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207-142
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-214 PRUDHOE BAY UN POL W-214 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/10/2025 W-214 50-029-23373-00-00 207-142-0 G SPT 4970 2071420 1500 764 770 771 770 0 0 0 0 4YRTST P Bob Noble 11/10/2024 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-214 Inspection Date: Tubing OA Packer Depth 0 2012 1890 1860IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN241111143108 BBL Pumped:5 BBL Returned:4 Friday, January 10, 2025 Page 1 of 1 9 9 9 9 999 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 15:30:58 -09'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-214 207142 500292337300 10 9/23/2023 MEMORANDUM TO: Jim Regg P.I. Supervisor3ee(ll 11( FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 4, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC W-214 PRUDHOE BAY UN POL W-214 Src: Inspector Reviewed By: P.I. Supry TJ Z_ Comm Well Name PRUDHOE BAY UN POL W-214 API Well Number 50-029-23373-00-00 Inspector Name: Brian Bixby Permit Number: 207-142-0 Inspection Date: 11/4/2020 Insp Num: mitBBB201104125017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T W-214 - Type Inj W TVD a970 Tubing 1755 1755 1755 1761 PTD 2071420 Type Test SP'r Test psi 1500 1A 290 2499 2451 2431 " ed- BBL Pum77�aY 2.7 BBL Returned: 1.5 OA 529 799 795 785 " Interval RmsT p/F P Notes: J 4A,9 1 10 I zo 7V710 Wednesday, November 4, 2020 Page I of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWel[Integrity@hilcorp.com> Sent: Tuesday, October 20, 2020 4:23 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska IMS User, Aras Worthington; Bo York; John Menke; Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: OPERABLE: WAG Injector W-214 (PTD #2071420) WFRV installed Mr. Wallace, WAG Injector W-214 (PTD #2071420) RMX plug body and prong has been set to provide sufficient backpressure and allow for functional SVS. The well is now classified as OPERABLE and can be brought on injection. An AOGCC MIT -IA will be conducted once rate and temperature has stabilized. Please call with any questions or concerns, Ryan Holt Hilcorp Alaska LLC Field Well Integrity/Compliance Ryan.Holt@HiIcorp.com P:(907)659-5102 M:(907)232-1005 From: Alaska NS - PB - Field Well Integrity S : Sunday, September 13, 2020 8:17 AM To: ch"allace@alaska.gov Cc: Regg, Jaimes B (CED) <jim.regg@alaska.gov>; Alaska IMS User <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthingto hilcorp.com>; Bo York <byork@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilco om>; Stan Golis <sgolis@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com> Subject: NOT OPERABLE: WA ector W-214 (PTD #2071420) Low Injection Pressure Mr. Wallace, WAG Injector W-214 (PTD #2071420) was maderable on 06/06/20 to put on injection for 4 year AOGCC MIT -IA. Low surface pressure while on injection tripped the pilot an he well was shut in and freeze protected. Intervention is planned to either install a downhole choke or otherwise inc se surface pressure while on injection for continued operation with functional SVS. The well is now classified as pressure is resolved. Please respond with any questions. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Rvan.Holt@Hilcorp.com P:(907)659-5102 M:(907)232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Sunday, September 6, 2020 5:10 PM To: chris.wallace@alaska.eov and will remain shut in until low injection Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWellIntegrity@hilcorp.com> Sent: Sunday, September 13, 2020 8:17 AM To: Wallace, Chris D (CED) Cc: Regg, lames B (CED); Alaska IMS User; Aras Worthington; Bo York; John Menke; Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: NOT OPERABLE: WAG Injector W-214 (PTD #2071420) Low Injection Pressure Mr. Wallace, WAG Injector W-214 (PTD #2071420) was made Operable on 06/06/20 to put on injection for 4 year AOGCC MIT -IA. Low surface pressure while on injection tripped the pilot and the well was shut in and freeze protected. Intervention is planned to either install a downhole choke or otherwise increase surface pressure while on injection for continued operation with functional SVS. The well is now classified as NOT OPERABLE and will remain shut in until low injection pressure is resolved. Please respond with any questions. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan. Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Send Sunday, September 6, 2020 5:10 PM To: chri"allace@alaska.gov Cc: Regg, Ja r�te,5 B (CED) <jim.regg@alaska.gov>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBField Illntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Bo York <byork@hilcorp.com>;7ohn Menke <jmenke@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Travis ith - (C) <Travis.Smith@hilcorp.com> Subject: OPERABLE: WAG Injector W, 14 (PTD #2071420) Ready for Injection Mr. Wallace, WAG Injector W-214 (PTD #2071420) was made Not 0 now ready for injection and will be classified back to O stable injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 ble on 08/31/20 for lapsing on its AOGCC MIT -IA. The well is 6te,-An AOGCC MIT -IA will be scheduled when the well is on Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, September 6, 2020 5:10 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska IMS User; Alaska NS - PB - Field Well Integrity; Aras Worthington; Bo York; John Menke; Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: OPERABLE: WAG Injector W-214 (PTD #2071420) Ready for Injection Mr. Wallace, WAG Injector W-214 (PTD #2071420) was made Not Operable on 08/31/20 for lapsing on its AOGCC MIT -IA. The well is now ready for injection and will be classified back to Operable. An AOGCC MIT -IA will be scheduled when the well is on stable injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Monday, August 31, 2020 6:13 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Bo York <byork@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com> Subject: NOT OPERABLE: WAG Injector W-214 (PTD #2071420) will lapse on 4 -year AOGCC MIT -IA Mr. Wallace, W-214 (PTD #2071420) is a mechanically sound WAG Injector that is coming due for its 4 -year AOGCC MIT -IA by the end of August. It has been shut in since 10/23/19 with no current plans to POI. It will now be classified as Not Operable for tracking purposes. When the well is ready for injection, an AOGCC witnessed MIT -IA will be scheduled. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance and rew.oee(Whilcoro.com P: (907) 659-5102 M: (307)399-3816 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, August 31, 2020 6:13 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska IMS User; Alaska NS - PB - Field Well Integrity; Aras Worthington; Bo York; John Menke; Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: NOT OPERABLE: WAG Injector W-214 (PTD #2071420) will lapse on 4 -year AOGCC MIT - IA Mr. Wallace, W-214 (PTD #2071420) is a mechanically sound WAG Injector that is coming due for its 4 -year AOGCC MIT -IA by the end of August. It has been shut in since 10/23/19 with no current plans to POI. It will now be classified as Not Operable for tracking purposes. When the well is ready for injection, an AOGCC witnessed MIT -IA will be scheduled. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Date: 6/17/2020 Transmittal Number: 93774 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 The digital zip file for the well log package listed below is being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format W-214 10/26/2019 Baker Hughes IPROF Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ Received by the AOGCC 06/17/2020 PTD: 2071420 E-Set: 33384 Received and signed by Abby Bell on 06/17/2020 • • pro ao7-/4- Z Loe. ', 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 SCOW) 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 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-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 lim.regg(c@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@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 ell Integrity Engineer<AKGWOWeliSiteEnginee@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) Infector W-214(PTD 2071420) l • 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&to BPXA's Tubular Design Advisor will review all of these wells. Upon completion,we'll present the findings to the AOGC . In the meantime,all will remain Not Operable and shut in. 1 • Thanks, • • 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:iim.regg@alaska.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 on. 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 90r- 793-1236 or iim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@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: Producer1-01B(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:J-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 ticlassify J-01 Not Operable,shut it in,an•ure it, until we can perform modelin 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.The 13-3/8" is a second conductor,and not coupled to the inner casing strings at the wellhead. In the event the 1 - 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 tUt1V L) STATE OF ALASKA DEC 1 2 2017 IllkLASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AO V C Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well VI Re-enter Susp Well 0 Other:Set Patch 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 207-142 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service El 6. API Number: 50-029-23373-00-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PBU W-214 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,POLARIS OIL 11.Present Well Condition Summary: Total Depth: measured 6331 feet Plugs measured 6066 feet true vertical 5476 feet Junk measured feet Effective Depth: measured 6066 feet Packer measured See Attachment feet true vertical 5249 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 28-107 28-107 1490 470 Surface 1282 13-3/8"68#L-80 28-1310 28-1300 5020 2260 Intermediate 3686 9-5/8"40#L-80 28-3714 28-3353 5750 3090 Production 6294 7"26#L-80 26-6320 26-5466 7240 5410 Liner 1 Perforation Depth: Measured depth: 5835-5861 feet feet 5925-5951 feet 5993-6043 feet True vertical depth: 5054-5075 feet feet 5129-5151 feet 5187-5229 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 24-6088 24-5267 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 3-1/2"MCX SSSv 2657 2514 12.Stimulation or cement squeeze summary: Intervals treated(measured): ��}} g^{��{�9 ��yy �jl� Treatment descriptions including volumes used and final pressure: SVo/'0Ew4e "t I) 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -1077 800 504 Subsequent to operation: Shut-In 0 950 14.Attachments:(required per 20 AAC 25.07(325.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service WI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG m GINJ 0 SUSP ❑ SPLUG 0 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: 317-002 Authorized Name: Youngmun,Alex Contact Name: Youngmun,Alex Authorized Title: Kuparuk&Schrader Bluff PE Contact Email: younak@BP.com Authorized Signature: i 1.--,.._ Date: /2 mfr.) Contact Phone: +1 907 564 4864 Form 10-404 Revised 04/2017 VT`L !/Z/t tEl ,f 0R D$+$ S 1 DEC 1 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary December 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Patch to Repair a leaking Injection Mandrel Station for Well W-214, PTD # 207-142. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0 • Packers and SSV's Attachment PBU W-214 SW Name Type MD yp TVD De scri tion p p W-214 SSSV 2656.98 2513.77 3-1/2" MCX SSSV W-214 TBG PACKER 5735.55 4969.68 3-1/2" HES Dual Feedthru Packer W-214 TBG PACKER 5883.08 5094.03 3-1/2" HES Dual Feedthru Packer W-214 TBG PACKER 5971.3 5168.46 3-1/2" HES Single Feedthru Packer 0 ! U) o o Q X Z 0 0 J �� 00 c Q z 0 0 ch (o v O c a) = u- 0 U' a) o) ( Un � @ z ° ao0 _ D@ II � X - .o E coM J J m QJ ( O_OJ > O C LL m(n N * b b I- c (b II (...9 En63 X N in Un 0 L.L-. 2 05 05 O OO > > CO• a) X J N Y d J W (n -O 0 LL o O U Oo (n U N W W a) O -c 2 CO O (n � w U CO0 (_) ( Z Z PX in-'D _ o + LL -o 15 II 0) © 0 co ( co > -E co - 5 O II -0 „, _o �~ p Y Y m � � -0N 0-c) o H Z � a_ 0 0 cnv `o , � E N- a CD Q) _C a) a) m 00 > ° -o a)c) U N o H .3 v _ To N 0_ co co O 2 O c a o o I-UJ O O � � > o Q O O � � E � Lc) IP • QZ ,- o 3 o a) a) c � a ----• Q� a m N00 Q L o c = a 0 X a D aS LS) i a_ i J a_ 0)? w > >N > !CV N Z (B LL O > a O r (n0ON a) � (n - � a_ m v > > - o0 p2wa _ CO II 0_.c i o (D Q' Y < a O O J O (0 •!...! N m �' a) m .c o LL -c _1 D rn 2 2 LI_ U) c a (n N m P a) � � () ami 2 o O � �` 5 I- � � 0 to �` H n I- (0 , (0 2 V/J� (fl a0 c j * I- N V 14 0 = _ .4 -1, o a o a) - i) J P - r 03 0 03 C 3 CO 0 W m O c J * M N O O to J -0 N 3 U- 0 W O a �cn - ( - > 0L ( `� p °00 � 0U) n ct OQn �, `� = N1Q coCe , ° a� (n cq > 001- XI- ip r` U) vi is r` U ,n U a a) * O ao mCXLLQ NOHa_ ,- C. O = (,-) _ Q (n = � 't � Q � QO E * E EI > OQOi_ = (� 2 (.5 d_ co () 0 (n0N_ - � N a) ac� a. 0a. cu a -oa oa. o") > in 10ON (n rnUHU = ©Q ©Qc� � oM E E -0rn '- X >- ZO in -. o 2 - - a. z = 0 0-.- o � 0 O fl- E o � LL _ a) L 5Et _o O2 U0, EN2zUn zDjpjprn aEi a) ° a (O2 u) o etc-. ZM c � � � o � � 00DQOu_ pZC ° f- E -o � pbbF- LL 0 o c -c 0w = QOp � � U W- , .-- 0NOz E Q] 0 3 � NLJLN W _ • *- *t 0 O ? . "- LL X o L.'x0 _0 0i_ _J00F- O aim ' cz2C, Qu) � u) F-• o -0 c o � c XJ o a) Z Q) � p t Zo oZZ = w � wZ O a) o o +�.. Zo2oJ E > � Z 2 w W J 0 II c 0 � D X z � rt ct 0 a ) 0 c 0 LU _c _c o 0) II (3 � cUJDOI-- OOa_ Oa_ U O Ws) a) 0UZJZ2� cn § « H ° 1- O : m : 1 00 : m m Q UW aa.. Q : m O J .E : X m X I, w H < N- r- (` r� N- I- r- 0 N O O O O O O I- (N CV N N N N N N M ,- N N M -C.:3 I- ao 0 a a) 0) 0) a a 0 Q ! 0 a 0 < 2 _ in II uy U II Q 00oQ � � Q a c0Ni IQQ ZZzw0el 0 CI Z� NN 2 O , z � p < _ O W F- J W _I QQ > O p eC 2 z Q O _ N 0F- D Om 0 Z cts Co O WOwO W EL. ci) nzQ ,r, , COCD- > . =w m _ cn D u) O .- Q ~ LUQ 4r.... -a d C%,1 fl (n r Lf) _ W N LL w Cl) Q '- O O = W _ }- = II z m -) iZO - O Ca —I - (3wQwp > �Da — a- 2 O IYD_ HLLw9 z Ce * 2 cn o O w a QS J N >+ Q O W co Z a } Z — Ii Z > a IfY Y O < II a 0 0 CO Q � = p _iOz F- a� w f- w 2 Oz II O J ° C7 - _ J a O _c m J O U O - J J � � O U o m � RNHL0O O 0 E O) Z °D « 0 0 fY II U) to � : Lo (/) 0 N. O 7 co OQ co N CO N 111, TREE= 4-1/16"CNV SA. NOTES:H2S READINGS AVERAGE 125 ppm WHEN VVELLPEAD= FMC ON NI REQUIRES A SSSV WHEN MI ACTUATOR= BAKER C Al-2 1 4 PKR @ 5736'IS-FULL RJLL TO RELEASE"BUT CAN ALSOS BE KB.ELEV= 80.9' RELEASED BY PRESSURE-DO NOT EXCEED 2000 PSI ON BF.aEV= 54.7' ` J ! THE IA w/OUT PERFORMING TBG MOVEMENT CALLS& KOP= 300' DISCUSSING w/APE'*` Max Angie= 33°@ 5663' • l 26' —14-1/2"X 3-1/2"XO,ID=2.992" Datum MD= 5868' Datum TVD= 5500.SS I 481' J--113-3/8"TAM PORT COLLARD=12.259'J 20"CONDUCTOR 91.5# A-53,D=19.124" 80' I ■ ` ( 1277' —[91-518"TAM PORT COLLAR D=8.835" 13-318"CSG,68#,L-80 BTC,D=12.415" H 1310' 2657 �3-1/2"t ES X NEP D=2_813"J L9-5/8"CSG,__40#,L-80 BTC,D=8_835" --L 3714' I—A , ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 5622 4875 33 !WIG DMY RK 0 07/23/08 7"LNR,26#,L-80 TC11 XO TO L-80 BTC-M 5241' —X X WATER INJECT ON MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 5761 4991 33 MMG-W DRAY RK 0 07/05/15 Minimum ID =2.330" 5838' '4 5849 5065 33 MMG-W 'P-15 RK 14 01/18/10 MP 3 5909 5116 33 MMG-W DMY RK 0 11/20/07 HES OWEN X-SPAN PATCH 2 5948 5148 32 MMG-W P-15XJRI RK 12 07/05/15 1 6016 5206 32 MMG-W P-15XJRI RK 21 07/05/15 'STA#4=I3ROKEN LATCH(6/27/14 AWGRS) COVERED BY OWEN X-SPAN PATCH(11/26117) ' ' II 6716' —3-1/2"HES X NP,D=2.813" pI 76736' H7"X 3-1Y2"HES DUAL FSU PKR D_2_965" j it 5749' J—PHOENIX PRESS/TENP SENSOR SL.U,0=2.992" 3-1/2"PP TAGJ—� 6760'-j 0 -- - -- [7" MARKERJOINT w/RA TAG H 6812' En 5837' -5865' —3-1/2"HES OWEN X-SPAN PATCH, D=2.330"(11/26/17) iIi - _—6873' —[3-112"I-ES X NP.D=2.813"J ' , X L 6883' 7"X3-1/2"DUAL FEI37THRU PKR 0=2.965" — FFORADON SUMMARY ■ [ 6897' ]—IPHO8SX PRESS/TEMP SENSOR SLB,0=2.992 1 REF LOG:USTT ON 11/19/07 ANGLE AT TOP PEW: 33'@ 5835' LL — Note:fifer to Roduction DB for historical perf data SIZE SW ZONE INTERVAL Opn/Sg2 DATE IIIIP — 4-1/2" 5 OBa 5835-5861 0 11/17/07 4-1/2" 5 OBc 5925-5951 0 11/17107 XI 6972' H7"X 3-1/2"SINGLE FE )1HRU PKR D=2_965" J 4-1/2" 5 OBd 5993-6043 0 11/17/07 ' ' 6996'—3-112"HES X MP,D=2.813" W 0 I ' _ 6046' —3-1/2"FES X NP,D=2.813" iAli 6042'SLM MOWED RMX PRONG w/A 1-3/16'FN& ' A 19/64'WFR(500BWPD)(09/02/17) 3-1/2"TBG,9.2#,L-80 TCN,.0087 bpf,D ii=2.992" — 6088' ---____.—_.___,__-- _ __ .—._ i 6066' , ES XNPD—3 1/2"HN , =2.750" I PBTD 623r 11111XXXXX.1H11X,.4 6088' i—3-1/2"WLEG,D=2.992"J 1�11111114 11 — L7 R LN26#,L-80 BTC-M,_0383 bpf,D=6.276" — 6320' J :....1.1.11..1.1.1 .1.1 DATE REV BY COMMENTS DATE REV BY COMMENTS POLARIS LW 11/22107 N9ES ORIGINAL COMPLETION 05/02/16 GCIJMD COFRECT D API NUMBER WaL: W-214 07/01/14 MGS/PkSTA#4 HAS BROKEN LATCH 11/03/16 NXW/JMC C/O RMX PLUG(10/30/16) P MT No:'1071420 09/05/14 MICS/PJC RJLURESET PXN(06/25/14) 09/21/17 BSE/JMD FULL&RESET RMX FRONG API No: 50-029-23373-00 09/15/141DLW/PJC RJLL CATCHER SU3(06/28/14) 11/30/17 MS/JM) SET PATCH OVER MANDREL(11/26/17 SEL;21,T11N,R12E,391'FTL&1176'Fa 09/11/15 STF/JMD RLL PXN PLUG/SET MAX PLUG(06/30115) 09/11/15 STF/JMD WFR C/O(07/05/15) BP Exploration(Alaska) 'V OF Tit • • 4'P' II/ , s,, THE STATE Alaska Oil and Gas ti �_�'�, ALAS,�`�1 1 Conservation Commission .,fix �1 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ---rs ' pF ., Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov r =~, Eric Zoesch NNEDn,1 t , Production Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Polaris Oil Pool, PBU POL W-214 Permit to Drill Number: 207-142 Sundry Number: 317-002 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or,such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ‘V-6 Cathy . Foerster Chair DATED this 1 t� day of January, 2017. RBDMS LL JAN Z 6 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N JMl' 0 4LU I APPLICATION FOR SUNDRY APPROVA S if3IS II to Tri0 20 AAC 25.280 AOGGC 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well a . Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Patch Inj Mandrel ® - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-142 ' Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-23373-00-00 • 99519-6612 Stratigraphic ❑ Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 11 PRUDHOE BAY UN POL W-214 . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028263 • PRUDHOE BAY,POLARIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 6331 - 5476 6066 5249 6066 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"91.5#H-40 28-107 28-107 1490 470 Surface 1282 13-3/8"68#L-80 28-1310 28-1300 5020 2260 Intermediate 3686 9-5/8"40#L-80 28-3714 28-3353 5750 3090 Production 6294 7"26#L-80 26-6320 26-5466 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 24-6088 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 3-1/2"MCX SSSV 2657, 2513.90 12.Attachments: Proposal Summary 0 Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program IZI BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ® - 14.Estimated Date for Commencing Operations: ^ I 1 ii 15. Well Status after proposed work: �( • Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 4 _ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Zoesch,Eric be deviated from without prior written approval. Email zoeseOQBP.com Printed Name Zoesch,Eric Title Production Engineer Signature /� Phone +1 907 564 4695 Date , 3 N .... COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 317-06 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No E/ Spacing Exception Required? Yes 0 No Q Subsequent Form Required: `0 404- a7 04- APPROVED BYTHE Approved by: P9ta,visv.---- COMMISSIONER COMMISSION Date:1 18--1 7 VTL ///3/l9- ORIGINAL RBDTMS 1/ "JAN262617 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. r Attachments in Duplicate lr� , YS (, s.t7 • 0 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DSR,LHD,EAZ,BPG 10/12/15) General Information Well Name: W-214 Well Type: WAG Injection Well API Number: 50-029-23373-00 Well Activity Conventional 4 Classification: Activity Description: Expandable Patch Over ST#4 Cost Code/AFE: APBINJEC Field/Reservoir: POLARIS t 12 Month Avg IOR, bopd: Job Type: Mech-Patch 1.,--- Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER V Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Eric Zoesch Contact numbers: (907)564-4695 (406)270-9837 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Dan Robertson Contact numbers: (907)564-5546 (907)529-5818 Date Created: December 19,2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Choke Setting Pressure d) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 12/17/2016 1,247 0 882 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date,ppm) NA 0 ppm • Maximum Deviation(Angle and Depth) 33° 5,663' MD Datum depth,ft TVDss 5,000'TVDss Dogleg Severity(Angle and Depth) 6° 4,258' MD Reservoir pressure(date, psig) 7/24/2011 2,098 psi Minimum ID and Depth 2.750" 6,066' MD Reservoir Temp,F 90°F Shut-in Wellhead Pressure 100 psi Known mech. integrity problems(specifics) Stuck valve in ST#4,washed out and over injecting Last downhole operation(date, operation) 10/30/2016 SL performed WFRV diagnostics to confirm ST#4 overinjection Most recent TD tag(date,depth, N/A toolstring OD) If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? Surface Equipment Checklist. Comments,well history, W-214 is a regulated three-zone WAG injector in Polaris field.The well last had its valves changed out in background information, July of 2015 and during that intervention the latch for the valve in ST#4 was broken.The valve was stuck in etc: the pocket so it was not recovered.As such,the valves in ST#1 &2 are new as of July 2015 but the valve in ST#4 is from 2010.The well passed its step-rate tests at the end of the 2015 intervention,but in mid- 2016 the well was observed to be taking up to 50% more than its valved rate(depending on WHIP). Due to the lack of functioning DHPG's, it was uncertain which zone was responsible for the overinjection.A diagnostic job was run with the X-selective tool,and slickline was prepared to change out whichever valve was found to be the problem. Unfortunately ST#4 was clearly the problem zone, so nothing could be done (attempts to retrieve the valve have already been made). To remediate the overiniection while maintaining sufficient ID for future WFRV C/O's,an expandable patch is to be run.The larger drift ID of an expandable patch will allow for WFRV C/O work to be performed even below the patch. IOR of job is injection target of OBa(275 bwpd) * Polaris VoW(0.25)*.5 injector value "ramp". • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Broken latch on valve in ST#4;overinjection through this valve. Specific Intervention or Well Objectives: 1 Set expandable patch across ST#4. 