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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-14B PRUDHOE BAY UNIT Z-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 Z-14B 50-029-21844-02-00 206-099-0 W SPT 8326 2060990 2900 943 948 946 947 233 251 254 254 REQVAR P Adam Earl 12/7/2025 MIT-IA tested as per AIO 3C.007 to MAIP 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 UNIT Z-14B Inspection Date: Tubing OA Packer Depth 393 3208 3119 3088IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE251209161533 BBL Pumped:7 BBL Returned:6 Friday, January 16, 2026 Page 1 of 1 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector Z-14B (PTD #2060990) AA AIO 3C.007 Slow TxIA Date:Thursday, February 8, 2024 7:32:17 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, February 8, 2024 6:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector Z-14B (PTD #2060990) AA AIO 3C.007 Slow TxIA Mr. Wallace, WAG Injector Z-14B (PTD #2060990) AA AIO 24C.002 for slow TxIA communication has been received and distributed to operations. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Tuesday, January 23, 2024 12:35 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATION: Injector Z-14B (PTD #2060990) AA request submitted Ryan, Your request to extend the under evaluation period for an additional 28 days is granted. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 23, 2024 10:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector Z-14B (PTD #2060990) AA request submitted Mr. Wallace, WAG Injector Z-14B (PTD # 2060990) AA request for continued WAG injection was signed and submitted on or around 01/11/24 based on passing AOGCC MIT-IA conducted on 12/31/23. The original 28 day under evaluation period ends 01/25/24. With your permission, we would like to extend the clock on 01/25/24 for an additional 28 days and keep the well on injection while the AA is processed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, December 28, 2023 10:01 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-14B (PTD #2060990) Slow IA repressurization Mr. Wallace, WAG Injector Z-14B (PTD # 2060990) has been found to have a slow IA re-pressurization trend after a bleed was performed on 12/20/23. The increasing trend does not appear to be related to thermals effects. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Fullbore: AOGCC witnessed MIT-IA 2. Well Integrity: Apply for AA Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Injector Z-14B (PTD #2060990) AA request submitted Date:Tuesday, January 23, 2024 12:35:58 PM From: Wallace, Chris D (OGC) Sent: Tuesday, January 23, 2024 12:35 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Injector Z-14B (PTD #2060990) AA request submitted Ryan, Your request to extend the under evaluation period for an additional 28 days is granted. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 23, 2024 10:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector Z-14B (PTD #2060990) AA request submitted Mr. Wallace, WAG Injector Z-14B (PTD # 2060990) AA request for continued WAG injection was signed and submitted on or around 01/11/24 based on passing AOGCC MIT-IA conducted on 12/31/23. The original 28 day under evaluation period ends 01/25/24. With your permission, we would like to extend the clock on 01/25/24 for an additional 28 days and keep the well on injection while the AA is processed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, December 28, 2023 10:01 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-14B (PTD #2060990) Slow IA repressurization Mr. Wallace, WAG Injector Z-14B (PTD # 2060990) has been found to have a slow IA re-pressurization trend after a bleed was performed on 12/20/23. The increasing trend does not appear to be related to thermals effects. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Fullbore: AOGCC witnessed MIT-IA 2. Well Integrity: Apply for AA Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector Z-14B (PTD #2060990) Slow IA repressurization Date:Tuesday, January 9, 2024 8:54:53 AM Attachments:Z-14B TIO Inj plot 231228.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, December 28, 2023 10:01 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-14B (PTD #2060990) Slow IA repressurization Mr. Wallace, WAG Injector Z-14B (PTD # 2060990) has been found to have a slow IA re-pressurization trend after a bleed was performed on 12/20/23. The increasing trend does not appear to be related to thermals effects. