.50 RUNC SU WOW N WAIT ;Perform misc. tasks while waiting on temperature to warm up above -40 degF (currently -45). Unable to arrange pump truck until -40. I Once freeze protect complete, unable to lower derrick until -35. Once derrick down, Z-112 pad is not prepped until heavy equipment ~ prepares pad (no heavy equipment operations until above -35 degF). I ~ i Pump 213 bbls old brine around surface to surface to warm well every 3 hours @ 167 gpm, 590 psi. Lowest temperature seen while E-Line ~ in hole was 33 degF @ 1,500' md. Freezing point of 9.0 ppg brine = -6 ' i degF. - _ Mud Loc Inforr ~ nation -- - -- Formation SCHRADEF BU_iFF F arm fop t.1D, 6.20n 0 (ft) Bkgrnd Gas T~~I~ r>> Lithologv SAND ~ Conn. Gas ~ Pupa. F Bess i ur~nl DIESEL -RIG Materials /Consumption Units ~ Usage On Hand Item Units ~ Usage On F land --- ~r'AL 2784 5184 _~------- _ - Personnel _ -- No. 'Hours Company No. Hours Company No. Hours -------------~ - -------i-.---- BP 2 ~ 12.00 NABORS 2 12.00 NABORS 22 12.00 DOYON 1 ' 15.00 M-I DRILLING FLUIDS 2 12.00 ANADRILL SCHLUMBERGER 0 12.00 ANADRILL SCHLUMBERGER O 12.00 PETROTECHNICAL RESOUR 0 12.00 THE REACH GROUP 1 12.00 Phase PRE Cumulative Phase Breakdown Planned Change of Scope ~ Total '~ Total Cost Total ! NPT- % Total WOW % Total Prod % Total NPT % Total WOW % Total Hours USD COND2 72.25 92.6% 5.75 7.4% SURF 105.50 84.4% 19.50 15.6% PROD1 56.00 100.0% ~ RUNPRD 46.00 100.0% I OTHCMP 47.00 77.0% 14.00 23.0% P i 9.50 16.4/0 ---- TOTALS . --------- .412.25...89.2° _ + -- --- - - ° 49.75 10.8 /o I _..____._- - - -- 0.00 - - 0.0% 0.00 0.0% I 0.00 0 Remarks Hold PJSM for all operations. Perform derrick inspection at begin ning of each tour. Function test Crown-O-Matic. Function test PVT's, Function test Cuttings tank high level alarm 38.00 i 296,295.47 78.00 969,105.50 125.00, 1,235,634.4 56.00 ~'~ 365,763.88 46.00!. 659,748.05 61.00; 331,107.24 58.00: 998,727.49 462.00! 4,856.382.0 Printed: 2/17/2008 7:20:04 PM • Operator: BP Well: W-216 Field: POLARIS Langham Crew Drill: Spill drill Hohn Crew Drill: Well kill drill (D5) • -- ~ BP ~ Daily Operations _Report Page 4 of 4 _ __ Rig: NABORS 9ES Report: 20 Event: DRILL+COMPLETE Date: 1!13/2008 Well Type: DEVELOPMENT -- - --- .Remarks Screens junked out today is 0. Screens junked out total for well is 0. Screens junked out total for the year is 0. Surtace Cement 16" down from top of conductor. OA Pressure = 100 psi. 0 bbls 9.0 ppg brine lost for the day. 45 bbls 9.0 ppg brine lost for the well. Bill Hohn Crew Changes: Short 2 hands- Short handed 1 floorhand missed flight up (Due in Monday) 1 roustabout position still unassigned since November Mike Pierce working over for roustabout spot until Monday Josh Sands filling in on floors from roustabout Roustabout pusher coming on tour early to fill in for second roustabout missing Ralph Langham Crew Changes: None Printed: 2/1712008 7:20:04 PM i+ ~t G r 6~ Oc, SCHLUMBERGER Survey report Client..... ............. Field ..................... well. .................. API number ...............: Engineer .................. Rig :................ .... STATE:....................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration (Alaska) Inc. Polaris W-216 50-029-23379-00 St. Amour Nabors 9ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.40 ft KB above permanent........ N/A (Top drive) DF above permanent.......: 81.90 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 20.77 degrees 6-Jan-2008 15:55:38 Page JAN 1 ~ ?Q Spud date ................ Last survey date......... Total accepted surveys... MD of first survey....... MD of last survey........ 27-Dec~~~a Oil & Gss C~n~. C~mmlc~tA~ 06-Jan-08 AI1ChOt8~ 79 0.00 ft 7052.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 04-Jan-2008 Magnetic field strength..: 57646.94 GAMA Magnetic dec (+E/W-).....: 23.24 degrees Magnetic dip .............: 80.87 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57646.50 GAMA 80.87 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections ------------------- g Magnetic dec (+E/W-).....: 23.22 de rees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.22 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • ~ SCHLUMBERGER Survey Report 6-Jan-2008 15:55:38 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ ------- Displ ------- Total -------- At ----- DLS - ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (ft) (ft) (f t) (deg) 100f) type (deg) 1 0.00 0.00 45.00 0.00 0.00 0.00 0.00 ------ 0.00 ------- 0.00 -------- 0.00 ----- 0.00 - ---- ------ TIP None 2 100.00 0.33 88.70 100.00 100.00 0.11 0.01 0.29 0.29 88.70 0.33 BP GYD CT DMS 3 179.00 0.45 129.54 79.00 179.00 0.09 -0.19 0.75 0.78 103.83 0.37 BP _ GYD CT DMS 4 271.00 1.17 80.65 92.00 270.99 0.45 -0.26 1.96 1.98 97.65 1.02 BP _ GYD CT DMS 5 363.00 1.70 49.08 92.00 362.96 2.12 0.78 3.92 4.00 78.69 1.01 BP _ GYD CT DMS 6 456.00 3.49 36.03 93.00 455.86 6.07 3.98 6.63 7.73 59.03 2.01 BP GYD CT DMS 7 548.00 5.06 32.27 92.00 547.60 12.75 9.67 10.44 14.23 47.19 1.73 BP _ GYD CT DMS 8 572.00 5.15 31.39 24.00 571.51 14.84 11.49 11.57 16.30 45.20 0.50 BP _ GYD CT DMS 9 640.00 6.74 28.86 68.00 639.14 21.79 17.59 15.08 23.17 40.61 2.37 BP _ GYD CT DMS 10 664.20 7.21 27.90 24.20 663.16 24.70 20.17 16.48 26.05 39.24 2.00 BP _ MWD+IFR+MS 11 758.16 8.04 25.32 93.96 756.29 37.11 31.32 22.05 38.30 35.14 0.96 BP MWD+IFR+MS 12 852.76 9.88 26.69 94.60 849.73 51.77 44.56 28.52 52.90 32.62 1.96 BP _ MWD+IFR+MS 13 945.91 11.95 25.97 93.15 941.19 69.33 60.37 36.34 70.46 31.04 2.23 BP _ MWD+IFR+MS 14 1040.11 13.47 22.59 94.20 1033.08 90.01 79.27 44.82 91.06 29.49 1.80 BP _ MWD+IFR+MS 15 1133.53 14.68 19.82 93.42 1123.70 112.72 100.45 53.01 113.58 27.82 1.48 BP _ MWD+IFR+MS 16 1225.53 16.65 20.99 92.00 1212.28 137.56 123.72 61.69 138.25 26.50 2.17 BP MWD+IFR+MS 17 1256.72 16.74 21.89 31.19 1242.15 146.52 132.06 64.96 147.18 26.19 0.88 BP _ MWD+IFR+MS 18 1316.63 17.39 20.99 59.91 1299.42 164.10 148.43 71.39 164.70 25.69 1.17 BP _ MWD+IFR+MS 19 1411.96 21.39 25.69 95.33 1389.33 195.68 177.41 84.03 196.30 25.35 4.50 BP _ MWD+IFR+MS 20 1507.44 23.58 26.06 95.48 1477.55 232.05 210.26 99.97 232.82 25.43 2.30 BP _ MWD+IFR+MS 21 1603.44 25.12 26.63 96.00 1565.01 271.44 245.72 117.54 272.39 25.56 1.62 BP MWD+IFR+MS 22 1700.04 26.76 28.16 96.60 1651.87 313.40 283.23 137.00 314.62 25.81 1.83 BP _ MWD+IFR+MS 23 1795.47 29.15 28.69 95.43 1736.16 357.74 322.56 158.30 359.31 26.14 2.52 BP _ MWD+IFR+MS 24 1889.91 31.40 27.68 94.44 1817.72 404.95 364.53 180.77 406.89 26.38 2.44 BP _ MWD+IFR+MS 25 ,1983.48 35.35 26.28 93.57 1895.84 456.11 410.41 204.09 458.35 26.44 4.30 BP _ MWD+IFR+MS 26 2080.59 36.56 26.89 97.11 1974.45 512.83 461.40 229.61 515.37 26.46 1.30 BP MWD+IFR+MS 27 2175.39 39.89 26.45 94.80 2048.91 571.17 513.81 255.93 574.02 26.48 3.52 BP _ MWD+IFR+MS 28 2269.04 41.77 27.62 93.65 2119.77 632,03 568.34 283.77 635.24 26.53 2.17 BP _ MWD+IFR+MS 29 2367.63 44.06 27.72 98.59 2191.97 698.67 627.79 314.94 702.36 26.64 2.32 BP _ MWD+IFR+MS 30 2464.97 46.65 26.90 97.34 2260.37 767.47 689.32 346.70 771.60 26.70 2.73 BP _ MWD+IFR+MS LJ i~ SCHLUMBERGER Survey Report 6-Jan-2008 15:55:38 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ - Total -------- At ----- DLS ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2558.10 49.11 26.32 93.13 2322.82 836.18 751.08 377.63 840.67 26.69 2.68 BP MWD+IFR+MS 32 2653.79 48.53 25.99 95.69 2385.83 907.89 815.73 409.38 912.69 26.65 0.66 _ BP MWD+IFR+MS 33 2748.04 47.82 25.51 94.25 2448.68 977.85 878.98 439.89 982.91 26.59 0.84 _ BP MWD+IFR+MS 34 2843.43 47.41 25.28 95.39 2512.98 1048.08 942.63 470.11 1053.36 26.51 0.47 _ MWD+IFR+MS BP 35 2939.14 47.15 25.21 95.71 2577.91 1118.18 1006.23 500.10 1123.66 26.43 0.28 _ BP MWD+IFR+MS 36 3031.04 46.54 25.25 91.90 2640.77 1185.02 1066.88 528.68 1190.68 26.36 37 3123.39 48.28. 