2 Set SPMG in ST#5 and perform step-rate infectivity test to confirm patch is holding. 3 Install live WFRV in ST#5 pending confirmation of patch integrity. Key risks,critical issues: Mitigation plan: 1 Inability to perform WFRV work through restriction Use expandable patch with larger ID Compare SRT results to anticipated injection through 2 SPMG shows backside pressure response from SRT's ST#1 &2(890 bpd on Diesel) Perform memory(PROF to determine if ST#4 is still taking injection 3 Schmoo&debris prevents patch from sealing Thoroughly B&F area around ST#4 4 Sand backflow from OBa Maintain overbalance with 750 psi WHP and a column of Diesel when pocket is open Summary Service Line Activity Step# 1 S Drift for patch,thoroughly brush 30'above&below ST#4 2 F A/SL w/cleaning of mandrel area by pumping hot Diesel as needed 3 F Set Owen 3-1/2"X-Span SPC patch over ST#4 mandrel with broken valve 4 S Perform patch diagnostics and install live WFRV in ST#5 per procedure below v" 5 F A/SL w/SRT's by pumping Diesel as needed Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Drift for patch,thoroughly clean interval above&below ST#4 per Owen's attached recommendations. Consult PDS caliper log from 4/30/16 for tubing condition details. 2 F Pump hot Diesel at 1 bpm while SL brushes around ST#4. 3 E Follow detailed procedure supplied by vendor for setting patch. Pull dummy and install SPMG set up for 5-second pressure readings of ANNULUS in ST#5. Perform step-rate test at 1600, 1800,and 2000 psi with Diesel.Target injection rate is 0.62 bpm on Diesel, +/-15%. Hold each pressure for 10 mins,recording rate at 5& 10 minutes. Max rate 1.2 bpm. Call APE with results prior to pulling SPMG if SRT is a fail. Pending passing SRT or APE approval,pull SPMG and download data. 4 S If no pressure response was seen by gauge during SRT's, install live WFRV with orifice size 14, light spring (275 bwpd)in ST#5. Repeat previous SRT,with target rate of 0.83 bpm on Diesel. If pass, RDMO.Consult APE if fails. If pressure response was seen by SPMG during SRT's,call APE. SPMG may need to be reinstalled and a memory(PROF may be necessary to determine if the patch is holding. 5 F See fullbore pumping schedule Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 1075 Expected Production Rates: FTP(psi): 1200 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POI well pending passing SRT's. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Pert form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc III TREE 4-1/16'CNV SAFE' OTES:H2S REA[ 1GS AVERAGE 125 ppm WHEN WELLHEAD- FMC ON M."'WELL REQUIRES A SSSV WHEN ON MI "'INS ' ACTUATOR= BAKERC VV-2 1 4 PKR @ 5138'IS'RJLL TO RELEASE BUT CAN ALSO BE KB.ELEV= 80.9' RELEASE)BY PRESSURE-DO NOT EXCEED 2000 PSI ON BF.ELEV= 54.7' l J I' 11-E b w/OUT PERFORMNG TBG MOVEMENT CALLS& KOP= 300 DISCUSSING w/APE"— Max Angle- 33°@ 5663' Datum MD= 5868' 25' —4-112 X 3-112 XO D-2997'J Datum TVD= 5500.SS — 481' --113-3/8"TAM PORT COLLAR D=12.259' 20'CONIX)CTOR 91 54,A 53,D=19 124' - 1241 / ' 1277' 9.5/8" TAM PORT COLLAR,D=8 835' 113-3/8'tSCi,68 ;L-80 B TC,U 2657' —3-1/2'HES X NP,D=2.813' I=12.415' I— 1310' / 1 9-5/8"CSG,40#,L-80 BTC,G=8.835' - 3714' I-----• , Si MD TVD DEV TY PE VLV LATCH PORT DATE 6 5622 4875 33 MMG MY RK 0 07/23/08 7"LNR,264,L-80 TC 1 1 XO TO 1_-80 STr M — 5241' I X WATER IIJEGTION MANDRELS ST MI) TVD DR/ TYPE VL.V LATCH PORT DATE 5 5761 4991 33 M MGW DMY RK 0 07105/15 Minimum ID -2.750" GOGG' 4 58495065 33 MMG-W `P-15 FIK 14 01/18/10 3-1/2" HES XN NIPPLE 1111 3 5909 5116 33 MMGW DIN RK 0 11/20/07 2 5948 5148 32 MMG-W P-15 XJR Rl< 12 07/05/15 1 6016 5206 32 MMG-W R15XJR RK 21 07/05/15 STA#4=BROKTh LATCH(6127/14 AWGRS) I I I 5715' -13-12'HES X NP,0=2 813- I X >J 1 5736' ,j--j[x 3-112'I+S I ttJAI FF H)11-RU R(R,D=2-965" r ._-. • 5749' H PHOENIX PRESS/TEMP SENSOR SLJB.D=2.992' 1 T 1/7 PPTAG 5750' I • 7' MARKER JOPYT w/RA TAG —1 5812' 111 — I ' I 5873' I-[3-12"HES X NP,D=?813_, X ><— i 5883' —7 X 3-1/2'DUA-FEEDTHRU PKR D=2.985" FM-ORATION SUMMYIRY • 5897' H Pt-ICA-Nix PRESS/TEMP SENSOR SLE,U=2-997 RET LOG:USE ON 11/19/07 - ANGLE AT TOP PERF. 33°@ 5835' „� over f.'1 j C c flvr Note:Refer to Production 08 for historical pert data SZE SIT ZONE! INTERVAL Opn/Sgc DATE — 4 112” 5 OBa '5835 5861 O 11117/07 4-1/2" 5 OBc '5925-5951 O 11%17/07 X 5972' —7'X 3-1/2"SINGLE FEED17-RU PKR D=2.965' 4-112" 5 OBd ,5993-6043 0 11/17/07 f ' L_ 3995' j-3-12"HES X NP,D=2 813' I No 0 ' ' 6045' 3-112'HES X NP,D-2.813' 'lHi' 6066' -3-1/2'HES XN NP,D-2.750' ---�-r 6066' 3.12'RMX PLUG(10/30/16) 3-1/2'TBG,9.2#,L-80 TEl 0087 bpf,D=2.992 — 6088' 1 " ``` 6088' -3-1/7 WI_I-G,I)=2 997' KM) —i 6237' l1 .1 17'LNR,264,L-80 BTC-M,.0383 bpf,D=6.276' H 6320' •....AV•T•'AVAVAV'I DATE RLV BY C()M E NTS DATE REV BY COWENTS POLARIS LNIT 11/22/07 MIES ORIGINAL COMPLETION 09/11/15 SIF/JM)PULL PXN PLUG/SET REVD(PLUG(0613C MIL: W-214 01/70/17 TIMYJMD FI2S SAFETY NOTE 09111/15 SIF/JMD WFR C/O(07/05/15) FERMI l+b."2071420 0701/14 MGSIPJC GLV CJO(06/28/14) 05/02/16 GGJMD CORRECTED ARI NUM3ER All No. 50-029-23373-00 0 T/01/14 MGS1PJC STA#4 HAS BROKEN LATCH 11/03/16 NXWIJMC C/O FAD(RUG(10130/16) SEC 21,T11N R12E,391'FTE&1176'FU 09105/14 UGS1 PJC I-U URESET PXN(U6/25/14) 09/15/14 DLW/PJC'FLILL CATCtER SUB(06/28/14) BP Exploration(Alaska) S • Well W-214 H2S Value 0 MIT#1 H2S Date 1/0/1900 Test Type Work Desc PATCH&WFRV INSTALL Target Pressure AFE APBINJEC Max Applied Pressure Date 12/19/16 Test Fluid Li Engineer Eric Zoesch Integrity Limits Confirmed Phone 9075644695 Job Objective Assist SL with cleaning of area around ST#4. MIT#2 Test Type Pump Schedule Target Pressure Stage Fluid Type Pump Into Volume(bbls) Rate(bpm) Max Pressure Max Applied. essure 1 Load Diesel TBG 60 1 2000 Test Fluid 2 Integrity Limits Confirmed 3 4 5 6 7 Detailed Procedure MIT#3 Pump hot Diesel to help clear schmoo and debris from interval around ST#4 while SL brushes. Test Type n Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confirmed • • Fullbore Pumping Design Template 1/0/1900 0 ppm H2S(date/ppm) 2000 Max Pumping Pressure(psi) Diesel Main Fluid Type 60 Main Fluid Volume(bbls) Diesel Freeze Protect Type 30 Freeze Protect Volume(bbls) Injecting Recent Tbg Fluid Level(ft) Surface Recent IA Fluid Level(ft) N/A Recent OA Fluid Level(ft) N/A Expected Tbg Fill Up Volume(bbls) N/A Expected IA Fill Up Volume(bbls) N/A Expected OA Fill Up Volume(bbls) 53 Wellbore Volume to Perfs(bbls) 2500 Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) size See helpful tips tab #VALUE! Tubing Collapse(psi) size See helpful tips tab #VALUEl Casing Burst(psi) size See helpful tips tab #VALUE! Casing Collapse(psi) size See helpful tips tab #VALUE! Select Input Depth Integrity Issues? Select Select Yes-Tbg cond good Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) • Well W-214 H2S Value 0 MIT#1 H2S Date 1/0/1900 Test Type Work Desc PATCH&WFRV INSTALL Target Pressure AFE APBINJEC Max Applied Pressure Date 12/19/16 Test Fluid ri Engineer Eric Zoesch Integrity Limits Confirmed Phone 9075644695 Job Objective Set patch over ST#4,install SPMG in ST#5 and perform SRT to test patch integrity. Install live WFRV and perform SRT to confirm full design is regulating as expected. MIT#2 Test Type Pump Schedule Target Pressure Stage Fluid Type Pump Into Volume(bbls) Rate(bpm) Max Pressure Max Applied,--essure 1 Load Diesel TBG 40 0.62 2000 Test Fluid 2 Load Diesel TBG 60 0.83 2000 Integrity Limits Confirmed 3 4 5 6 7 Detailed Procedure MIT#3 Perform step-rate tests at 1600,1800,and 2000 psi,holding each pressure for 10 mins and recording Test Type r injection rate at 5&10 minutes.Do not exceed a sustained injection rate of twice the design rate.Pass Target Pressure criteria is evidence of a rate plateau at+/-15%of design rate. Max Applied Pressure Test Fluid Integrity Limits Confirmed • • Fullbore Pumping Design Template 1/0/1900 0 ppm H2S(date/ppm) 2000 Max Pumping Pressure(psi) Diesel Main Fluid Type 100 Main Fluid Volume(bbls) Diesel Freeze Protect Type 30 Freeze Protect Volume(bbls) Injecting Recent Tbg Fluid Level(ft) Surface Recent IA Fluid Level(ft) N/A Recent OA Fluid Level(ft) N/A Expected Tbg Fill Up Volume(bbls) N/A Expected IA Fill Up Volume(bbls) N/A Expected OA Fill Up Volume(bbls) 53 Wellbore Volume to Perfs(bbls) 2500 Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) size See helpful tips tab #VALUE! Tubing Collapse(psi) size See helpful tips tab #VALUE! Casing Burst(psi) size See helpful tips tab #VALUE! Casing Collapse(psi) size See helpful tips tab #VALUE! Select Input Depth Integrity Issues? Select Select - Tubing Caliper? Burst/Collapse ratings mayneed to be Yes Tbg cond good A Pe P 9 derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) 0 . Ale EA i hark-4 NA Owen Oil Tools X-SPAN Tubing Patch I oreLab SPC-3500-004 - BOM SPC-3500-004 IMPERIAL METRIC �_ G CASING 0.0.(in)(mm) 2500 88.90 -{ CASING WT(IbIlt)(kg/tn) 9.2-9.3 13.69-13.54 1 1d CASING I_D_(ht)(mm) 2.992 76.00 •`, < PATCH MAX_RUNNING O.D.(in)(mm) 2775 70.49 13 -- PATCH LD_AFTER SETTING(in)(mm) 2.33 59.18 11 BURST HYDRAULIC RATING(psi)(Mpa) 7600 55.39 COLLAPSE HYDRAULIC RATING(psi)(Mpa) 6200 4274 if - 12 GAS BURST RATING(psi)(Mpa) KA NA 14 IGAS COLLAPSE RATING(psi)(Mpa:� WA !WASYSTEM r IATERIAL L-80 1 ITEM CITY DESCRIP11ON 3 SHORT ASSY.-ITEMS 1-7 SPC-3500-004 q€ 1 1 PIN ELEMENT SPC-3500-060 ( 2 1 BOX ELEMENT SPC-3500-061 I 3 1 TOP SWAGE SCC-3500-054 4 1 BOTTOM SWAGE SCC-3500-055 i —1 1* 5 "'N"+1 PIN 0-RING 000-V569-143....7 6 1N'+1 BOX 0-RING 000-V569-143 _— 7 1 RELEASE RING PAT-3500-058(43K) 5 °"N" 10-FT.SECTION SPC-3500-047 Iii 7 6 8 OPT_ 5-FT SECTION SPC-3500-050 •17 SET-2687-101 16 g 1 SETTING TOOL 2-11/16"O_D_MSST 10 1 SLEEVE NUT SET-2687-130 8 11 1 SLEEVE LOCK NUT SET-2125-121 _.. •18 12 1 SEI t ING SLEEVE ASSY SET-2125-127L Nt- 13 1 QUICK CHANGE ROD SET-2125-130 -6 14 1 QUICK CHANGE NUT SET-2125-131 2 21 15 1 TOP ADAPTER ROD SET-2125-132 7 16 "N"+2 ROD TANDEM CONNECTOR SET-2125-133 i 9 "N" 10-FT ROD SET-2125-134 17 - OPT. 5-FT.ROD SET-2125-135 18 1 BOTTOM ROD SET-2125-136 19 1 COLLET ASSY. SET-2125-143 1l i2d 1 COLLET SUPPORT SET-2125-155 3 4 21 1 RELEASE RING ADAPTER SET-2125-145 r- 2d Note:"'N'=Patch Length(in feet)divided by 10 Note:"N"=Patch Length(in meters)divided by 3.048 Last Revised 09/2014 SPC-3500-004(a) ©2007.2013.2014 Owen Oil Toots All rights reserved . III • • ,,,,,i, _teat1....,, , Owen Oil Tools X-SPAN° Tubing Patch Core Lab SPC-3500-004 - LENGTHS 1 1 4 034 93 SPC-3500-004 IMPERIAL METRIC f __ 12 7 CASING 0.D.(in)(mm) 3.500 88.00 068.28 CASING WT.(Ibit)(kg ml 9.2-9_3 13.09-1384 CASING I.D.(in)(mmi 2.992 78.00 17 46 PATCH MAX_RUNNING O.D.(n)(mm) 2.775 7049 -_ .— PATCH 10.AFTER SETTING(in)(mm) 2.33 59_18 IH 055_63 lU 11 BURST HYDRAULIC RATING(psi)(MPa) 7500 52.39 1'1, .... ,. k<:.1)16 COLLAPSE HYDRAULIC RATING(psi)IMPa) 13200 42.74 G .2,3 1 ' :.2-''U' GAS BURST RATING(Psi)(MPa) N/A N/A -j I 1.3 GAS COLLAPSE RATING(psi)(MPa) N/A N/A 033.53 L298,8.5 SYSTEM MATERIAL L-ao A isioiis F1Z01 i - ,,,,i,720849 REF BON 11111 MIES PAM io4 64 I B 1 A 1,2,3,4,8 2.775 70.49 ' <,> B 1.2,3.4,8 2.330 59.18 E C 4 5.603 112.31 i___---_z___ 1)4 2-51 AP34 D 2 9.185 233.31 i - Sk. 63 50 1 E 1 10.796 274.23 i , 2 8 ' 1 1 is -,, B D7049 2981 04 .1 025 40 • = I [1.4 F 3 4.213 10700 G 12 8.245 2.750 209.12 H 12 69.85 [1200,L2,51 I 'ct.,34 93 J 12 2.375 60.33 3046 63.50 _ -BA K 19 2.140 54_36 -1--- I [i3 _, L 20 1_853 47_07 31..M. M 19 6.560 166_62 N 20 +250 107.95 731 j. 184 1 , a B D C M i 141[ N 351.12 -1- J ILJNITS:Vhi Last Revised 0912014 SPC-3500-004(b) (82007.2013.2014 Owen Oil Tools All rights reserved . • • AtOwen Oil Tools X-SPAN Tubing Patch SPC-3500-004 - WEIGHTS I SPC-3500-004 [12] [1 8] 0 x 0.31 DESCRIPTION WEIGHT(LBS) WEIGHT(KG) 055 1 CABLEHEAD 1.0 1.8 i [6] 2-1116 CCL 10.0 1.5 018 CONTACT SUB 10 05 [5] FIRING HEAD 1.0 0.5 0 15 I 2-11=16 MSST 900 108 CI TOTAL 106-0 48.1 61 I [=I] 0.12 PAT SHORT ASSY. 12.6 5 7 I I •10-FT SECTION 59.5 27.0 10-FT ROD 26.7 12.1 "TAND COUPL 0.6 0.3 O.C. ROD 1.1 0.5 0.C.NUT 0.6 0.3 [9.4] 1 [7 0-] 2.87 2 t 3 TOP ROD 3.2 1.5 [10 7] BOTTOM ROD 4.2 1.9 326 SLEEVE NUT 4.3 2.0 SLEEVE LOCK NUT 0.3 0.1 [22 0] 671 [ fl SETTING SLEEVE 6.8 3.1 003 7 COLLET ASSEMBLY 2.3 1.0 [23.8] i 7 25I COLLET SUPPORT 1.5 0.7 [7] 1 0 21 TOTAL 123.6 56.1 II= I: ! [14] 043 [.1] .r, TOTAL WEIGHT 229.6 104.2 "EA ADDITIONAL 10-FT LGTH ADD 86 766 LBS ii [4] .EA ADDITIONAL 305-METER LGTH ADD 39.40 KG ciI L9] 0.21 ..... D. to m q [100] 3.05 0- z 0 1 [8] 013 [ Si -45 ri'MrlQ Last Revised 09/2014 SPC-3500-004(C) .)2007,2013,2014 Owen Oil Tools 411 rights reserved • ILIBP,16 SUMMAR). RIG Nabors SES Date 1t/2002007 04,0 WELLS W-2141 • TUBING 3.5" 1-80 TCIl TBG WT. 9.2 23.95 RKB TO TS 189 JTS ON RACK 177 JTS 3.5"L-80 TCII 6050.69 FT ON RACK 5663.70 FT 3.5"L-80 TCII ITEM Description includes: SIZE.TYPE,CONNECTION ITEM ID OD LENGTH TOP BOTTOM 3.5"9.2#WLEG,3.5"TC-11 2.992 3.900 1.34 6086.56 6087.90 3.5 .9.2#.L-80 TC-I1 Pup 2.992 3.900 9.79 6076.77 6086.56 3.5",9.2#.L-80 TC-I1 Pup 2.992 3.900 9.80 6066.97 6076.77 3.5"HES'XNNipple:ID 2.750 2.750 3.960 1.45 6065.52 6066.97 3.5".9.2#.L-80 TC-II Pup 2.992 3.900 9.80 6055.72 6065.52 3.5",92#.L-80 TC-II Pup 2.992 3.900 9.80 6045.92 6055.72 3.5"HES'X'Nipple:2.813"ID RHC-M Plug 2.813 3.960 1.27 6044.65 6045.92 3.5",9.2#.L-80 TC-Il Pup 2.992 3.900 9.79 6034.86 6044.65 3.5"9.24 1-80 TC-ll Pup 2.992 3.900 9.79 6025.07 6034.86 GLM#1 -3.5"x 1.5"MMG-W w:RD Dummy-RK latch 2.920 5.968 9.31 6015.76 6025.07 3.5"9.2#L-80 TC-II Pup 2.992 3.900 9.80 6005.96 6015.76 3.5"9.24 L-80 TC-II Pup 2.992 3.900 9.78 5996.18 6005.96 3.5"HES'X'Nipple:2.813"ID 2.813 3.960 1.26 5994.92 5996.18 3.5"9.2#1-80 7C-11 Pup 2.992 3.900 9.79 5985.13 5994.92 3.5"9.2#1-80 TC-l1 Pup 2.992 3.900 9.79 5975.34 5985.13 3.5"x r HES single feedthru Packer(Pinned-60K) #1 packer 2.965 6.100 3.66 5971.68 5975.34 3.5"9.2#L-80 TC-11 Pup 2.992 3.900 4.68 5967.00 5971.68 3.5"9.2#L-80 TC-II Pup 2.992 3.900 9.77 5957.23 5967.00 -2 -3.5"x 1.5"MMG-W ve:RD Dummy-RK latch 2.920 5.968 9.65 5947.58 5957.23 3.5"9.241-80 TC-11 Pup 2.992 3.900 9.81 5937.77 5947.58 3.5"9.21*L-80 TC-II Pup 2.992 3.900 9.82 5927.95 5937.77 3.5"9.24 L-80 TC-lI Pup 2.992 3.900 9.77 5918.18 5927.95 _M#3-3.5"x 1.5-MMG-W re RD Dummy-RK latch 2.920 5.968 9.23 5908.95 5918.18 33"92#1-80 TC-l1 Pup 2.992 3.900 9.80 5899.15 5908.95 3.5"9.2#L-80 TC-I1 Pup 2.992 3.900 1.49 5897.66 5899.15 Phoenix Sensor sub 2.992 5,062 .75 5896.91 5897.66 3.5",9.20.,1-80 TC-11 Pup 2.992 3.900 9.78 5887.13 5896.91 3.5"x 7"HES Dual feedthru Packer t Pinned-60K) #2 packer 2.965 6.100 3.67 5883.46 5887.13 3.5".920,1-80 TC-II Pup 2.992 3.900 4.79 5878.67 5883.46 3.5".9.24,L-80 TC-IIPup2.992 3.900 4.67 5874.00 5878.67 3.5"HES'X'Nipple:2.813"ID 2.813 3.960 1.26 5872.74 5874.00 3.5".9.2#.L-80 TC-I1 Pup 2.992 3.900 4.75 5867.99 5872.74 3.5"9.2#L-80 TC-U Pup 2.992 3.900 9.80 5858.19 5867.99 I -3.5"x 1.5"MMG-W re RD Dummy-RK latch 2.920 5.968 933 5848.86 5858.19 3.5"9.24 L-80 TC-11 Pup 2.992 3.900 4.57 5844.29 5848.86 2 Its 3.5"9.24 L-80 TC-I1 Tubing (#1 -2) 2.992 3.900 63.89 5780.40 5844.29 3.5"9.2#L-80 TC-11 Pup 2.992 3.900 9.77 5770.63 5780.40 GLM#s-3.5"x15"MMG-W w:RD Dummy-RK latch 2.920 5.968 9.24 5761.39 5770.63 3.5"9.2#L-80 TC-Il Pup 2.992 3.900 9.80 5751.59 5761.39 3.5-9.2#L-80 TC-11 Pup(Centralizer w/PIP t 2.992 3.900 1.45 5750.14 5751.59 Phoenix Sensor sub 2.992 5.062 .75 5749.39 5750.14 3.5",9.24,1-80 TC-I1 Pup 2.992 3.900 9.80 5739.59 5749.39 3.5"x 7"HES Dual feedthru Packer(Pinned-60K) #3 packer 2.965 6.100 3.66 5735.93 5739.59 3.5",9.2#,L-80 TC-II Pup 2.992 3.900 9.78 5726.15 5735.93 3.5".9.2#,L-80 TC-II Pup 2.992 3.900 9.79 571636 5726.15 3.5"HES'X'Nipple:2.813"ID 2.813 3.960 1.26 5715.10 5716.36 3.5",9.24,L-80 TC-II Pup 2.992 3.900 9.79 5705.31 5715.10 2 its 3.5"9.24 L-80 TC-11 Tubing (#3-4) 2.992 3.900 64.32 5640.99 5705.31 3.5"9.20 L-80 TC-ll Pup 2.992 3.900 9.80 5631.19 5640.99 -3.5"x 1.5"MMG w:DCR-1 Shear-RKP latch 2.920 5.968 8.85 5622.34 5631.19 3.5"9.2#L-80 TC-11 Pup 2.992 3.900 9.80 5612.54 5622.34 92 jts 3.5"9.24 L-80 TC-II Tubing (#5-96) 2.992 3.900 2944.71 2667.83 5612.54 3.5".9.2#.L-80 TC-I1 Pup 2.992 3.900 9.77 2658.06 2667.83 3.5"HES'X'Nipple:2.813"ID 2.813 3.960 1.08 2656.98 2658.06 3.5".9.2#.L-80 TC-I1 Pup 2.992 3.900 9.78 2647.20 2656.98 81 its 3.5"9.2#L-80 TC-II Tubing (#97-176) 2.992 3.900 2558.71 88.49 2647.20 3 ea 3.5",9.24, L-80 TC-11 Space out Pups(9.80'.9.79',7.081=26.67' 2.992 3.900 26.67 61.82 88.49 lit 3.5"9.24 1-80 TC-I1 Tubing (#177) 2.992 3.900 32.07 29.75 61.82 3.5"9.24 L-80 TC-II Hanger Pup 2.992 3.900 3.78 25.97 29.75 4.5"X 3.5"TC-I1 Crossover 2.992 4.500 1.22 24.75 25.97 FMC Tubing Hanger w/4 1/2"TC-11 Lifting Threads 3.958 11.000 .80 23.95 24.75 Nabors 9-ES RKB 23.95 23.95 Lip wr=85k,Do wt=65k 95 full Cannon clamps.13 Half clamps • • a) N m CO N N O -c M O Q Ln O7 a) N- L N ❑ O N ❑ LC) Ln LO > I- o.a O 1 L O O t 1"-- d - N 00 w ❑ O ❑ to In 0 > 2 H w a a 0 0 w Z w w p Li H H J aw a) 0 Y > r m O� cn J U U w w w W ry 0• 00rnO U_ U_ _0 J w w 11 CI" z Q) ❑ (n (n 0 Z Z Z O J J J ❑ J J ,�, ¢ ¢ < iaa a � O- F I I I z p H p t 0 0 0 0 w Z O Z C) 0- M O co co cn ccnn n Q 1- C >C LULn (�) O M N 6) }� CD• M O LO 0) 0) ❑ LU LU Ln Ni- W 2 • O E w Y 0 O (1) cc it _ O ) a) can co U)) CD ? a ne 0 0 0., c O O O m H H H a1 U) U) co a 0 t m a a) F- m O p ❑ LOLO p 9 0 C 0 Z O O£ 0 0 J J CN CN Z 1 a < w W N t j l j O w 1J a w LU N N a p J w p W Y y N. Z a J J 3 0 W w W a W G ,- Q a _ J H J J » 7 Y a O CO ro n R w J J 3 Q 0 w w < < Do a T1 u) LL LL :n LL (1) a a CD E m z v v N N N a a (/) O a N a a co J Q Q m m LUL U w cn d cc • • Packers and SSV's Attachment PRUDHOE BAY UN POL W-214 SW Name Type MD TVD Depscription W-214 SSSV 2656.98 2513.77 3-1/2" MCX SSSV W-214 TBG PACKER 5735.55 4969.68 3-1/2" HES Dual Feedthru Packer W-214 TBG PACKER 5883.08 5094.03 3-1/2" HES Dual Feedthru Packer W-214 TBG PACKER 5971.3 5168.46 3-1/2" HES Single Feedthru Packer 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 31,2016 TO: Jim Regg c/ / P.I.Supervisor I l `I,� SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC. W-214 FROM: Jeff Jones PRUDHOE BAY UN POL W-214 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvS NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-214 API Well Number 50-029-23373-00-00 Inspector Name: Jeff Jones Permit Number: 207-142-0 Inspection Date: 8/27/2016 Insp Num: mitJJ160827151618 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-214 - Type Inj w 'TVD 4970 - j Tubing 1031 1032 - I 1031_ 1033 PTD Type Test SPT Test psi 2071420 yp p 1500 IA 413 2225 - 2162 . 2153 , Interval 4YRTST P/F P '/' OA 288 511 - 513 • 511 L Notes: 1.3 BBLS diesel pumped. 1 well inspected,no exceptions noted. . SCANNED JUN 2 3 2017, Wednesday,August 31,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, August 14, 2016 11:45 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Ops Lead;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad Z;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;Grey, Leighton;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector W-214 (PTD#2071420)To Be Placed on Injection for AOGCC MIT-IA All, Injector W-214(PTD#2071420) is a mechanically sound well that missed its AOGCC MIT-IA test date,due to being shut in for surface work.The well is now ready to be brought online on produced water injection, and is reclassified as Operable. Please be aware of the fluid-packed annuli when bringing the well online. Plan Forward: 1. Operations: Put on Injection 2. Downhole Diagnostics:AOGCC MIT-IA to 2000 psi Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) SCANNED JAN ! 82017, 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Se ednesday, June 22, 2016 6:45 AM To: AK, I° C2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad Z; AK, OPS • Q. Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Pro)- • AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Zoesch, Eric; 'chris.wallace@alaska.gov' (c ' allace ' alaska.