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Fullbore: AOGCC witnessed MIT-IA 2. Well Integrity: Apply for AA Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 26, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-14B PRUDHOE BAY UNIT Z-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2024 Z-14B 50-029-21844-02-00 206-099-0 G SPT 8326 2060990 3000 2241 2245 2243 2241 348 364 365 366 OTHER P Bob Noble 12/31/2023 MIT-IA to injection pressure to inform AA. Well is under eval. 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 UNIT Z-14B Inspection Date: Tubing OA Packer Depth 768 3301 3234 3212IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN231231140415 BBL Pumped:4.8 BBL Returned:4.9 Friday, January 26, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Well is under eval. James B. Regg Digitally signed by James B. Regg Date: 2024.01.26 10:01:22 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 4, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-14B PRUDHOE BAY UNIT Z-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2023 Z-14B 50-029-21844-02-00 206-099-0 G SPT 8326 2060990 3500 2432 2438 2438 2437 368 390 392 394 INITAL P Kam StJohn 2/14/2023 Initial MIT-IA to 3500 psi per sundry 322-610 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 UNIT Z-14B Inspection Date: Tubing OA Packer Depth 942 3726 3680 3672IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230214153439 BBL Pumped:5.5 BBL Returned:5.5 Tuesday, April 4, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-14B PRUDHOE BAY UNIT Z-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 Z-14B 50-029-21844-02-00 206-099-0 N SPT 8326 2060990 3500 195 3726 3650 3612 250 252 255 255 OTHER P Guy Cook 2/4/2023 MIT-T per Sundry 322-610. Testing done with a Thunderbird Oilfield Services pump truck and calibrated gauges. 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 UNIT Z-14B Inspection Date: Tubing OA Packer Depth 369 555 556 555IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230204053707 BBL Pumped:3.6 BBL Returned:2.4 Friday, March 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 &RQYHUVLRQWR:$*LQMHFWRU MIT-T per Sundry 322-610. James B. Regg Digitally signed by James B. Regg Date: 2023.03.21 16:00:31 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-14B PRUDHOE BAY UNIT Z-14B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 Z-14B 50-029-21844-02-00 206-099-0 N SPT 8326 2060990 3500 1940 2436 2429 2423 252 264 266 266 OTHER P Guy Cook 2/4/2023 MIT-IA per Sundry 322-610. Testing done with a Thunderbird Oilfield Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT Z-14B Inspection Date: Tubing OA Packer Depth 456 3697 3639 3624IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230204170026 BBL Pumped:5.4 BBL Returned:5.4 Friday, March 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 &RQYHUVLRQWR:$*LQMHFWRU 9 MIT-IA per Sundry 322-610. James B. Regg Digitally signed by James B. Regg Date: 2023.03.21 16:03:55 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-14B Convert to Injector Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-099 50-029-21844-02-00 11765 Conductor Surface Intermediate Liner Liner 9229 80 2613 5087 6055 1044 11404 20" 13-3/8" 9-5/8" 7" 4-1/2" 8898 30 - 110 29 - 2642 27 - 5115 4967 - 11022 10719 - 11763 31 - 110 29 - 2642 27 - 4869 4744 - 8580 8362 - 9227 None 470 2260 4760 5410 7500 11412 1490 5020 6870 7240 8430 11281 - 11454 4-1/2" 12.6# L-80 25 - 10724 8790 - 8942 Structural 4-1/2" Baker S-3 Perm Packer 10668, 8326 10668 8326 Stan Golis Sr. Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028262 25 - 8365 N/A N/A 50 478 3231 344 1358 1250 306 2441 322-610 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Carlisle at 8:12 am, Feb 22, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.02.21 17:55:09 -09'00' Stan Golis (880) PRUDHOE BAY, PRUDHOE OIL RBDMS JSB 022323 WCB 11-24-2023 Sundry Number PBU Z-14B 206-099 322-610 DSR-2/22/23 Convert to Injnector ACTIVITY DATE SUMMARY 1/28/2023 ***WELL S/I UPON ARRIVAL*** (conversion-permanent) TAGGED FILL W/ 3.0" SAMPLE BAILER @ 11,410' SLM (sample of asphaltines, issue around sta #3) ***CONT WSR ON 1/29/23*** 1/29/2023 ***CONT WSR FROM 1/28/23*** (conversion-permanent) BRUSHED/TAGGED XN-NIPPLE W/ 3.80" GAUGE RING AND 4 1/2" BRUSH @ 10,726' SLM / 10,713' MD (13' corr) ATTEMPTED TO SET 4 1/2" PXN-PLUG BODY, UNABLE TO PASS 4,438' SLM (hard paraffin) B&F HOT CRUDE W/ 3.80" GAUGE RING, 4 1/2" BRUSH DOWN TO XN NIPPLE @ 10,713' MD SET 4 1/2" PXN PLUG IN XN-NIPPLE @ 10,713' MD SET 4 1/2" WHIDDON ON PRONG @ 10,723' SLM ***CONT WSR ON 1/30/23*** 1/29/2023 ** Assist SL ** T/I/O= 1995/1777/250 Pumped 148 bbls 180* crude down TBG to assist SL with brush-n-flush. *** Job conintued to 01-30-2023 *** 1/30/2023 ***CONT WSR FROM 1/29/23*** (conversion-permanent) PULL 1" BK-OGLV FROM STA #2 @ 8,672' MD PULL 1" BK-LGLV FROM STA #3 @ 5,904' MD PULL 1-1/2" RK-LGLV FROM STA #4 @ 3,133' MD SET 1-1/2" RK-DMY GLV IN STA #4 @ 3,133' MD SET 1" BK-DMY GLV IN STA #3 @ 5,904' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 1/30/2023 *** Job continued from 01-29-2023 ***. Assist SL. Job cancelled due to weather and no fluids. 