27.31 92.35 2703.27 1252.69 1127.83 558.79 1258.66 26.36 38 3216.20 47.76 27.64 92.81 2765.35 1321.21 1189.04 590.62 1327.64 26.41 39 3306.92 47.25 27.19 90.72 2826.63 1387.65 1248.41 621.42 1394.53 26.46 40 3399.67 46.91 26.79 92.75 2889.79 1455.17 1308.94 652.25 1462.44 26.49 41 3495.51 46.41 26.74 95.84 2955.57 1524.49 1371.17 683.63 1532.15 26.50 42 3591.09 48.03 27.31 95.58 3020.48 1594.22 1433.66 715.51 1602.29 26.52 43 3685.48 47,31 26.77 94.39 3084.05 1663.59 1495.81 747.24 1672.07 26.54 44 3780.36 46.87 26.51 94.88 3148.64 1732.71 1557.93 778.40 1741.56 26.55 45 3876.07 46.63 26.22 95.71 3214.22 1802.09 1620.39 809.36 1811.27 26.54 46 3967.62 48.07 27.85 91.55 3276.25 1869.02 1680.35 839.97 1878.60 26.56 47 4053.57 47.22 27.39 85.95 3334.16 1932.08 1736.63 869.42 1942.11 26.59 48 4153.82 46.40 27.54 100.25 3402.77 2004.67 1801.48 903.13 2015.19 26.63 49 4248.50 45.67 28.30 94.68 3468.50 2072.29 1861.70 935.03 2083.32 26.67 50 4344.25 45.94 26.86 95.75 3535.25 2140.45 1922.55 966.81 2151.95 26.70 51 4440.44 46.69 26.07 96.19 3601.68 2209.67 1984.82 997.81 2221.51 26.69 52 4535.68 45.48 26.50 95.24 3667.74 2277.96 2046.33 1028.19 2290.12 26.68 53 4630.51 46.70 25.97 94.83 3733.51 2345.96 2107.61 1058.38 2358.43 26.66 54 4723.64 46.78 25.79 93.13 3797.33 2413.51 2168.63 1087.99 2426.25 26.64 55 4819.23 45.61 26.24 95.59 3863.50 2482.21 2230.63 1118.24 2495.23 26.63 56 4913.34 47.66 27.22 94.11 3928.11 2550.25 2291.72 1149.02 2563.64 26.63 57 5006.37 47.77 27.22 93.03 3990.71 2618.64 2352.93 1180.50 2632.46 26.64 58 5100.49 46.62 27.97 94.12 4054.66 2687.20 2414.13 1212.49 2701.50 26.67 59 5194.80 45.77 28.26 94.31 4119.94 2754.71 2474.16 1244.56 2769.54 26.70 60 5287.61 46.83 28.87 92.81 4184.06 2821.18 2533.09 1276.64 2836.61 26.75 0.66 BP_MWD+IFR+MS 2.50 BP_MWD+IFR+MS 0.62 BP_MWD+IFR+MS 0.67 BP_MWD+IFR+MS 0.48 BP_MWD+IFR+MS 0.52 BP_MWD+IFR+MS 1.75 BP_MWD+IFR+MS 0.87 BP_MWD+IFR+MS 0.51 BP_MWD+IFR+MS 0.33 BP_MWD+IFR+MS 2.05 BP_MWD+IFR+MS 1.07 BP_MWD+IFR+MS 0.83 BP_MWD+IFR+MS 0.96 BP_MWD+IFR+MS 1.11 BP_MWD+IFR+MS 0.98 BP_MWD+IFR+MS 1.31 BP_MWD+IFR+MS 1.35 BP_MWD+IFR+MS 0.16 BP_MWD+IFR+MS 1.27 BP MWD+IFR+MS 2.31 BP_MWD+IFR+MS 0.12 BP_MWD+IFR+MS 1.35 BP_MWD+IFR+MS 0.93 BP_MWD+IFR+MS 1.24 BP_MWD+IFR+MS • I, ~~ SCHLUMBERGER Survey Report 6-Jan-2008 15:55:38 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ - Displ ---- Total ------ At ----- DLS - ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5382.57 49.13 28.62 94.96 4247.62 2891.04 2594.94 1310.57 2907.11 26.80 2.43 BP MWD+IFR+MS 62 5476.85 48.67 28.33 94.28 4309.60 2961.45 2657.39 1344.44 2978.12 26.84 0.54 BP _ MWD+IFR+MS 63 5572.74 49.10 26.71 95.89 4372.66 3033.19 2721.45 1377.81 3050.36 26.85 1.35 BP _ MWD+IFR+MS 64 5667.45 50.22 26.01 94.71 4433.97 3105.03 2786.14 1409.86 3122.54 26.84 1.31 BP _ MWD+IFR+MS 65 5761.86 48.56 23.99 94.41 4495.42 3176.50 2851.08 1440.16 3194.17 26.80 2.39 BP _ MWD+IFR+MS 66 5858.02 46.83 19.43 96.16 4560.16 3247.57 2917.10 1466.49 3264.98 26.69 3.94 BP MWD+IFR+MS 67 5947.52 44.65 13.41 89.50 4622.65 3311.42 2978.51 1484.65 3328.02 26.49 5.40 BP _ MWD+IFR+MS 68 6041.99 45.90 7.15 94.47 4689.16 3377.35 3044.49 1496.58 3392.44 26.18 4.89 BP - MWD+IFR+MS 69 6135.42 46.20 4.58 93.43 4754.01 3442.34 3111.39 1503.45 3455.59 25.79 2.01 BP _ MWD+IFR+MS 70 6228.16 46.67 359.20 92.74 4817.95 3505.87 3178.51 1505.65 3517.09 25.35 4.23 BP _ MWD+IFR+MS 71 6324.14 47.25 354.87 95.98 4883.47 3570.05 3248.53 1502.01 3578.96 24.81 3.35 BP MWD+IFR+MS 72 6418.24 46.43 354.32 94.10 4947.84 3631.65 3316.86 1495.55 3638.44 24.27 0.97 BP _ MWD+IFR+MS 73 6513.75 45.80 354.15 95.51 5014.05 3693.24 3385.35 1488.63 3698.19 23.74 0.67 BP _ MWD+IFR+MS 74 6608.79 45.63 354.02 95.04 5080.41 3754.03 3453.03 1481.62 3757.47 23.22 0.20 BP _ MWD+IFR+MS 75 6701.98 44.85 354.46 93.19 5146.02 3813.23 3518.86 1474.98 3815.49 22.74 0.90 BP _ MWD+IFR+MS 76 6795.92 44.47 354.82 93.94 5212.84 3872.51 3584.60 1468.81 3873.86 22.28 0.49 BP MWD+IFR+MS 77 6890.79 43.83 353.77 94.87 5280.91 3931.66 3650.36 1462.25 3932.34 21.83 1.02 BP _ MWD+IFR+MS 78 6981.89 43.20 354.35 91.10 5346.98 3987.69 3712.74 1455.75 3987.94 21.41 0.82 BP _ MWD+IFR+MS 79 7052.00 43.20 354.35 70.11 5398.09 4030.67 3760.50 1451.03 4030.74 21.10 0.00 _ Projected To TD [(0)2008 IDEAL ID12 OC 13] i oz/zo/oa Schlumber~er NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Betty 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne Wcll _Inh if 1 nn nncnrin4inn n~4o RI C..li.. cn 18-32A 11968923 SCMT / - / 02112/08 1 MPE-12 11978438 MEM INJ PROFILE tJIL' c~US - C)Co 02/08108 1 4-14/R-34 11996383 USIT (, 02!12/08 1 V-07 40016096 OH MWD/LWD EDIT `~ - G ( Lft 12/04107 2 1 L1-14 11626482 RST ~ '-- / ~ ~9Y3 05/09/07 1 1 L2-18A 11657124 RST C 05/10/07 1 1 L2-33 11626484 RST ( (p - ( '~j C ~ 05/11/07 1 1 G-31A 11962778 RST - r:}S ~( ~~ 01/01/08 1 1 V-111 11978439 MEM GLS 02/10/08 1 W-216 12031441 CH EDIT PDC GR (USIT) 9 01/11/08 1 W-214 40016055 OH MWD/LWD EDIT V=, _ ( 11115107 2 1 Y-07A 11962576 USIT '~ 12/18/07 1 C-35B 11978432 MEM DDL _ / 01102108 1 YLtASt AGKNUWLtUGE KECEIP 16Y SIGNING AND RETURNINGwO~E COPY EACH TO: BP Exploration (Alaska) Inc. ' ~ R`~~ ~ , __ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 , , ~ „ ~ ~ ~ 1t (.~~~t~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: ry o2roaros ~Clumbe~g~r' NO. 4572 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambelt Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt, Polaris,Lisburne Wpll .Inh it ! nn DPSr_rintinn Date RI. Colnr CD LGI-04 11970706 SBHP SURVEY ~ ~ ' '- 01/01108 1 MPH-12 11978435 MEM DDL 01/31/08 1 W-216 12031441 USIT (x}- 01/11/08 1 W-214 11855826 CH EDIT PDC GR (USIT) (, 11/19/07 1 GNI-04 11846828 CH EDIT PDC GR (USIT) 11/11/07 1 15-36B 11216209 MCNL (0 08105/06 1 1 H-24A 11767145 MCNL ~- 15 C 11129/07 1 1 C-04B 11216198 MCNL ~ - Gt~"~ ~) 3 06/02/06 1 1 L3-11 11962776 MCNL ~ ~ 9 12/12/07 1 1 YLtASt AGKNOWLtU(it REGEIPI t3Y SIGNING AND KtIUKNING ONE DOPY EAGN TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 1''' ~ - ~~~~ 6~ 900 E. Benson Blvd. Anchorage, Alaska 99508 a 8.... - ' 'r, Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: i ~v MEMORANDUM TO~ Jim Regg P.I. Supervisor I ~~ i~l ~~ (rb FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) ]NC W'-2 t 6 PRUDHOE BAY [JN POL W-216 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv;~ Comm Well Name: PRUDHOE BAY UN POL ~V-216 Insp Num: mitLG080 1 1 3 103624 Rel Insp Num: API Well Number: 50-029-23379-00-00 Permit Number: 20`7-168-0 Inspector Name: Lou Grimaldi Inspection Date: 1~13i2008 Packer Depth Pretest Initial 15 iVlin. 