•ov) Cc: AK, GWO DHD Well Integrity; GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; AK, GWO SUPT Well Integrity; McVey, Adrienne; Hibbert, Mic .- • Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, • Worthington, Aras J; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (iim.regg@alaska.gov) Subject: NOT OPERABLE: W-214 (PTD # 2071420)Wil '- ain Shut In Past AOGCC MIT Test Date All, Injector W-214(PTD#2071420) is due for an AOGCC-witnessed MIT-IA by the en. June 2016.The well is currently shut in, and will not be brought online for testing before that time.The well is reclassifi- s Not Operable. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,June 22, 2016 6:45 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Ops Lead;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad Z;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey,Adrienne; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J; Regg, James B (DOA) Subject: NOT OPERABLE:W-214 (PTD#2071420)Will Remain Shut In Past AOGCC MIT Test Date All, Injector W-214 (PTD#2071420) is due for an AOGCC-witnessed MIT-IA by the end of June 2016.The well is currently shut in, and will not be brought online for testing before that time.The well is reclassified as Not Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 �6�i���® � `U Email: AKDCWeIIIntegrityCoordinator(a)BP.com 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c~ Q ~ - ~ ~- ~ Well History File Identifier Organizing (done) ^ Two-sided II I IIII () II II I V III ^ Rescan Needed II I II IIII II I I I II III RE CAN DI TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. 'I ^ Maps: ^ Greyscale Items: Other, No/Type: ~,'~ NAB ~ ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ Project Proofing I III II III III II VII I BY: Maria Date: ~ / ~ ~ Q q 1sl P Scanning Preparation ~ x 30 = ~ ~ + 1 ~ =TOTAL PAGES (Count does not include cover sheet) BY: aria Date: /s/ Production Scanning III IIIIII VIII II III Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) 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 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII III 10/6/2005 Well History File Cover Page.doc • ~, ,~ :k- ~s n x ~ X £~~ MICROFILMED r~ ~~~..~ ~+le~ 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THISPAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • SEAN PARNELL, GOVERNOR ADMINISTRATIVE APPROVAL NO. AIO 25A.002 Ms. Diane Richmond GPB West Subsurface Resource Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Request to Allow Enriched Hydrocarbon Gas Injection PBU W-214 (PTD 2071420) Polaris Oil Pool Dear Ms. Richmond: ~~ ~ ? ~1~ ~~~~- By letter dated March 29, 2010, BP Exploration (Alaska) Inc. (BPXA) requested approval to allow enriched hydrocarbon gas injection in Well PBU Polaris W-214 (2071420). The Alaska Oil and Gas Conservation 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. Alaska and dated April 14, 2010. ..'~ ~ , ~~~ . ~ ~ ~~~ ~ ~ ~niel T. eamount, Jr. ;~ ~°~~, ommissioner, Chair RECONSIDERA Cathy P. F erster Commis' ner AND APPEAL NOTICE As provided in AS 3 ] .05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. ]f 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 are 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 after 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. b ~ ~ p March 29, 2010 900 East Bel~soniBoulevard P.0. Box 196612 Anchorage, Alaska 99519-6612 {907) 561-5111 Daniel T. Seamount ~ ~`, Chairman Alaska Oil and Gas Conservation Commission MAR ;~ 1 201 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 ON~G~BCOn~_~m'~101 RE: Administrative Approval for Enriched Hydrocarbon Gas Injection in Well PBU W-214 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-214. The following wells are approved for enriched hydrocarbon gas injection under AIO 25A Rule 2: 5-215i, W-2091, and W-2151. The rule also states that upon "proper application" additional water injecting wells can be reclassified as WAG injectors. W-2141 was drilled in November 2007 and is currently approved for water injection. Figure 1 provides data on the zonal isolation status of the wellbore. There are no offset wells present within aone-quarter mile radius of W-2141 as depicted by Figure 2. The top of cement (TOC) in W-214 was determined by a cement bond log to be 3750' MD, providing 1742' 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, A ~1 ~~~ Diane Richmond GPB WEST, Resource Manager CC: Mark Agnew (ExxonMobil) Alan Mitchell (BPXA) Dan Kruse (CPAI) David Lenig (BPXA) Glenn Frederick (Chevron) Claire Sullivan (BPXA) Attachments: Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of W-2141 Figure 2: W-2141 '/ mi Radius Map March 18, 2010 Page 2 ~~ J Figure 1: Zonal Isolation Status of Wellbores Within One-Quarter Mile of W-214i Well Dist from TOC, TOC Determination Top Pool (MC Top Injection Coverage injector, ft MD Method sand), MD Sand (Oba), MD W-2141 0 3750 Cement Bond Log 5492 5829 1742' and Dated 19./Nov/2007 No offset wells within one-quarter mile of W-2141 2: W-214i '/ mi Radius _~_, 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 • 2:ECR~IICAL ~,NTEGRITY REPORT _ FUD %:. _ .. t ~ ~ 5 ~O~ OPER ~ FI'ELD ~~ ~ . ~~- ~ t~ i.~.I, NUMBER C~sirg: Sha~:i~ ~~~~ u®i.^.g . ~~~1 P~kcr ~3 I~ y~ o ole Size .~3 ~~ 2n~ ~_®~ Perfs ?:w~.,F.Nir ~.Ir iNTEGB.?T'~' a :~ ~I # Asinuius Fr.~a~ Test: _.~ : C omcaen t s : ` V~`~~~-~-s~~ ~`~` `` T~ :~9ECI3A.NIC?Z INTEGRZI'T -PART ~ 2 ,, - '~ 'MCP . '~ ~~~ Sep ae ~ ~Q S~6a~ to S'~rS~ •• . ~ r ~ - 5°`~ `ta Cemen~ Vol~ass r ~.mC. L;;.ner~ ~. Gsg aS; DV A~, C~a~ ~oZ to cover pere,s ~. ©'2 S \ ~ ca~Ec- ~ Q\vs~~ y n ^ 44 ` ..._, T~1F.fl~ELj.CF.1. To(M` ~3O ~.1~~rr.wr~.~ia~N~.~.+riwri ' Cement Bond Lcag (Yes or Ho)~„_: Tn AC?GCC File,~~.~ CBL :.vaJ.u~tion q gone wove perfs ',~~'~-~I4, ~~ ~\~<~~~' Froduction Log: Type _ ~ Evaluation . - ~° 3T7~ : ~~ ~ ~ ?'ID S3~t ~?VD 10 /ORI09 schfumberipp / „ -r s :,ec '•3�'t. �a L11 NO. 5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE 01/25/07 1 1-4 -03 AY1M-00032 PRODUCTION PROFILE 09/09/09 1 L5 -05 AP30 -00061 PRODUCTION PROFILE 09/15/09 1 03 -24A AZCM -00042 LDL 09/14/09 1 07 -32B BOCV -00027 JEWELRY LOG/GR W/PRESS/TEMP /15/09 1 W -214 AYS4 -00095 INJECTION PROFILE 09/12/09 1 04 -26 BSJN -00014 PRODUCTION PROFILE / 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE — 09/17/VqN/24/09 1 • W -04 88K5 -00003 PRODUCTION PROFILE — 1 P2 -53 AP30 -00060 PRODUCTION PROFILE 9 1 S-43 AWLS -00037 PRODUCTION PROFILE 9 1 12.23 AWLB•00035 INJECTION PROFILE 1 05 -38 AYTO.00029 LDL 1 W -29 AWJI.00050 MEM INJECTION PROFILE 1 W -30 AYIW00034 PLUGBACK W/X -FLOW CHECK 1 3.371L -35 B3S0 -00024 PRODUCTION PROFILE V 1 NK -09 AP30 -00057 USIT 09/07/09 1 W -07A AWJI -00047 MEM CEMENT EVAL ATION 09/07/09 1 11 -10 AYTU -00054 USIT 08/28/09 1 02 -06B ANHY -00111 USIT 09/21/09 1 G -1 BA AWJI -00048 MEM CEMENT BOND LOG C 09117109 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • L/Q DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071420 Well Name/No. PRUDHOE BAY UN POL W-214 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23373-00-00 MD 6331 TVD 5476 Completion Date 11/22/2007 Completion Status 1WINJ REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR, GR, RES, NEU, AZI /DENS PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc Directional Survey ~t Directional Survey ;i~u C Exc Directional Survey (~pt Directional Survey ~ I~ Sonic _ / ~D C Las 15921~Density f~D C Lis 15925t/Sonic WEED C Li 1593 ~d i R s uct on/ esistivity 8 ~g I Induction/Resistivity '~,l}e~9 Induction/Resistivity Well Cores/Samples Information: Samples No Current Status 1 WINJ Directional (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments 0 6331 Open 11 /21 /2007 0 6331 Open 11/21/2007 0 800 Open 12/4/2007 0 800 Open 12/4/2007 5 Col 0 6100 Case 12/21!2007 USIT, CCL, GR, DSLT 19- Nov-2007 399 6331 Open 2/8/2008 LAS DRHB, DRHL, DRHO, RPM, GR, NPHI, RAM, RHOB, ROP in PDF graphics 42 6036 Open 2/13/2008 LIS Veri, USIT, CCL w/PDF and Tif graphics 407 6337 Open 2/22/2008 LIS Veri, GR, ROP, FET, RPM, DRHO, NPHI w/PDS and Tif graphics 25 Blu 398 6290 Open 2/22/2008 MD Vision Service 15-Nov- 2007 25 Blu 398 6290 Open 2/22/2008 TVD Vision Service 15- Nov-2007 ~. Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/9/2008 Permit to Drill 2071420 Well Name/No. PRUDHOE BAY UN POL W-214 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23373-00-00 MD 6331 TVD 5476 ADDITIONAL INFORMATION Well Cored? Y Chips Received? 'Y'7-IQ' Analysis •-~/-Pl Received? Comments: _ __ __ Compliance Reviewed By: ______ Completion Date 11/22/2007 Completion Status 1WINJ Daily History Received? Formation Tops Current Status 1WINJ ~N ~Y'N Date: UIC Y OPERABLE - W-214 (PTD #1420) Slow IA repressurization Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, October 13, 2008 5:44 PM ~~~,tpl`?~`l~~ To: 'NSU, ADW Well Integrity Engineer' Subject: RE: OPERABLE - W-214 (PTD #2071420) Slow IA repressurization Don't recall seeing any further info on this; please provide update on IA repressurization. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer~a BP.com] Sent: Sunday, July 13, 2008 7:59 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Wells Opt Eng; GPB,. Prod Controllers; GPB, Optimization Engr; Rossberg, R Steven Ce: Winslow, Jack L.; Makarov, Egor; NSU, ADW Well Integrity Engineer; West, Taylor Subject: OPERABLE - W-214 (PTD #2071420) Slow IA repressurization Hi all, We(I W-214 (PTD #2071420} continues to exhibit slow IA repressurization but meets the definition of Operable and therefore the well has been reclassified as Operable. Before pursuing a request far AOGCC Administrative Approval for continued injection with slow IA repressurization, attempt will be made to reset dummy gas lift values to mitigate the repressurization. A recent TIO plot has been Included for reference. ~/ «W-214 TIO plot.BMP» Please call with any questions. ,Anna ~u6e, ~'. E. Wei( Integrity Coordinator GPs WeII Group Phone: {907) 659-5102 Pager: (907} 659-5100.x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, June 15, 2008 7:39 PM To: GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Wellman, Taylor T; Makarov, Egor Subject: UNDER EVALUATION - W-214 (PTD #2071420) for IA repressurization Hi all, 10/13/2008 OPERABLE - W-214 (PTD #1420) Slow IA repressurization Page 2 of 2 Well W-214 (PTD #2071420) has been found to have IA pressurization. On 06/07/08, the well passed an AOGCC witnessed MITIA post initial injection. After the test, operations has bled the IA pressure but it continues to repressurize. The wellhead pressures were tubing/IA/OA equal to 1350/960/0 on 6/13/08 after bleeding the IAP from 1400 psi to 960 psi. The IA repressurized to 1560 on 6/14. The well has been reclassified as Under Evaluation and has been added to the AOGCC Monthly Injection Report. The plan forward includes: 1. DHD: Bleed IAP, monitor IA repressurization rate 2. Fullbore: AOGCC invited MITIA. Obtain LLR if MITIA fails. 3. Well Integrity Engineer: If MITIA fails, consider having slickline check the DGLV to ensure it is fully set. A TIO plot and wellbore schematic have been included for reference. 10/13/2008 • 10/13/2008 W-214 TIO Plot ,ant , .. ....................................................................................... . L~~ ^~ ~ ,i W-214 Injection Plot 0" ~3~ o' ~ CkcnplOg OEtnjgr~ OBltfilOB [g/Zcn7g OB/,mro8 Q9r'06.n78 09lIZn78 Q7,:.9!~+ ¢3f'rA% tnru~ ii7,'it?QE N i N ~y T 0 a 0 4 1D 7 Y? ti ]Q 4 CO 1 ~ ~ O 1 ~ I CO ~ i 1 i O O ~ j U7 Q N Cn ~ °a a a 0 cr; ~t O 4'.'" Q Q O ='~ 0 a 0 cv ~ ~ O C` 1 If? i O O a m MEMORANDUM • Toy Jim Regg ~ 7 f P.I. Supervisor ~v~ ((~~ 1 J~ FROM: Chuck Scheve Petroleum Inspector State of Alaska -- Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 02, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) TNC W-214 PRUDHOE BAY UN POL W-214 Src: Inspector NnN-('nNFTIIFNTi A i . Reviewed By: P.I. Suprv~/_'~I~ (~n mm Well Name: PRUDHOE BAY UN POL W-214 Insp Num: mitCS080702080I l9 Rel Insp Num: API Well Number: 50-029-23373-00-00 Inspector Name• Chuck Scheve Permit Number: 207-142-0 Inspection Date: 7/I/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well w-zta TYPe Inj. w Tarp a97o IA 160 -- 2510 2420 2420 P.T. zo7lazo TYPeTest SPT Test psi Isoo pA o 17o no vo -- Interval orllER p/F P ~ Tubing o 17o Igo vo NOteS' Test performed for possible IA repressurization. Wednesday, July 02, 2008 Page l of t 1VIEM®RAl~I)UlVi To: Jim Regg ~~.,%~ 6jl Z ~C7~'j P.I. Supervisor ( C FROM: Chuck Scheve Petroleum Inspector J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 09, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-214 PRUDHOE BAY UN POL W-214 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. SuprvJ Comm Well Name: PRUDHOE BAY UN POL W-214 API Well Number: 50-029-23373-00-00 Inspector Name Chuck Scheve Insp Num: mitCS080G09075954 Pernut Number: 207-142-0 Inspection Date: 6i7~2o08 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i, w-z1a ~ T ---- - - ----- e n'. w a97o ______ -- ~ P.T.~ TYpeTest ~ TVD ]soo - I, IA 60I zslo za9o ~ za9o - -- - 1 zo7lazo sPT P . _ _ ~ Lazo ' Yp ,Test st OA ~- 190 190 1 190 IMTAL P Tubin ; 1230 ' 1250 1290 - 1320 Interval P/F .i g L------ _ ----- Notes: Monday, June 09, 2008 Page I of l o2/zo/os ~chlgmber~r NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P:Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne Well Jnh # 1 nn nwccrintinn Hato RI Cnlnr Cn 18-32A 11968923 SCMT (- / 02112108 1 MPE-12 11978438 MEM INJ PROFILE IU Z C' o~U 5` - C3Cv 02/08108 1 4-14/R-34 11996383 USIT (, 02112/08 1 V-07 40016096 OH MWD/LWD EDIT '~ - G ( Lit 12/04107 2 1 L1-14 11626482 RST ~ '-- ( 1 s'~~~3 05/09/07 1 1 L2-18A 11657124 RST ~ 05/10/07 1 1 L2-33 11626484 RST j (p - j 'nj G ( 05/11/07 1 7 G-31A 11962778 RST - t)S`~( ~~ 01/01/08 1 1 V-111 11978439 MEM GLS ~ ~ 02/10/08 1 W-216 12031441 _ CH EDIT PDC GR (USIT) ~ 9 01/11108 1 W-214 40016055 OH MWD/LWD EDIT V=, - ( 11/15107 2 1 Y-07A 11962576 USIT 12178107 1 C-356 11978432 _ MEM DDL _ ( 01/02108 1 rl_tASt AGRNVWLtU(it Ktlalr I tlY SItaNIN(a ANU Kt I UKNING.~VNt.,GtJPY tAGN TQ: a Y BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I x „ t ~ •>r fit, _.,~ t1~f111~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: rU o21oa1os • :7 ~~hlumbe~g~~. NO. 4572 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt, Polaris,Lisburne Wnll Jnh $ Inn rlocerin4inn rlatp BI_ Cnlnr CD LGI-04 11970706 SBHP SURVEY J ~ ' '- 01/01/08 1 MPH-12 11978435 MEM DDL 01131/08 W-216 12031441 USIT (~--. 01/11/08 1 W-214 11855826 CH EDIT PDC GR (USIT) (. 11/19107 1 GNI-04 11846828 CH EDIT PDC GR (USIT) 11/11/07 1 15-36B 11216209 MCNL (0 ^ 08/05/06 1 1 H-24A 11767145 MCNL "~_ 15 t 11129/07 1 1 C-04B 11216198 MCNL ~ ~ ~"~ ~ ( 3 06/02/06 1 1 L3-11 11962776 MCNL ~ ~ q 12/12107 1 1 YLtASt AI:KNUWLtUl9t KtGtIY 1 tSr JIt9NINli ANU Kt I UKNINCi VNt GVYY tAGFI I U: BP Exploration (Alaska) Inc. - - ~ ~ ~ _~ ~~ ~, Petrotechnical Data Center 1R2-1 ~ ~~`~' ~ ~ 1_' " ~~ ~' °'~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~~~~ y ~? ~ ~ ~t'~j Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ `-' Date 02-08-2008 Transmittal Number:92927 ~ ~j ~, ~~ . ~ _ -_ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. m ~ ~°~ ~ ,'= h (BPXA FIELD LOG DATA) , ~ ,~.. , . , If you have anv questions, please contact Dortch at the PDC at 564-4973 leliverv Contents 8-13BPB1 l ~'~--loo tS q ~ S- 8-13BP62 l$'~-r6o lS`~l~ 8-136PB3 ISS~-l~ l S9i~ 1-14B c)U'~ - I~ (v ~~ 4 / ~ -14A c'~U~-_ !03 159ab /-214 V2(° 2U~- «a -59a1 L 1,~~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box (.96612 Anchorage, AK 995 19-66 1 2 12/19/07 ~~ SchEumherger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.4528 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris, Aurora Date BL Color CD W214 5-126 11855826 11594528 USIT ISOLATION SCANNER REVISED 11/19/07 11101107 1 1 5-126 5-126 11594528 40015989 CH EDIT PDC ISOLATION SCANNER OH MWDILWD EDIT ~ - 11101107 10128107 2 1 1 PLEASE ACKNOWLEDGE RECEIPT RY SIGNING AND RETURNING ONE COPY EACH T O: BP Exploration (Alaska) Inc. Schlumberger-DCS Petrotechnical Data Center LR2-1 2525 Gambell St, Suite 400 900 E Benson Blvd ~ Anchorage, AK 99503-2838 ~ Anchorage AK 99508-4254 U ~~- F.» F! }; ~'~~ ~~ ~ - ATTN: Beth Date Delivered. Received by: ~.~ 4-~ y, ~ a.... > (t .~ ,~; STATE OF ALASKA ~'~~~~•~ ~ ~ ~_~~- -- ALASKA~L AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~C ~. tt9nel~.s r1~i ta. ~?~~. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.~,o ^ GINJ ®WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well C ^ Dev ~nt~ ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 11/22/2007. 12. Permit to Drill Number 207-142. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/5/2007 i 13. API Number 50-029-23373-00-00 4a. Location of Well (Governmental Section): Surface: 4889' FSL 1176' FEL SEC 21 T11 R12E 7. Date T.D. Reached 11/14/2007/ 14. Well Name and Number: PBU W-2141 ' , , , . N, , UM Top of Productive Horizon: 1222' FSL, 4637' FEL, SEC. 15, T11 N, R12E, UM 8. KB (ft above MSL): 80.9' Ground (ft MSL): 52.4' 15. Field /Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 1489' FSL, 4615' FEL, SEC. 15, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 6237 5395 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 612049 y- 5959866 Zone- ASP4 10. Total Depth (MD+TVD) 6331 5476 16. Property Designation: ADL 028263 TPI: x- 613840 y- 5961507 Zone- ASP4 Total Depth: x- 613857 y- 5961773 Zone- ASP4 11. SSSV Depth (MD+TVD) NIA 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rin ed information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1961' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR, GR, RES, NEU, AZI /DENS PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# A-53 Surf ce 108' Surface 108' 42" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 28' 1310' 28' 1310' 16" 872 sx AS Lite 726 sx AS I 9-5l8" 40# L-80 28' 3714' 28' 3353' 12-1/4" 443 sx Dee Crete 329 sx Class'G' 7" 26# L-80 26' 632 ' 26' 5466' 8-3/4" 298 sx Cla s' ' 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 6088' 5736', 5883', 5972' MD TVD MD TVD 5826' - 5852' 5046' - 5068' 5916' - 5942' 5122' - 5144' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5984' - 6034' 5179' - 5221' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED 2275' Freeze Protect w/ 82 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~.~..w__~...._,..._._• CO~,tPLE7iC~1 None ~~~.., is~-~4. ~ ~ ~~~% /l-afrl-O J:. Form 10-407 ReVlsed 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST AlL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . ^ Yes ®No Permafrost Top 29' 29' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1990' 1946' detailed test information per 20 AAC 25.071. Ugnu 3816' 3433' None Schrader Bluff NA 5566' 4828' Schrader Bluff NB 5595' 4852' Schrader Bluff NC 5636' 4886' Schrader Bluff NE 5648' 4896' Schrader Bluff NF 5718' 4955' Schrader Bluff OA 5755' 4986' Schrader Bluff OBa 5821' 5042' Schrader Bluff OBb 5854' 5070' Schrader Bluff OBc 5915' 5121' Schrader Bluff OBd 5984' 5179' Schrader Bluff OBe 6061' 5244' Schrader Bluff OBf 6109' 5285' Base Schrader Bluff OBf / 6174' 5341' Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 6174' 5341' 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. ~ ~~ ~~D Signed Terrie Hubble Title Drilling Technologist Date PBU W-2141 207-142 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Amanda Rebol, 564-5543 Permit No. / A royal No. INSTRUCTIONS GeNeaA~: 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 1 a: 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. !rear 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 $P EXPLORATION -Page 1 of 1 Leak-Off Test Summary Legal Name: W-214 Common Name: W-214 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 11/14/2006 LOT 3,745.0 (ft) 3,377.0 (ft) 8.80 (ppg) 680 (psi) 2,224 (psi) 12.68 (ppg) • ~~ Printed: 12/4/2007 8:55:37 AM $P EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/3/2007 16:00 - 20:30 4.50 RIGD P PRE Rig down and prep for rig move. Moved satellite camp, shops to W-Pad. 20:30 - 22:30 2.00 MOB P PRE PJSM. Pull -mud pits away from sub. Pull sub off of S-1261. 22:30 - 00:00 1.50 MOB P PRE PJSM. Lay over derrick. Pull up to edge of pad. 11/4/2007 00:00 - 02:00 2.00 MOB P PRE Move sub and mud pits to W-2141. 01:00 - 05:00 4.00 MOB P PRE Adjust time for Daylight Savings Time. Continue moving to W-2141. Rig on pad @ 05:00 hr. Position rig to raise derrick (off well) 05:00 - 09:00 4.00 MOB P PRE Spot and set mats, herculite and sub base on W-214i. 09:00 - 10:30 1.50 MOB P PRE Spot and set mud pits. 10:30 - 11:00 0.50 MOB P PRE Spot and set cuttings box, hook up interconnect between rig and mud pits. 11:00 - 12:00 1.00 MOB P PRE PJSM. Raise and pin derrick. Take on seawater. 