1/31/2023 Lrs unit 42 SB for weather 1/31/2023 Lrs unit 42 SB for weather 1/31/2023 LRS unit 42 SB for weather 2/1/2023 ** Circ-Out ** T/I/O= 1375/1606/257 Pumped 3 bbls 60/40 methonal followed by 297 bbls inhibited SW water followed by 132 bbls SW water followed by 172 bbls diesel up IA to Z-13 FL. U-tube diesel TBG to IA for FP for 1 hour. Pumped 9.6 bbls into TxIA for CMIT. Continued on 02-02-2023 2/1/2023 ***CONT JOB FROM WSR ON 1/30/23*** (conversion-permanent) STANDBY FOR LRS TO CIRC AND PERFORM CMIT-TxIA ***CONT WSR ON 2 /2/23*** 2/2/2023 ***CONT WSR FROM 2/1/23*** (conversion-permanent) SET BK-DGLV IN STA #2 @ 8,672' MD (bled ia to confirm) PULLED EMPTY WHIDDON CATCHER SUB FROM PRONG @ 10,723' SLM. LRS PERFORMED PASSING MIT-T TO 3701psi. LRS PERFORMED PASSING MIT-IA TO 3709psi. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU Z-14B ( SET BK-DGLV IN STA #2 @ 8,672' MD ( STANDBY FOR LRS TO CIRC AND PERFORM CMIT-TxIA BRUSHED/TAGGED XN-NIPPLE ( PULL 1" BK-OGLV FROM STA #2 @ 8,672' MD@ PULL 1" BK-LGLV FROM STA #3 @ 5,904' MD@ PULL 1-1/2" RK-LGLV FROM STA #4 @ 3,133' MD@ SET 1-1/2" RK-DMY GLV IN STA #4 @ 3,133' MD@ SET 1" BK-DMY GLV IN STA #3 @ 5,904' MD SET 4 1/2" PXN PLUG IN XN-NIPPLE @ 10,713' MD SET 4 1/2" WHIDDON ON PRONG @ 10,723' SLM @ () TAGGED FILL W/ 3.0" SAMPLE BAILER @ 11,410' SLM () ATTEMPTED TO SET 4 1/2" PXN-PLUG BODY, UNABLE TO PASS 4,438' SLM () B&F HOT CRUDE W/ 3.80" GAUGE RING, 4 1/2" BRUSH DOWN TO XN NIPPLE @ 10,713' MD LRS PERFORMED PASSING MIT-T TO 3701psi. LRS PERFORMED PASSING MIT-IA TO 3709psi. ** Circ-Out ** T/I/O= 1375/1606/257 Pumped 3 bbls 60/40 methonal followed by 297y bbls inhibited SW water followed by 132 bbls SW water followed by 172 bbls diesely up IA to Z-13 FL. U-tube diesel TBG to IA for FP for 1 hour. A Daily Report of Well Operations PBU Z-14B 2/2/2023 Continued from 02-01-2023 CMIT TxIA FAILED Loss of 20/24 TxIA 1st 15 min, Loss of 24/27 TxIA 2nd 15 min. S-Line Set DGLV. MIT-T to 3663 psi ***PASS*** MIT-IA to 3699 psi ***PASS*** Pumped 2.6 bbls to take Tbg to 3788 psi. Tbg lost 63 psi in 1st 15 mins and 24 psi in 2nd 15 mins for a total loss of 87 psi in 30 min test. PASS. Bled Tbg to 750 psi and got back ~2.4 bbls. Pumped 5.7 bbls DSL to take IA to 3760 psi. IA lost 38 psi in the 1st 15 mins and 13 psi in 2nd 15 mins for a total loss of 51 psi in 30 min test. PASS. Bled Tbg/IA to 500 psi and got back ~6 bbls. SL in control of well per LRS departure. IA,OA=OTG **Tags hung on MV and IA 2/3/2023 Weather Standby 2/4/2023 AOGCC MIT-T and MIT-IA Witnessed by Guy Cook. MIT-T = ***PASS*** at 3612/555/255 pumped 3.6 BBLS to achieve Test PSI Bed back 2.4 BBLS to achieve ending PSI of 1940/458/252 //// MIT-IA ***PASS** at 2425/3624/264, pumped 5.4 BBLS to achive test PSI, Bled back 5.4 BBLS to acheive FWHP of 1957/454/233 2/4/2023 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD #59 / RIG DOWN FOR MECHANICAL ISSUE ***WELL LEFT S/I*** 2/5/2023 ***WELL S/I ON ARRIVAL*** WEATHER STANDBY ***WSR CONT ON 2-6-23*** 2/6/2023 ***WSR CONT FROM 2-5-23*** PULLED 4-1/2" PXN PLUG FROM 10,713' MD (missing packing) RAN 4-1/2" BLB, 3.65" 3 PRONG WIRE GRAB TO 11,405' SLM (RECOVERED 2 PIECES OF PACKING) RAN 4-1/2" BLB, 3.65" 3 PRONG WIRE GRAB TO 11,405' SLM (RECOVERED 1/2 PIECE OF PACKING) ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE PAD-OP NOTIFIED*** 2/12/2023 T/I/O = 2400/1000/350. Temp = 115*. IA FL (pre AOGCC MIT-IA). IA FL @ surface. 2/14/2023 ** MIT IA ** (Passed ) at 3672 psi. State wtinessed by Kam St John T/I/O= 2422/787/348 Pumped 5.5 bbls 100* diesel down IA for MIT IA to 3726 psi. Lost 46 psi in 1st 15 min and 8 psi. in 2nd 15 min. bled same amount back to starting pressures. FWHP's= 2437/942/373 DSO notified of results upon departure. ) ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE PAD-OP NOTIFIED*** AOGCC MIT-T and MIT-IA Witnessed by Guy Cook. MIT-T = ***PASS*** atyy 3612/555/255 pumped 3.6 BBLS to achieve Test PSI Bed back 2.4 BBLS to achieve ending PSI of 1940/458/252 //// MIT-IA ***PASS** CMIT TxIA FAILED ** MIT IA ** (Passed ) at 3672 psi.State wtinessed by Kam St John was the a stipulation of Sundry 322-610. -WCB MIT-T to 3663 psi ***PASS*** MIT-IA to 3699 psi ***PASS*** The final (passing) MIT-IA (pre AOGCC MIT-IA). PULLED 4-1/2" PXN PLUG FROM 10,713' MD (missing packing) RBDMS JSB 120222 David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Hilcorp North Slope, LLC DATE: 10/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU Z-14B PTD: 206-099 API: 