30 Min. 45 Min. 60 Min. We 1 W-216 ~jType Inj I N ~I TVD 4972 :,`'" IA j o i 4 40 o aoo~aooo p T ~ zo~t6ao ~TypeTest ~I srr !Test psi ~ Isoo~ ~ OA ~' too I aso ! azo i aoo ~ i Interval OT1~R P/F _P __ _ -~ Tubing, z6oo I 3270 ~ _ sz7o r 3z~o NOteS: Post-completion, pre-injection test perfromed on rig after landing tubing and setting packer. Inner AnulluslPacker portion only.)- ~~ T- ~ Friday, January 18, 2008 Page 1 of 1 MEMORANDUM To: Jim Regg ~ ~~ ~ ~) ~~~ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, January 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-2] 6 PRL~HOE BAY UN POL W-216 Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv ~t~- Comm Well Name: PRUDHOE BAY UN POL W-216 API Well Number: ~0-029-23379-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG080 1 1 3084242 Permit Number: 207-168-0 Inspection Date: 1!13;"2008 Rel Insp Num: Packer Depth ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ Well i' ~'-',t6 !Type Inj. N ! TVD ~ 4973 j IA ~ o ~' o ~ I o ~ o ~ P T i, ?o~t6so TypeTest "PT ~ Test psi I __ goo ~ tso~ goo ioo ioo ~ I Interval ort-iER p~F P ~ - Tubing o ~tso aoao ~ 4oao NOteS' Post-completion, pre-injection test perfromed on rig after landing tubing and setting packer. Tubing test portion only. e). J~1 '~ ~ Friday, January 18, 2008 Page 1 of 1 • Schlumber er 9 Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No W-216 Date Dispatched: 11-Jan-08 Installation/Rig Nabors 9ES Dispatched By: Franklin Medina LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Received By: I Please sign and return to: Drilling & Measurements LWD Division ~ (J~ 2525 Gambell Street, Suite 400 (( ~ ~ ~ 0'/L- ~~' " Anchorage, Alaska 99501 l fclarke3C~slb.com Fax:907-561-8317 a~~-l~~ ~~ ~ ~ ~ ~ SARAH PAL/N, GOVERNOR COwT~v~~~Aj~O ~ ~~v~-~ 333 W. 7th AVENUE, SUITE 100 a~-7 ilii 1.~~~j~~r~~~111~~•111111----777 01t ANCHORAGE, ALASKA 99501-3539 Robert Tlrpack PHONE (907) 279-1433 Engineering Team Leader FAx (so7> 27s-7542 BP Exploration Alaska Inc. PO Box 196612 Anchora e Al g , aska 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU W-216 BP Exploration Alaska Inc. Permit No: 207-168 Surface Location: 4904 FSL, 1176' FEL, SEC. 21, T11N, R12E. UM Bottomhole Location: 3420' FSL, 273' FWL, SEC. 15, 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely Daniel Seamount Commissioner DATED this 7 day of month, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~IVCu STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI~N ~~~ 4 '~ ~n~7 PERMIT TO DRILL ~-~ 20 AAC 25.005 ~'~~~~ QI) & ~~s Cnnl;. C~rnmission 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 sed for: ^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-216 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7081 TVD 5410 12. Field /Pool(s): Prudhoe Bay Field /Polaris Pool 4a. Location of Well (Governmental Section): Surface: 4904' FSL 1176' FEL SEC 21 T11N UM R12E 7. Property Designation: ADL 028263 , , . , , , Top of Productive Horizon: 3001' FSL, 333' FWL, SEC. 15, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 20, 2007 Total Depth: 3420' FSL, 273' FWL, SEC. 15, T11 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,070 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y-5959881 Zone-ASP4 10. KB Elevation Plan (Height above GL): 81.9 feet 15. Distance to Nearest well within Pool: 813' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 48 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2419 Surface: 1878 1 Casin Pr ra S c~ n T in D th -Bottom nt~ of ment .f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 34" 20" 91.5# A-53 Weld 80' Surface Surfa 109' 109' 260 sx Arctic Set A rox. 16" 13-3/8" 68# L-80 BTC 1300' Surface Surface 1300' 13 0' 561 sx AS 126 sx AS Lite 12-1 /4" 9-5/8" 40# L-80 BTC 7 ' rface Urfa 73' 3297' 482 sx DeepCrete, 308 sx Class'G', ~~ sx ourastone 8-3/4" 7" 26# L-80 TC-il 5925' Surface Surfa 5925' 4607' See Below 8-3/4" 7" 26# L-80 BTC-M 1156' 5925' 4607' 7081' 5410' 365 sx Class 'G' 19. 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 emerit olume MD TVD Conductor /Structural Surface Intermediate r in Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Bob Coolidge, 564-5776 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4166 Date %? ~ Terrie Hubble, 564-4628 Commission Use Ont Permit To Drill Number:oTa /6d~a API Number: 50-0~9~3,3 90000 Permit Approval Dat See cover letter for o h rre it m n Conditions of Approval: M `~1 ~~~~~~-~V ~\ ~ ~ 0 If box is checked, well may not be used to explore for, tt~st, or produce Coalbed methane, gas hydrates, or gas contained shales: ~`~~ pS`l ~0~ ~-C-S~ GS ~`U.~'t~(~ Samples Req'd: Yes ~No Mud Log Req'd: ~ Yes ~No pp \\ tt~ HZS Measures: Yes ^ No Directional Survey Req'd: 0 Yes ^ No Other: C~GVV`~G K~MO\sG.~ 0.000~~`~`~ ~ 1~0, , a04~C,a.S.Q3~,~ > J ~~ APPROVED BY THE COMMISSION Date , - ,COMMISSIONER Form io-ao,( I~eytss~ 12/2005 ~ Y / Submit In Duplicate ORIGINAL ~~6h Well Name: W-216i Drill and Complete Plan Summary Well Design: Grassroots Polaris Injector 3-'/z",9.2#, L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion API Number: TBD b AOGCC Estimated Start Date: December 20, 2007 O eratin da s: 18.4 Ri Nabors 9ES ODE: Bob Coolid a Geolo ist: G. Bernaski PE: E or Makarov TMD 7081' TVD RKB: 5410.4' RKB/GL 28.5'/53.40' RTE 81.90' Tar et X Y Z TVDss Townshi Ran a Section FNL FEL Surface 612,049 5,959,881 53.5 11N 12E 21 376 1176 To of O Sands 613,500 5,963,280 -4,920 11N 12E 15 2278 4946 BHL 613,432 5,963,698 -5,328 11N 12E 15 1859 5007 Formation Markers: Formation Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. G 1 -285 +/-50' No 128 8.7 SV6 -1205 +/-50' No 542 8.7 EOCU -1750 +/-50' No 788 8.7 SV5 -1855 +/-50' No 835 8.7 Base Permafrost -1885 +/-50' No 848 8.7 SV4 -2010 +/-50' Poss. Free Gas or Gas H drates 905 8.7 Fault 1 -2380 +/- 100' (See fault section for details SV3 -2460 +/-50' Poss. Free Gas or Gas H drates 1107 8.7 SV2 -2650 +/-50' P Gas Hedratesor 1193 8.7 SV1 -2960 +/-50' Poss. Free Gas or Gas H drates 1332 8.7 UG4 -3295 +/-50' Thin coal 1483 8.7 UG4A -3335 +/-50' Heary Oil between - 3335 and -3530' SS 1501 8.7 UG3 -3685 +/-50' Thin coals 1658 8.7 UG1 -4170 +/-50' No, water 1877 8.7 UG Ma -4525 +/-50' Heary Oil between - 4525 and -4555' SS 2036 8.7 UG Mb1 -4570 +/-50' Heavy Oil between - 4570 and -4615' SS 2057 8.7 UG Mb2 -4625 +/-50' No, water 2081 UG Mc -4690 +/-50' No, water 2111 8.7 SB Na -4760 +/-50' No, water 2142 8.7 SB_Nb -4785 +/- 25' No, water 2153 8.7 SB Nc -4815 +/- 25' No, water 2167 8.7 SB Ne -4823 +/- 25' No, water 2170 8.7 SB OA -4910 +/- 25' No, water 2160. 