12:00 - 15:00 i 3.00 ~ RIGU ~ P 15:00 - 00:00 9.00 DIVRTR P 11/5/2007 00:00 - 03:00 3.00 DIVRTR P 03:00 - 04:00 1.001 RIGU P 04:00 - 08:00 4.00 RIGU P 08:00 - 09:00 1.00 I RIGU I P 09:00 - 12:00 3.00 RIGU P 12:00 - 12:30 I 0.501 DIVRTR ~ P 12:30 - 13:30 I 1.001 RIGU I P 13:30 - 14:00 0.501 RIGU P 14:00 - 14:30 0.50 RIGU P 14:30 - 15:30 I 1.001 DRILL I P 15:30 - 17:00 I 1.501 DRILL I P 17:00 - 00:00 I 7.001 DRILL J P 111/6/2007 100:00 - 02:00 I 2.001 DRILL 1 P 'Rig accepted for operations on W-214i @ 12:00 hr, 11/4/2007. PRE Unbridal from blocks. Berm rig. Rig up rig floor. Mix spud mud. PRE Nipple up diverter system. PRE Continue nippling up diverter. Mix spud mud. Change out topdrive saver sub. Prep floor to pickup drill pipe. PRE Change out lower TIW valve. Adjust topdrive back-up wrench. PRE Pick up and rack back 5" drill pipe. Picked up 48 jts of drill pipe and 17joints of 5" HWDP. Make up and rack back Jar stand. PRE Prep floor for BHA. Stage BHA tools to rig floor. PRE Make up BHA #1: New 16" HTC MXL-1 bit, PDM w/ ABH- 1.83 deg, NM lead. DC, NM Stab, MWD, UBHO, NM Stab. PRE Function test surface diverter system. Perform accumulator draw down test. Witnessing of test waived by AOGCC rep Jeff Jones. Test witnessed by BP WSL T. Anglen and NAD TP M. Ashley. PRE Fill mud circulating lines with mud. Pressure test lines to 3,000 psi - OK. Install topdrive blower hose. Fill hole and check for leaks - OK. PRE Rig up Gyro Data and Halibuton E-line support. PRE Hold Pre-Spud, safety and environmental meeting with WSL and TP. COND2 Spud in W-214i 16" surface hole from 108' to 267'. 650 gpm, 930 psi off, 1,000 psi on. 60 rpm, 1k TO off, 2k TO on. PU - 53k, SO - 50k, RWT - 52k, WOB - 10k. COND2 POH for jar stand from 267' to 85'. Pick up Sea NM DCs, Saver Sub and make up Jar stand. Run in hole to bottom. 5 ft of fill. COND2 Directionally drill 16" surface hole from 267' to 702'. 670 gpm, 1,300 psi off, 1,540 psi on. 60 rpm, 2k TQ off, 5k TQ on. PU - 74k, SO - 74k, RWT - 74k, WOB - 20k. AST - 2.06 hrs, ART - 2.26 hrs. Gyro survey every 100 ff. COND2 Directionally drill 16" surface hole from 702' to 907'. 690 gpm, 1,515 psi off, 1,680 psi on. 60 rpm, 2k TO off, 5.5k TO on. PU - 84k, SO - 81 k, RWT - 82k, WOB - 35k. Printed: 12/a/2007 8:55:44 Ann BP EXPLORATION Page 2 of 12 .Operations Summary: Report Legal Well Name: W-214 Common Well Name: W-214 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To Hours Task Coded NPT 11/6/2007 00:00 - 02:00 2.00 DRILL P 02:00 - 03:00 1.00 DRILL P 03:00 - 10:00 7.00 DRILL P 10:00 - 12:00 I 2.001 DRILL I P 12:00 - 13:30 I 1.501 DRILL I P 13:30 - 14:00 I 0.501 DRILL I P 14:00 - 16:15 I 2.251 DRILL I P 16:15 - 17:00 I 0.751 DRILL P 17:00 - 19:30 2.50 DRILL P 19:30 - 20:00 0.50 DRILL P 20:00 - 00:00 4.00 CASE P 11/7/2007 100:00 - 05:15 I 5.251 CASE I P 05:15 - 06:00 I 0.751 CASE P 06:00 - 08:00 I 2.001 CASE I P 08:00 - 12:00 I 4.001 CASE I P 12:00 - 12:30 I 0.501 CEMT I P 12:30 - 13:30 I 1.00 I CEMT I P 13:30 - 14:30 1.00 CEMT P 14:30 - 15:00 0.50 CEMT P Spud Date: 11/5/2007 Start: 11/3/2007 End: 11/22/2007 Rig Release: 11/22/2007 Rig Number: Phase Description of Operations COND2 Gyro survey every 100 ft. Last Gyro @ 800' COND2 Rig down Gyro Data and Haliburton E-line equipment. COND2 Directionally drill 16" surface hole from 907' to TD @ 1,320'. PU - 86k, SO - 77k, RWT - 85k, WOB - 35k. 60 rpm, 2k TO off, 5-7k TO on. 698 gpm, 1,630 psi off, 1,950 psi on. AST = 3.21 hrs, ART = 3.55 hrs from 00:00 - 10:00 COND2 CBU x3 @ 680 gpm, 1565 psi, 80 rpm. Shut down, monitor well - OK. COND2 POH for wiper trip pumps off from 1,320 - 173' (Top of Drill Collars). No tight spots reported. PU - 93k, SO - 86k. COND2 RIH from 173' to 1,200' md. No tight spots reported. Wash from 1,200' to TD @ 1,320' md. Found 30' of hole fill and cleaned out. COND2 CBU x 6 reciprocating 50' strokes. 695 gpm, 1,600 psi, 60 rpm, 2.5k TQ, PU - 93k, SO - 87k, RTW - 87k, MW - 9.2 ppg. First 3 BU had sand (no running gravels) coming over shakers 4" deep but then started tapering off. After 6 BU, very little sand returning. COND2 Shut down pumps. Monitor Well - OK. POH from 1,320' to top of HWDP @ 725' md. No problems or tight spots. COND2 Stand back HWDP, Jar and DC stands from 725'. Laydown BHA #1 motor and bit. Bit Grade 5-3-WT-A-0-1-NO-TD. COND2 Clean & clear rig floor. COND2 Rig up to run 13-3/8" Secondary conductor casing. RU casing tongs. CO Bales & install casing slips and elevators. Change out backup tongs. Make dummy run with hanger and landing joint. Bring 10' pup to rig floor. COND2 PJSM. Pick up and Baker-Lok 13 3/8" shoe track. Check floats - OK. Run in hole with 31 joints 13 3/8" 68# L-80 BTC secondary conductor casing to 1,280'. Make up torque to mark - 9,400 ft/Ibs avg. using Best-O-Life 2000 NM. Ran 15 bowspring centralizers on first 15 joints with 1 locked down 10 ft above Float Shoe and 1 locked in middle of full joints above and below TAM collar. Fill every joint with casing fill-up tool. Casing running hooktoads consistant without until last joint took 20k for 5-10 feet before weight came back. COND2 Make up hanger and landing joint. Wash down w/ Franks tool. Washed out hole 30' of fill from 1,280' and and land casing on depth @ 1,310' md. PU - 120k, SO - 85k 420 gpm, 675 psi. COND2 Continue circulating to 2 bottoms up. Shut down pumps. Monitor hole - OK. COND2 Rig down casing running equipment. Attempt to split landing joint at collar below flowline, but not backing out. Drain stack, disconnect knife valve, close diverter bag. Back out & lay down split joint. Blow down top drive. Change out bales and elevators. COND2 Make up stab in cementing BHA - Halliburton stab in stinger, 1 jt 5" HWDP, 12-1/4" Ghost Reamer, 2 jt 5" HWDP, 12-1/4" Ghost Reamer. COND2 RIH on 5" HWDP & DP to 1,220' md. PU - 70k, SO - 66k. COND2 Rig up surface equipment for cementing operations. COND2 Spot 50 bbl thinning pill inside casing above stab in collar. 5 Printed: 12/4/2007 8:55:44 AM i ~ $P EXPLORATION' Page 3 of 12 Operatiolns Summary: Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date ~ From - To' Hours' Task ~ Code ~ NPT ~ Phase Description of Operations 11/7/2007 15:00 - 18:030 3.50 CEMT P I I COND2 18:30 - 23:30 I 5.001 CEMT I P I I COND2 23:30 - 00:00 I 0.501 CEMT I P I I COND2 ~ 11/8/2007 100:00 - 00:30 I 0.501 CEMT P I I COND2 00:30 - 01:15 0.75 CEMT P COND2 01:15 - 02:15 1.00 CEMT P COND2 02:15 - 03:15 I 1.001 CEMT I P I I COND2 03:15 - 04:00 I 0.751 CEMT I P I I COND2 04:00 - 04:30 I 0.501 CEMT I P I I COND2 04:30 - 05:00 I 0.501 CEMT I P I I COND2 04:30 - 07:00 I 2.501 CEMT I P I I COND2 07:00 - 08:00 1.00 CEMT P COND2 08:00 - 08:30 0.50 CEMT P COND2 08:30 - 09:00 0.50 CEMT P COND2 09:00 - 09:30 0.50 CEMT P COND2 09:30 - 10:00 0.50 CEMT P COND2 10:00 - 11:00 1.00 CEMT P COND2 bpm, 260 psi. Sting into float collar @ 1,225' and and verify space out. Break circulation and stage pumps up to 11 bpm, 1050 psi. Circulate and condition mud from 400 vis spud mud to 16 YP. PJSM w/ Schlumberger cementers. Batch up cement. Pump 5 bbls water, test lines to 3500 psi. Pump 156 bbls of 10.0 ppg mud push. Pump 710 bbls of lead 10.7 ppg ASL cement. 6.0 bbl/min with full returns. Pumped 120.5 bbls 15.7ppg AS1 cement at 4 bpm. After 60 bbls tail pumped and 20 bbls of solid mudpush and clabbered mud at surface, returns went to 0%. Dowell chased cement with 17.5 bbls of water (leaving 5 bbls in drillstring). Based on mudpush returns, hole volume had -820% excess. Good lifting pressure on first half of tail until returns lost, then pressure stayed flat. Saw good indication w/ pump pressure of 15.7ppg tail cement turning corner and moving up hole. Bleed off and check floats. CIP @ 23:37. Assuming 820% excess, Top of cement expected at -210' md. Rig down surface valves for cementing. Unsling from stab in float collar & PU 5 feet. Insert foam drill pipe wiper ball. Load TAM shifting tool in pipe shed. Prepare for port collar cementing attempt. 'Notify AOGCC Rep. Chuck Scheve of lack of cement to surface on primary cement job. Unsling from stab in float collar and circulate out remaining 5 bbls of cement to surface. 700 gpm, 625 psi. POH w/ cementing toolstring to top 12.25" ghost reamer. Break out and lay down top reamer. Make up TAM shifting tool RIH w/ shifting tool 460' and and RU pups for spacing in preparation for secondary cement job. Take parameters prior to latching into collar. PU - 57k, SO - 54k, TO - 4.1k. Slowly RIH to 481' md. 5k slack off indicates dogs engaged in collar. Rotate right to stop at 4.8k TO to confirm latch. Pressure test sleeve and shifting tool cups to 1000 psi - OK. Bleed pressure to 300 psi. Rotate left until 300 psi bled down to 175 psi. Break circulation and pump mud through Tam collar @ 3 bpm. Attempt to establish circulation -unable. Injecting up to 3 bpm, 450 psi. No returns at surface. Shut down after pumping 18 bbls fluid away. Rotate right to close TAM collar. Pressure up to 1000 psi to confirm closed - OK. Maintaining 5k overpull, rotate to release dogs from collar. PU string 20' and standby. PJSM w/ all hands. Pressure up on TAM shifting tool to 2,600 psi and blow rupture disk in choke. POH laying down 5" drillpipe. LD TAM shifting tool and cementing BHA. Clean and clear rig floor. PJSM. Run in hole w/ 5" drillpipe from derrick to 950' md. POH laying down 5" DP to 425' md. Run in hole w/ 5" drillpipe from derrick to 950' md. POH laying down 5" DP to surface. Printed: 12/4/2007 8:55:44 AM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date from - To Hours Task: Code NPT Phase Description of Operations .11/8/2007 11:00 - 12:00 1.00 CEMT P COND2 Clean and clear rig floor of 5" handling equipment. Service topdrive & adjust backup wrench. 12:00 - 13:00 1.00 CEMT P COND2 PJSM. Change out elevators. Attempt to MU split landing joint pup to landing joint but cross-threaded. Mobilise casing tongs. 13:00 - 15:00 2.00 CEMT P COND2 Pick up 33 joints 4" drillpipe from pipe shed to 1,045' and rack back 11 stands in derrick. 15:00 - 17:00 2.00 CEMT P COND2 PJSM. RU casing tongs and make up split landing joint pup into landing joint. Pull and lay down landing joint. RD tongs ~ and clear floor. 17:00 - 21:00 4.00 CEMT P COND2 Pick up 33 joints 4" drillpipe from pipe shed to 1,045' and rack back 11 stands in derrick. Repeat. Total 4" drillpipe racked back is 33 stands = 3,093'. 21:00 - 00:00 3.00 DRILL P SURF Make up BHA #2: New 12.25" HTC MXL-1X bit, 1.5 deg PDM, NM lead DC, NM STAB, MWD, NM STAB, , NM DC, NM XO, 2 ea NM DC, 1 jt 5" HWDP, Jars, 1 jt 5" HWDP, XO. 11/9/2007 00:00 - 02:00 2.00 DRILL P SURF RIH with BHA #2 picking up 4" HWDP from shed to 1001' md. 02:00 - 02:30 0.50 DRILL P SURF Shallow test MWD - OK. 02:30 - 04:00 1.50 DRILL P SURF Tag up on top of cement stringers at 1,203' md. Clean out shoe track and rathole from 1,203' - 1,320' md. 600 gpm, 1740 psi, 40 rpm, 2-4k TQ, PU - 77k, SO - 75k, RTW - 76k, 5k WOB. 04:00 - 05:00 1.00 DRILL P SURF Circulate 620 gpm, 1806 psi and reciprocate pipe to get cement contamination out of hole. Prepare for and swap to new 8.6 ppg spud mud. 05:00 - 07:30 2.50 DRILL P SURF New mud to surface. Shut down pumps. Clean flowline, under shakers, and possum belly of all cement contamination. Build replacement mud volume. Clean pill pit of contaminated mud. 07:30 - 12:00 4.50 DRILL P SURF Directional driN from 1,320' - 1,925'. 695 gpm, 2,780 psi off, 2,850 psi on. 80 rpm, 2.Ok TQ off, 6.Ok TO on. PU - 75k, SO - 72k, RWT - 75k, WOB - 30k. AST = 2.10 hrs, ART = 1.08 hrs Steady clays returning across shakers. 12:00 - 22:30 10.50 DRILL P SURF Directional drill from 1,925' - TD @ 3,725' md. 625 gpm, 3,245 psi off, 3,315 psi on. 80 rpm, 4.Ok TO off, 8.Ok TO on. PU - 110k, SO - 90k, RWT - 100k, WOB - 25-35k. AST = 1.53 hrs, ART = 4.25 hrs Clays returning across shakers 1-2 inches deep. 22:30 - 00:00 1.50 DRILL P SURF Circulate bottoms up 3 x at 700 gpm while reciprocating pipe. 60 rpm, 3350 psi, 2.8k TQ, PU - 110k, SO - 75k, RWT - 97k. 11/10/2007 00:00 - 00:30 0.50 DRILL P SURF Continue to circulate bottoms up 3 x at 700 gpm while reciprocating pipe. 60 rpm, 3350 psi, 2.8k TO, PU - 110k, SO - 75k, RWT - 97k. 00:30 - 03:30 3.00 DRILL P SURF POH from TD @ 3,725' - 2,480' and pumps off. Pulling 35-40k over in several spots. Wipe tight spots and pull past with less than 25k over 03:30 - 04:30 1.00 DRILL P SURF Attempt to pull past 2,480' several times, but unable to wipe clean. Pump out of hole 4 stands from 2,480' - 2,120' md. 250 gpm, 900 psi, PU - 95k, SO - 80k. 04:30 - 08:00 3.50 DRILL P SURF Backream out of hole from 2,120' and to 1,475' md. 80 rpm, 2.6k TO, 600 gpm, 2125 psi, 82k pulling weight. Clay returns across shakers beginning at bottoms up from pumping out and Printed: 12/4/2007 8:55:44 AM ~~ BP EXPLORATION. Page 5 of 12 Qperations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date I From - To I .Hours ~ Task I Code I NPT I Phase I Description of Operations 11/10/2007 04:30 - 08:00 3.50 DRILL P SURF increasing. 08:00 - 08:30 0.50 DRILL P SURF Returns cleaning up somewhat. Shut down pumps and pull last 2 stands into casing - OK with 5-18k overpulls but no swabbing. PU - 91 k. 08:30 - 10:00 1.50 DRILL P SURF Blow down and service topdrive. Clean rig floor from wet trip. Clean out possum belly. Epoch on location to service software trouble w/ pit gain/-oss variable. 10:00 - 13:30 3.50 DRILL P SURF Trip in hole from 1,290' to 3,725' md. Work tight spots from 2,110' to 2,160'. RIH pumps off 2,160' to 2,570' md. Unable to pass 2,570' w/o pumps. Wash and ream down 2,570' to 2,630 @ 300 gpm, 1000 psi, 80 RPM, 5-10k TO. RIH pumps off 2,630 - 2,840, Wash and ream 2,840 - 2,930. RIH pumps off 2,930 - 3,310. Wash and ream 3,310 - 3,370. RIH pumps off 3,370 - 3,590. Wash and ream 3,590 - TD @ 3,725' md. PU - 110k, SO - 80k, RTW - 100k. 13:30 - 15:00 1.50 DRILL P SURF Circulate and recipricate 3+ bottoms up. 690 gpm, 3540 psi, 105 rpm, 5.1 k TQ, RTW - 102k. MW in 9.5ppg, MW out 9.7 PP9• 15:00 - 19:00 4.00 DRILL P SURF Shut down pumps, monitor well -static. POH slick to 1,290' (above 13-3/8" casing shoe @ 1,310' md). Wipe one spot at 2410' and after 25k overpull, and pull 15k over at 2,100. Otherwise, no more than 5-10k overpulls entire trip out. PU @ TD - 125k, PU @ Shoe - 85k. 19:00 - 19:30 0.50 DRILL P SURF CBU at casing shoe. 525 gpm, 1430 psi, 42 rpm, 1-3k TO, RTW - 76k. Shakers still clean at bottoms up. 19:30 - 20:00 0.50 DRILL P SURF Blow down top drive, disconnect blower hose. 20:00 - 21:00 1.00 DRILL P SURF POH from 1,282' to BHA @ 186' md. 21:00 - 00:00 3.00 DRILL P SURF PJSM. Pull out of the hole standing back jars & drill collars. Lay down MWD. 11/11/2007 00:00 - 01:00 1.00 DRILL P SURF 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. 01:00 - 02:00 1.00 DRILL P SURF Clean and clear rig floor of all BHA componants. 02:00 - 06:00 4.00 CASE P SURF Rig up Nabors casing equipment. Change out bales and make up franks fill up tool. Make dummy run with 9 5/8" mandrel casing hanger. Hanger on seat w/ landing joint 28' in and 6.9' out. 06:00 - 07:00 1.00 CASE P SURF PJSM. Begin running 9-5/8" 40# BTC surface casing. Baker Loc shoe track. Check floats. Run bow spring centralizer on joint #1 - 10' back from shoe. 07:00 - 12:00 5.00 CASE P SURF Run 9-5/8" 40# BTC surface casing to joint number 52 @ 2,112' md. shoe depth. Average make up tq 9400 ft/Ibs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every joint. Install bowspring centralizer over collars on joints 3-25. PU - 115k, SO - 85k 12:00 - 14:00 2.00 CASE P SURF Change out cup on franks tool. Pipe skate inoperable. Begin troubleshooting skate while changing out Franks tool cup. 14:00 - 00:00 10.00 CASE N RREP SURF Troubleshoot pipe skate. Found faulty solenoid. Hot shot part Printed: 12/4/2007 8:55:44 AM BP EXPLORATION` Page 6 of 12' Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date: From - To Hours Task Code NPT Phase Description of Operations 11/11/2007 14:00 - 00:00 10.00 CASE N RREP SURF from deadhorse & replace. Test skate. Roll pumps over and obtain PU & SO every 30 minutes. No change in hookloads. 11/12/2007 00:00 - 03:00 3.00 CASE P SURF Pipe skate repaired and operating corcectly. Resume running 9-5/8" 40# BTC surface casing from joint number 52 @ 2,112' md. shoe depth to joint 90 @ 3,643' md. Average make up tq 9400 ft/Ibs. Lubricate threads w/ BOL 2000 thread compound. Filling pipe every joint. Install TAM collar between joints 60&61 w/ bowspring centralizers over stop rings 15' either side of TAM collar. PU - 187k, SO - 85k. 03:00 - 04:00 1.00 CASE P SURF Precautionary wash last joint down 2 bpm, 660 psi. PU Landing joint and hanger. Wash down and land 9 5/8" surface casing on ring @ 3,715' with mandrel hanger. 04:00 - 04:30 0.50 CEMT P SURF Rig down franks fill up tool, casing tongs, & slips. Blow down lines. Make up cement head and manifold. 04:30 - 08:30 4.00 CEMT P SURF Stage up pumps to 340 gpm, 630 psi. Reciprocate pipe in 10' strokes. Circulate and condition mud back in preparation for cement job. Beginning parameters: PU - 150k, SO - 105k, 104 gpm, 490 psi. Final parameters: PU - 185k, SO - 125k, 351 gpm, 525 psi. 08:30 - 12:15 3.75 CEMT P SURF PJSM w/ Schlumberger cementers. Batch up cement. Pump 5 bbls water, test lines to 3500 psi. Pump 97.5 bbls of 10 ppg mud push. Drop bottom plug, pump 314 bbls of lead 10.7 ppg DeepCrete cement. 6.1 bbl/min with full returns. Pumped 49 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 @ 5 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 and hold at 1550 psi 3748 strokes = 96.5% efficiency. CIP @ 12:12. Full returns throughout job. 130 bbls cement back to surface. Reciprocated pipe in 7' strokes until 8 bbls of durastone away. PU weight rose 20k in one 7' stroke. Set back on ring & stop reciprocation. 12:15 - 13:00 0.75 CEMT P SURF Pressure up casing to 3500 psi & hold for 30 minutes -Good Test -Only lost 20 psi. 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 - 22:00 6.00 DIVRTR P SURF Flush stack. Lay down drilling riser. Nipple down diverter & remove diverter stack from wellhead. 22:00 - 00:00 2.00 WHSUR P SURF Prepare tubing spool & wellhead. Position spool on wellhead. Run in set screws to 450 ft-Ibs. Test metal to metal seal to 1000 psi for 10 minutes - OK. 11/13/2007 00:00 - 06:00 6.00 BOPSU P SURF Position BOP stack on tubing spool. Nipple up stack. Make up turnbuckles, riser, casing & tubing working valves. 06:00 - 08:00 2.00 BOPSU P SURF Make up BOPE floor equipment. Install test plug. Fill all testing lines. 08:00 - 15:30 7.50 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 Chuck Scheve. Test witnessed by NAD Toolpusher Ronnie Dalton. 15:30 - 19:30 4.00 DRILL P PROD1 Pick up BHA #3 consisting of 8-3/4" DSX619M Hycalog PDC Printed: 12/4/2007 8:55:44 AM BP EXPLORATION: Page 7 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Descripti©n of Operations 11/13/2007 15:30 - 19:30 4.00 DRILL P PROD1 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 992'. 19:30 - 21:00 1.50 DRILL P PROD1 RIH on drillpipe singles from shed. Rotate past TAM Port collar from 1,270' to 1,311' w/ 40 rpm and no pumps. Pressure test casing to 1000 psi for 5 minutes after BHA past TAM collar - OK. Shallow test MWD @ 1,311'. 500 gpm, 837 psi - OK. MU Ghost reamer 1,381' back from bit. 21:00 - 23:30 2.50 DRILL P PROD1 RIH w/drillpipe singles from pipeshed 1,381' to 3,581' md. 23:30 - 00:00 0.50 DRILL P PROD1 Cut and slip 92' drilling line. Inspect under drawworks. Service rig. Lubricate top drive. 11/14/2007 00:00 - 03:00 3.00 DRILL P PROD1 Cut and slip 92' drilling line. Inspect under drawworks. Service rig. Lubricate top drive. 03:00 - 04:30 1.50 DRILL P PROD1 Wash down. Begin drilling cement at 3,606'. Drill cement, landing collar, shoe, and rathole to 3,725'. Tag collar on depth at 3,631' md. 530 gpm, 2000 psi. 60 rpm, 4.6k tq. on 3.2k tq off. 3k WOB. PU - 105k, SO - 90k, RTW - 98k. 04:30 - 05:00 0.50 DRILL P PROD1 Drill 20' of new hole to 3,745' MD. Begin displacement to new 8.8ppg LSND mud. Mud weight in =mud weight out = 8.8 ppg. 05:00 - 06:00 1.00 DRILL P PROD1 Perform leak off test to 680 psi EMW of 12.69 ppg. Take benchmark ECD readings. Calculated & actual clean hole ECD at 0 rpm = 9.2ppg, 100 rpm = 9.3 ppg correction factor was -0.14ppg. 06:00 - 12:00 6.00 DRILL P PROD1 Directional drill 8-3/4" hole from 3,745' - 4,890'. 585 gpm, 2400 psi on, 1930 psi off. 100 rpm, 6-7k tq on, 4-6k tq off. PU - 130k, SO - 95k. RTW - 100k. 20-30k WOB. CECD - 9.42ppg, AECD - 10.20ppg. AST - .98, ART - 1.87 12:00 - 20:30 8.50 DRILL P PROD1 Directional drill 8-3/4" hole from 4,890' - TD @ 6,331' md. ~ I 585 gpm, 2805 psi on, 2490 psi off. 100 rpm, 9k tq on, 7k tq off. PU - 145k, SO - 105k, RTW - 115k, 30k WOB. CECD - 9.54ppg, AECD - 10.24ppg. AST - 1.42, ART - 4.42 20:30 - 21:00 0.50 DRILL P PROD1 Circulate 1.5 open hole volumes @ 550 gpm, 2450 psi, 100 rpm. Shut down, monitor well -Static. 21:00 - 00:00 3.00 DRILL P PROD1 Backream bit to 5,542' md. 530 gpm, 100 rpm, 2050 psi, 5k TQ. Maintain less than 100 psi delta pressure. 11/15/2007 00:00 - 02:15 2.25 DRILL P PROD1 Backream Ghost reamer into casing shoe and bit to 5,070' and (above ghost reamer depth). 535 gpm, 100 rpm, 2050 psi, 8-9k TO. 02:15 - 03:00 0.75 DRILL P PROD1 CBU @ 5,070'. 535 gpm, 1920 psi, Initial ECD = 10.3, final ECD = 9.81. Monitor well -static. 03:00 - 08:00 5.00 DRILL P PROD1 Monitor well - OK. MW in 9.1ppg, MW out 9.1ppg. POH to BHA. Pulled up to 25k over on first stand pulled. No other overpulls or swabbing seen while POOH. No weight indication when bit pulled into shoe. Pump dry job after bit in shoe. 08:00 - 11:00 3.00 DRILL P PROD1 PJSM. Lay down BHA #3. Bit grade: 4-3-WT-A-X-2-BU-TD. 11:00 - 12:00 1.00 DRILL P PROD1 Clean and clear rig floor of all BHA handling equipment. 12:00 - 13:30 1.50 BOPSU P RUNPRD Pull wear bushing and install ROPE test plug. 13:30 - 15:00 1.50 BOPSU P RUNPRD Change out upper pipe rams from 3.5" x 6" VBRs to 7". Printed: 12/4/2007 8:55:44 AM fr.~ BP EXPLORATION Page 8 of 12 Operations Sulmllnalry Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task: Code NPT Phase Description of Qperations 11/15/2007 15:00 - 16:30 1.50 BOPSU P RUNPRD Rig up and test 7" rams to 4,000 psi - OK. Rig down test equipment. Test witnessed by BP WSL Blair Neufeld. 