50-029-21844-02-00 FINAL CEMENT EVALUATION LOG (07/29/2006) (PDS,TIF and PDF File Formats) Z-14B-2006_07_29-SCH-500292184402_CH_CEMENT_EVALUATION.pds Z-14B-2006_07_29-SCH-500292184402_CH_CEMENT_EVALUATION.tif Z-14B-2006_07_29-SCH-500292184402_CH_CEMENT_EVALUATION.pdf Please include current contact information if different from above. PTD:206-099 T37186 Kayla Junke Digitally signed by Kayla Junke Date: 2022.10.24 12:58:18 -08'00' STATE OF ALASKA RECEIVED 0LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed s8 Abandon 0 PlugPerforations ❑ Fracture StimulateMAR ��lut ❑ 0 Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate H Other Stimulate ❑ Alter Casing 0 Change Apar gre�r�my ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: '���`�✓j Irv!•fid ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-099 3. Address: P.O.Box 196612 Anchorage, Development IA Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21844-02-00 7. Property Designation(Lease Number): ADL 028262 8. Well Name and Number: PBU Z-14B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11765 feet Plugs measured 11412 feet true vertical 9229 feet Junk measured None feet Effective Depth: measured 11404 feet Packer measured 10667 feet true vertical 8898 feet Packer true vertical 8326 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 2613 13-3/8" 29-2642 29-2642 5020 2260 Intermediate 5087 9-5/8" 27-5114 27-4868 6870 4760 Liner 6083 7" 4939-11022 4721-8580 7240 5410 Liner 1044 4-1/2" 10718-11762 8361-9226 8430 7500 Perforation Depth: Measured depth: 11281-11454 feet True vertical depth: 8790-8942 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-10724 25-8365 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 10667 8326 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 53 404 542 1230 254 Subsequent to operation: 129 426 842 1400 220 14.Attachments:(required per 20 AAC 25 070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 1 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ 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: N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleu E 'neer Contact Email: Cale.Peru@bp.com Authorized Signature: Date: 3/// //g Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 1/7-1- 3/2 3//g A 0-0 RBDMS� MAR 2 9 it Original Only : w • • 0 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 19, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU Z-14B, PTD #206-099. 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 . • • Daily Report of Well Operations PBU Z-14B ACTIVITYDATE SUMMARY T/I/O= 1680/1680/260. Temp= SI. T FL(E-line req). ALP = 1680 psi, AL online. T FL @ 5220' (80 bbls). IA FL @ 5300' (284 bbls). 2/21/2018 SV, WV= C. SSV, MV= O. OA, OA= OTG. 12:45 ***WELL S/I ON ARRIVAL*** (SLB E-LINE PERFORATING) INITIAL T/I/O= 1650/1700/300. MIRU, LPT/HPT= PASS. 0.23" CABLE 2/22/2018 ***JOB CONTINUED 23-FEBRUARY-2018*** ***JOB CONTINUED FROM 22-FEBRUARY-2018*** RUN 1: 3.375"X 25' OF 3406 POWERJET HMX, 6 SPF, 60 DEG PHASED. OAL= 51'. OAW= 775 LBS. MAX OD = 3.375". LOSE COMMUNICATION WITH TS AT 8900', POOH TO SWAP OUT CORRELATING TOOLS. RUN 2: 3.375"X 25'OF 3406 POWERJET HMX, 6 SPF, 60 DEG PHASED. OAL= 51'. OAW= 775 LBS. MAX OD = 3.66" (GUN SWELL IN LIQUID). PERFORATE 11354'- 11379'. RUN 3: 2-7/8"X 10' OF POWERJET OMEGA, 6 SPF, 60 DEG PAHSE. OAL= 24', OAW=275 LBS, MAX OD = 3.16" (GUN SWELL IN FLUID). PERFORATE 11394'- 11404'. ALL LOGS CORRELATED TO SLB TEMPERATURE SURVEY DATED 23-JUNE-2009 POOH, RDMO. WELL S/I ON DEPARTURE. FINAL T/I/O = 1700/1700/250 2/23/2018 ***JOB COMPLETE 23-FEBRUARY-2018*** Fluids Summary Bbls Type 1 DIESEL 5 METHANOL 1-- , 1110 • SAFETY NOTES: PREVIOUS VVELLBORES NOT II&L= 4-1/16"CIW ° Z.-1 4B WELLHEAD= PASEVOY ACTUATOR AKBR C SHOWN BELOW WHIPSTOCK *•' = B OKB.ELEV= 92.04' I I BF.Ei_EV= 56.24' KOP= 5115' Max Angle= 59°@ asee —:cAD"DucT°R. —I ? j I F I 2216' L4-1/2"FES X Np,ID=3.813" Datum KU= 11387' —#, - Datum ND= 8800 SS U= . GAS LFT MANDRE1S [13-3/8"CSG.68#,L-80,D=12.415^ H- 2663' j ST KU TVO DEV TYPE VLV LATCH PORT DATE 4 3133 3130 11 WAG 00k€ RK 12 06/23/15 3 5904 5415 47 KGB2 DONE BK 16 06/23/15 I. 2 8672 7108 58 KG82 SO BK 24 06/23/15 1 10580 8266 47 KGB2 WY' BK 0 07/01/10 9-5/8'X 7"ZXP LIP,PBR — 4967' . .-- 'STA#1 -BROKEN SO w/SFEC1AL TY OX)DrIFD[WY &FLEX LOCK HGR,ID=6.276" ‘' FOR INFC..,RITY. CO NOT RIACV F.:. 04 • W-IPSTOCK(07/16/06) H 6116' °•• \ & [9-5/8-GSG,47#,L-80,ID=8.681" — –6132 MLLOUT WINDOW(Z-148)5115'-5132" I Minimum ID = 3.725" @ 10713' ''':<.•;..r4 4-112" HES XN NIPPLE 6 kT4, I [ 0 [ 7916' ]_,7' HES ES CEMENTER I i L 10647' I_4-1/2'HES x NP,ID-=3.813" I X Er10668' _7"X 4-1/2"BKR S-3 PKR, ID=3.87' I i [ 10692 _l_4-1/2"FES X NIP,ID=3.813' 1 I I 10713' _4-1/7'I ir,XN NP,1D--=3.725' 10718'ELMO(5/20/09 14-1/2'TBG,L-80 7C11,.0152 bpf,13=3.958 10726' 10719' _r x 5"BKR ZXP LTP w/TEBACK SLV 1 .