8.6 SB OBa -4955 +/- 25' Yes 2155-2205 8.4-8.6 SB OBb -4985 +/- 25' Yes 2218 8.6 SB OBc -5035 +/- 25' Yes 2241 8.6 SB OBd -5085 +/- 25' Yes 2212-2263 8.4-8.6 SB OBe -5155 +/- 25' Yes 2230-2270 8.4-8.6 SB_OBf -5195 +/- 25' Yes 2295 8.6 Base SB OBf -5245 +/- 25' No 2320 8.6 TD -5303 Casin~/Tubin~ Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Connection Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 34" Insulated 20" 91.5 A-53 WLD 80 GL 108.5/108.5 16" 13 3/8 68 L-80 BTC 1300 GL 1300 12-'/" 9-5/8" 40 L-80 BTC 3973 GL 3973/3297 8-'/" 7" 26 L-80 TC-II 5925 GL 5925/4607 8-3/" 7" 26 L-80 BTC-M 1156 5925/4607 7081/5410 Tubing 3-''/z" 9.2 L-80 TC-II 6832 GL 6832/5239 Note: Top production packer within 200' MD of top perforation X Ni le at 2500 TVD +/- for future SSSV if desired Mud Program & Disposal: Fluid System Equipment diagram on file with AOGCC for this rig, Nabors 9ES. 16" Second Conductor Hole Mud Pro erties S ud -Freshwater Mud Interval Densi PV YP PH Funnel Vis FL 0-1400'MD (SV6) 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 12-%" Surface Hole Mud Pro erties S ud -Freshwater Mud Interval Densi PV YP PH Funnel Vis FL 1400' - 3973' MD SV 1 8.8-9.5 30-55 45 - 60 9.0 - 9.5 225 - 250 8.0 8-%" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densi PV YP PH API Filtrate MBT 3973'-7081' MD (OBf TD) 8.8-9.3 12-18 18-24 9.0-10.0 <6 < 18 Completion Fluid+ +/- 9.Oppg Brine & 6.8p g Diesel Disposal of Drilling Mud & Cuttings No annular disposal in this well. Haul all drilling and completion fluids, and other Class II wastes, to DS-04 for disposal. Haul any and all Class I wastes to Pad 3 for disposal. Directional & Survey Program: Refer to attached Directional Plan 4b (Approved 10/22/2007) Distance to nearest Property Line boundary: 21,070 feet to PBU boundary i • Wells within 1/4 mi. of this injection well @ Top of Pool (=Mc): • No wells within 1/4 mile at Top of Pool (Mc). • The Plug Back leg of the W-204P61 multi-lateral is 813' distance (from planned W- 216i Wellbore) @ Schrader Bluff OBd in SB_OBd sand. • For pool interval, next closest wells are W-204 production legs (W-204 - 1389' (OBd), W-204L2 - 1391' (OBa), and W-204L1 - 1472' (OBc). Second Conductor Cementin Casin Size 13 3/8" 68 lb/ft L-80 BTC Two Sta a Job Basis Lead: none Tail: 400 feet Open hole volume + 350% planned excess + 80' shoe track. A Tam Port collar WILL be located at bottom of conductor 108.5' as a contin enc for cement to surface. Fluid Se uence and Volume: 1st Stage S acer 50 bbls of 10.0 MUDPUSH II Tail 93 bbls (561 sks) 15.71b/gal AS 1-Yield = .93 cu ft/sk 2" Sta e TAM 30 bbls of 10.0 ppg MUDPUSH II 21 bbls (26 sks) of 10.7 pg ASL -Yield = 4.63 cu ft/sk Temperature BHST ~ 35° F Surface Casin Size Surface Casin - 9 s/8" 401b/ft L-80 BTC Sin le Sta e Basis Lead: Pump annular volume within the 13 3/8" x 9 /5" annulus, pump open hole volume (OHV) + 350% excess in permafrost, pump OHV + 30% from BPF to TD. TOC at surface criteria. Tail: Open hole volume + 30% excess + 80' shoe track. Top of tail = 2973 ft. MD (1000' above 9 5/8" shoe). Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: Wash None 3 acer 100 bbls of 10.0 p MudPush II Lead 331 bbls (482 sks) 10.71b/gal DeepCRETE - Yield = 3.85 cuft/sk Tail 64 bbls (308 sks) 15.8 lb/gal Class G Yield = 1.16 cuft/sk ,followed 15 bbls (71 sacks) 16.3 Durastone - Yield = 1.18 cuft/sk Temp BHST ~ 80° F Surface Shoe Integrity Test: Perform Formation Leak Off Test within 20' - 50' from 9 5/g" shoe Production Cementin Casin Size Production Casin - 7" 261b/ft L-80 BTC-M x TC-II -Sin le Sta e Basis Tail; O en hole volume + 30% excess. TOC to 4973' MD (1000' below shoe/1049' above Ma). Fluid Se uence & Volume: This cement 'ob is lanned for one sta e. Wash None S acer 30 bbl of 11. g MUDPUSH II Tail 76.5 bbl (365 sks) 15.8 Class G + Latex - Yield = 1.17 cuft/sk Temp BHST ~ 105° F 8-3/" Hole Section Cement Inte ri A USIT log will be run on wireline from ~20' above PBTD to surface. Well Control Surface hole and second conductor will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. A function pressure test of the casing rams is reguired after changing the casing rams. Anticipated surface pressures will not exceed 3,000psi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics for Nabors Rig 9E5 are on file with the AOGCC. Second Conductor Interval Integrity: • Diverter: • Maximum anticipated BHP: • Planned test: • Kick Tolerance: Surface Interval Integrity: • Diverter: • Maximum anticipated BHP: • Planned test: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 663 psi - SV6 (8.7 ppg EMW @ 1467' TVD) Function Test NA Hydril GK, 21-1/4", 2000 psi 1491 psi - SV 1 (8.7 ppg EMW @ 3297' TVD) Function Test 3,500 psi surface pressure test NA Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to 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. Production Interval Integri • BOPE: • Maximum anticipated BHP: • Maximum Anticipated surfa • Planned BOP test pressure: • 7" Casing Test: Estimated BHT: Hydril, 13-5/8", 5000 psi 2419psi - OBf (8.6 ppg EMW @ 5410' TVD) ce pressure: 1878 psi -Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular 4,000 psi surface pressure test 110°F @ 5411' TVD Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control /Reservoir Pressures: a. The Schrader Bluff sands are expected to be pressured at 8.4-8.7 ppg EMW. b. Kick tolerance for 9 5/8" casing and 3500psi casing test pressure: Maximum Influx Volume = 97.1 bbls with 9.3 ppg and maximum pore pressure of 8.7ppg EMW. 2. Broaching: New wells recently drilled from surface on the North side of the W pad have experienced drilling mud broaching into adjacent well cellars due to permeable, shallow unconsolidated gravel and rock formations near surface. Risks will be mitigated by: a. Adjacent surface wells will be inspected prior to drilling this well, and topped offwith cement if none is visible upon inspection. b. 13 3/8" casing will be set at 1300 feet MD, and 9 5/8" casing will be set into the SV1. c. LC material may be added if needed. d. Adjacent wells will be monitored until 9 5/8" casing is cemented into 12 '/" surface hole. 3. Hydrates and Shallow gas: a. Gas hydrates and/or free gas may be present in the SV4 thru SV 1 within 12 ''/a" surface hole interval, below base Permafrost. Use standard operating procedures for hydrates. Set surface casing below deepest SVl sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. 4. Heavy Oil: Heavy oil is expected in the UG4A and M sand intervals which could plug shaker screens. 5. Running Gravels: Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. "Obstructions" including wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See W Pad Data Sheet for details. 