16:30 - 20:00 3.50 CASE P RUNPRD Make dummy run with 7" hanger and landing joint. Rig up to run casing. 20:00 - 22:30 2.50 CASE P RUNPRD PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole @ 1.5 minutes perjoint with 7" 26# L-80 BTC-M casing to 1,079'. 26 jts of BTC-M, 1 markerjt. w/ 2-pip RA tag. Make up casing to mark with average make-up torque of 8,400 ft/Ibs. Used BOL-2000 M pipe lubricant. Fill each joint and break circulation every 20 joints for 5 minutes. PU - 65k, SO - 60k @ 1,079' 22:30 - 00:00 1.50 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 1,079' to 1,767'. Fill each joint and break circulation every 20 joints for 5 minutes. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 16 joints of TC-II casing run so far. PU - 77k, SO - 72k @ 1,767'. 11/16/2007 00:00 - 03:00 3.00 CASE P RUNPRD Continue running in hole @ 1.5 minutes per joint with 7" 26# L-80 TC-II casing from 1,767' to 3,723'. Fill each joint and break circulation every 20 joints for 5 minutes. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 64 joints of TC-II casing run so far. 03:00 - 05:00 2.00 CASE P RUNPRD RD Franks tool. CBU x 1.5 w/ circulating head - 210 gpm, 440 psi. Change out Franks tool cup. RD circulating head, RU Franks tool. 05:00 - 11:30 6.50 CASE P RUNPRD Continue running in hole (into open hole) @ 2 minutes perjoint with 7" 26# L-80 TC-II casing from 3,723' to 6,321'. Fill each joint. Did not break circulation while RIH to avoid damaging Franks tool cup. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 127 joints of TC-II casing run. Pick up 7" hanger, landing joint and land casing on depth @ 6,321', Up wt 180k Dn Wt 120k. No problems at all running in hole. HES Float Shoe -Bottom @ 6,321' 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Landing Collar -Top @ 6,238' 10 Jts 7", 26#, L-80 BTC-Mod (#3-12) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ 2 pip RA tag @ 5,812' 14 Jts 7", 26#, L-80 BTC-Mod (#13-26) 7", 26#,L-80 TC-II X BTC-Mod Crossover Pup. 127 Jts 7", 26#, TC-II (#1-127) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Total of 75 - 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers and 37 stop collars: 2 centralizers on shoe joint w/ stop ring 5' from shoe. BTC-M jts 3-26, XO jt, & TC-II jts 1-12 have 2 free floating per joint separated by stop ring in middle. 20' BTC-M markerjt has one free floating. Printed: 12/4/2007 8:55:44 AM BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11 /22/2007 Rig Name: NABORS 9ES Rig Number: Date From = To Hours Task. Code NPT 11/16/2007 11:30 - 12:30 1.00 CASE P 12:30 - 14:00 1.50 CEMT P 14:00 - 15:00 I 1.001 CEMT I P 15:00 - 16:00 I 1.001 CEMT I P 16:00 - 18:00 2.00 CEMT P 18:00 - 18:30 0.50 WHSUR P 18:30 - 20:00 1.50 EVAL P 20:00 - 00:00 4.00 BOPSU P 11/17/2007 00:00 - 02:00 2.00 BOPSU P 02:00 - 03:00 1.00 PERFO P 03:00 - 04:00 1.00 PERFO P 04:00 - 05:00 1.00 PERFO P 05:00 - 06:30 1.50 PERFO P 06:30 - 10:30 4.00 PERFO P 10:30 - 13:00 2.50 PERFO P 13:00 - 14:00 I 1.001 PERFOBI P Phase. I Description of Operations RUNPRD Rig down Frank's tool. Make up cementing head. RUNPRD Break circulation. Stage pumps up to 5 bpm, 480 psi. Condition mud for cementing. Held cementing PJSM while circulating. Reciprocate casing 6 ft strokes. PU - 190k, SO - 124k. RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 41 bbls 12.0 ppg of MudPush II viscosified spacer @ 5 bpm, 550 psi. Batch mix and pump 62 bbls of Class "G" 16.0 ppg cement @ 5 bpm avg, 350 - 150 psi. Drop plug and chase w/ 10 bbls H2O. Swap to rig pumps. Reciprocate pipe in 6' strokes. RUNPRD Switch to rig and displace cement with 238 bbls of seawater. 1st 150 bbls @ 5 bpm, 135 psi ICP, 456 psi FCP. Reduce rate to 4 bpm 420 psi ICP, 1210 psi FCP. Stopped reciprocating and landed casing with 200 bbls away. PU - 157k, SO - 93k. Last 20 bbls @ 2 bpm, 1194 psi ICP, 1700 psi FCP. Bumped plug at 3,940 strokes. CIP @ 16:05 hr. Attempt to pressure test to 4000 psi, but slow leak from cement head. Bleed off pressure, check for flowback - OK. RUNPRD Lay down all casing and cementing equipment. RUNPRD Install 7" Packoff and run in lock down screws. Torque to 450 ft-Ibs. Test to 5000 psi for 10 min., Good Test. RUNPRD Conduct LOT down 9-5/8" x 7" annulus to 12.7 ppg. Leak off pressure at 680 psi. Inject 4.8 bbls during leak off test. *Note: Outside of critical path, inject 3 bbls used LSND mud into OA every hour. no increase in leak off pressure.. RUNPRD Change Upper Pipe Rams to 3 1/2 x 6 variables & test w/ 3.5" and 4" test joints to 4,000 psi. RUNPRD Change Upper Pipe Rams to 3 1/2 x 6 variables & test w/ 3.5" and 4" test joints to 4,000 psi. OTHCMP RU equipment for DPC perforating. OTHCMP Pressure test 7" casing to 4000 psi - OK. OTHCMP RU equipment for DPC perforating. OTHCMP PJSM. Pick up and make up 4.5" HSD Power Jet 4505 5 SPF DPC perforating guns (7 ea loaded or partial guns, 4 ea blanks, including 2 ea blank punchers), XO, bumper sub, MWD, XO, 1-stand 4" HWDP, 10 ft pup joint. OTHCMP Run in hole with DPC pert assembly from 395' to 6,153'. *Note all depths reported are to bottom nose. G/R sensor is 271 ft up from bottom nose. OTHCMP Tag up on top of cement at 6.184' md. Log to correlate depth to reference log -MWD Realtime field print 15-Nov-2007. 295 gpm, 1100 psi while displacing well from seawater to 9.0 ppg brine . GR log found BHA 1 foot deep. Apply depth corcection needed. Log confirmation pass - OK. Log into position & set on depth w/ Top shot @ 5,826', Bottom nose @ 6,035'. Note: Sim Ops - OA injection and freeze protection: Inject 105 bbls 9.2 ppg LSND mud total 1 @bpm to keep annulus open while standing by on compressive strength. RU Little Red & pump 67 bbls 50 deg dead crude @ 2 bpm, 1250 ICP, 1350 FCP, 950 SIP. OTHCMP Perforate well. Initiate firing sequence by pump and bleed. Printed: 12/4/2007 8:55:44 AM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date I From - To I Hours I Task I Code I NPT Spud Date: 11 /5/2007 Start: 11/3/2007 End: 11/22/2007 Rig Release: 11 /22/2007 Rig Number: Phase I Description of Operations ,11/17/2007 113:00 - 14:00 I 1.001 PERFOBI P 14:00 - 15:30 I 1.501 PERFOBI P 15:30 - 19:30 4.00 PERFOB~ P 19:30 - 21:30 2.00 PERFO P 21:30 - 00:00 2.50 PERFO P 11/18/2007 00:00 - 00:30 0.50 PERFO P 00:30 - 02:30 2.00 EVAL P 02:30 - 04:30 2.00 EVAL P 04:30 - 07:00 I 2.501 EVAL I P 07:00 - 08:30 1.50 EVAL P 08:30 - 09:30 1.00 EVAL P 09:30 - 12:00 I 2.501 EVAL I P 12:00 - 13:00 1.00 EVAL P 13:00 - 14:30 1.50 EVAL P 14:30 - 15:00 0.50 EVAL P 15:00 - 16:30 1.50 EVAL P 16:30 - 19:00 2.50 EVAL P 19:00 - 22:00 3.00 EVAL P 22:00 - 23:00 I 1.00 I EVAL I N 23:00 - 00:00 1.00 EVAL P 11/19/2007 00:00 - 01:30 1.501 EVAL I P 01:30 - 03:00 1.50 WHSUR P OTHCMP Wait 5 minutes for guns to fire. Good indication of guns firing. Well initially lost 2.5 bbls then went on a 3 bph loss rate. Perforation intervals: OBa - 5826 - 5852' OBc - 5916 - 5942' OBd - 5984 - 6034' OTHCMP POH from 6,035' to 5,800' (above top pert) and circulate surface to surface 208 gpm, 560 psi. Shut down, monitor well - losses @ 3 bph and falling. Blow down top drive. OTHCMP POH laying down drill pipe from 5,800' to 2,970' md. OTHCMP Notified of 8+ hour minimum delay in E-Line truck availability. Mobilize string mill and bit for cleanout to top of cement. Begin POH in stands to perforating BHA. OTHCMP PJSM. Lay down pert gun assembly. All guns fired. OTHCMP Clean rig floor of gun residue and rig down all perforating tools. OTHCMP Schlumberger E-Line unit on location -made available due to delays in Nabors 2ES operations. Spot Unit into location. PJSM. Rig up SLB E-line and GR/JB assembly. OTHCMP RIH and log w/ 6.13" gauge ring /junk basket /CCL. Tag obstruction @ 5,826' and (depth of top perf). Attempt to work tool but unable. Pull up to 1,000# over after setting down harder on tag. POOH to surface. No debris in Junk basket. OTHCMP Change out gauge ring and RIH w/ 5.5" gauge ring /junk basket /CCL. Tag obstruction again @ 5,826' and (depth of top perf). Work tool several times and able to fall past. Tension very ratty below top perforation, and finally set down again at 6,024' md. POOH to surface. OTHCMP Junk basket at surface. No debris recovered in basket. Rig down E-line and associated equipment. OTHCMP MU Cleanout BHA - 6-1/8" milttooth bit, 6-1 /8" string mill, bit sub, XO, 8 stands 4" HWDP to 745' md. OTHCMP RIH picking up singles from pipeshed from 745' and to 3,170' md. OTHCMP RIH on stands from derrick to 5,820' md. OTHCMP Wash and ream down from top pert depth 5,826' to 6,104' md. 20-30 rpm, 5-5.5k TO, 90 gpm, 125 psi. Rotating weight never dropped more than 5k while rotating down and Torque never rose more than 500 ft-Ibs. Losses at 5 bph while reaming. OTHCMP CBU. Brine returns smelled of perforations, but no other debris on bottoms up. OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 6,104' - 5,040' md. OTHCMP Cut and slip 60' of drilling line. OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 5,040' - 2,310' md. OTHCMP Inspect and adjust topdrive. OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 2,310' - 1,350' md. OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 1,350' - surface. RUNCMP Standing by on E-Line Unit. Drain and flush stack. Pull wear ring. Make dummy run with tubing hanger - OK. Install wear bushing. Printed: 12/4/2007 8:55:44 AM • $P EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date from - To Hours Task Code NPT Phase. I Description of Operations 11/19/2007 03:00 - 09:00 6.00 EVAL N WAIT OTHCMP 09:00 - 11:00 2.00 EVAL P OTHCMP 11:00 - 22:00 11.00 EVAL P OTHCMP 22:00 - 23:00 1.00 EVAL P OTHCMP 23:00 - 23:30 0.50 WHSUR P RUNCMP 23:30 - 00:00 0.50 BOPSU N RREP RUNCMP 11/20/2007 00:00 - 01:30 1.50 BOPSU N RREP RUNCMP 01:30 - 03:30 2.00 RUNCO RUNCMP 03:30 - 22:00 18.50 RUNCO RUNCMP 22:00 - 23:00 1.00 RUNCO RUNCMP 23:00 - 00:00 1.00 RUNCO DPRB RUNCMP 11/21/2007 00:00 - 02:30 2.50 RUNCO RUNCMP 02:30 - 03:00 0.50 RUNCO RUNCMP 03:00 - 04:00 1.00 RUNCO RUNCMP 04:00 - 05:30 1.50 RUNCO RUNCMP Wait on E-Line unit. Prepare and stage completion equipment where able. PJSM. Rig up SWS and USIT tools. Run in hole with USIT logging tools to 6,100'. Log to surface, make repeat runs as required. Logs indicated top of cement @ 3,700', with good cement top @ 4,500'. Rig down SWS. Pull wear bushing. Change out lower IBOP on topdrive. Continue installing lower IBOP valve on topdrive. Rig up I-wire equipment. PJSM. Run in hole with completion jewelry to 362'. Baker Lok'd all connections below packers. Make I-wire terminations. Test line connections to 5,000 psi - OK. Test I-wire continuity - OK. Continue running in hole with 3.5" 9.2# L-80 TCII 3 packer completion to planned depth setting depth of 6,084'. 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 - 85k, SO - 65k. Rig up SWS pack-off and pump-in sub. Make up GR/CCL tool. Attemt to run in hole with logging tool. Tool stopped 20 ft below surface. Rig down pack-off assembly and swap out top joint of tubing. Rig up pack-off assembly. (Drifted layed down joint in pipeshed - OK) Run in hole with GR/CCL tool to 6,047'. Log up and correlate RA tags and packers. 4 foot down adjustment needed. POH with logging tools. Rig down SWS. Space out tubing with 3 pup joints under last joint (#177) 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: 3.5" 9.2 #WLEG, 3.5" TC-II set @ 6,088'. Tops: 3.5" 9.2 #WLEG, 3.5" TC-II @ 6,087'. 3.5" HES 'XN' Nipple: ID 2.750 @ 6,066'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug @ 6,045'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,016'. 3.5" HES 'X' Nipple: 2.813" ID @ 5,995'. 3.5" x 7" HES single feedthru Packer #1 packer @ 5,972'. GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 5,948'. GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 5,909'. Phoenix Sensor sub @ 5,897'. 3.5" x 7" HES Dual feedthru Packer #2 packer @ 5,883'. 3.5" HES 'X' Nipple: 2.813" ID @ 5,873'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 2 jts 3.5" 9.2# L-80 TC-II Tubing (#1 - 2) @ 5,849'. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ Printed: 12/4/2007 8:55:44 AM i ~> BP EXPLORATION Page 12 of 12` Operations 5lummary Repolrt Legal Well Name: W-214 Common Well Name: W-214 Spud Date: 11/5/2007 Event Name: DRILL+COMPLETE Start: 11/3/2007 End: 11/22/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/22/2007 Rig Name: NABORS 9ES Rig Number: Date From- To Hours Task. Code NPT Phase Description of Operations 11/21/2007 04:00 - 05:30 1.50 RUNCO RUNCMP 5,761'. 3.5" 9.2# L-80 TC-II Pup (Centralizer w/PIP tag) @ 5,750'. Phoenix Sensor sub @ 5,749'. 3.5" x 7" HES Dual feedthru Packer #3 packer @ 5,736'. 3.5" HES 'X' Nipple: 2.813" ID @ 5,715'. 2 jts 3.5" 9.2# L-80 TC-I I Tubing (#3 - 4) @ 5,641'. GLM #6 - 3.5" x 1.5" MMG w/ DCR-1 Shear- RKP latch @ 5,622'. 92 jts 3.5" 9.2# L-80 TC-II Tubing (#5 - 96) @ 2,668'. 3.5" HES'X' Nipple: 2.813" ID @ 2,657'. 81 jts 3.5" 9.2# L-80 TC-II Tubing (# 97- 176) @ 88' 3 ea 3.5", 9.2#, L-80 TC-II Space out Pups 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 177 ) 3.5" 9.2# L-80 TC-11 Hanger Pup 4.5" X 3.5" TC-I I Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads 05:30 - 06:00 I 0.50 06:00 - 08:00 2.00 08:00 - 09:00 I 1.00 09:00 - 10:00 I 1.001 WHSUR I P 10:00 - 12:00 I 2.001 BOPSUF~P 12:00 - 15:00 I 3.001 BOPSU~ P 15:00 - 17:00 2.00 WHSUR P 17:00 - 19:00 2.00 WHSUR P 19:00 - 21:00 I 2.001 WHSUR P 21:00 - 22:00 1.00 WHSUR P 22:00 - 23:30 1.50 WHSUR P 23:30 - 00:00 0.50 WHSUR P 11/22/2007 00:00 - 02:00 2.00 WHSUR P 02:00-03:00 I 1.001 WHSURIP 05:00 - 06:00 1.001 WHSUR P Up wt = 85k, Dn wt = 65k 95 full Cannon clamps, 13 Half clamps RUNCMP Drop rod and ball. Laydown landing joint. RUNCMP PJSM. 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 2,500 psi. Pressure up inner annulus and test to 4,000 psi - 30 min -Good test! (tubing pressure @ 2,800 psi during IA test). Bleed off annulus pressure to 0 psi, bleed off tubing pressure to 0 psi. Pressure up on annulus to shear DCR valve. Sheared at 2,100 psi. Establish circulation briefly both ways - OK. RUNCMP Reverse circulate 114 bbls of clean 9.9 ppg brine, followed by 86 bbls of inhibited brine @ 4.6 bpm, 650 psi. RUNCMP Dry rod 2 way check valve. Test valve from below to 1,000 psi - OK. 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. Rig down lubricator. RUNCMP PJSM. Rig up to freeze protect IA and tubing. ~ RUNCMP PJSM. Pressure test lines to 3,000 psi - OK. Freeze protect IA and tubing to 2,275' MD, 2,200' TVD. Pump 82 bbls of diesel down annulus @ 2 bpm, 500 psi ICP, 1,000 psi FCP. U-tube diesel back to tubing. IA and tubing. SIP - 0 psi. RUNCMP Rig up lubricator and install BPV. Test BPV from below to 1,000 psi - OK. Rig down lubricator. RUNCMP Nipple down double valve. Install VR plugs in IA and OA. RUNCMP Pump out cellar box. Secure cellar area and tree. "Release rig from W-2141 operations @ 06:00 hr, 11/22/2007. Printed: 12/4/2007 8:55:44 AM by Schlumberger W-214 Survey Report Report Date: November 15, 2001 Survey 1 DLS Computation Method: Minimum Curvatufe / Lubinsk .Client: BP Expbration Alaska Vertical Section Azimuth: 44.400° Field: Prudtloe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ti Structure I Slot: W-PAD / W-214 TVD Reference Datum: Rotary Table Well: W-214 TVD Reference Elevation: 80.90 ft relative to MSL Borehole: W-214 Sea Bed I Ground Level Elevation: 52.70 R relative b MSL UWIIAPI#: 50029233730( Magnetic Declination: 23.319° Survey Name 1 Date: W-214 /November 15, 2001 Total Field Strength: 57643.031 nT Tort 1 AHO1 DDI I ERD ratio: 93.739° / 2857.62 ft / 5.491 / 0.52; Magnetic Dip: 80.870° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Declination Date: .November 12, 2007 location Latllong: N 7017 57.473, W 149 5 33.111 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5959865.970 ftl1S, E 612049.020 fill: North Reference: True NoAh Grid Convergence Angle: +0.85435860° Total Corr Mag North -> True North: +23.319° Gdd Seale Factor. D 99991d26 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft A An ftUS CACAOCC A7 ftUS C~~IAAA Ail AI 7A .17 C7 A74 \A/ AAA G 44 ~ 1C fttt_ V.UU V.VV V.VII -AV.UV U.VU V. VI/ V.VV V.VV V.VV U.VV V.VV JVJAwJ.a° v~~v+a.v~ ~~ rv ~° r/.-°~~/ •• ~~~.~.~v.~~v GYD CT DMS 100.00 0.09 224.94 19.10 100.00 -0.08 0.08 0.08 -0.06 -0.O6 0.09 5959865.91 612048.97 N 7017 57.473 W 149 5 33.118 200.00 0.15 156.91 119.10 200.00 -0.21 0.27 0.24 -0.23 -0.06 0.14 5959865.74 612048.96 N 7017 57.471 W 149 5 33.118 300.00 1.37 94.83 219.09 299.99 0.50 1.54 1.27 -0.45 1.18 1.31 5959865.54 612050.21 N 7017 57.469 W 149 5 33.081 400.00 4.81 90.33 318.93 399.83 4.18 6.93 6.59 -0.58 6.57 3.45 5959865.49 612055.60 N 70 17 57.468 W 149 5 32.924 500.00 5.82 91.06 418.50 499.40 10.58 16.19 15.85 -0.70 15.83 1.01 5959865.51 612064.86 N 70 17 57.467 W 149 5 32.654 600.00 5.93 92.83 517.97 598.87 17.49 26.43 26.08 -1.04 26.06 0.21 5959865.31 612075.09 N 7017 57.463 W 149 5 32.356 700.00 6.16 93.06 617.42 698.32 24.46 36.96 36.61 -1.59 36.58 0.23 5959864.93 612085.61 N 7017 57.458 W 149 5 32.050 800.00 7.32 92.61 716.72 797.62 32.25 48.69 48.35 -2.16 48.30 1.16 5959864.53 612097.34 N 7017 57.452 W 149 5 31.708 MWD+IFR+MS 861.87 8.28 92.21 778.02 858.92 37.87 57.09 56.74 -2.51 56.69 1.55 5959864.30 612105.73 N 7017 57.449 W 149 5 31.463 953.30 9.11 89.84 868.40 949.30 47.37 70.91 70.56 -2.75 70.50 0.99 5959864.27 612119.55 N 7017 57.446 W 149 5 31.061 1044.76 9.52 86.75 958.65 1039.55 58.04 85.71 85.33 -2.30 85.30 0.71 5959864.94 612134.33 N 70 17 57.451 W 149 5 30.6 1135.09 9.92 81.24 1047.69 1128.59 69.78 100.95 100.45 -0.69 100.44 1.12 5959866.78 612149.45 N 7017 57.467 W 149 5 30.1 1229.76 10.76 74.74 1140.82 1221.72 83.94 117.92 117.07 2.88 117.03 1.52 5959870.59 612165.98 N 7017 57.502 W 149 5 29.704 1259.97 11.30 77.10 1170.48 1251.38 88.86 123.70 122.71 4.28 122.64 2.33 5959872.08 612171.57 N 70 17 57.516 W 149 5 29.541 1359.96 12.98 71.61 1268.23 1349.13 107.10 144.71 143.19 10.01 142.84 2.04 5959878.11 612191.69 N 70 17 57.572 W 149 5 28.952 1409.86 14.59 70.59 1316.69 1397.59 117.72 156.60 154.71 13.87 154.09 3.26 5959882.13 612202.87 N 70 17 57.610 W 149 5 28.624 1501.23 16.61 72.01 1404.69 1485.59 139.62 181.17 178.69 21.73 177.37 2.25 5959890.34 612226.03 N 70 17 57.687 W 149 5 27.945 1596.10 17.50 73.66 1485.39 1576.29 164.08 209.00 206.14 29.93 203.95 1.07 5959898.93 612252.49 N 70 17 57.768 W 148 5 27.170 1689.61 18.13 72.75 1584.41 1665.31 189.15 237.60 234.47 38.20 231.34 0.74 5959907.61 612279.74 N 70 17 57.849 W 149 5 26.372 1782.74 19.01 71.07 1672.70 1753.60 215.46 267.26 263.82 47.42 259.52 1.11 5959917.25 612307.79 N 70 17 57.940 W 149 5 25.550 1877.17 21.29 70.18 1761.34 1842.24 244.64 299.79 295.99 58.22 290.20 2.44 5959928.50 612338.30 N 70 1758.046 W 149 5 24.656 1970.22 24.10 66.31 1847.18 1928.08 277.49 335.67 331.33 71.58 323.50 3.42 5959942.36 612371.39 N 70 17 58.177 W 149 5 23.685 2062.60 25.90 64.41 1931.09 2011.99 314.03 374.79 369.66 87.91 359.05 2.13 5959959.22 612406.69 N 70 17 58.338 W 149 5 22.649 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) W-214\W-214\W-214\W-214 Generated 12/17/2007 2:47 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft d 1100 k ftUS ftUS L 1.7U.OJ Ll.OV OJ. 10 LV IY.DL LVJJ.OL JJJ.Va Y1I.VJ YII.VL IvV.JV J.~v.w ..civ vvvvv•v.-rv v.c-.~-~.v. .. ... .. .......rr .. .~.. .. r....~~ 2250.34 29.37 63.26 2097.23 2178.13 396.16 461.71 454.83 126.71 436.83 1.89 5959999.16 612483.87 N 7017 58.719 W 149 5 20.381 2344.52 30.98 59.05 2178.66 2259.56 441.48 509.03 501.09 149.57 478.25 2.82 5960022.64 612524.95 N 7017 58.944 W 149 5 19.174 2436.14 34.73 58.56 2255.61 2336.51 489.61 558.73 549.47 175.32 520.75 4.10 5960049.02 612567.06 N 70 17 59.197 W 149 5 17.935 2530.38 37.24 56.66 2331.86 2412.76 543.52 614.10 603.38 205.00 567.49 2.91 5960079.39 612613.34 N 7017 59.489 W 149 516.572 2622.59 37.01 56.39 2405.38 2486.28 597.93 669.75 657.60 235.69 613.91 0.31 5960110.77 612659.30 N 70 17 59.791 W 149 515.219 2716.30 36.58 55.72 2480.43 2561.33 652.90 725.88 712.41 267.03 660.47 0.63 5960142.80 612705.38 N 70 18 0.099 W 149 5 13.861 2809.82 37.19 58.09 2555.23 2636.13 707.69 782.00 767.57 297.67 707.50 1.65 5960174.13 612751.94 N 70 18 0.401 W 149 5 12.490 2902.32 36.95 57.30 2629.04 2709.94 761.95 837.76 822.61 327.47 754.62 0.58 5960204.63 612798.61 N 70 18 0.694 W 149 5 11.116 2994.90 36.89 56.93 2703.05 2783.95 816.20 893.37 877.52 357.66 801.32 0.25 5960235.51 612844.85 N 70 18 0.991 W 149 5 9.755 3090.99 36.81 56.68 2779.94 2860.84 872.48 951.00 934.46 389.21 849.55 0.18 5960267.77 612892.60 N 70 181.301 W 149 5 8.349 3187.98 37.91 59.93 2857.04 2937.94 929.59 1009.85 992.88 420.11 899.62 2.33 5960299.41 612942.20 N 70 181.605 W 149 5 6.8~ 3281.65 37.67 60.05 2931.07 3011.97 984.87 1067.24 1050.07 448.82 949.32 0.27 5960328.85 612991.46 N 70 181.887 W 149 5 5.440 3378.02 37.13 59.39 3007.62 3088.52 1041.33 1125.78 1108.40 478.33 999.87 0.70 5960359.11 613041.56 N 70 18 2.177 W 149 5 3.966 3473.71 38.21 59.34 3083.36 3164.26 1097.82 1184.25 1166.66 508.13 1050.19 1.13 5960389.65 613091.42 N 7018 2.470 W 149 5 2.499 3568.33 38.08 59.09 3157.78 3238.68 1154.32 1242.69 1224.89 538.04 1100.39 0.21 5960420.31 613141.17 N 70 18 2.764 W 149 5 1.035 3666.15 38.57 56.51 3234.52 3315.42 1213.32 1303.35 1285.20 570.36 1151.71 1.71 5960453.39 613192.00 N 7018 3.082 W 149 4 59.539 3792.49 38.08 56.19 3333.64 3414.54 1289.97 1381.69 1362.95 613.77 1216.93 0.42 5960497.77 613256.56 N 7018 3.509 W 149 4 57.637 3884.06 38.39 54.15 3405.57 3486.47 1345.63 1438.36 1419.08 646.14 1263.44 1.42 5960530.82 613302.58 N 70 18 3.827 W 149 4 56.281 3976.68 39.42 54.19 3477.64 3558.54 1402.96 1496.53 1476.59 680.19 1310.60 1.11 5960565.57 613349.22 N 7018 4.162 W 149 454.906 4070.68 39.71 53.53 3550.11 3631.01 1462.02 1556.40 1535.80 715.50 1358.95 0.54 5960601.59 613397.03 N 70 18 4.509 W 149 4 53.496 4165.33 40.79 49.08 3622.36 3703.26 1522.70 1617.54 1595.85 753.73 1406.64 3.24 5960640.53 613444.14 N 70 18 4.885 W 149 4 52.106 4258.22 40.95 40.04 3692.67 3773.57 1583.34 1678.25 1653.87 796.95 1449.19 6.37 5960684.37 613486.04 N 70 18 5.310 W 149 4 50.865 4352.68 38.67 34.36 3765.25 3846.15 1643.30 1738.69 1709.27 845.03 1485.77 4.54 5960732.99 613521.90 N 70 18 5.783 W 149 4 49.798 4446.10 37.98 32.08 3838.54 3919.44 1700.12 1796.62 1761.01 893.49 1517.51 1.68 5960781.90 613552.91 N 70 18 6.259 W 149 4 48.872 4539.17 38.30 32.56 3911.74 3992.64 1756.33 1854.10 1812.33 942.06 1548.25 0.47 5960830.93 613582.91 N 70 18 6.737 W 149 4 47.976 4632.34 36.94 33.86 3985.54 4066.44 1812.11 1910.97 1863.83 989.65 1579.38 1.69 5960878.97 613613.34 N 7018 7.205 W 149 4 47.068 4726.41 36.43 34.90 4060.98 4141.88 1867.45 1967.17 1915.48 1036.03 1611.12 0.85 5960925.81 613644.37 N 70 18 7.661 W 149 446.142 4817 78 36.25 34.50 4134.57 4215.47 1920.82 2021.31 1965.59 1080.54 1641.94 0.33 5960970.78 613674.52 N 70 18 8.099 W 149 4 45.243 . 