-. .: &BKR FLEXLOCK HGR,ID=4.37" ill ,I •••' 17'LNR,26#,L-80,BTC-M,.0383 bpf,ID=6.276' H 11022' r • 10726' _14-1/2"VVLEG,ID=3.958" e • i I . . 10747' _15"X 4-1/7 xo.io=3.93- PERFORATION SUPRA RY REF LOG: MVVD/GR(07/31/06) • f 11269' _4-1/2"MARKER JOKT i ANSLE AT TOP FERF: 31°@ 11281' Note:Refer to Roduction DB for historical perf data SEE SW i INTERVAL Opn/Sqz SHOT SCE 2-1/2" 6 11281- 11307 0 10/10/17 3-3/8" 6 11353- 11378 0 02/23/18 11404'ELM _TAG FLL ON TOP OF EZSV(02/23/18) 2-7/8" 6 11373- 11378 0 04/20/09 Ps , 11412' _14-1/7-HES EZSV(06/23/15) 2-7/8" 6 11393- 11403 0 02/23/18 2-1/2" 6 11396- 11410 0 10/29/06 2-1/2" 6 11420- 11435 C 10/29/06P.. . 11431' FILL&ROCKS(TAGGED 11/06/14) . . 2-1/2" 6 11448- 11454 C 10/29/06 ,'.. tss.\.. _ P13173 I— 11493' .•-•-•• •• [4-1/2-LW, 126#,L-80 67-M, .0152 bpf,D=3.958 _I— 11763' 1 •••-•....**.• 1 DATE REV BY (MOMENTS DATE REV BY COMMENTS FRUCHCIE BAY UNIT 08/13/88 ORIGINAL COMPLETION '07/17/15 KARIM)SET EZSV(06/23/15) VVELL: Z-148 1 03/31/98 CJS CTD SIDETRACK"A" 07/17/15'JMVIJM:i GLV C/0(06/23/15) FEHMT No:' 060990 08/04/06 RTES SIDETRACK"B" 09/27/16 AC WBS CLEAN IF PER TALLIES AR ND: 50-029-21844-02 09/15/14 KAI3/PJC XN hIP ELK)LOGGED 05/20/09 10/17/17 KFS/JM)ADPERFS(10/10/17) SEC 19,T11N,R12E,981'FTL,3097'FEL I 11/17/14 GF/M) GLV C/0(11/12/14) 02/26/18 MS/JM3 ADRERFS&TAG RLL(02/23/18) 03/18/15 CAB/PJC FILL&ROCKS(11/06/14 TAGGE )) BP Exploration(Alaska)k a) • 2_,0C9-0°1 • 2'5`6`6 5 BA ER ® PRINT DISTRIBUTION LIST UGHES a GE company [� Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Int �w E1VE'BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGEC WELL NAME Z-14B DEC 18 2017 900 E.Benson Blvd. \ %/201$ M K.BENDEF Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit AOGCC to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE October 10,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(abakerhughes.com TODAYS DATE December 20,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #01-I'KIN IS #OF COPIES #OF COPIESr #OF COPIES �7 V 1 BP North Slope. 0 1 1 0 ROA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker0 G �o Q 900 E.Benson Blvd. S!sn NNEll FEBDD U Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5.DNR-Division ofOil&Gas *** 0 0 1 0 Attn:James Flynn 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,[.R2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson TOTALS FOR THIS PAGE: 0 2 5 0 0 -"ECEIVED STATE OF ALASKA spLASKA OIL AND GAS CONSERVATION COMMIS NOV 0 2 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 OperatioAQGCC o Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-099 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21844-02-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU Z-14B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11765 feet Plugs measured 11412 feet true vertical 9229 feet Junk measured feet Effective Depth: measured 11412 feet Packer measured 10667 feet true vertical 8905 feet Packer true vertical 8326 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2613 13-3/8"68#L-80 29-2642 29-2642 5020 2260 Intermediate 5087 9-5/8"47#L-80 27-5114 27-4868 6870 4760 Production Liner 1044 4-1/2"12.6#L-80 10718-11762 8361-9226 8430 7500 Liner 6083 7"26#L-80 4939-11022 4721-8580 7240 5410 Perforation Depth: Measured depth: 11281-11307 feet 11373-11378 feet 11396-11410 feet 11420-11435 feet 11448-11454 feet True vertical depth: 8790-8813 feet feet 8870-8875 feet 8891-8903 feet 8912-8925 feet 8937-8942 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-10724 25-8365 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): y NNED DEC 2 8 2017 Treatment descriptions including volumes used and final pressure: ��vs' '�AlI 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 151 434 124 847 259 Subsequent to operation: 125 359 113 873 275 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleum E gineer Contact Email: Cale.Peru@bp.com Authorized Signature: Date: if i 7117 Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 V 1 L 12/7i/17- ��D n � �� - �OS7 A / 7/17 NOVU YI 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 November 2, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Additional Perforations for Well Z-14B, PTD # 206-099. 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 • • Packers and SSV's Attachment PBU Z-14A SW Name Type MD TVD Depscription Z-14B PACKER 4939.04 4720.64 7" Liner Top Packer Z-14B TBG PACKER 10667.11 8325.58 4-1/2" Baker S-3 Perm Packer Z-14B PACKER 10729.59 8369.32 5" Baker ZXP Top Packer 0 • N 1m0 m a O E N c z O • a 1.5 .y7; 42 M 0 O W (7 O N N (0p 0 @ U > W O U) Z In' ii Q Z:1- o UN 0 0U -JOU) io o (u O a CO La v- Z d ce cc N � � � Q a* U) W mCr0 E . co E * Low v LL O 0 N � 0 m OQW ,- Cr) 03 CO N Q O (0 < ; Q Y *n 0m2 c @ @ ° ' "O '- Cl) 0 J d O J LL O �� E ..u. 01- Q p = o co ce o U r- C -J Q QLL O o d O >- Q 2Q c UW = < 2 = 0 Qac • a o r- LL z aOZ OOLLM 6. 