6. Faults /Lost Circulation / Breathinj±: Formation Where Encounter Fault MD Intersect tvdss Est. Throw Throw Direction Uncertain Fault #1 -SV4 2866 -2380 -50' West +/-150' M.D. a. No Breathing is expected. b. No faults are expected in the reservoir section c. Minor LC possible in Oba, OBc, OBd due to depletion. Utilize the LCM decision tree. 7. Stuck Pipe & Casing a. 9 5/8" & 7" Casing: low probability of differential sticking. b. Assure clean hole prior to running casing, follow the centralizer program, keep casing moving while RIH, and reciprocate and rotate while cementing all casing strings. 8. Hydrogen Sulfide a. Standard Operating Procedures for H2S precautions should be followed at all times. b. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Watch for possible H2S when drilling near wells on MI injection. c. All W Pad gas lift wells are ex ected to have H25 levels in the 5 to 60 m ran e. #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-201 20 m 11/1/2005 #2 Closest BHL Well H2S Level W-21 15 m 1/15/2007 Max. Recorded H2S on Pad/Facility W-O1 60 ppm 8/16/2005 Wells within 114 mi. of this injection well Top of Pool (=Mc) Well Name Dist, Ft. Annulus Inte rit Comments W-204PB1 813' SB OBd PB le of W-204 muki-lateral in SB OBd sand. Well Status Com letion Schrader Bluff In'ection Well No wells within 1/4 mile at Top of Pool (Mc). For pool interval, other than W-204PB1 @813' from W-216 @Top OBd, next closest wells are W-204 production legs (W-204 -1389' (OBd), W-204L2 - 1391' (OBa), Comments and W-204L1 - 1472' OBc . CONSULT THE W PAD DATA SHEET & THE WELL PLAN FOR ADDITIONAL INFORMATION W-216i -Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. Weld on 13 '/S" string butt-weld sub. 2. Prepare pad and 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 & rack back sufficient 5" DP for 16" hole. 2. MU 16" drilling assembly with MWD/GR and drill surface hole to approximately top of SVI. CBU, POOH, LD 5" DP & BHA. 3. Run and cement the 13 '/g", 68 lb/ft casing as a two stage job providing 400' of annulus height at the shoe, then open TAM collar located at the bottom of 20" conductor @ 108' MD, and pump mud push followed by cement to surface. Land casing in the butt-weld sub. 4. PU & stand back 4" DP as needed. MU 12-'/" drilling assembly with MWD/GR. Directionally drill surface hole to TD @ ~ 80 feet above the UG4 with one BHA. CBU, short trip to 13 3/s" shoe, RIH to TD, CBS, then POOH and lay down BHA. 5. Run and cement the 9 5/8", 40.0 lb/ft. surface casing to surface, displacing cement with mud. At plug bump, test the 9 5/8" casing to 3,500 psi for 30 minutes. 6. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to rams @ 4,000 psi / 250psi, and annulars to 2500 psi/ 250psi. 7. MU 8-3/"drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Drill shoe track and displace to new 8.8 ppg LSND mud. Drill new formation to 20-50' below 9-5/8" shoe and perform LOT. 8. Drill ahead to production hole TD (Z50' below below OBe top). Clean and wipe hole. POOH. 9. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater, and pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 10. PU DPC guns and RIH w/ 100' of 4.5" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR/CCL for gun correlation. 11. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate the OBa, OBc, and OBd sands. POOH LD DP and guns. 12. 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. 13. Run USIT/CBL log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. ! i 14. Run the 3-lh", 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 threaded tubing. Top packer must be within 200' of OBa perfs. 15. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 16. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 17. Freeze protect the well to 2,500' TVD by pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to a-tube into tubing. 18. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'h" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 19. 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. SEC 16 SEC 21 N N 2414.5 ~- - ~ _ i 16 `. rUp'9RO 15 ~ p/~44f L7 ~ W PA C~ _ P a WEST ENO NO. 1 Q - 21~ ~ _ - ~ KUP UK STA __ ^ 201 -_ - .. .____- NO.t 22 ^ 200 ^ 24 ^ 23 STAGING AREA w :2; W-PAD VICINITY MAP - ^ 20 N T S 33^ ^ 19 . . . 1 53 32^ ^ 18 523 31 ^ 30 ^ ^ 17 . 1 s ~}~-,_ ~ O F q~ `mot() °° so3 29^ 211 ^ ^ 14 .212 °°q .`P~°°°° °s ~ ° °°°~'9 z7^ ° s 26^ .2101 ~ o 49 ~ °° ~ ~~ `!~ _ 25^ ~ ^ 215 ^ 207 o M 0°°°°°°°°°°°°°°°°°°°°°°°o°°° ~ _ N W zo9 o°°°°°°°°°°°°°°°a°°°° ° Leonard J. O'Hanley ~° ~ ° ~ ,°° ^ 1 ~ ° ~ ° W I z s 11386 °° ~°°° 34 351It 3 ~ 4 °°°° "'w'ESSIONA~ ~'~ 36 ~ I 5 37 + 7 38 } ~ 6 39* 8 SURVEYOR'S CERTIFICATE 40 400 ~ ' ' r 9 I HEREBY CERTIFY THAT I AM 10 PROPERLY REGISTERED AND LICENSED 42 ~ 11 TO PRACTICE LAND SURVEYING IN SPARE ' •12 THE STATE OF ALASKA AND THAT 44~ }205 THIS AS-BUILT REPRESENTS A SURVEY 1203 MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL ,~ ' DIMENSIONS AND OTHER DETAILS ARE rn _ b CORRECT AS OF SEPTEMBER 18, 2007. W __ ~I NOTE S. ---- 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. BASIS OF LOCATION IS W PAD MONUMENTS W-1 & W-2. LEGEND 3. BASIS OF ELEVATION IS W PAD MONUMENT W-2. AS-BUILT CONDUCTOR ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. ^ EXISTING CONDUCTOR 5. PAD MEAN SCALE FACTOR IS 0.99991426. 6. DATE OF SURVEY: SEPTEMBER 18, 2007. 7. REFERENCE FIELD BOOK: W007-17 PGS. 68-71. 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-2141 Y= 5,959,865.97 N= 2,672.02 70'17'57.473" 70.2992981' 52 4 4,889' FSL ' X= 612,049.02 E= 2,130.03 149'05'33.116" 149.0925322' ' FEL 1,176 W-216i Y= 5,959,880.87 N= 2,686.93 70'17'57.620" 70.2993389' 53 4' 4,904' FSL ' X= 612,048.88 E= 2,129.89 149'05'33.113" 149.0925314' . FEL 1,176 CHECKED: HACKEL! DAtE: 9/21 /0" DRAWING: ~~(~(~ (~ FR807 WOW 07- ~°a 1J~~0~a JoD No: SCALE: JJ KWH REVISION BV CHK oHww•ce. w>ss. sssos 1"=300 by woA w-PAS SHEET: AS-BUILT CONDUCTOR WELLS W-214i & W-2161 1 of 1 NEILHEAO = ~ FMC ~y _21 ~ Propose d ACTUATOR = 3aker Hydraulic C8. EI_El/ _ _ 3F. ELEV = :OP= ~~~ _ 300 /lax Angle = 47.5 deg ~tum MD = _ ~~_~ )atum ND =~ ~~ 4-1/2" TBG, 12.6#, L-80, 29' TG11, .0152 bpf, ID= 3.958" 13-3/8" CSG, 68#, L-80, BTC, ID = 12.415" 1300' 9-5/8" CSG, 40#, L-80, BTC, ID = 8.835" ~-~ 3973' Y 7" CSG, 26#, L-80, TG11, .0383 bpf, ID = 6.276" 4476' Minimum ID = 2.75" @ xxxx' 3-1 /2" HES XN NIPPLE sAFN01'1:5. ~ r~ ~ bb7.~ IS PUtt '7'0 REL BUT CAN ALSO BE Rf3EASE0 BY PRESSURE DO NOT EXC®4300 PSI. TEST PRESSURE PKR AO TI~If~ = l:d~r. DCI 1d449 DCI IC RII~ AC DKI? AD T1111f71"'"* 29' J-~ 4-1/2" XO 3-1/2", ID = 2.992" 341' 3-1/2" HES X NIP, ID = 2.813" 6 6442 MMG DMY RK WATER INJECTION MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 6536 MMG-W RK 4 6575 MMG-W RK 3 6649 NMG-W RK 2 6688 MMG-W RK 1 6761 MMG-W RK 3-1/2" HES X NIP, ID = 2.813" MARKER JOINTw/ RA TAG OA 6477 MARKER JOINT w / RA TAG REF LOG: SLB Reaftime LWD A NGLE AT TOP PERF: Note: Refer to Production DB for histor~al perf data S2E SPF INTERVAL Opn/Sqz DATE 4-1l2" 5 Oba xxxx'-xxxx' O 4-1/2" 5 Obc xxxx'-xxxx' O 4-1/2" 5 Obd xxxx'-xxxx' O ~3-1/2" TBG, 9.2#, L-80, TGII, .0087 bpf, ID= 2.992" PBTD 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 I 6832' I 7080' ~~ 6511' H 7" HES A HR PKR w / 114" FEED THRU, ID = 2.920" . 