4912.81 36.22 34.77 4211.23 4292.13 1976.18 2077.48 2017.77 1126.76 1673.86 0.17 5961017.46 613705.75 N 70 18 8.553 W 149 4 44.3 5005.71 35.77 30.76 4286.40 4367.30 2029.63 2132.07 2068.02 1172.64 1703.41 2.58 5961063.78 613734.60 N 7018 9.004 W 149 4 43.4 5098.99 35.91 24.54 4362.04 4442.94 2081.87 2186.65 2116.42 1220.97 1728.72 3.91 5961112.47 613759.19 N 70 18 9.480 W 149 4 42.712 5191.98 36.28 19.02 4437.20 4518.10 2132.39 2241.40 2162.53 1271.80 1749.02 3.52 5961163.60 613778.73 N 70 i8 9.979 W 149 4 42.120 5285.88 35.21 15.93 4513.42 4594.32 2181.29 2296.25 2206.86 1324.10 1765.50 2.23 5961216.13 613794.43 N 70 1810.494 W 149 4 41.639 5379.11 33.58 11.82 4590.36 4671.26 2226.66 2348.90 2247.89 1375.19 1778.16 3.04 5961267.40 613806.33 N 70 1810.996 W 149 4 41.269 5472.70 33.13 9.87 4668.53 4749.43 2269.54 2400.35 2286.72 1425.73 1787.85 1.24 5961318.07 613815.26 N 7018 11.493 W 149 440.987 5586.06 33.23 9.15 4746.67 4827.57 2311.44 2451.44 2324.99 1476.12 1796.29 0.44 5961368.58 613822.95 N 701811.989 W 149 440.740 5862.62 33.06 8.47 4827.52 4908.42 2354.38 2504.24 2364.62 1528.29 1804.38 0.42 5961420.86 613830.25 N 701812.502 W 149 440.504 5756.94 32.54 7.46 4906.80 4987.70 2395.48 2555.33 2402.97 1578.89 1811.46 0.80 5961471.55 613836.58 N 70 1813.000 W 149 440.297 5848.91 32.56 6.27 4984.33 5065.23 2434.72 2604.81 2439.93 1628.01 1817.37 0.70 5961520.76 613841.76 N 701813.483 W 149 440.124 5948.24 32.46 5.34 5068.09 5148.99 2476.45 2658.20 2479.65 1681.12 1822.77 0.51 5961573.94 613846.37 N 701814.005 W 149 4 39.967 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-214\W-214\W-214\W-214 Generated 12/17/2007 2:47 PM Page 2 of 3 CommeMS Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft k de 1100 ft ftUS ftUS 6044.45 32.13 4.56 5149.42 5230.32 2516.14 2709.60 2517.87 1732.33 1827.21 0.55 5961625.20 6137.82 31.53 3.53 5228.75 5309.65 2553.66 2758.84 2554.41 1781.45 1830.69 0.87 5961674.36 6230.99 30.72 3.82 5308.51 5389.41 2590.16 2807.00 2590.34 1829.51 1833.77 0.88 5961722.46 Last Survey 6260.52 30.35 2.97 5333.94 5414.84 2601.48 2822.00 2601.56 1844.49 1834.66 1.93 5961737.45 TD (Projected) 6331.00 30.35 2.97 5394.76 5475.66 2628.18 2857.62 2628.19 1880.05 1836.51 0.00 5961773.03 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillplpe mis -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Letaal Descri~tfon: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4888 FSL 1176 FEL S21 T11N R12E UM 5959865.97 612049.02 BHL : 1488 FSL 4615 FEL S15 T11 N R12E UM 5961773.03 613857.13 613850.04 N 70 1814.509 W 149 4 39.837 613852.78 N 70 1814.992 W 149 4 39.735 613855.15 N 70 1815.464 W 149 4 39.645 613855.82 N 70 1815.612 W 149 4 39.619 613857.13 N 70 1815.961 W 149 4 39.565 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-214\W-214\W-2141W-214 Generated 12/17/2007 2:47 PM Page 3 of 3 TREE= 4-1/16" CIW VVELLHEA D = FMC ACTUATOR = Baker Hydrau5c KB. ELEV = 80.9' BF. ELEV = 54.7' KOP = 300' Max Angie = 41° ~ 4258' Datum MD = 5868' Datum TV D = 5000' SS DRLG DRAFT 4-112" TBG, 126#, L-80, -i 25' •~'~ TG19, .0152 bpf, ~ = 3.958" i 3-318" CSG, SBit, L-80, BTC, ~ =12.415" 1310' i18" CSG, 40x1, L-80, BTC, ID = 8.835" I~ CSG, 26x1, L-80, TGII, .0363 bpf, ID = 6.276" ~ 5203" 1 Minimum I©= 2.75" ~ 6066' 3-112" HES XN NIPPLE MA RKER JONJ'T w ! RA TAG S75Q' QA MARKERJO~ITw/RA TAG H5812' OBa PERFDRAl10N SUMMARY REF LOG: SLB ReaRime LWD ANGLE AT TOP PERF: 37 Note: Refer to Production DB for histor~al pert data SQE SPF INTERVAL OpnlSgz DATE 4112" 5 DBa 5826'-5852' O 11117/07 4112" 5 OBc 5916'-5942' O 11/17/07 4-112" 5 OBd 5984'-6034' O 11117/0? [023 7' PBTD 1-~ CSG, 26#, t-80, BTGM, .!0383 bpf, ID = 6.276 --~-~ SAFEI'~I~TES: "'"HES PIQZ,S ARE "PULL TO RH.EASE' 13tIf CAM ALSO BE RELEASED 8Y Pl7J~SSURE DO NOT ~ ~ ~ ~' EXCEED 4300 PSI. TEST PRESSURE PIQi RATING =5415 PSI (4332 PSI IS 80% ~ PFQt RATING)"'" ~- 2§' I-14-yz" xD 3-112". ~ = 2.992" ( 2657' 3-1/2" HES X Nom, ID = 2.813" t GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 5622 4875 33 MMG DCR RKP 11/21!07 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 5761 4991 33 MMG-W DMY RK 11(21!07 4 5849 5065 33 MMG-W DMY RK 11/21/07 3 5909 5116 33 MMG-W DMY RK 11/21/07 2 5948 5148 32 MMG-W DMY RK 11!21107 1 6016 5206 32 MMG-W DMY RK 11/21/07 13-1 r2" HES X t~P, ID = 2.813" ~ 5736' 7" HES A HR PKR w 1114" FEED THRU, ~ = 2.920" ' DUAL 5749' PHOENIX PRESITEM1AP SENSOR SUB, ID = 2.992" ' 5873' 3-1/2" HES X NIP, ID = 2.813" 5$$3' 7" HES A HR PKR w / 114" FEED THRU, ~ = 2.9~ DUAL ))) 5$97' PHOENDC PRES/TBu1P SENSOR SUB, ID = 2.992" 5972' 7" HES AHR PKR w 1 114" FEED THRU, ID = 2.920" SGL 5995' 3-112" HES X NP, ID = 2.819" 6045' -i 3-1 /2" HES X NIP, ID = 2.813" 6066' 3-112". HES XN NIP, ~ = 2.75" 608$' H 3-112" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/22107 N9ES ORIGINAL COMPLETION 11/30107 ITCH CORRISCTtONS ORION UNIT YVB.L: V~-214i PERMIT No: 207-142 A Pi No: 50-029-23373 Seo.21. Tw o. Rae ~ Exploration (Alaska) • • gyr data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 November 28, 2007 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: W-Pad, Well #W-214 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, / /1~ ~' Rob Shoup North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyr data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 7131461-3146 Fax: 713/461-0920 SURVEY REPORT BP W-Pad #W-214 Prudhoe Bay, AK AK1107G_559 6 Nov 2007 Serving the Worldwide Energy Industry with Precision Survey Instrumentation ~~ ?- l~ ~. A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: W-Pad Well: W-214, Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1107G 559 Run Date: 06 Nov 2007 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.299298 deg. N Longitude: 149.092532 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location • • Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: W-Pad Well: W-214 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1107G 559 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 ----------------------------------------------------------------------------------------------------------------------------------------------------------- 0 - 800 FT. RATE GYROSCOPIC MULTISHOT SURVEY ALL SURVEY DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES ROTARY TABLE OF 80.90 FT. AMSL 100.00 0.09 224.94 S 44 57 W 200.00 0.15 156.91 S 23 5 E 300.00 1.37 94.83 S 85 10 E 400.00 4.81 90.33 S 89 40 E 500.00 5.82 91.06 S 88 56 E 600.00 5.93 92.83 S 87 10 E 700.00 6.16 93.06 S 86 57 E 800.00 7.32 92.61 S 87 23 E Final Station Closure: Distance: 48.34 ft Az: 92.57 deg. 0.00 N 0.00 E 0.09 100.00 0.1 224.9 0.06 S 0.06 W 0.15 200.00 0.2 194.7 0.24 S 0.06 W 1.31 299.99 1.3 111.3 0.46 S 1.18 E 3.45 399.83 6.6 95.1 0.59 S 6.57 E 1.00 499.40 15.9 92.5 0.70 S 15.84 E 0.21 598.87 26.1 92.3 1.05 S 26.06 E 0.24 698.32 36.6 92.5 1.59 S 36.57 E 1.16 797.62 48.3 92.6 2.17 S 48.29 E u • 2 BP Exploration (Alaska) Inc. Well: W-Pad W-214 Location: Nabors #9ES, Prudhoe Bay, Alaska 0.0 -0.2 -0.4 -0.6 -0.8 .. -1.0 c~ z -1.2 O z -1.4 -1.6 -1.8 -2.0 -2.2 Outrun Gyrodata _ AK1107G_559 DEFINITIVE BOTT M HOLE LOCA ED MD: 8 0.00 • 0 5 10 15 20 25 30 35 40 45 50 FASTING (ft) BP Exploration (Alaska) Well: W-Pad W-214 Location: Nabors #9ES, 10 Inc. Prudhoe Bay, Alaska Outrun Gyrodata . AK1107G_559 DEFINITIVE I B TTOM HOLE L M CATED :800.00 ~ ~ ~ ~ ~ i ~ i 10 0 20 0 30 0 40 0 50 0 60 0 70 0 80 0 900 9 8 .- 0 0 a~ a~ ... w w w J 4 O MEASURED DEPTH (ft) • BP Exploration (Alaska) Inc. Well: W-Pad W-214 Location: Nabors #9ES, Prudhoe Bay, Alaska z O Q4 z J U z 0 Outrun Gyrodata AK1107G_559 DEFINITIVE LOCATED MD: 800.00 I i i i ~ ~ ~ i 10 0 20 0 300 400 500 60 0 70 0 80 0 90 0 MEASURED DEPTH (1"t) ~7 v t it -~ Ir .• SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Polaris Well .....................: W-214 API number ...............: 50-029-23373-00 Engineer .................: Minnick COUNTY ...................: North Slope Borough STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent........: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 52.40 ft N/A (Topdrive) 80.90 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: 0.00 degrees 15-Nov-2007 07:15:15 Page 1 of 4 Spud date ................. 5-Nov-07 Last survey date.........: 15-Nov-07 Total accepted surveys...: 70 MD of first survey.......: 0.00 ft MD of last survey........: 6331.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 05-Nov-2007 Magnetic field strength..: 57642.68 LAMA Magnetic dec (+E/W-).....: 23.762 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 57642.50 LAMA 80.87 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.76 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.76 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 ~CHLUMBERGER Survey Report 15-Nov-2007 07:15:15 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.09 224.94 100.00 100.00 -0.06 -0.06 -0.06 0.08 224.94 0.09 BP _GYD CT DMS 3 200.00 0.15 156.91 100.00 200.00 -0.23 -0.23 -0.06 0.24 194.44 0.14 BP _GYD CT DMS 4 300.00 1.37 94.83 100.00 299.99 -0.45 -0.45 1.18 1.27 110.94 1.31 BP _GYD CT DMS 5 400.00 4.81 90.33 100.00 399.83 -0.58 -0.58 6.57 6.59 95.02 3.45 BP GYD CT DMS 6 500.00 5.82 91.06 100.00 499.40 -0.70 -0.70 15.83 15.85 92.52 1.01 BP _GYD CT DMS • 7 600.00 5.93 92.83 100.00 598.87 -1.04 -1.04 26.06 26.08 92.29 0.21 BP _GYD CT DMS 8 700.00 6.16 93.06 100.00 698.32 -1.59 -1.59 36.58 36.61 92.48 0.23 BP _GYD CT DMS 9 800.00 7.32 92.61 100.00 797.62 -2.16 -2.16 48.30 48.35 92.56 1.16 BP _GYD CT DMS 10 861.87 8.28 92.21 61.87 858.92 -2.51 -2.51 56.69 56.74 92.54 1.55 BP MWD+IFR+MS 11 953.30 9.11 89.84 91.43 949.30 -2.75 -2.75 70.50 70.56 92.23 0.99 BP _MWD+IFR+MS 12 1044.76 9.52 86.75 91.46 1039.55 -2.30 -2.30 85.30 85.33 91.54 0.71 BP _MWD+IFR+MS 13 1135.09 9.92 81.24 90.33 1128.59 -0.69 -0.69 100.44 100.45 90.39 1.12 BP _MWD+IFR+MS 14 1229.76 10.76 74.74 94.67 1221.72 2.88 2.88 117.03 117.07 88.59 1.52 BP _MWD+IFR+MS 15 1259.97 11.30 77.10 30.21 1251.38 4.28 4.28 122.64 122.71 88.00 2.33 BP MWD+IFR+MS 16 1359.96 12.98 71.61 99.99 1349.13 10.01 10.01 142.84 143.19 85.99 2.04 BP _MWD+IFR+MS 17 1409.86 14.59 70.59 49.90 1397.59 13.87 13.87 154.09 154.71 84.86 3.26 BP _MWD+IFR+MS 18 1501.23 16.61 72.01 91.37 1485.59 21.73 21.73 177.37 178.69 83.02 2.25 BP _MWD+IFR+MS 19 1596.10 17.50 73.66 94.87 1576.29 29.93 29.93 203.95 206.14 81.65 1.07 BP _MWD+IFR+MS 20 1689.61 18.13 72.75 93.51 1665.31 38.20 38.20 231.34 234.47 80.62 0.74 BP _MWD+IFR+MS • 21 1782.74 19.01 71.07 93.13 1753.59 47.42 47.42 259.52 263.82 79.65 1.11 BP _MWD+IFR+MS 22 1877.17 21.29 70.18 94.43 1842.24 58.22 58.22 290.20 295.99 78.66 2.44 BP _MWD+IFR+MS 23 1970.22 24.10 66.31 93.05 1928.08 71.58 71.58 323.50 331.33 77.52 3.42 BP _MWD+IFR+MS 24 2062.80 25.90 64.41 92.58 2011.99 87.91 87.91 359.05 369.66 76.24 2.13 BP _MWD+IFR+MS 25 2156.69 27.60 63.18 93.89 2095.82 106.58 106.58 396.96 411.02 74.97 1.90 BP MWD+IFR+MS 26 2250.34 29.37 63.26 93.65 2178.13 126.71 126.71 436.83 454.83 73.82 1.89 BP _MWD+IFR+MS 27 2344.52 30.98 59.05 94.18 2259.56 149.57 149.57 478.25 501.09 72.63 2.82 BP MWD+IFR+MS 28 2436.14 34.73 58.56 91.62 2336.51 175.32 175.32 520.75 549.47 71.39 4.10 BP _ _MWD+IFR+MS 29 2530.38 37.24 56.66 94.24 2412.76 205.00 205.00 567.49 603.38 70.14 2.91 BP _MWD+IFR+MS 30 2622.59 37.01 56.39 92.21 2486.28 235.69 235.69 613.91 657.60 69.00 0.31 BP MWD+IFR+MS SrHLUMBERGER Survey Report 15-Nov-2007 07:15:15 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) --------- (f t) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 31 -------- 2716.30 ------ 36.58 ------- 55.72 ------ 93.71 -------- 2561.33 -------- 267.03 ------- 267.03 --------- 660.47 ------- 712.41 -------- 67.99 ----- 0.63 - BP ---- ------ _MWD+IFR+MS 32 2809.82 37.19 58.09 93.52 2636.13 297.67 297.67 707.50 767.57 67.18 1.65 BP _MWD+IFR+MS 33 2902.32 36.95 57.30 92.50 2709.94 327.47 327.47 754.62 822.61 66.54 0.58 BP _MWD+IFR+MS 34 2994.90 36.89 56.93 92.58 2783.95 357.66 357.66 801.32 877.52 65.95 0.25 BP _MWD+IFR+MS 35 3090.99 36.81 56.68 96.09 2860.84 389.21 389.21 849.55 934.46 65.39 0.18 BP _MWD+IFR+MS 36 3187.98 37.91 59.93 96.99 2937.94 420.11 420.11 899.62 992.88 64.97 2.33 BP _MWD+IFR+MS 37 3281.65 37.67 60.05 93.67 3011.97 448.82 448.82 949.32 1050.07 64.70 0.27 BP _MWD+IFR+MS 38 3378.02 37.13 59.39 96.37 3088.52 478.33 478.33 999.87 1108.40 64.43 0.70 BP _MWD+IFR+MS 39 3473.71 38.21 59.34 95.69 3164.26 508.13 508.13 1050.19 1166.66 64.18 1.13 BP _MWD+IFR+MS 40 3568.33 38.08 59.09 94.62 3238.68 538.04 538.04 1100.39 1224.89 63.94 0.21 BP MWD+IFR+MS 41 3666.15 38.57 56.51 97.82 3315.42 570.36 570.36 1151.71 1285.20 63.65 1.71 BP _MWD+IFR+MS 42 3792.49 38.08 56.19 126.34 3414.54 613.77 613.77 1216.93 1362.95 63.24 0.42 BP _MWD+IFR+MS 43 3884.06 38.39 54.15 91.57 3486.47 646.14 646.14 1263.44 1419.08 62.91 1.42 BP _MWD+IFR+MS 44 3976.68 39.42 54.19 92.62 3558.54 680.19 680.19 1310.60 1476.59 62.57 1.11 BP _MWD+IFR+MS 45 4070.68 39.71 53.53 94.00 3631.01 715.50 715.50 1358.95 1535.80 62.23 0.54 BP _MWD+IFR+MS 46 4165.33 40.79 49.08 94.65 3703.26 753.73 753.73 1406.64 1595.85 61.82 3.24 BP _MWD+IFR+MS 47 4258.22 40.95 40.04 92.89 3773.57 796.95 796.95 1449.19 1653.87 61.19 6.37 BP _MWD+IFR+MS 48 4352.68 38.67 34.36 94.46 3846.15 845.03 845.03 1485.77 1709.27 60.37 4.54 BP _MWD+IFR+MS 49 4446.10 37.98 32.08 93.42 3919.44 893.49 893.49 1517.51 1761.01 59.51 1.68 BP _MWD+IFR+MS 50 4539.17 38.30 32.56 93.07 3992.64 942.06 942.06 1548.25 1812.33 58.68 0.47 BP _MWD+IFR+MS 51 4632.34 36.94 33.86 93.17 4066.44 989.65 989.65 1579.38 1863.83 57.93 1.69 BP _MWD+IFR+MS 52 4726.41 36.43 34.90 94.07 4141.88 1036.03 1036.03 1611.12 1915.48 57.26 0.85 BP _MWD+IFR+MS 53 4817.78 36.25 34.50 91.37 4215.47 1080.54 1080.54 1641.94 1965.59 56.65 0.33 BP _MWD+IFR+MS 54 4912.81 36.22 34.77 95.03 4292.13 1126.76 1126.76 1673.86 2017.77 56.05 0.17 BP _MWD+IFR+MS 55 5005.71 35.77 30.76 92.90 4367.30 1172.64 1172.64 1703.41 2068.01 55.46 2.58 BP _MWD+IFR+MS 56 5098.99 35.91 24.54 93.28 4442.94 1220.97 1220.97 1728.72 2116.42 54.77 3.91 BP _MWD+IFR+MS 57 5191.98 36.28 19.02 92.99 4518.10 1271.80 1271.80 1749.02 2162.53 53.98 3.52 BP _MWD+IFR+MS 58 5285.88 35.21 15.93 93.90 4594.32 1324.10 1324.10 1765.50 2206.86 53.13 2.23 BP _MWD+IFR+MS 59 5379.11 33.58 11.82 93.23 4671.26 1375.19 1375.19 1778.16 2247.89 52.28 3.04 BP _MWD+IFR+MS 60 5472.70 33.13 9.87 93.59 4749.43 1425.73 1425.73 1787.85 2286.72 51.43 1.24 BP _MWD+IFR+MS • S~HLUMBERGER Survey Report 15-Nov-2007 07:15:15 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 5566.06 33.23 9.15 93.36 4827.57 1476.12 1476.12 1796.29 2324.99 50.59 0.44 BP MWD+IFR+MS 62 5662.62 33.06 8.47 96.56 4908.42 1528.29 1528.29 1804.38 2364.62 49.74 0.42 BP _ MWD+IFR+MS 63 5756.94 32.54 7.46 94.32 4987.70 1578.89 1578.89 1811.46 2402.97 48.92 0.80 BP _ MWD+IFR+MS 64 5848.91 32.56 6.27 91.97 5065.23 1628.01 1628.01 1817.37 2439.93 48.15 0.70 BP _ MWD+IFR+MS 65 5948.24 32.46 5.34 99.33 5148.99 1681.12 1681.12 1822.77 2479.65 47.32 0.51 BP _ MWD+IFR+MS 66 6044.45 32.13 4.56 96.21 5230.32 1732.33 1732.33 1827.21 2517.87 46.53 0.55 BP MWD+IFR+MS 67 6137.82 31.53 3.53 93.37 5309.65 1781.45 1781.45 1830.69 2554.41 45.78 0.87 BP _ MWD+IFR+MS 68 6230.99 30.72 3.82 93.17 5389.41 1829.51 1829.51 1833.77 2590.34 45.07 0.88 BP _ MWD+IFR+MS 69 6260.52 30.35 2.97 29.53 5414.84 1844.49 1844.49 1834.66 2601.56 44.85 1.93 BP _ _MWD+IFR+MS 70 6331.00 30.35 2.97 70.48 5475.66 1880.05 1880.05 1836.51 2628.19 44.33 0.00 Projected to TD [(c)2007 IDEAL ID12 OC 13] • Drilling 8 Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No W-214 Date Dispatched: 16-Nov-07 Installation/Rig Nabors-9ES Dispatched By: Franklin Medina LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Flo ies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division r~ / ~ ('~` ~ ~ /) ~~, 2525 Gambell Street, Suite 400 I'~ `-emu v~ Anchorage, Alaska 99501 fclarke3@slb.com Fax: 907-561-8317 ,~07~~~~ W-214i 13-3/8" cement job Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, November 08, 2007 10:05 AM To: 'McVey, Adrienne' Ce: Chuck Scheve Subject: RE: W-214i (207-142) 13-3/8" cement job Page 1 Qf 2 Adrienne, Chuck called me this morning regarding this matter. I concur with Chuck's assessment that it is not necessary to continue remedial operations on the 13-3/8" deep conductor/gravel string. Cementing the 9-5/$" casing to surtace should provide the isolation and structural support needed. Good luck with the remaining operations. Call or message with any questions. Tom Maunder, PE AOGCC From: McVey, Adrienne [mailto:Adrienne.McVey@bp.com] Sent: Thursday, November 08, 2007 9:56 AM To: Maunder, Thomas E (DOA) Subject: W-214i 13-3/8" cement job Tom, We pumped our 13-3/8" second conductor cement job on W 2141 last night. You may remember from the permitting process that we added this shallow string in order to case off problematic shallow formations (running gravel and wood sections} that gave us trouble an previously-drilled wells on this part of W-pad. The thought was that getting these formations isolated as quickly as possible (and thus decreasing perms#rost thaw} would make drilling and casing our 12-114" surtace hole much easier. We planned for cement to surface for the 13-3/8" casing string. Due to the losses we'd. experienced on previous wells, we did astab-in job, and also ran a TAM port collar at 500'. We had 700°!o excess lead cement on Location for the stab-in job; we pumped all of it (710 bbls Arctic Set Lite) without seeing cement retums to surtace. We did have full returns while pumping the lead slurry. We then switched over to pump 120.5 bbls of AS1 tail; we started out getting full returns (Mudpush and clabbered mud at surface}, but after pumping 60 bbls, lost all returns. We pumped the rest of the tail cement and chased it with water. The rig noted good lifting pressure while pumping the first half of the fait (they faxed me the chart recorder data, and it shows good indication that the 15.7 ppg slurry had rounded the corner and was moving uphoie prior to Losing retums). We then attempted to pump a secondary cement job through the TAM collar. We were able to establish injection (up to 3 bpm}, but saw no returns at surface; after pumping 18 bbls, we shut down and shifted the collar closed. The estimated excess hole volume, based on Mudpush returns, is approximately 820°!0; based on this figure, we estimate TOC to be at -210'. Matt Marlyn, 9ES nigh# WSt., contacted Chuck Scheve; due to the fact that we will be casing and cementing our 9-5/8" surface string as usual (i.e. cement back to surface}, Chuck supported our plan to proceed without attempting any further remedial work beyond the attempt at a TAM job to get cement to surface on this 13-3/8" string. Please a-mail or call at your earliest convenience and let me know if this is acceptable. Thanks for your help, Adrienne McVey GPB Rotary Drilling 11 /8/2007 SARAH P AL/N, GIVERN~R °`~~~ OI~ ~ ~ / 333 W. 7th AVENUE, SUITE 100 CO1~tSF.R'QA'1'IOl'~T COl-'II-I15SIOIY / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU W-2141 BP Exploration Alaska Inc. Permit No: 207-142 Surface Location: 4889' FSL, 1176' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 1476' FSL, 4622' FEL, SEC. 15, T11 N, R 12E, 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 {90659-3607 (pager). 0 DATED this ~ day of November, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 . ~c~i~v ,o.~,~~ ~~~.