2 c �Qa N chO O mW W O � � :_. o — — a. c`o (o CI) O , z 2 z F- F- Q - O cow , emr O E t U Oa = F., <I— O � , m a) •v• Q Qv F- 0 O UYw► o �+ r' � N L 0 o Q O�cei LJL _I c d, •- N v Lo c p * J O m ~ H cuo QJ N > (/) O LL CC O U N LL w N ac 5 o d iQQ LL � 2o o � oho ^oo � 2 Nd10zww ,_ w � OU A E n ~ o i M 7 Q N N V Q M W U) ~ ~ O ~ m Q (n ~ Oi HO Z i o O Z O > W 0 LLQO �� ~ j � � (7) 0),- M O O B J N X Z 00 0 W , J a- )5 0 a U F- � 0 co O O L O N Z Z o a N M N * 0 Z Op W>> J IV O > (% W W M c , \ N ow > z — Z p U) W W H (Om W WU � Z oYaoccE m - off - 2 -02 00 Z 1 1 Q � cc > Q wU) � o - II w oOJN - - X E § W5? -ci LL 0 < < 0 - wUOI- QO2z N �^> E0JQ2 0J1-0� F-• F- W a) aJ F- --, U0E- QMM- � O0 Q it c p OQ c_ ?j c -jaZZF- oi_ w � w ppQJO � a• �(`?tim O i E c cE (• 0U0UU � W 0 XOt- u) = JOOO � = o o •wo S Q* � * * 0 `- � * * 0 * O CL QW000 * F- 0 0 U = co it O « U) « « J a s « U) « J Z J tY O F- J J J : W F- Q r r- r- o N N 0 N N N co N N a, r r r P CO' m 63a o o 0 Q 0 • N .- & N $ 0 a U a II I I ! E 2 e Q = E O/ I 0 \ ƒ cl 2 : . Z0 $ n 0 0 kt E& Ems ® / 2 Tat o 0 / ƒ a ƒ c w > o I Wo kk / k - E-1 / 2 WO \ w a \ me Cl) 2 a ¥ �� 2 / >- � � O < 2 � c 2 = R oc ¥ & R H kcc= 0- m 2 c / ■ o w (j 0 -• 7 k / C e R R m 1 0 : z M a O 0 , o \ E etS 2 U *. 2 0 = R w ƒ a 7 o E Q L. a- f t & # ¥ O -J w '.§ ,) >, @ e = a cc t G 2 ® Q ® I— O. � t2 / \ / — § = / M c ma. - 2 -1 0 3 a . 3 2 § & Cl) 0 E / ƒ / E 2 � / t N 70 7-o 2 � . 0 o - J � o ¥ d \ m | 6a 0 — k k 0 1-1-I co co L 2 o ) O. ¥ » ® G2LN ' / G 22 re L 2 2 ƒ $ II 0 \ � 2 0 o / / / m co H@ f CI 0 0 = 2 � U Z Lu-4- o N co - \ C@ - \ z 22 ,E\ k D u z \ - 'c k _0k ZW 0WH — Ems \ k 6 n � oo , n ± < 08 2G % k / k O / / $ c) Q § 4_ O « L / 2 \ § $ '0 (0 .- 0 g a / / / C % | O rl 0 � a - | - a E m 6 o .- O ¥ ¥ ¥ / 0 0 m ~ L0 2 r 6 TREE= 4-1/16"CNV 1/1E111-FAD= MCEVOY • Z-14B SA NOTES: PREVIOUS WELLBORES NOT ACTUATOR= BAKER SHOWN BELOW WHIPSTOCK""" OKB.ELEV= 92.04' ' BF,13 EV= 56.24' KOP= 5115' Max Angle= 59"alp 8566' —"C°NDUCMR, -1----- i? , , 2216' _14-1/2"HES X NP,D=3.813" Datum MD= 11387' —#, Datum ND= 8800'SS D= " GAS LFT MANDRELS 13-3/8"CSG,68#,L-80,D=12.415" --I 2663' J ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3133 3130 11 IAMG DOME RK 12 06/23/15 Ir 3 5904 5415 47 KGB2 DOME BK 16 06/23/15 1 2 8672 7108 58 KGB2 SO BK 24 06/23/15 1 10580 8266 47 KGB2 MY- BK 0 07/01/10 9-5/8'X 7"ZXP LIP,PER —{ 4967' _ `STA#1=BROKEN SO w/SPECALTY MDDFED DMY &FLEX LOCK HGR,D=6.276" C •�4 FOR NTEGRITY- DO NOT RIg OVE • 11M-IPSTOCK(07/16/06) 1—[.. 6116' • (9-5/8"CSG,47#,L-80,D=8.681' H -6132 ►4 A MZLLOUT WIDOW(Z-148)5115'-5132" Minimum ID =3.725" @ 10713' V 4-112" HES XN NIPPLE !4 I L 0 7916' _7" HES ES CEMENT132 I , 10647' _14-1/2"HES XNP,D=3.813" E s3-1 10668' _17"X 4-1/2"BKR S-3 PKR,D=3.87" ' 10692' _14-1/2"HES X NP,D=3.813" ' 10713' J4-1/2"Fid XN NIP,D=3.725" 10718'ELMD(5/20/09 10719' _,7'x 5"BKR ZXP LTP w fTEBACK SLV 4-1/2'TBG,L-80 TC$,.0152 bpf,D=3.958 H 10726' ra 8 BKR FLIXLOCK HGR D=4.37" oi i 10725' J4-1/2"WLEG,D=3.958" i • 7'LNR,26#,L-80,BIC-PA,.0383 bpf,D=6.216' --i 11022' • •1 10747' 5`X 4-1/2-XO,ID=3.93' PERFORATION SUMaAARY • 11259' .441/2"MARKER JONT REF LOG: MMD I GR(07/31/06) ANGLE AT TOP PERF: 31" 7 11281' Nate:Refer to Production DB for historical perf data SIZE SPF NTER1/AL Opn/Sqz SHOT SQZ 2-1/2" 6 11281-11307 0 10/10/17 11412' _14-1/2"1-ES EZSV(06/23/15) 2-7/8" 6 11373-11378 0 04/20/09 2-1/2" 6 11396-11410 0 10/29/06 2-1/2" 6 11420-11435 C 10/29/06 11431' (i FILL 8 ROCKS(TAGGED 11/06/14) 2-1/2" 6 11448-11454 C 10/29/06 \\\.\\ Pe-ro -I 11493 4-1/2"LNR, 12.6#,L-80 BT--M,.0152 bpf,D=3.958j—L 11763' J ••••••_• DATE REV BY COMMENTS DATE REV BY COMJENTS PRUDHOE BAY UNIT 08/13188 ORIGINAL COMPLETION 07/17/15 KAPYJM3 SET EZSV(06/23/15) WELL: Z-14B 03/31/98 CJS CTD SIDETRACK"A" 07/17/15 JMNYJMD GLV CIO(06/23/15) PERMIT Mx' 060990 08/04/06 NTES SIDETRACK"B" 09/27/16 ND WBS CLEANUP PER TALLIES API Na: 50-029-2184402 09/15/14 KAB/PJC XN NP HMI LOGGED 05/20/09 10/17/17 KFS/JMJ ADF B2FS(10/10/17) SEC 19,T11 N,R12E,981'FNL,3097'FEL 11/17/14 GJF/,M)GLV CIO(11/12/14) dt loratioo Alaska 03/18/15 CAB/PJC FLL&ROCKS(11/06/14 TA BP P (Alaska) GCS STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMIooION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations El Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ,,G f--I.