6524' PHOENDC PRES/TEMP S ENSOR SUB, ID = 2.992" 6604' 3-1/2" HES X NIP, ID = 2.813" 6624' 7" HES AHR PKR w J 1!4" FEED THRU, ID = 2.920" 6638' H PHOENDC PRESlTEMP SENSOR SUB, ID = 2.992" 6717' H 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 6740' ~3-1/2" HES X NIP, ID= 2.813" 6790' 3-1/2" HES X NIP, ID = 2.813" 6810' 3-1/2" HES XN NIP, ID = 2.75" 6832' 3-1/2" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/27/07 BJP Proposed WBD (Tube Ver 1) 11/27/07 RBC revised 13 3/8 & 9 5/8" depths ORION UNfT WELL: W-216i PERMR No; xxxxx API No; 50-029-xxxxx Sec, Tw p, Rge BP Exploration (Alaska) by W-216 (P4) Proposal Schlumberger Report Date: 28-Nov-07 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: Well: W-PAD I W-216 Plan Plan W-216 Borehole: Plan W-216 ~ p UWOAPI#: ~ 50029 e Survey Name 1 Date: W-216 (P4) /January 15, OS Tort 1 AHD 1 DDI 1 ERD ratio: 72.899° / 4143.96 ft / 5.597 10.766 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.29933889, W 149.09253153 location Grid NIE YIX: N 5959880.870 ftUS, E 612048.880 ftUS Grid Convergence Angle: +0.85435944° 5.42 28.71 517.69 599.59 7.41 27,08 617.06 698.96 9.40 26,14 715.98 797.88 10.00 25.93 745.36 827.26 11.40 25,93 814.33 896.23 13.40 25.93 911.99 993.89 15.40 25.93 1008.84 1090.74 17.40 25.93 1104.77 1186.67 19.40 25.93 1199.65 1281.55 19.52 25.93 1205.00 1286.90 Comments Measured Inclination Azimuth Subsea TVD TVD Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft k k ft de de 1100 ft Index ftUS ftUS K I t U.UU U.UU 45.00 -131.90 U.UU U.UU U.UU U.UU -- U.UU KOP Bld 1.5/100 300.00 0.00 45.00 218.10 300.00 0.00 0.00 0.00 HS 0.00 G 1 366.90 1.00 45.00 285.00 366.90 0.53 0.41 0.41 HS 1.50 Crv 2/100 400.00 1.50 45.00 318.09 399.99 1.19 0.93 0.93 22.31 L 1.50 500.00 3.44 32.23 417.99 499.89 5.32 4.39 3.45 9.55E 2.00 Crv 2/100 13-3/8" Csg Pt SV6 EOCU 600.00 700.00 800.00 829.81 900.00 1000.00 1100.00 1200.00 1300.00 1305.68 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 1910.98 Survey 1 DLS Computation Method: Minimum Curvature / Li Vertical Section Azimuth: 20.770° ~ Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table TVD Reference Elevation: 81.90 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.40 ft relative to MSL Magnetic Declination: 23.224° Total Field Strength: 57647.310 nT Magnetic Dip: 80.872° Declination Date: January 15, 2008 Magnetic Declination Model: BGGM 2007 North Reference: Title North Total Corr Mag North -> True North: +23.224° 12.94 11.06 7.32 6.04E 2.00 24.02 20.94 12.52 4.42E 2.00 38.57 34.02 19.05 3.49E 2.00 43.57 38.53 21.26 HS 2.00 56.55 50.26 26.96 HS 2.00 U.UU b9b923tiU.i3/ 0.00 5959880.87 0.00 5959881.29 0.29 5959881.81 1.29 5959885.31 1.86 5959892.04 2.26 5959902.00 2.57 5959915.17 2.65 5959919.71 2.82 5959931.52 77 .94 69.57 36.35 HS 2.00 3.03 5959950.97 102 .72 91.94 47.23 HS 2.00 3.21 5959973.50 130 .84 117.34 59.58 HS 2.00 3.37 5959999.07 162. 28 145.73 73.38 HS 2.00 3.51 5960027.67 164. 17 147.43 74.21 HS 2.00 3.52 5960029.38 ti1'LU4tf.tit3 N /U.29933t3tf9 W 149.09253153 612048.88 N 70.29933889 W 149.09253153 612049.29 N 70.29934002 W 149.09252817 612049.79 N 70.29934141 W 149.09252403 612052.26 N 70.29935087 W 149.09250360 612056.03 N 70.29936910 W 149.09247229 612061.08 N 70.29939610 W 149.09243015 612067.42 N 70.29943183 W 149.09237722 612069.56 N 70.29944416 W 149.09235937 612075.08 N 70.29947618 W 149.09231322 612084. f 9 N 70.29952896 W 149.092 612094.73 N 70.29959007 W 149.0921 612106.69 N 70.29965945 W 149.09204908 612120.07 N 70.29973701 W 149.09193729 612120.88 N 70.29974166 W 149.09193060 21.40 25.93 1293.37 1375.27 197 .00 177. 08 88.62 HS 2.00 3.64 5960059. 24 612134 .85 N 70 .29982266 W 149.09181385 23.40 25.93 1385.82 1467.72 234 .96 211. 36 105.29 HS 2.00 3.75 5960093. 76 612151 .00 N 70 .29991630 W 149.09167889 25.40 25.93 1476.88 1558.78 276 .11 248. 51 123.36 HS 2.00 3.86 5960131. 17 612168 .51 N 70 .30001780 W 149.09153259 27.40 25.93 1566.44 1648.34 320 .39 288. 50 142.80 HS 2.00 3.96 5960171. 45 612187 .35 N 70 .30012705 W 149.09137512 29.40 25.93 .1654.40 1736.30 367 .77 331. 28 163.60 HS 2.00 4.05 5960214. 52 612207 .51 N 70 .30024392 W 149.09120668 31.40 25.93 1740.64 1822.54 418 .17 376. 79 185.73 HS 2.00 4.14 5960260. 36 612228 .95 N 70 .30036825 W 149.09102747 31.62 25.93 1750.00 1831.90 423. 88 381. 95 188.24 HS 2.00 4.15 5960265. 55 612231. 39 N 70. 30038235 W 149.09100715 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-216 Plan\Plan W-216\Plan W-216\W-216 (P4) Generated 11/28/2007 8:40 AM Page 1 of 3 Comments Measured Inclination Azimuth SulrSea ND ND Vertical NS EW Grawty DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS row0.3w JL.JJ LA.yJ I/aU.VV 1a07.`JU wwL.Dw 3`Ja.aV l`Jo.w3 I7J L.VU 4.1a DJOVL6L.OL OILL3J.3L IV /V.3VV4La30 W 74`J. uplu`JwvaL 2000.00 33.40 25.93 1825.07 1906.97 471.54 424.98 209.16 HS 2.00 4.22 5960308.89 612251.66 N 70.30049990 W 149.09083770 SV5 2036.01 34.12 25.93 1855.00 1936.90 491.47 442.98 217.91 HS 2.00 4.25 5960327.01 612260.14 N 70.30054907 W 149.09076683 End Bld 2060.24 34.61 25.93 1875.00 1956.90 505.09 455.28 223.89 --- 2.00 4.27 5960339.40 612265.94 N 70.30058267 W 149.09071840 Base Perm 2072.39 34.61 25.93 1885.00 1966.90 511.96 461.49 226.91 --- 0.00 4.27 5960345.65 612268.86 N 70.30059963 W 149.09069396 Bld 2/100 2084.54 34.61 25.93 1895.00 1976.90 518.84 467.69 229.93 HS 0.00 4.28 5960351.90 612271.79 N 70.30061658 W 149.09066952 2100.00 34.92 25.93 1907.70 1989.60 527.62 475.62 233.78 HS 2.00 4.29 5960359.88 612275.52 N 70.30063824 W 149.09063830 2200.00 36.92 25.93 1988.69 2070.59 586.04 528.38 259.43 HS 2.00 4.36 5960413.01 612300.38 N 70.30078236 W 149.09043056 SV4 2226.75 37.45 25.93 2010.00 2091.90 602.14 542.92 266.50 HS 2.00 4.38 5960427.66 612307.24 N 70.30082209 W 149.09037329 2300.00 38.92 25.93 2067.57 2149.47 647.24 583.64 286.30 HS 2.00 4.43 5960468.66 612326.42 N 70.30093333 W 149.09021 3 2400.00 40.92 25.93 2144.26 2226.16 711.14 641.35 314.36 HS 2.00 4.50 5960526.78 612353.62 N 70.30109098 W 149.0899 2500.00 42.92 25.93 2218.67 2300.57 777.68 701.42 343.58 HS 2.00 4.56 5960587.28 612381.93 N 70.30125510 W 149.0897 2600.00 44.92 25.93 2290.70 2372.60 846.75 763.80 373.91 HS 2.00 4.62 5960650.09 612411.33 N 70.30142550 W 149.08950339 2700.00 46.92 25.93 2360.26 2442.16 918.29 828.40 405.32 HS 2.00 4.68 5960715.14 612441.77 N 70.30160197 W 149.08924896 Fault Crossing 2729.05 47.5 25.93 2380 2461.9 939.53 847.57 414.64 HS 2 4.7 5960734.45 612450.81 N 70.30165434 W 149.08917345 End Crv 2746.07 47.84 25.93 2391.46 2473.36 952.06 858.88 420.15 --- 2.00 4.71 5960745.85 612456.14 N 70.30168525 W 149.08912888 SV3 2848.18 47.84 25.93 2460.00 2541.90 1027.44 926.95 453.25 --- 0.00 4.74 5960814.40 612488.22 N 70.30187121 W 149.08886076 SV2 