~~ OCT 2 2 2001 ~iaska Oi! & Gas Cons. Cim~mission 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed 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-2141 " 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 6278' TVD 5421' 12. Field /Pool(s): _ Prudhoe Bay Field /Polaris Pool 4a. Location of Well (Governmental Section): Surface: 4889' FSL 1176' FEL SEC T11N R12E UM 21 7. Property Designation: ADL 028263 , , . , , , Top of Productive Horizon: 1176' FSL, 4628' FEL, SEC. 15, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2007 Total Depth: 1476' FSL, 4622' FEL, SEC. 15, T11 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,295' 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y-5959866 Zone-ASP4 10. KB Elevation Plan (Height above GL): 80.9 feet 15. Distance to Nearest Wetl Within Pool: 1,385' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 37 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2320 Surface: 1789 18. Ca in .Pro ram: S ecificatio ns To - Settin _ D th -Bo ttom Quanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# A-53 WLD 80' Surface Surface 80' 80' 260 sx Arctic Set A rox. 16" 13-3/8" 6 # L-80 BTC 1903' Surface Surface 1903' 1860' 845 sx Dee Crete 12-1/4" 9-5/8" 40# L-80 BTC 3676' Surface Surfa 3676' 3336' 300 sx Dee rete 205 sx Class 'G' 8-3/4" 7" 26# L-80 TC-II 5192' Surface Surface 5192' 4549' See Below 8-3/4" 7" 26# L-80 BTC-M 1085' 5192' 4549' 6277' 5420' 305 sx Class 'G' 19. PRESE NT WELL CONDITION SUMMARY (To' be completed for Redrill and Reentry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Pr ducti n 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 Amanda Rebol, 564-5543 Printed Name Robert Tirpack Title Engineering Team Leader ~ Prepared By Name/Number: Si nature Phone 564-4166 Date /<i a ~s~ Terrie Hubble, 564-4628 Commission-Use Onl Permit To Drill Number: a?o~ly~a0 API Number: 50-Oo?9 ~33~.3-DOOd Permit A proval Date: ~ See cover letter for other re uirements Conditions of Approval: ~a~`v~~c ~,Mpuq lc~,cc~~~-cr~o~c ~ ~pp~ ~ ~ ~ 0 p~ q..~ a ~ , C~3 3 If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or~as contained shales: ~~0~~ ` t ~Y ~~5~ , µ\T~, LtZtv~Q'^~~~`~~,„r, Samples Req'd: ^,Yes ~No Mud Log Req'd: Yes No v`~`~~~~ OpCc.C'iCl~~tOh1h ~~CA~W ~ ~`'~~JA HZ ~~seSS~Yes No D ectional S ey Req'd: Yes ^ No Other: ` ~ Q \ r~ • ~ ~1,o~~z~ ~-.) A' CZ ON~.~ i D APPROVED BY THE COMMISSION Date ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~~ ~ ~ ~ ~ ~ ~ ~ V ~ ~ ~/ Sub ~®~pliCate • Well Name: W-214 Drill and Complete Plan Summary T e of Well service / roducer / injector : Injector Surface Location: As-Staked X=612049 Y=5959866 4889' FSL, 1176' FEL , T11N, R12E, Sec. 21 Target Locations: Top OBa X=613850 Y=5961460 1176' FSL, 652' FWL, T 11 N, R 12E, Sec. 15 Bottom Hole Location: X =613850 Y =5961760 1476' FSL, 657' FWL, T11N, R12E, Sec. 15 API NUMBER: TBD Ri Nabors 9ES Estimated Start Date: 11 /01 /2007 MD: 6278' TVD: 5421' O eratin Da s to com lete: 12.8 RT/GL: 28.5' RTE: 80.9' Well Design: Grassroots Schrader Bluff Injector 3'/z" tbg, 9.2# L80, TC-II, multi-packers, zonal injection Ob'ective: Multi-zonal injector into Schrader Bluff OBa, OBc and OBd sands Directional Plan: Version: Schlumberger P10 KOP: 300' MD, build 1.5/100 Maximum Hole An le: 37° Close Approach Wells: Nearest well within Pool All wells pass major risk criteria. Reference anti-collision report W-201 is 1385' from W-214 C~3 5492' MD Distance to Nearest Property Line• 18295' to PBU boundary Comments: No wells within'/a mile at injection depth Page 1 Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: N/A Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density PWD Open Hole: None Cased Hole: USIT Primar De th Control mode Mud Program: 16" & 12 ~/a" Surface Hole: Fresh Water Surface Hole Mud Density Viscosity seconds Yield Point Ib/1-OOf~- API FL mis/30min PH Initial 8.5 - 9.2 250-300 50 - 70 15 - 20 8.5 - 9.5 Base PF to to SV 9.0 - 9.5 250-300 30 - 45 < 10 8.5 - 9.5 SV to TD 9.5 max 250-300 20 - 40 < 10 8.5 - 9.5 8 3/a" Production Hole: LSND Interval Density (ppg) Tau o YP PV pH API Filtrate 10' Gel Cs Shoe to TD 8.7-9.0 4-7 25-30 10-15 8.5-9.5 6-10 10 Casina/Tubina Proaram: Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MDlTVD Btm MDlTVD RTE 42" Insulated 20" 91.5 A-53 WLD 80' GL 80'/ 80' 16" 13 /8" 68 L-80 BTC 1903' GL 1903' / 1860' 12 '/a" 9 /e" 40 L-80 BTC 3676' G L 3676' / 3336' 8 3/a" 7" 26 L-80 TC-II 5192' GL 5192' / 4549' 8 3/a" 7" 26 L-80 BTC-M 1085' 5192' / 4549' 6277' / 5420' Tubin 3'h" 9.2 L-80 TC-II 6175' GL 6175' / 5338' ~ Comments: ~ Tbg crossover to 4'/z" just below tree ~ I me rit Testi n Test Point Depth Test Type 9 e/R' Surface Casing 20' - 50' from surface shoe LOT The 12 1/a" hole will be drilled with a diverter, therefore no FIT or LOT will be performed after drilling out the 13 s/a". In accordance with AOGCC 20 AAC 25.030.f. W-2141 Permit Application Page 2 Cement Calculations: Second Conductor: Casin Size 13 /8" Basis: Lead: Open hole volume + 350% excess in permafrost and 80' shoe track volume. TOC at surface. Total Cement Volume: Lead 668 bbl / 3750 ft / 845 sks of DeepCrete 10.7 ppg and 4.44 cf/sk. Surface Casin Casin Size 9 /e" Basis: Lead: Based on 1903' of OA with 13 /8" second conductor (I.D. = 12.415") and 1273' open hole with 30% excess. Port collar used if necessary. Lead TOC: Surface Tail: Based on 80' shoe track volume and 500' of open 12'/a" hole with 30% excess. Tail TOC: 500' MD above the Casin shoe Total Cement Volume: Lead 206 bbl / 1156 ft / 300 sks of DeepCrete at 10.7 ppg and 3.85 cf/sk Tail 42 bbl / 238 ft / 205 sks of Class `G' at 15.8 and 1.16 cf/sk Production Casina: Casin Size 7" Basis: Tail: Based on 1539' of 83/a" open hole with 40% excess and 80' shoe track volume, ID 6.276" TOC at 4676' MD (1000' MD below surface casing shoe), 562' above Ug_MA Total Cement Volume: Tail 63 bbl / 354 ft / 305 sks of Class `G' at 15.8 ppg at 1.16 cf/sk Formation Tops(TVDss) and Estimated Pore Pressures Est. Est. Commercial Formation Formation Hydrocarbon Est. Pore To s To s Uncertain Bearin Press. Est. Pore Press. Formation (MD) (TVDss) (eet) (Yes/No) (Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells Gl 380 330 +/- 50' No 135 8.7 SV6 1291 1200 +/- 50' No 540 8.7 EOCU 1871 1750 +/- 50' No 788 8.7 SV5 1984 1855 +/- 50' No 835 8.7 Base Permafrost 1984 1855 +/- 50' No 835 8.7 Poss. Free Gas SV4 2145 2000 +/- 50' or H drates 900 8.7 (See fault (See fault Fault 1 2372 2200 +/- 100' section section 8.7 W-214i Permit Application Page 3 • u SV3 2687 2465 +/- 50' Poss. Free Gas or H drates 1109 8.7 SV2 2949 2675 +/- 50' Poss. Free Gas or H drates 1204 8.7 SVl 3343 2990 +/- 50' Poss. Free Gas or H drates 1346 8.7 UG4 3775 3335 +/- 50' Thin Coal 1501 8.7 UG4A 3824 3375 +/- 50' Heavy Oil btw (3375-3530' SS 1519 8.7 UG3 4255 3720 +/- 50' Thin Coal 1674 8.7 UGl 4868 4210 +/- 50' No; water 1895 8.7 Ma UG 5238 4505 +/- 50' Heavy Oil btw (4505-4535' SS 2027 8.7 _ Mbl UG 5300 4555 +/- 50' Heavy Oil btw (4555-4600' SS 2050 8.7 _ Mb2 UG 5356 4600 +/- 50' No; water 2070 8.7 _ Mc UG 5442 4670 +/- 50' No; water 2102 8.7 _ Na SB 5528 4740 +/- 50' No; water 2133 8.7 _ Nb SB 5559 4765 +/- 25' No; water 2144 8.7 _ Nc SB 5596 4795 +/- 25' No; water 2158 8.7 _ Ne SB 5609 4805 +/- 25' No; water 2162 8.7 _ OA SB 5714 4890 +/- 25' No; water 2160 8.6 _ OBa SB 5777 4940 +/- 25' Yes 2115-2155 8.3-8.5 _ OBb SB 5808 4965 +!- 25' Yes 2205 8.6 _ OBc SB 5871 5015 +/- 25' Yes 2150-2185 8.3-8.5 _ OBd SB 5940 5070 +/- 25' Yes 2135-2185 8.2-8.4 _ OBe SB 6027 5140 +/- 25' Yes 2280 8.6 _ OBf SB 6077 5180 +/- 25' Yes 2295 8.6 _ Base_SB_OBf 6140 5230 +/- 25' No 2320 8.6 Well TD T.D. is 250' MD past Top_OBe marker Criteria (ie ??ft TVD, ??ft Rathole, ..4.. ~ G Ll.. Comments• Formation pressures from surface to the OA are calculated based on a .45 water gradient. Formation pressures from the OA sands down to the SB_OBd are estimated based on the 1-07 W-204 MDT pressures Page 4 Well Control: 16" and 12'/a" holes will be drilled with diverter. The 8 3/a" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 2320 psi C~3 5310' TVD, 8.6-8.7 ppg EMW (at base of Schrader Bluff OBf, 6140' MD) • Maximum surface pressure: 1789 psi @ surface (based on BHP and a full column of gas from TD C~3 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer 250 / 2500 psi • Rams 250 / 4000 psi • Planned completion fluid: 8.6 ppg seawater / 6.8 ppg diesel (6277' MD, also TD) K~~~ Tn~erance / Infi~nrity Testing Summary Tabie Casing and Casing Test Maximum. Mud Weight Exp Pore LOT / Interval Pressure Influx Press FIT Volume; 95/8" Surface 3500 psi 51 BBLS 9.5 8.7 LOT Casing (assuming 10.8 LOT" 7" Production 4000 psi NA NA NA NA Casin *nowever- a ~~.a ~~. i is expGC~~u Disposal: No annular disposal in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 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. W-2141 Permit Application Page 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC landing ring for the FMC slimhole well head on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test diverter. 3. MU 16" drilling assembly with MW D/GR/Dir and drill surface hole to approximately 1903' MD. 4. Run and cement the 13 3/8", 68# casing back to surface. 5. MU 12 '/," drilling assembly with MWD/GR/DIR and RIH to float collar. Drill to 3676' MD, approximately 300' below the top of the SV1. 6. Run and cement 9 5/8" surface casing. Pressure test casing to 3500 psi for 30 minutes at plug bump. 7. ND diverter and NU casing /tubing head. NU BOPE and test. 8. Make up 8 3/a" drilling BHA. Drill out shoe joints and displace well to LSND drilling fluid. Drill 20' - 50' of new formation and perform Leak Off Test. 9. Drill ahead to Production hole Target TD (Approx. 6277' MD, 200' below OBf base). Circulate one BU, back-ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 10. Run and cement the 7" production casing. Displace with 8.6 ppg seawater. Pressure test casing to 4000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-5/8" annulus. 11. PU DPC guns and RIH w/ 134' of 4.5" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR/CCL for gun correlation. 12. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate OBa, OBc, and OBd. POOH LD DP and guns. 13. 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. 14. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 15. Run the 3-'/z", 9.2# completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OA perfs. 16. Confirm that packers are on depth using E-line. 17. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 18. Install and test TWC. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to 2500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 20. InstaN BPV in tubing hanger. Install a VR plug in the 7"x 3-'/z" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 21. Rig down and move off. Post-Rig Work• 1. MIRU slickline. Pull the ball and rod / RHC plug. 2. Pull shear valve, install GLV in all of the other mandrels as per the PE. 3. Perforate as per PE. W-214i Permit Application Page 6 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE Tight Hole/ Lost Circulation A. Recent W Pad wells have experienced tight hole and lost circulation with drilling and running casing in Permafrost interval. Use best practices for drilling and lining surface hole interval. 13 3/8" second conductor added to address this problem. Well Control /Reservoir Pressures: Interval Psi EMW TVDss MD Schrader Bluff Sands 2150-2185 8.3-8.7 4940- 5070 5777- 5940 III. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. IV. Running Gravels: A. 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 S Pad Data Sheet for details. V. Lost Circulation /Breathing: A. Possible small throw fault may be encountered in the SV4, but no faults expected in the reservoir interval. If encountered, follow LCM decision tree; reduce mudweight slightly. B. Pressure depletion of OBa, OBc and OBd zones produced in offset wells W-200 and W-201 to as low as 8.2 ppg. VI. Kick Tolerance /Integrity Testing: A. The 13 3/8" cemented to surface. The 9 5/$" casing will be cemented to surface using a port collar at 1000'. The 7" casing will be cemented 1000' MD from the 9 5/8" casing shoe. B. Kick To{erance ! Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure Influx.. Press FIT Volume 95/8" Surface 3500 psi 51 BBLS 9.5 8.7 LOT Casing (assuming 10.8 LOT" 7" Production 4000 psi NA NA NA NA Casin *However- a 12.5 LOT is expected W-2141 Permit Application Page 7 VII. Heavy Oil A, Heavy oil is expected in the UG4A and M sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones. VIII. Hydrogen Sulfide A. All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range; result of PBU ' gas lift gas H2S Summa Table Welt Name H2S Level m Date of Readin #1 Closest SHL Well H2S Level W-201 20 11/1/2005 #2 Closest SHL Well H2S Level W-200 15 8/21/2006 #1 Closest BHL Well H2S Level W-201 20 11/1/2005 #2 Closest BHL Well H2S Level W-21 15 1/15/2007 Max. Recorded H2S on Pad/Facilit W-01 60 8/16/2005 IX. Faults Formation Where MD TVDss Est. Throw Encounter Fault Intersect Intersect Throw Direction Uncertaint M.D. Possible Fault #1 - SV4 Formation 2472' 2200' 25' West +/-100' X. Broaching A. Monitor adjacent wells for broaching while drilling 13 3/g" second conductor hole. CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-2141 Permit Application Page 8 WELLHEA. D = ~ FMC ACTUATOR = Baker Hydraulic _.___ _- KB. ELEV = BF. ELEV KOP = 300' -- Max Angle = 40 deg ~- ._ __ Cratum MG = Datum TV D = SAFETY NOTES: ""*HES PKR ~ ' !S "PULL TO RELEASE" ~ ~ ~ j"\ 1A Q BUT CAN ALSO BE RELEASED BY PRESSURE. DO NOT ~,,,I/ ~"j V EXCEED 4300 PSL TEST PRESSURE PKR RATING = 5415 PSI (4332 PSI IS $0°lo OF PKR RATING)"" 29` --~4-112" XO 3-1l2". ID = 2.992" 4-112" TBG, 12.6#, L-80, 2~ 9' ~~ TG11..0152 bpf, fD = 3.958" 13-318" CSG, 68#, L-80, BTC, ID = '' 2.415" f 9-518" CSG, 40#, L-80, BTC, ID = 8.835" ~ ~ 1903' q I ss7s` 1 7" CSG, 26#, L-80, TG11..0383 bpf, ID = 6.2 ~ 6" 5192` Minimum ID = 2.75" xxxx' 3-'ii2" HES RCN MPP'LE S`v1A RKER JOINT w i RA TAG OA MARKER JOINT~vf RA TAG OE7a REF LOG: SLB Realtirne LG~VD A NGLE A7 TOP PERF: f~lote: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpntSgz DATE 4-1?2" 5 Oba xxxx'-xxxx' O 4-172" 5 Obc xxx;<"-xxxx' O 4-1.t2" 5 Obd xxxx'-xxxx` O 2300` (-j3-1,~2" HES X NfP, ID = 2.$13" 6 5100 MMG DMY RK \AtLti TFR IRI IFC :TItIN MA NnR FI.S 5T MD TVD DEV TYPE VLV LATCH PORT DATE 5 MMG-W RK 4 MMG-W RK 3 MMG-W RK 2 (~rtMG-V~d RK 1 MNIG-W RK 7 d' 3-112" HES X NIP, ID =2.813" 575 7" HES A HR PKR w t` 1I4" FEED THRU, ID = 2.920" 5 ~ PHOENIX PRESITEMP SEPJSOR SUB, ID = 2.992" 5g$5' 3-112" HES X NIP, iD = 2.813'" 5855` "' HES A HR PKR w / 1 ?4" FEED THRU, iD = ?_.920" ' PHOENIX PRES(fEIV1P SENSOR SUB, ID = 2.992" 5930' %" HES A HR PKR +,v 1 1 /4" FEED THRU, ID = 2.920" S~~Q` 3-112" HES X N1P, ID = 2.813" 5970' 3-112" HES X NIP, ID = 2.813" ~30' ~`'-112" HES XN t^JIP, ID=2.75" 3-ii2" TBG, 9.2#, L-80, TGII, .0087 bpf, iD = 2.992" 6175` PBTD ~-~ 6197' 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 5(jQ$' 3-112" WLEG, iD = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 07!19/07 SRK Proposed WBD (Tube Ver 1) ORION UNIT WELL: W-2141 PERMIT No: xxxxx API No: 50-029-xxxxx Sec, Tw p, Rge by Schlumberger W-214 (P10) Proposal Report Date: October 2, 2007 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 44.400° Field: Prudhoe Ba Unit - WOA Vertical Section Ori in: N 0.000 ft, E 0.000 ft y Structure 1 Slot: Well: W-PAD / W 214 plan ~~' ~~ s u TVD Reference Datum: Rotary Table Plan W-214 ~~ TVD Reference Elevation: 80.90 elative to MSL Borehole: ~ Plan W-214 ~~ Sea Bed I Ground Level Elevation: 52.40 ft relative to MSL UWVAPI#: 50029 Magnetic Declination: 23.315° Survey Name I Date: W-214 (P10) I October 2, 2007 Total Field Strength: 57643.233 nT Tort I AHD 1 DDI 1 ERD ratio: 74.004° / 2847.28 ft / 5.387 / 0.525 Magnetic Dip: 80.870° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 15, 2007 Location LaVLong: N 70.29929818, W 149.09253219 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5959865.970 ftUS, E 612049.020 ftUS North Reference: True North Grid Convergence Angle: +0.85435860° Total Corr Mag North -> True North: +23.315° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Gravdy DLS Directional Northing Easting Lathude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 K Index ftUS ftUS licit u.uu u.uu 9U.UU -23U.9U U.UU U.UU U.UU U.UU - U.UU U.UU 59592365.9/ 61YU49.U'L N /U.L99L923125 W 149.179253219 KOP Bld 1.5/100 300.00 0.00 90.00 219.10 300.00 0.00 0.00 0.00 HS 0.00 0.00 5959865.97 612049.02 N 70.29929818 W 149.09253219 G1 380.91 1.21 90.00 300.00 380.90 0.60 0.00 0.86 HS 1.50 0.02 5959865.98 612049.88 N 70.29929818 W 149.09252525 Bld 1.5/100 400.00 1.50 90.00 319.09 399.99 0.92 0.00 1.31 HS 1.50 0.29 5959865.99 612050.33 N 70.29929818 W 149.09252159 500.00 3.00 90.00 419.01 499.91 3.66 0.00 5.23 HS 1.50 1.20 5959866.05 612054.25 N 70.29929818 W 149.09248980 600.00 4.50 90.00 518.79 599.69 8.24 0.00 11.77 HS 1.50 1.72 5959866.15 612060.79 N 70.29929818 W 149.09243684 700.00 6.00 90.00 618.37 699.27 14.64 0.00 20.92 HS 1.50 2.10 5959866.28 612069.94 N 70.29929818 W 149.09236275 800.00 7.50 90.00 717.67 798.57 22.86 0.00 32.68 HS 1.50 2.39 5959866.46 612081.69 N 70.29929818 W 149.09226757 900.00 9.00 90.00 816.64 897.54 32.90 0.00 47.03 HS 1.50 2.63 5959866.67 612096.04 N 70.29929817 W 149.09215138 Crv 1.5/100 966.67 10.00 90.00 882.39 963.29 40.60 0.00 58.03 38.44E 1.50 2.77 5959866.84 612107.04 N 70.29929817 W 149.09206228 1000.00 10.40 88.28 915.19 996.09 44.79 0.09 63.93 36.75E 1.50 2.83 5959867.01 612112.94 N 70.29929842 W 149.0921 1100.00 11.63 83.82 1013.35 1094.25 59.09 1.45 82.97 32.37E 1.50 3.00 5959868.65 612131.96 N 70.29930213 W 149.09186030 1200.00 12.92 80.23 1111.06 1191.96 75.94 4.43 104.02 28.86E 1.50 3.15 5959871.95 612152.95 N 70.29931027 W 149.09168988 SV6 1291.48 14.14 77.52 1200.00 1280.90 93.60 8.58 125.01 26.22E 1.50 3.28 5959876.41 612173.88 N 70.29932161 W 149.09151988 1300.00 14.26 77.29 1208.26 1289.16 95.35 9.04 127.05 26.00E 1.50 3.29 5959876.90 612175.91 N 70.29932286 W 149.09150336 1400.00 15.62 74.85 1304.88 1385.78 117.29 15.27 152.06 23.64E 1.50 3.41 5959883.50 612200.82 N 70.29933987 W 149.09130088 1500.00 17.00 72.79 1400.86 1481.76 141.76 23.11 179.02 21.67E 1.50 3.52 5959891.75 612227.66 N 70.29936131 W 149.09108257 1600.00 18.40 71.03 1496.12 1577.02 168.74 32.57 207.91 20.00E 1.50 3.62 5959901.63 612256.40 N 70.29938714 W 149.09084857 1700.00 19.82 69.52 1590.61 1671.51 198.20 43.63 238.72 18.57E 1.50 3.72 5959913.15 612287.05 N 70.29941736 W 149.09059905 1800.00 21.25 68.20 1684.25 1765.15 230.13 56.29 271.43 17.33E 1.50 3.81 5959926.30 612319.56 N 70.29945194 W 149.09033419 1900.00 22.68 67.04 1776.99 1857.89 264.50 70.54 306.01 16.26E 1.50 3.89 5959941.06 612353.92 N 70.29949087 W 149.09005415 13-3/8" Csg Pt 1903.26 22.73 67.01 1780.00 1860.90 265.67 71.03 307.17 16.22E 1.50 3.89 5959941.57 612355.07 N 70.29949221 W 149.09004476 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-214 plan\Plan W-214\Plan W-214\W-214 (P10) Generated 10/2/2007 1:00 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS ~v~/oeserCrm roo4.a4 ca.m~ oo.~o ~oaauv iyav.av Lao.o/ as.aa aao.a4 IJ.4~L l.w 2000.00 24.13 66.02 1868.76 1949.66 301.30 86.37 342.44 15.31 L 1.50 2100.00 25.58 65.10 1959.50 2040.40 340.50 103.77 380.70 14.48E 1.50 SV4 2145.03 26.23 64.72 2000.00 2080.90 358.92 112.11 398.51 14.14E 1.50 Crv 2/100 2145.92 26.24 64.71 2000.80 2081.70 359.29 112.28 398.87 14.99E 1.50 2200.00 27.16 64.17 2049.11 2130.01 382.12 122.76 420.79 14.51 L 1.75 2300.00 28.86 63.27 2137.40 2218.30 426.44 143.56 462.89 13.71 L 1.75 2400.00 30.56 62.45 2224.25 2305.15 473.44 166.18 506.98 13.00E 1.75 2500.00 32.27 61.71 2309.59 2390.49 523.10 190.59 553.03 12.37E 1.75 2600.00 33.98 61.04 2393.34 2474.24 575.36 216.77 600.99 11.81 L 1.75 SV3 2687.19 35.47 60.50 2465.00 2545.90 623.01 241.02 644.32 11.37E 1.75 2700.00 35.69 60.43 2475.42 2556.32 630.18 244.70 650.81 11.31 L 1.75 End Cnr 2775.01 36.98 60.00 2535.84 2616.74 672.94 266.78 689.38 -- 1.75 SV2 2949.21 36.98 60.00 2675.00 2755.90 773.86 319.17 780.13 --- 0.00 SV1 3343.53 36.98 60.00 2990.00 3070.90 1002.32 437.77 985.55 -- 0.00 9-5/8" Csg Pt 3676.26 36.98 60.00 3255.80 3336.70 1195.10 537.84 1158.88 --- 0.00 Crv 4/100 3696.66 36.98 60.00 3272.10 3353.00 1206.92 543.98 1169.51 99.79E 0.00 3700.00 36.96 59.78 3274.77 3355.67 1208.86 544.99 1171.25 99.61 L 4.00 UG4 3775.16 36.56 54.80 3335.00 3415.90 1252.67 569.27 1209.07 95.62E 4.00 3800.00 36.47 53.14 3354.96 3435.86 1267.24 577.96 1221.02 94.28E 4.00 UG4A 3824.91 36.41 51.46 3375.00 3455.90 1281.90 587.01 1232.73 92.94E 4.00 3900.00 36.36 46.40 3435.47 3516.37 1326.27 616.25 1266.29 88.86E 4.00 4000.00 36.63 39.69 3515.89 3596.79 1385.65 659.67 1306.83 83.46E 4.00 End Crv 4063.94 37.00 35.46 3567.09 3647.99 1423.68 690.03 1330.17 -- 4.00 UG3 4255.41 37.00 35.46 3720.00 3800.90 1537.50 783.87 1397.02 -- 0.00 UG 1 4868.93 37.00 35.46 4210.00 4290.90 1902.23 1084.60 1611.22 -- 0.00 Crv 4/100 5211.90 37.00 35.46 4483.91 4564.81 2106.11 1252.70 1730.96 104.02E 0.00 Ma 5238.26 36.75 33.75 4505.00 4585.90 2121.70 1265.72 1739.94 102.65E 4.00 5300.00 36.28 29.68 4554.63 4635.53 2157.53 1296.96 1759.25 99.38E 4.00 Mb 1 5300.46 36.28 29.65 4555.00 4635.90 2157.79 1297.19 1759.39 99.35E 4.00 Mb2 5356.17 35.98 25.90 4600.00 4680.90 2189.25 1326.24 1774.69 96.33E 4.00 5400.00 35.82 22.92 4635.51 4716.41 2213.39 1349.63 1785.31 93.91 L 4.00 Mc 5442.51 35.74 20.02 4670.00 4750.90 2236.28 1372.76 1794.41 91.56E 4.00 5500.00 35.74 16.08 4716.67 4797.57 2266.36 1404.67 1804.81 88.36E 4.00 Na 5528.75 35.79 14.11 4740.00 4820.90 2281.01 1420.89 1809.18 86.76E 4.00 Nb 5559.59 35.88 12.01 4765.00 4845.90 2296.42 1438.47 1813.26 85.06E 4.00 Nc 5596.65 36.03 9.50 4795.00 4875.90 2314.53 1459.85 1817.32 83.03E 4,00 5600.00 36.05 9.28 4797.71 4878.61 2316.15 1461.79 1817.64 82.84E 4.00 Ne 5609.02 36.09 8.67 4805.00 4885.90 2320.48 1467.04 1818.47 82.35E 4.00 5700.00 36.73 2.63 4878.24 4959.14 2362.54 1520.72 1823.76 77.49E 4.00 J.