-7-✓ 12( 2 Operator Name BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-099 3. Address: P.O Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21844-02-00 7 Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU Z-14B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: RECEIVED Total Depth measured 11765 feet Plugs measured 11412 feet iUL 3 0 2015 true vertical 9229 _feet Junk measured feet Effective Depth: measured 11412 feet Packer measured See Attachment feet h true vertical 8905 feet Packer true vertical See Attachment feet 1t./ Casing: Length: Size: MD: TVD: Burst' Collapse' Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2614 13-3/8"68#L-80 29-2643 29-2643 5020 2260 Intermediate 5088 9-5/8"47#L-80 26-5114 26-4868 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11373-11378 feet 11396-11410 feet 11420-11435 feet 11448-11454 feet True vertical depth: 8870-8875 feet 8891-8903 feet 8912-8925 feet 8937-8942 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-10724 24-8366 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) No SSSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured) CAN HEUJ 4"-H. x' (j!' Treatment descriptions including volumes used and final pressure: CMN ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 459 3840 1386 1387 321 Subsequent to operation: 532 2010 57 863 286 14 Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations Ed Exploratory ❑ Development Q( Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 7/29/15 Fnrrn 1n_eru Rat/marl vonis i ! L, $l 3/1 5 \1 1 �..........,......._ n..... Packers and SSV's Attachment PBU Z-14B SW Name Type MD TVD Depscription Z-14B PACKER 4938.25 4719.98 7" Liner Top Packer Z-14B PACKER 10667.38 8325.77 4-1/2" Baker S-3 Perm Packer Z-14B PACKER 10729.86 8369.51 5" Baker ZXP Top Packer 0.oOOOOO co cocoo U 7 O CO N NI- En CD 1� CO CO OCf) O0) (DCC) CD I� N CO N co C co O N O) 0) CO N CD N N N r- co N C N CI � N 0 s V- C) p 2 = CO< co co • NN N N O N 12 • M ILcp 0o0 0000 c° 0 J J •� N 00 cO N r N r U O 50 O M N N N O) I I L OHO - 00 0 (00 NI- c=) O C OO CO 0 0 O J N cc) CO w r c Q Luw ' U V au_ CLCLCLZ Z 0 W W W m Q Z Z U Z J J I- L 0 2 QF 2 w we E k / 0 0 co. . 2 </ - w a_ 2 $ Oe z cLo a a)a 0 E \ \ u) CC < / o $ O o ƒ < > w / < co w I- w 2 � � � § » 2 3 P. � � w E § 0 e «0 F- e & 00 E@ m N Z O 2c V k 0 0 bo_ O (0I- / / m . -2. O e I- _ u_ z 2 E S 0 2 -00 0 o w = V 0 1- \ U) E I k 2 Lu / 0- D N G % k $ Ik / ct 0 2 R > / 3 oD kLoE 2 2 ��bcoo� _1 w w0 -1 0. f / f / R 22g 0 : : \ \ L o . % t k E / w w < o % � e \ \ | 3 U w I-- o .- o o c & « 0- a w a_ ■ : _ 0_/ - * - - ® m L c co 2 : - 2 2 o N - - 2 IX - G : > G_ 4 2 G q _ E L L 2 -I m * 2 9 m Q o 2 2 2 2 - 2 R 2 9 . # 2 n >i « 2@ O-Ic � m R -I -I - 2 ¥ 602 < o9 � a- a > N - c w O q 2 W m m m = 2 < 2 9 FK® 2 a_ o a E 0 9 - » 0 O w - b - a O LLa �� ` D 2 = cte , 9m2 = 20 � 2 � 2 _ L0 � � 2n �< 0 Ci)a) c - w OE � � 2OE ,ItW2 / I- OO@0W0 D / On > , a � \ 0CELLo_ww0 w \ * kkz01_ 41 � 32_ q / R20 -1 ,4- 1- 81- c0001- 1-- 000 < < < z1- z0 -1 \ P' k $ O O � n0 '� � OO -- -' RR -J -J _ mnm000jw w / = oq < = K > KKK gw / � / / / JwwwJ4 / D / / 2w \ , k4 $ . m : A : : L co a : : a a 2 m n m 2 : : a : : � @ a ix e : 6 Lu < in co in r co in E. d d d d d 2 - > 0, N N N CO q = po o o co co 2 < -TREE 1- 41„6"CIW Z 14 B SA.—.Y NOTES: PREVIOUS WELLBORES NOT ACTUATOR= BAKER _ SHOWN BELOW WHIPSTOCK••' OKE.ELE/= 92.04' 1 I L GAS LFT MANDRELS BF.a = 56.24' /J KOP 5115' Max Angle= 59"@ 8566' --COPDUCTOR — 7 I 1 2216' 4-12'HES X NP,D=3.813' Datum MD= 11387' —#, Datum ND= 8800'SS D=EP/ 13-3/8'CSG,68#,L-80,D=12.415' H 2662' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3133 3130 11 MAG DONE RK 12 0623/15 3 5904 5415 47 KGB2 DOME BK 16 0623/15 L 2 8672 7108 58 KGB2 SO BK 24 06/23/15 1 10580 8266 47 KGB2 06.4Y" BK 0 07/01/10 9-5/8"X 7'ZXP LIP,PIR — 496T .. 'STA#1 =BROKEN SO w/SPECIALTY MODF )OMY &FLEX LOCK HGR,D=6.276" 0 4 FOR INTEGRITY, DO NOT REMOVE • W4-IPSTOCK(07/16/06) H 5116' I., ►•: ►;4 9-5/8'LNR,47#,L-80,.0732 bpf,D=8.681' H —5132 •►4 _, MLLOUT WIIDOW(Z-148)5115'-5132" ►4 Minimum ID =3.725" 10713' • 4-1/2" HES XN NIPPLE ; • L 0 7916' _7" FES E5 CEMENTER I I 10647' 1_14-12"HES X NP,D=3.813' 10668' --I 7"X 4-1/2"BKR S-3 PM,D=3.87" I I 10692' 1_14-12'HES X NP,D=3.813" , 4-1/2"TBG,L-80 TC,.0152 bpf,D=3.958 —I 10725' I I 10713' J4-1/2"I-ES XN NP,D=3.725' 1110718'E.UD(5120/09 7'LNR,26#,L-80,BTC-M.0383 bpf,13=6.276" H 11022' E. 10719' __I 7"x 4-1/2"BKR LTE 13=4.45' i + 10725' J_4-12"WLR,13=3.958' ►• • • • • • , PERFORATION SUMMARY REF LOG: MMD/GR(07/31/06) ' I ANGLE AT TOP FERE 7't 11373' • 11259' H 4-1/2'MARKER JOINT Note:Refer to Roduction DB for historical perf data SIZE SFF INTERVAL Opn/Sgz SHOT SQZ 2-7/8" 6 11373- 11378 0 04/20/09 2-12' 6 11396-11410 0 10/29/06 2-1/2" 6 11420-11435 C 1029/06 11412' _14-1/2'FES EZSV(0623/15) 2-1/2' 6 11448-11454 