3131.25 47.84 25.93 2650.00 2731.90 1236.42 1115.65 545.01 --- 0.00 4.83 5961004.43 612577.15 N 70.30238671 W 149.08811747 SVl 3593.10 47.84 25.93 2960.00 3041.90 1577.38 1423.53 694.74 --- 0.00 4.95 5961314.48 612722.25 N 70.30322777 W 149.08690464 9-5/8" Csg Pt 3973.01 47.84 25.93 3215.00 3296.90 1857.85 1676.79 817.89 --- 0.00 5.03 5961569.52 612841.61 N 70.30391961 W 149.08590692 UG4 4092.20 47.84 25.93 3295.00 3376.90 1945.84 1756.24 856.53 --- 0.00 5.06 5961649.53 612879.06 N 70.30413666 W 149.08559390 UG4A 4151.79 47.84 25.93 3335.00 3416.90 1989.84 1795.96 875.85 --- 0.00 5.07 5961689.54 612897.78 N 70.30424518 W 149.08543739 UG3 4673.24 47.84 25.93 3685.00 3766.90 2374.80 2143.57 1044.89 --- 0.00 5.15 5962039.59 613061.60 N 70.30519475 W 149.08406781 UG1 5395.81 47.84 25.93 4170.00 4251.90 2908.24 2625.25 1279.13 -- 0.00 5.25 5962524.67 613288.62 N 70.30651057 W 149.08216977 Crv 4/100 5868.27 47.84 25.93 4487.12 4569.02 3257.04 2940.20 1432.29 105.86E 0.00 5.30 5962841.84 613437.05 N 70.30737091 W 149.08092859 5900.00 47.50 24.28 4508.49 4590.39 3280.43 2961.44 1442.25 104.75E 4.00 5.32 5962863.23 613446.69 N 70.30742894 W 149.08084792 Ma 5924.39 47.26 22.99 4525.00 4606.90 3298.35 2977.88 1449.44 103.88E 4.00 5.33 5962879.77 613453.64 N 70.30747384 W 149.08078961 Mb1 5990.33 46.68 19.47 4570.00 4651.90 3346.54 3022.80 1466.90 101.47E 4.00 5.36 5962924.94 613470.42 N 70.30759654 W 149.08064811 6000.00 46.61 18.95 4576.64 4658.54 3353.57 3029.44 1469.22 101.12E 4.00 5.36 5962931.61 613472.64 N 70.30761469 W 149.0806 Mb2 6070.07 46.13 15.13 4625.00 4706.90 3404.16 3077.91 1484.08 98.48E 4.00 5.39 5962980.30 613486.78 N 70.30774710 W 149.08050884 6100.00 45.97 13.49 4645.77 4727.67 3425.57 3098.79 1489.41 97.34E 4.00 5.40 5963001.25 613491.79 N 70.30780413 W 149.08046566 Mc 6163.46 45.70 9.97 4690.00 4771.90 3470.51 3143.34 1498.66 94.89E 4.00 5.43 5963045.93 613500.38 N 70.30792585 W 149.08039062 6200.00 45.59 7.93 4715.55 4797.45 3496.08 3169.15 1502.72 93.46E 4.00 5.44 5963071.79 613504.06 N 70.30799634 W 149.08035766 Na 6263.46 45.49 4.38 4760.00 4841.90 3539.90 3214.17 1507.58 90.97E 4.00 5.47 5963116.87 613508.24 N 70.30811932 W 149.08031826 Nb 6299.12 45.48 2.38 4785.00 4866.90 3564.16 3239.55 1509.08 89.57E 4.00 5.48 5963142.27 613509.36 N 70.30818866 W 149.08030609 6300.00 45.48 2.33 4785.62 4867.52 3564.76 3240.18 1509.10 89.53E 4.00 5.48 5963142.90 613509.37 N 70.30819038 W 149.08030588 Nc 6341.92 45.52 359.98 4815.00 4896.90 3592.92 3270.07 1509.70 87.89E 4.00 5.50 5963172.79 613509.53 N 70.30827203 W 149.08030097 Ne 6353.34 45.54 359.34 4823.00 4904.90 3600.52 3278.22 1509.65 87.44E 4.00 5.50 5963180.94 613509.36 N 70.30829430 W 149.08030135 6400.00 45.65 356.73 4855.65 4937.55 3631.26 3311.53 1508.51 85.61 L 4.00 5.52 5963214.23 613507.72 N 70.30838530 W 149.08031057 OA 6477.96 45.97 352.40 4910.00 4991.90 3681.39 3367.15 1503.21 82.60E 4.00 5.54 5963269.76 613501.59 N 70.30853727 W 149.08035340 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-216 Plan\Plan W-216\Plan W-216\W-216 (P4) Generated 11/28/2007 8:40 AM Page 2 of 3 Measured Vertical Gravity Directional Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS tnacrv/ iargell b4yL.3b 4b.U5 35"I.b"I 4yZU.UU 5UU7.yU 3byU .4/ 33//.41 15U7.// -- OBa 6542.79 46.05 351. 61 4955.00 5036.90 3722. 18 3413.33 1496.47 -- OBb 6586.01 46.05 351. 61 4985.00 5066.90 3749. 35 3444.12 1491.93 -- OBc 6658.06 46.05 351. 61 5035.00 5116.90 3794. 65 3495.43 1484.36 --- OBd 6730.10 46.05 351. 61 5085.00 5166.90 3839. 95 3546.75 1476.79 --- Target 2 6794.94 46.05 351 .61 5130.00 5211.90 3880 .71 3592.93 1469.98 --- 6830.97 46.05 351 .61 5155.00 5236.90 3903 .36 3618.59 1466.20 --- OBe 6830.98 46.05 351. 61 5155.01 5236.91 3903. 37 3618.60 1466.19 --- OBf 6888.60 46.05 351. 61 5195.00 5276.90 3939. 60 3659.64 1460.14 --- OBf Base 6960.65 46.05 351. 61 5245.00 5326.90 3984. 89 3710.95 1452.57 --- TD / 7" Csg 7080.97 46.05 351 .61 5328.50 5410.40 4060 .54 3796.65 1439.93 --- Lestal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4903 FSL 1176 FEL S21 T11N R12E UM 5959880. 87 612048.88 Target 1 : 3001 FSL 4947 FEL S15 T11 N R12E UM 5963280. 00 613500.00 Target 2 : 3216 FSL 4978 FEL S15 T11 N R12E UM 5963495. 00 613465.00 BHL : 3420 FSL 5008 FEL S15 T11 N R12E UM 5963698. 23 613431.92 4.UU 5.55 5y53LtSU .UU b135UU.UU N /U.3UtS5(i5'Ly W 14y.UtfU3b5U5 0.00 5.55 5963315. 83 613494.16 N 70.30866343 W 149.08040792 0.00 5.55 5963346. 55 613489.16 N 70.30874754 W 149.08044466 0.00 5.56 5963397. 74 613480.83 N 70.30888773 W 149.08050590 0.00 5.57 5963448. 93 613472.50 N 70.30902792 W 149.08056714 0.00 5.57 5963495 .00 613465.00 N 70.30915409 W 149.08062226 0.00 5.58 5963520 .60 613460.83 N 70.30922419 W 149.08065288 0.00 5.58 5963520. 61 613460.83 N 70.30922422 W 149.08065289 0.00 5.58 5963561. 55 613454.17 N 70.30933634 W 149.08070187 0.00 5.59 5963612. 74 613445.83 N 70.30947653 W 149.080 0.00 5.60 5963698 .23 613431.92 7 N 70.30971066 W 149.080 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-216 Plan\Plan W-216\Plan W-216\W-216 (P4) Generated 11/28/2007 8:40 AM Page 3 of 3 a by ~~~ WELL FIELD STRUCTURE W-216 (P4b) Prudhoe Bay Unit - WOA W-PAD Magnellc Parame,ars Burlaca LOCaWn n'nD2] NasAa SIMe Plates. Zme 44. US Fcet MlscelUneols Model aGGA13011] Dip .. 9]2` Da,e January 111 3IXi9 N)0 t)5)fi39 onnng 59590900]'IUS GN COnv -005435944` W~2t6 Plan NDReI Ro,ary Tabk 19. 901abnvx MSLI Maq Dec 2323'" f5'. 5)64)0 nT W149533.t t] Eaan,g'. 6120a0001NS Style Faq 0.9999142622 Plan W~3161P4b1 Srvy Date'. h vamps) 2B. 300] 0 800 1600 2400 3200 4000 U 800 1600 ~ 2400 0 0 ou c a~ c~ 0 3200 H 4000 4800 5600 RTE ...... _.~ ......................_...._i........_...................._..!_._............... ...... ...__....._........._.___._.........................................c KOP Bld 7.5/100 .. _.. _. .. _.. _.. _.. _.. _.. _.. _.. _. }-.._.._..-..-.. _.. _.. _..-t._.._..-..-..-..-..-..-....,.-..-..-..-..-..-..-.._.. y.._.. _.. _.. _.. _.. _.. _.. _.. ~ cN v~oo _~crvznoo \~ _~ Target 2 TD / 7" Csl _....._M_._~_...._._...._ ............................._......................._.._....__...........................__...._........._............,...... _......., ......_ _.... w-zts U 800 1600 2400 3200 4000 4800 5600 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 20.77°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V ~~ ! • ~~~ HELL FIELD STRUCTURE W-216 (P4b) Prudhoe Bay Unit - WOA W-PAD Magnel+c Pa+am ele+s SuAa+n Ln:auen NFD21 Kaska Stale PUnna Zone 04. US Feel Mncellarieous Motel. RGGM 200] OiV U:+le anuar 08 Lal. 0 piny 9~~08]'IUS GnX GOnv •085435944' Sbl. W-1t6 Plan NO ReI Rdary Taple 191.90 X apove MSLI Mag Dec. N23231' F5. 5]8.1]0 ni 20 Lon W'a953]t2',3 Eating 80i 20d8 B8 M13 Srale Fact 09999142822 PMn. W~2t6 (Pdpl Srvy Dale-NOVemter 28. 2001 -500 0 500 1000 1500 2000 3500 3000 2500 n n n Z 0 0 Y? 2000 c m U ~ 1500 v v 1000 500 BII . .................