`JO .7J.7,7J.74.tl0 O/LSO4.74 IV /V.LJJ7L/3L W 74J.U2f`JUU4~.i 3.97 5959957.43 612390.11 N 70.29953411 W 149.08975914 4.04 5959975.39 612428.09 N 70.29958163 W 149.08944935 4.08 5959984.00 612445.78 N 70.29960441 W 149.08930510 4.08 5959984.17 612446.13 N 70.29960488 W 149.08930221 4.12 5959994.98 612467.90 N 70.29963352 W 149.08912469 4.19 5960016.40 612509.67 N 70.29969033 W 149.08878377 4.26 5960039.67 612553.42 N 70.29975211 W 149.08842670 4.32 5960064.76 612599.10 N 70.29981879 W 149.08805380 4.38 5960091.65 612646.65 N 70.29989030 W 149.0876 1 4.44 5960116.55 612689.62 N 70.29995655 W 149.087 4.44 5960120.32 612696.05 N 70.29996659 W 149.087 4.49 5960142.97 612734.29 N 70.30002690 W 149.08694955 4.55 5960196.71 612824.23 N 70.30017001 W 149.08621463 4.66 5960318.34 613027.84 N 70.30049394 W 149.08455100 4.74 5960420.98 613199.65 N 70.30076727 W 149.08314718 4.74 5960427.28 613210.19 N 70.30078403 W 149.08306109 4.75 5960428.31 613211.91 N 70.30078679 W 149.08304702 4.80 5960453.15 613249.37 N 70.30085310 W 149.08274066 4.81 5960462.02 613261.18 N 70.30087685 W 149.08264387 4.83 5960471.24 613272.75 N 70.30090156 W 149.08254906 4.87 5960500.98 613305.87 N 70.30098143 W 149.08227723 4.92 5960544.99 613345.75 N 70.30110003 W 149.08194890 4.96 5960575.69 613368.64 N 70.30118295 W 149.08175977 4.99 5960670.52 613434.07 N 70.30143930 W 149.08121828 5.08 5960974.37 613643.75 N 70.30226073 W 149.07948304 5.13 5961144.23 613760.96 N 70.30271991 W 149.07851297 5.14 5961157.38 613769.75 N 70.30275547 W 149.07844018 5.17 5961188.90 613788.59 N 70.30284079 W 149.078 5.17 5961189.14 613788.72 N 70.30284145 W 149.07828262 5.19 5961218.41 613803.59 N 70.30292079 W 149.07815863 5.21 5961241.95 613813.85 N 70.30298469 W 149.07807257 5.23 5961265.21 613822.60 N 70.30304786 W 149.07799885 5.25 5961297.27 613832.53 N 70.30313503 W 149.07791457 5.26 5961313.55 613836.66 N 70.30317935 W 149.07787909 5.27 5961331.19 613840.48 N 70.30322738 W 149.07784602 5.28 5961352.62 613844.22 N 70.30328576 W 149.07781310 5.29 5961354.57 613844.51 N 70.30329108 W 149.07781048 5.29 5961359.83 613845.26 N 70.30330540 W 149.07780377 5.32 5961413.58 613849.75 N 70.30345207 W 149.07776083 WeIlDesign Ver SP 2.1 Bld( docAOx_100) W-214 plan\Plan W-214\Plan W-214\W-214 (P10) Generated 10/2/2007 1:00 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS UH 0/74.Otf 3b.tf6 1.0/ 4t3`JV.UU 4y/U.yU End Crv 5727.26 36.98 0.86 4900.06 4980.96 W-214 Tgt OBa 5777.26 36.98 0.86 4940.00 5020.90 OBa 5777.27 36.98 0.86 4940.01 5020.91 OBb 5808.56 36.98 0.86 4965.00 5045.90 OBc 5871.15 36.98 0.86 5015.00 5095.90 OBd 5940.00 36.98 0.86 5070.00 5150.90 OBe 6027.62 36.98 0.86 5140.00 5220.90 OBf 6077.69 36.98 0.86 5180.00 5260.90 Base OBf 6140.28 36.98 0.86 5230.00 5310.90 TD / 7" Csg 6277.62 36.98 0.86 5339.71 5420.61 Lesaal Description: Surface : 4888 FSL 1176 FEL S21 T11 N R12E UM Target OBa : 1175 FSL 4628 FEL S15 T11 N R12E UM BHL : 1476 FSL 4623 FEL S15 T11 N R12E UM L30y.U4 70L`J.07 7tfZ4. UP! /O./3L 4.UV 0.33 0`J014LL.3/ O/J04y.y4 IV /V.3V34/OV6 VV /4:J.V///OOIJ 2374.56 1537.07 1824.26 -- 4.00 5.33 5961429.93 613850.00 N 70.30349672 W 149 .07775677 2396.36 1567.14 1824.71 -- 0.00 5.34 5961460.00 613850.00 N 70.30357887 W 149 .07775305 2396.37 1567.15 1824.71 -- 0.00 5.34 5961460.01 613850.00 N 70.30357889 W 149. 07775305 2410.01 1585.96 1824.99 --- 0.00 5.34 5961478.83 613850.00 N 70.30363030 W 149. 07775073 2437.30 1623.61 1825.56 -- 0.00 5.35 5961516.47 613850.01 N 70.30373314 W 149. 07774607 2467.32 1665.02 1826.18 -- 0.00 5.35 5961557.89 613850.01 N 70.30384627 W 149. 07774096 2505.53 1717.72 1826.97 -- 0.00 5.36 5961610.59 613850.02 N 70.30399026 W 149 .07773445 2527.37 1747.84 1827.42 --- 0.00 5.37 5961640.71 613850.02 N 70.30407253 W 149. 07773072 2554.66 1785.49 1827.99 --- 0.00 5.37 5961678.36 613850.02 N 70.30417538 W 149. 0777 2614.54 1868.09 1829.23 --- 0.00 5.39 5961760.96 613850.03 N 70.30440105 W 149 .077 Northi ng (Y) [ftUS] Easting (X) [ftUS] 5959865.97 612049.02 5961460.00 613850.00 5961760.96 613850.03 WeIlDesign Ver SP 2.1 Bld( dorAOx_100) W-214 plan\Plan W-214\Plan W-214\W-214 (P10) Generated 10/2!2007 1:00 PM Page 3 of 3 bP Schlumberger ~" W-214 (P10) FIE`D Prudhoe Bay Unit - WOA sTRppnRE W-PAD Mayneuc Paramelars Surlaca Eeration NAD2] AlasMa 51ate Planes Zone Oc U9 Feel Mvscnllanenus Meael BGGM200/ Dip 608IC' Da{o Novumnar'S 21/01 N)0'I5)?]3 NunMny 9S966z 9/yU5 ny COnv_•O6S465660" SI01 W~3~y plan ND RnI Rosary Tale 1809011 afiove M9ll May per: -33315' FS 5/fiJ]2nT W'J95 J3'tfi Eastmg 6120J902'NS Sale FaM Oygy91 J2622 W~21y (Pt01 Srvy Date Oclobnr 02. 300/ -800 0 800 1600 2400 3200 0 800 1600 2400 0 0 C U ~ 3200 4000 ........ j... 'E KOP Bld 1.51100 ' .-..-. . _.._.._.._..-.:~..-.._.._..-..-..-..-..-:.-..-..-..-..-.._..-.._.._i._..-..-.._..-..-..-.._..~.._.. ela ~snoo crv ~.snoo .-.._.. j... V6.._.._..-.._.._..-.j-..-..-..-..-..-..-..-..-r-..-..~..-..-..~..-..~..-j....-..-..-..-..-..-..-.. y.._.. ......... i ....... ..........................~..................................~..................................j...................................~..... 73-3/8^ Csg Pt .~..-..~.._.._.. .V5l~ase Perm.;_.._.._.._.._.._.._.._.._:._.._..~..-..-..~..-..~..-:.~..-..-..-..-..-.._..-. - Crv2/100 •~•• •• .-..- ._.. _.._ V4 . _.._.._ _ ._.._.._.. _..-..-..-..- -..-..~..-..-..~..-..~. -i._.._..-.._.._..-..-..-... _ End Crv .-..~..f..-..~..-..-..~..-..-..- ~ .-.._.._..-ry-..-..~..-..-..~..-......j....-..~..-..-..-..-..-.. y..-.. L~.-.._.._.. _. .-..-..j...-..-..-..-..~..-..-..-.j-.._.. V'.._.._.._.._.._q_.._..-..-..-..-..-..-..-j.-..-..-..-..-.._.. _.._...j.._.. 9-5/B' Csg Pt ` crya~oo .-..-..j...-..-.._..-..~..-..-.._. i-.. _.. _.. _.. _. .. 4A_.. _.;. _.. _.._.._.. _.._.._..-.. _i.-..-..-..-..-..-..-..-...j..-.. .-..-..t...-..-..~..-..-..-..-.._.._.. _.. _.. _.. _.. .. _.. _.. _.. _..-.. _.. _.. _.. _.. _.. _..-..-..-..-..-.. _..-..-...p. _.. End Crv .-..~..w..-..~..-..-..-..-..-..~.i-.. _.._.._.. _.. _.._.. _. ~ 3..-..-..-..-..~..-..~..-i.-.._..-..-..-..-..-..-..~.._.. . : rv ~ioo 4800 5600 ro 1 r• .....: ................................................................... E................................. w- 00 0 800 1600 2400 3200 Vertical Section (ft) Azim = 44.4°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 0 800 1600 2400 3200 4000 4800 5600 by Schlumberger WELL W-214 (P10) FlE`D Prudhoe Bay Unit - WOA STRUCTURE W-PAD Mayne i~ Par Surface NFD2] Alas a SN1e Plat s Zan US Fee MlaLe a Model.1 BGGM 200] Dip: 606/0' Da1u be~t5. 300] LaL C N]0 t]5]i]3 S9b96S69]hUS Grid DunrMb Sid Il neo~3t4 ylan ND Rei Rdary Table 1609011 above MSLi Mag Dec: x2331 S' FS'. 5/6C32nT Lon: Wt69533.116 Ca Nrt~yy fi12U1902 MIS Scale Faca. 099993x2622 Plan. W-21a 1P t01 9rvy Dale Oduber 02. 200] -400 0 400 800 1200 1600 2000 2400 2000 2000 n n n 1600 Z 1200 0 0 a c a~ ~ 800 v v v 400 0 1600 1200 800 • 400 0 -400 0 400 800 1200 1600 2000 2400 ~« W Scale = 1(in):400(ft) E »> BP Alaska Anticollision Report Company: BP Amoco Date: 10/2!2007 Time: 13:06:06 Page: I Field: Prudhoe Bay . Reference Site: PB W Pad Co=ordinate(NE) Reference: Well: Plan W-214, True North i' Reference Well: Plan W-214 Vel'tieal(TVD) Reference: W-214 Plan 80.9 ReferegceReQpath: Plan W-214 i Db: Oracle ~ GLOBAL SCAN APPLIED: All wellpaths within 2UU'+ IUU/lUUU of reference -There are t1fPhLHaeells in thisRt+iid9pal Plan & PLANNED PROGRAM ' Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse ' Depth Range: 28.50 to 6277.62 ft Scan Method: Trav Cylinder North ' Maximum Radius: 824.91 ft Error Surface: Ellipse + Casing ----------- ----- Survey Program for Definitive Wellpath ', 'Date: 7/6/2001 Validated: No Version: 13 Planned From To Survey Toolcode Tool Name ft ft ' 28.50 600.00 Planned: Plan #10 V1 GYD-GC-SS Gyrodata gyro single shots 600.00 1840.00 Planned: Plan #10 V1 MWD MWD -Standard ' 600.00 3615.00 Planned: Plan #10 V1 MWD+IFR+MS MWD +IFR + Multi Station 3615.00 6277.62 Planned: Plan #10 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD" Diameter-- Hole Size Name ft ft ' in in 1903.26 1860.90 13.375 16.000 13 3/8" ', 3675.25 3335.90 9.625 12.250 9 5/8" ', 6277.62 5420.61 7.000 8.750 7" Summary <- --------- ----- Offset Wellpath ----.-----> Reference Offset Ctr-Ctr No-Go .-~liowable Site ~ Well Wellpath MD MD Distapce .Area .'Deviation Warning ' ft ft ft'' ft ft PB W Pad Plan W-202 Plan W-202 V2 Plan: PI 1208.00 1210.00 39.54 22.01 17.52 Pass. Major Risk ' PB W Pad Plan W-216 Plan W-216 V4 Plan: PI 398.90 400.00 15.96 7.84 8.11 Pass: Major Risk ', PB W Pad W-200 W-200 V2 726.81 730.00 96.08 12.62 83.46 Pass: Major Risk ', PB W Pad W-200 W-200PB1 V11 726.81 730.00 96.08 12.62 83.46 Pass: Major Risk ', PB W Pad W-201 W-201 V4 818.45 820.00 63.51 13.08 50.44 Pass: Major Risk ' ', PB W Pad W-204 W-204 V2 504.28 505.00 34.69 9.99 24.69 Pass: Major Risk PB W Pad W-204 W-204L1 V6 504.28 505.00 34.69 9.99 24.69 Pass: Major Risk ' PB W Pad W-204 W-204L2 V6 504.28 505.00 34.69 9.99 24.69 Pass: Major Risk ', PB W Pad W-204 W-204P61 V2 504.28 505.00 34.69 9.99 24.69 Pass: Major Risk ' PB W Pad W-20 W-20 V2 711.94 715.00 271.94 12.14 259.80 Pass: Major Risk ', PB W Pad W-213 W-213 V13 414.38 415.00 15.17 7.75 7.43 Pass: Major Risk ' PB W Pad W-21 W-21 V3 1003.76 1020.00 233.43 23.97 209.46 Pass: Major Risk PB W Pad W-21 W-21A V13 1007.85 1015.00 233.48 24.02 209.46 Pass: Major Risk PB W Pad W-22 W-22 V2 701.73 705.00 204.49 13.56 190.93 Pass: Major Risk ' PB W Pad W-23 W-23 V5 703.64 715.00 167.77 15.68 152.10 Pass: Major Risk ', ' PB W Pad W-23 W-23A VS 701.90 705.00 167.75 15.65 152.10 Pass: Major Risk ', ' PB W Pad W-24 W-24 V2 815.87 820.00 133.21 15.27 117.94 Pass: Major Risk ' • FieldPrudhoe Bay Site PB W Pad Well:Plan W-214 WellpathElan W-214 313 300 200 100 0 2 100 200 300 -3 1 3 ~~ 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t Target: W-214 Tgt 1 ~ ~ Site: PB W Pad I: Plan W-214 Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 4910.00 ft below Mean Sea Level Map Northing: 5961460.00 ft Local +N/-S: 1567.13 ft Map Fasting : 613850.00 ft Local +E/-W: 1824.70 ft Latitude: 70° 18' 12.884N - -- _ _ _ __ --_ _ -. _ Longitude: 149°04'39.911 W _ _ ----- n _ - - - --- _ Shape: Circle _- _ Radius: 50 ft ' SEC 16 _ I SEC 2i I i I I i i N 2822 - I I I I I I I I I w I J / N 2414.5 I~/ 33^ 5:3 32^ ^ 5z3 31 30^ 29 ^ II a I 509 211 ^ 27^ 26 • __'~~~ 25^ 34 W 35 36 j 37 } 38 39 ^ 40 } 400 t} 42 SPARE 44 r - - - - \ \ II \ N \ \ w \\ \\ 16 -"- I ~Lo 15 ~ \ \ ~ r-N 2904 \ \ v v ~ ~ v +v I \ ~ W PA ---- II \ \\ \ 1 C7 - -~ ~/ \~ j \\ \ \ ~ ~- P WEST END NO.i it W -2161 Q z1` I II ~Zb~W -2141 \~ - N KUP UK STA ~ I I I I ^ 2O1 _______________ ' N0.1 ZZ I I ^ 200 i ~ I I I I ^ 24 I I I I I ^ 23 i sTACU~AaEA II ' I ^ 22 ^ 21 I I W-PAD VICINITY MAP I I l ^ 20 N T S i I ^ 19 I . . . ^ 18 I I ~ I I r I ^ 17 ^ 1s I i ~}., ~~ °OF ° q~ `~(/ I I ~I II ^ 15 ^ 14 ° °~ .`P°° ° °~ ° I ^212 ' I ~ ~ °9 ^ 215 ^ 207 I I °°°°°°°°°°°°°°°°°°°°°°°°°°°°° L J o M I I N W ~Ir ~I zos I I °°°°ea°°°o9 °°°a°°°e° o o0 0 Leonard J. O'Hanley e °'~, ~° l I ~ I 1 i 2 I I I ° ~ 11386 °° ° i ~ I I I I 3 I I ° °°°P~ ~ I I 4 ~ I ' "'~*ESSIONA~- ~ 5 II 7 ~I III ~ e SURVEYOR'S CERTIFICATE I I I + O II I HEREBY CERTIFY THAT I AM $ PROPERLY REGISTERED AND LICENSED 11 TO PRACTICE LAND SURVEYING IN I ^12 i THE STATE OF ALASKA AND THAT I THIS AS-BUILT REPRESENTS A SURVEY ~2 3 i MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE \~ / I CORRECT AS OF SEPTEMBER 18, 2007. LEGEND -~- AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR `~ NOTES: -~~, `~ 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. ~~ 2. BASIS OF LOCATION IS W PAD MONUMENTS W-1 8c W-2. 3. BASIS OF ELEVATION IS W PAD MONUMENT W-2. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. 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' S2 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 ~ ~~~~~a ~~ ~. ~~~EO u 1'=300' wwoR.~. k by WOA W-PAD SHEET: AS-BUILT CONDUCTOR WELLS W-2141 & W-216i 1 °` 1 Alaska Department of Natural Resources Land Administration System Page 1 of 4 • _,~ _.~F~t€;~ ~ ~~=t ~.;a Sta#e Cala~ns ~ tIE`~ ~J S _.. ~S ~e ~ ark irA 4enu i Case Abstract I Case Retail i L~anci Abstract ,:_ ":. 1~'rlc. ~()1, 2'{2(i3 ~ Sr:<~;~;I~ 3~r ,:~~t~;7 °i~t !i; .i,; 1> c,t Ili/> ~i2(i07 Customer: 000107377 BP EXPLORA"PION (ALASKA)1NC PO BOX 1 966 1 2/900 E. BENSON BL AT"f N: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 12 Ccrsc Type:., OIL & GAS LEASE COMP D~~R Unit' 780 OIL AND GAS File I,ocalk~ra: DOG DIV OIL AND GAS Case Slalz~s: 35 ISS/APPRV/ACTV/ RUTH Statars Date: 08/11/1965 Total Acres: 2560.000 Date haitiutecl: 05/28/1965 Office of Primar°y Respon,cibili~l%: DOG DiV O1L AND GAS Lass Ti~unsaction Date: 12/04/2006 Case Si+b~pe : 1°~~ NORTH SLOPE Last lj~ansaciion: AA-NRB ASSIGNMENT APPROVED ME~rir/i~«~' U lu~v~aship: O11N Range: 012E ti~eclio~t. I ~ , S'cc~~r~~n :Icr~~~ ~ h l(1 ~~~~~. ~ s V~~ri~lrc~rt~ U luu~nsllip: O11N Range: UI-1~ ti~c[ion: 1(~ ,ti'r~~iruir I~_r~~~~: (iIO 1I~~r•i~/r~nr~ U 7~ni~ns/lip: O11N Range: r)I ~I. section: 21 ~~~~~~lir~fr l~~f~~-~: (,-~O tl~~~~i~liu~i~ U l~~ivnshiF~: Ol IN Range: (!121: ,ti~~~rinn.~ ,~'~°c~tiufr.lc~~~~~~ 6-G(I Legal Description< 0~-?<5-19<~ ** `.SALE:VOTIC"E LL~GAL DESCRIPTION `~.R CI-1-?9 TIIN. RI?E. C11I1~, 16. '1. ?2 260.00 II -28-19~> ~SEG:l1EA'T I T 11,'x', R I?F_. C,1I http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263.._ 10/23/2007 Alaska Department of Natural Resources Land Administration System Page 2 of 4 SEC'TION' Ii: 6-10.1CRE~S SEC'MO~V 16: 6=10 ACRES C'ONT~ILVING I?80 ACRES. MORE OR LESS. SEGMENT 2 - LANDS A S:SIGNED T I IN, R 12E, UM SF.CTIOV 31: 6=10 ACRES SECTION 32: 6.10 ACRES CONTAINING 1?<40ACRES, MORE OR LESS. 0-1-01-1> **'~`~ U.~~ITIZEDAN'DLEASF_ LEGALDESC'RIPTIO_N'~*k:;::;:::~:a::~:~:< ENTIRE I E<1,SE COIL~IITTED TO PRCDHOE P_~ t" ZiNIT PRUDHOE B:1 Y` C11VIT TR.-1C'T ~ T. 1 I IV. , R. 1 ? E. , U~t~IIAT MERIDIAN, A L:~ SK.-I SECTION' 1 ~: h-l0 AC'RES' SECTION 16: 6-10 ACRES SECTION ? 1: 6=t 0 ACRES SECTION??: 6-10 ACRES C'Ol~'T.-~I'~%LtiG ?,60.00 ACRES, ~tlORF. OIZ LESSS'. 0-1-01-1 >,-~ :<:~ :P.~RTI~'IPATTI%G AIZE.-1 LEGAL DESCRIPTION ~ T < < ~: <:~: ~ k-T,: <, ENTIRE LLASE L'~~CORPOR.~I7ED INTO OIL RIMAND GAS CAP PA'.S T 11 :`' , IZ. 12 F... C~III. ~ T ~IIERIDL9;V; , U,ASKA SEC TION I ~: 6-10 ACRES SECTION 16: 6~0 AC'RES http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263... 10/23/2007 Alaska Department of Natural Resources Land Administration System Page 3 of 4 • S'EC"I'1O:1- 21: 6-10 ACRE'S S'ECTIC~ ~' 2 2: 6-10.4 CRLS CO.~"7:-1/~~'L-VG 2.60.00 ACRES, aIORE OR LESS. 11-01-1999 "**PARTICIPATL'~'GARE.-1 LEC.'.1I DESCRIPTION' ** *******'`**~' L! ~~SE TtUCORPORATED IN Pr~RT INTO INITLII POL~IRIS P~1 T. 11 N., R. 12 E., UILIIAT ~llE1ZIDI,4N, ALASKA SEC'TION' 1 ~: 6-10.-1C'RES SEC'TION' 16: E,%?, 320ACRES,' S'L'C'TIO:'V 21: NE/=1, NE/-INW/~, NE/=ISE/~1, 2=10 ~ 1CRES: SECTION 22: N/2, N/2SGT~/-1, SE/=1Sti~/-1, SF,/=1, 600 ~C'RES: CON'T.AINING l,b'00.00 ACRES, R~IORE OR LESS. 02-01-200-I `*EOR~LIATIONOFORIONPARTICIPATINGARE.A LEG11I DESCRIPTION** LE:-1SE CO;lI;111TTED L~V P.AR"T TO ORIO,'~'"P_ARTIC'II'.~1 TL1'G ARE: ~ PR t i'DIIOE f;.A Y L VIT TR.AC'T ~~ ORION' P: IRTIC'IP:1 TLV G .AIZE_A T 11 N., R. 12E., UIlI11TMERIDIAN, ALASI%A S'ECI7O~'~' 1 <: S'6i 1%-1, SIi2N'W"1/-1, 3-10.00.9CRE.S': CONTAINI'~rG APPKC~YINIf1TELY2-{O.OOACRES, MORE OR LF'.SS. PR UDHOE I3:4Y UVIT TR,~1CT ~~.A ORlO`' P,~RTICIPATI'~'C ARE_4 T 11 .~ . , R. 13 E. , U-1IL ~ T ;11I:'IZIDL ~ N; .-~ L:-~ SK:-1 SE'CTIO.V 21: Sii'1/-1 S1/2NYI'1/~l, ~~"1/-1J7V1~"l. ~i~ li?SEI%-1, 360.00 ~1CRF_S: C'ONT~L~'IN'G :-1PPRO.YI;IL-{TELY >60.00,1C'RES, MORE OR LESS`. http://www. dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28263 ... 10/23/2007 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Tirpack, Robert B [Robert.Tirpack@bp.com] Sent: Thursday, October 25, 2007 5:36 PM To: Maunder, Thomas E (DOA); McVey, Adrienne; Rebol, Amanda Cc: West, Taylor; Williamson, Mary J (DOA) Subject: RE: W-2141 Tom, Please see responses below: From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 24, 2007 3:44 PM To: Tirpack, Robert B; amanda.rebol@bp.com Cc: West, Taylor; Williamson, Mary J (DOA) Subject: W-214i Amanda and Rob, I am starting review of the permit application for this well and am requesting some additional information. 1. A 13-3/8" casing string is included in this well design to about 2000'. Please provide information what has prompted the design change. Will this string be employed on all future grass roots wells on W pad? The last two wells drilled on W-Pad (W-213 & W-204) had very problematic surface holes. Both wells experienced large volumes of running gravel, pea gravel, and wood sections. Drilling the surface holes were difficult and running casing was extremely difficult. The problem is thought to be gravel sections somewhere between 1000' and 2000' (BPF). By placing the second conductor across these trouble zones, drilling the surface hole and running the surface casing should be much less problematic. This change will not be employed all future grass roots wells on W-Pad. Each well location will be investigated to determine if the 13-3/8" second conductor will be in the base plan, a contingency, or not run at all. 2. The 12-1l4" hole is planned to be drilled with a diverter. Please comment as to the rationale for this choice. The 12-1/4" hole will be drilled just like a standard surface hole. No changes from the norm. The 13-318" casing is a second conductor. 3. Although it is stated that there are no wells within a !4 mile radius of the planned trajectory at injection depth, please identify where wells are located with regard to W-214 and the separation distance. 4. Is the November 1 potential spud date still valid? Yes -Nabors 9es will move to W-2141 after S-126i, the current well they on. Thanks in advance for your response. Call or message with any questions. Tom Maunder, PE AOGCC 10/26/2007 • Page 1 of 2 Maunder, Thomas E (DOA) From: McVey, Adrienne [Adrienne.McVey@bp.com] Sent: Thursday, October 25, 2007 4:50 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: RE: W-2141 Tom, The Asset Team has provided me with the 5 closest offset wells at the top of the injection interval. They are as follows: opt ; ea06- IS£s' gyp`-Ibt~ W-204 L2: 1508' (this is for a slotted liner-completed lateral; the distance to the motherbore is greater) w~r+:, W-212:1655' ~Oel-O~~ a i \ W-201: 1706' apt -~ O51 o~ 1 W-17A: 1904' ,OS` ta~ ~,p~ W-17:1990' 1~'s~f-O~ For other portions of the pool, the distances vary, but the absolute closest approach to W-2141 is about 340' above the injection interval: W-201, 1378'. Let me know if you have any questions. Thanks, Adrienne McVey GPB Rotary Drilling 907-564-4184 (office) 907-748-9865 (cell) adrienne.mcvey@bp.com From: Tirpack, Robert B Sent: Thursday, October 25, 2007 4:00 PM To: McVey, Adrienne Cc: Maunder, Thomas E (DOA} Subject: FW: W-214i Adrienne, Please work with the WRD Asset team to answer item #3 on Tom's email below. Even though the AOGCC regs only ask for wells with-in a 1/4 mile radius, Tom is asking for wells that are "close" to the 1/4 mile radius. Currently, the permit states that there are no wells in the 1/4 mile radius. I will answer items #1, #2 and #4. Thanks, Rob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 24, 2007 3:44 PM 10/26/2007 Page 2 of 2 To: Tirpack, Robert B; amanda.rebol@bp.cam Cc: West, Taylor; Williamson, Mary 3 (DOA) Subject: W-214i Amanda and Rob, I am starting review of the permit application for this well and am requesting some additional information. 1. A 13-3/8" casing string is included in this well design to about 2000'. Please provide information what has prompted the design change. Wilt this string be employed on all future grass roots wells on W pad? 2. The 12-114" hole is planned to be drilled with a diverter. Please comment as to the rationale for this choice. 3. Although it is stated that there are no wells within a'/. mile radius of the planned trajectory at injection depth, please identify where wells are located with regard to W 214 and the separation distance. 4. Is the November 1 potential spud date still valid? Thanks in advance for your response. Call or message with any questions. Tom Maunder, PE AOGCC 10/26/2007 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 G~ ~3 5900000 5850000 ~- 400000 500000 600000 700000 800000 TRANSMITTAL LETTER CHECKLIST WELL NAME ~.~~ ~~' o?/~~~ PTD# o?Os?/~~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~) from records, data and logs acquired for well SPACING The permit is approved subject to ful! compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after jCompanxName) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. S,Company Nttme) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ^^ : ~ ~ ~ , m °- N N , ~ p i 3. ~ o N , N, O N; N a ~ O c ~ Q' a m O. c ~ ~ °~' ' m ; ' o ; ; ; a m o >, ~ ; ; O y o ; y, ; ; o : a~ n ~ al ~ ; ; ~ ; ai w ; ; :3 ; ~ ~~ ; ; ~°~ g' ~ ~ ; ; ; ; , ~ ~ ~ ~ ~ ; ; ; ; Q; c v; 0 ; ~ f ~~ ; ; ; , ; ; ; ; ; o; m t o ~~ ; ~ ; ; ; ; ; ; ; c ~ '° °' .x' v a a Z ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N, ~ ~: G p~ ~ ~ ~ 7. O. ~ _ ~ ~ ~ ~ M: o~ ~ ~ ~ ~ Q, ~ , ~ ~ O O' ~' , aO ~ N c. 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