~.............. E 13-318" Csg Pt\ 0 Crv 2/100 Crv 21100 \ • KOP Bld 1.51100 End Paull Crossi 'P W-216 FII 2450ss 3500 3000 2500 2000 1500 1000 500 0 -500 0 500 1000 1500 2000 «< W Scale = 1(in):500(ft) E »> a1NMl { cuf i M-3'_1N-t') ~ _ 01 ?B00 .,., jK , =+KB + 36 ;t5 W ?,t 'f: = N-i_JN-3_~1 ill ~ M '11 ~ i2 __ '_UeB 4 v L ~} 3f 5 7] r 'tp 70 69 ~K , ~. 6' _ `NIB ~'. Cb il'-I Y~N-lY4l .IP11; ~ h_ l~ ti± _. s41 I ` \. M `'Y 26 IOKO ~,t~D `rs '_3 ' ~" :Ti 1; 4 .nay dZ ~ a3 11 ~{\~.. ~ a' ~ 11 ' a 1C-21? rN"-21?I ~ 1, it - K1 ~+15J 1w u \` ~= ~_ 1R` 71~ ~ }' 2a~"~. . 4t N-?fi fN-_'641 ih 5(Nl • • Field: Prudhoe Bav Site: PB ~V Pad Nell: Plan W-216 Wellpath: Plan W-216 ~ .S ~~~~ I w~ E~ ~~ w-N_+wc+w-2w1°f N.2osra-'(13PlS11 p~,~ I ', w11M 216 V /'y\' ~J Y 1a I *i o`1 ;, 'J "x ~, ~ . z~~~~ .r N-`?tN-'?1 i4 v0 I N ~:1 IN-211 N9 M ~` N' ~~ Kn / \ flJl K3 / y ~ I ~ K3 / is ~ f, KI I 1~ \ NNf I ~1 ~Y/ I \ wu ' ~ '~ ' qy -"N - 1'Isn N-'_U7 JPlsn N-'021 _. _~ / '1 -pl 7~~ ys ~f en ~ Kn ~ /A~ A_ N".u1N _1a1 a[. 4h nA Y a$ _ 6 i< ~~ 1*~ ~~~ ~ N-'I rN-'_I 41 ~ ~ ~ i' a? ~ r ti I Nt t 3: as 7p l "a- bt 3J ~K ~ aK ~ ~ yJ N1N q ~ _ ~f i'Y a / Di W x ~' ~ Y 2 ~ r~ a K / ' 1f as .~ aB ,~ ~; 33 ~ J12 . ~` ~ .. 4 i _s Kw ? _ ~? ,~ " ~"" 7 a >12 R sz . l 1 T ~ ?a it i4 ~ « ~I Ifp tr 2a j- M_fp-22a I aK n a' ~*.. ~ w b 3' KI a6 .. as ~ y(1 if ~~ .1p 'o Li -' }~{ Y T. it ~- K b+l l l u 7r ~ +w n ~. :JO 'K a' ' Je ^^_h , al 20 ~° u.' " I, w IJ _ ~ - a - - 1 i. 1 a- ~ .. .I'~'_ 25 N'-21'fN'-212f 500 1000 1300 2000 2SW 1\esfl-1'1asf1'~1 (3000;in~ • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Wednesday, November 28, 2007 Bob Coolidge BP Exploration (Alaska) Inc. • Prudhoe Bay W-216 (P4b) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Proaram: Instrument Type Start Depth End Depth GYD GC SS 28.50' and 600.00' and MWD -Standard 600.00' and 1300.00' and MWD +IFR + MS 600.00' and 1300.00' and MWD +IFR + MS 1300.00'md 3910.00'md MWD +IFR + MS 3910.00' and 7080.97' and Close Approach Analysis results: Under method (2), note. All wells pass major risk. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillina Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 11/28/2007 ' ~ ~ BP Alaska Anticollision Report Company:_ BP Amoco Date: 1.1/28!2007 Time: 08:52.5$ Page: 1 Field: Prudhoe Bay ~~ Reference Site: PB W Pad Co-ord-nate(NE)ReTerence: Well: Plan W-216, True North Reference Well:. PIanW-21.6 Vertical (`CVD) Reference: W-216 Plan 82.0 Reference Wetlpath: Plan W-216 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1[M~IitBoeells in thisRlrrhtJpal Plan & PLANNED PROGRAM -,'I Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7080.97 ft Scan Method: Trav Cylinder North ILMaximum Radius: 905.25 ft ----- _ - - - - --- Error Surface Elli se + Casin - ~ -- - --- -- - _- _-_- p 9 i Survey Program for Definitive Wellpath ___ -- _- ~I Date: 6/11/2007 Validated: No Version: 6 Planned Erom To Survey Toolcode Tool Name ', ft ft 28.50 600.00 Planned: Plan #4 V2 GYD-GC-SS Gyrodata gyro single shots '~ 600.00 1300.00 Planned: Plan #4 V2 MWD MWD -Standard ~ 600.00 1300.00 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station 1300.00 3910.00 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station ~ 3910.00 7080.97 Planned: Plan #4 V2 MWD+IFR+MS MWD +IFR + Multi Station ' Casing Points MD T'VD Diameter ' Note Size Name ~ ft ft in ih 1300.00 1281.55 13.375 16.000 13 3/8" 3973.16 3297.00 9.625 12.250 9 5/8" 7080.97 5410.41 7.000 8.750 7" Summary <----------- Offset Wellpath ---- -----> Reference Offset Ctr-Ctr No-Go Allonabic Site Well Wellpath MD MD DiStat-ce Area... Deviation Warning ft ft ft ft ft PB W Pad Plan W-202 Plan W-202 V2 Plan: PI 399.35 400.00 61.92 7.85 54.07 Pass: Major Risk PB W Pad W-200 W-200 V2 392.20 395.00 110.87 7.19 103.68 Pass: Major Risk ~, PB W Pad W-200 W-200P61 V11 392.20 395.00 110.87 7.19 103.68 Pass: Major Risk ', PB W Pad W-201 W-201 V4 349.99 350.00 76.16 6.15 70.00 Pass: Major Risk PB W Pad W-204 W-204 V2 335.16 335.00 47.46 7.12 40.34 Pass: Major Risk ~~ PB W Pad W-204 W-204L1 V6 335.16 335.00 47.46 7.12 40.34 Pass: Major Risk PB W Pad W-204 W-204L2 V6 335.16 335.00 47.46 7.12 40.34 Pass: Major Risk PB W Pad W-204 W-204P61 V2 335.16 335.00 47.46 7.12 40.34 Pass: Major Risk ', ', PB W Pad W-213 W-213 V13 404.96 405.00 30.58 7.57 23.01 Pass: Major Risk ', ', PB W Pad W-214 W-214 V16 355.91 355.00 16.11 7.24 8.87 Pass: Major Risk PB W Pad W-21 W-21 V3 410.55 425.00 251.24 9.12 242.11 Pass: Major Risk ', PB W Pad W-21 W-21A V13 409.90 415.00 251.22 9.11 242.11 Pass: Major Risk !, PB W Pad W-22 W-22 V2 400.56 405.00 217.00 7.57 209.43 Pass: Major Risk PB W Pad W-23 W-23 V5 416.97 430.00 182.71 9.41 173.30 Pass: Major Risk ', PB W Pad W-23 W-23A V8 420.03 425.00 182.79 9.49 173.30 Pass: Major Risk ', PB W Pad W-24 W-24 V2 358.41 360.00 145.63 6.79 138.85 Pass: Major Risk ', FieldPrudhoe Bay SitePB W Pad We11:Plan W-216 WellpathElan W-216 -3 1 3 300 200 1D0 D 2 100 200 300 -3 1 3 0 Travelling Cylinder Azimuth (TFO+AZI) [deg[ vs Centre t ` Site: PB W Pad • Drilling Target Conf.: 90% Description: Map Northing: 5963280.00 ft Map Easting :613500.00 ft Latitude: 70° 18'30.835N Shape: Circle Target: W-216 OBa 1: Plan W-216 Based on: Planned Program Vertical Depth: 4920.00 ft below Mean Sea Level Local +N/-S: 3377.28 ft Local +E/-W: 1501.65 ft Longitude: 149 ° 04'49.314 W Radius: 50 ft 3 5 0 0 34-50 3+00 0 0 0 0 0 ~n o ~n o ~n ~- ~n o~ ~.o ~o Site: PB W Pad Drilling Target Conf.: 95% Description: Map Northing: 5963495.00 ft Map Easting :613465.00 ft Latitude: 70° 18'32.955N Shape: Circle Target: W-216 OBe Well: Plan W-216 Based on: Planned Program Vertical Depth: 5130.00 ft below Mean Sea Level Local +N/-S: 3592.79 ft Local +E/-W: 1469.86 ft Longitude: 149°04'50.240 W Radius: 50 ft ~ ~l 0 0 ~~ X650 ~~~ X600 '~ ~ 5 5 0 0 0 _ __ 0 _~~ 3 5 0 0 0 0 ~o 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 of 4 :, . .. ':~:,. -.arcs „~.. _ ~i,~."ats _ :~der`~SE~,r~hSfatsCabins ~1~te~a~ ~rdl1`V~S __.,.._...~. Alaska D~IR base Summary File Type A~~......___ ; File Number: 28263 ~ ~ Printable Case i=i.Lg. Summary See Township, Range, Section and Acreage? New search ~~ C Yes ~ No ~-- ~- LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract ~". F[!e: :~DL 28263 ''~ Search for Stat~.~=; Plat Updates C'zrslornei°: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX ] 96612/900 E. BENSON BL ATTN: LAND IvIANAGER- ALASKA ANCHORAGE AK 995196612 Cure Type: '7~~~. OIL & GAS LEASE COMP DNR Ur~iit~ 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/1 l/1965 Total Acres: 2560.000 Dute Initiated: 05/28/1965 Office of~Pf•inrafy Responsihilit~,: DOG DIV OIL AND GAS Last Ti~unsaction Date: 12/04/2006 Case Subtype : ~•d NORTH SLOPE Last Ti~unsaction: AA-NRB ASSIGNMENT APPROVED Mei°idian: l ~ 7<nrr~~{~i/~: I) I i N l<<rir~~~.~ i1 i?E ,Ce~~~/r'on_ 15 Se~~[inir ,Ici~~~c.~ (~~0 Search Plats 1 /~ ri~lrcrr~.~ I_~ %utrn~/trj;: Ol I N I~ci~r~c_ 012E Sc~c~iun. I (~ Section :l~~r~~~~~: 6-~Q ~1~'i'ltllcln.' I! lUt6n,~{