C 1029106 \ 11431' �FLL&ROCKS(TAGGED 11/06/14) 11 PM H 11493' 4-1/2"LIJR 12.6#,L-80,BT-M,.0152 bpf,1:0=3.958 H 11763' �•�•� DATE REV BY COMMENTS 7 DATE REV BY COM'ITS PRUDE BAY UNIT 08/1388 ORIGINAL COMPLETION 07/17/15 KAP/JM)SET EZSV(06/23/15) WCL: Z-148 03/31/98 CJS CTD SIDETRACK"A" 07/17/15 JIIAJMD GLV CIO(06/23/15) FERMI'No:"`2060990 08/04/06 NTES SIDETRACK"B" AR No: 50-029-21844-02 09/15/14 KAB/PJC XN NP ELM3 LOGGED 05/20/09 SEC 19,T11 N,R12E,981'FNL,3097'FE- 11/17/14 GJF/JMD GLV CIO(11/12/14) 03/18/15 CAB!PJC FLL&ROCKS(11/06/14 TAGGED) BP Brploratbn(Alaska) • Image Praje~t 1Ne11 History File haver P~c~e XHVZE This page identifies those items that were not scanned during the initial prodt.tctian 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. ~~ ~ - ,~ ~~ Well History File Identifier Organizing (done) o.wo,~~ imuumiiiuiu RE CAN DIGITAL DATA olor Items: ~iskettes, No. Greyscale Items: ~ ~~ ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: o a,s~a~~~cea IIIIIIIIIVIIIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ 0 /s/ '~ ' Project Proofing III IIII~IIIIII II~II BY: Maria Date: I t/ © /s/ Scanning Preparation _~, x 30 = ~Q~ + 3 =TOTAL PAGES l4 3 (Count does not include cover sheet) BY: .- Maria Date: 1 ~ ~ D O ~ lsl Production Scanning Stage 7 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: I d~ f l ~ ~O g ls! 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. III II'I II I II II I I III ReScanned III IIII~II~III VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'I(I III II'I II (o ~} f 0/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKAOAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development lig Exploratory ❑ 206 -0990 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 0 50- 029 - 21844 -02 -00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 028262 .` PBU Z -14B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11765 feet Plugs (measured) None feet true vertical 9228.95 feet Junk (measured) None feet Effective Depth measured 11493 feet Packer (measured) 4967 10668 10719 feet true vertical 8977.09 feet (true vertical) 4744 8326 8362 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 26 - 106 26 - 106 Surface 2617' 13 -3/8" 68# L -80 25 - 2642 25 - 2642 4930 2270 Production 5108' 9 -5/8" 47# L -80 24 - 5132 24 - 4883 6870 4760 Liner 6074' 7" 26# L -80 4948 - 11022 4728 - 8580 7240 5410 Liner 1017' 4 -1/2" 12.6# L -80 10746 - 11763 8381 - 9227 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - — - 6] 2 rr + :_ — True Vertical depth: _ A g ZU � k — Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 23 - 10725 23 - 8366 Packers and SSSV (type, measured and true vertical depth) 7" ZXP LTP 4967 4744 4 -1/2" BKR S -3 PKR 10668 8326 4 -1/2" BKR LTP i. ,_ ; • 8362 RECEI .k 12. Stimulation or cement squeeze summary: 2 2 Intervals treated (measured): '� . Treatment descriptions including volumes used and final pressure: Aask3 04 & fi $ Cl fl$ Gij1>i1miss $Un ncnorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 382 1,775 864 260 Subsequent to operation: 371 1,481 6,894 260 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Ei Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N- - • e Las Ilk i Title Petrotechnical Data Technologist Signat m 1 Phone 564 -4091 Date 4/22/2011 Form 10-404 Revised 10/2010 71 �G'G 1/ RBDMS APR 2 6 2011 ' / 40te Original Only Z -14B 206 -099 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -14B 10/29/06 PER 11,396. 11,410. 8,890.52 8,902.89 Z -14B 10/29/06 PER 11,420. 11,435. 8,911.75 8,925.08 Z -14B 10/29/06 PER 11,448. 11,454. 8,936.67 8,942.03 Z -14B 4/20/09 APF 11,373. 11,378. 8,870.27 8,874.66 Z -14B 5/20/09 MLK 11,481. 11,488. 8,966.27 8,972.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • Z -14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY — 4/14/20111T/1/0=1900/760/209. SI. Pumped SIT. Pumped 25 bbls of 1% Techni -Wet 4353 in 1 1% KCL followed up with 90 bbls of 10% Scaletrol 720 w /0.25% Techni -Wet in 1% KCL, 50 bbls 1% Techni -Wet 4353, 6 bbls 240# DS Wax Beads in 1% Oil seeker, 1 20 bbls 1% Techni -Wet 4353 in 1% KCL, 90 bbls 10% Scaletrol 720 w/ 0.25% Techni -Wet 4353 in 1% KCL, 50 bbls 1% Techni -Wet 4353 in KCL, 145 bbls 1% `KCL, 5 bbla Neat and 30 bbls of Diesel. Job Complete. Final WHP's= 1200/1810/250 FLUIDS PUMPED BBLS 95 1% TECHNI -WET 4353 IN 1% KCL 180 10% SCALETROL 720 W/0.25% TECHNI -WET IN 1% KCL 50 1% TECHNI -WET 4353 6 240# DS WAX BEADS IN 1% OIL SEEKER 145 1% KCL 5 NEAT METH 30 DIESEL 511 TOTAL TREE _ . 4" CIW WELLHEAD = MCEVOY • S AFEtY IP: ORIGINAL WELLBORE NOT ACTUATOR = AXELSON Z -1 A B SHOWN KB. ELEV = 92.04' f•� BF. ELEV = 56.24' KOP= 5115' Max Angle = 59 @ 8566' Datum MD = 11387' Datum TV D = 8800' SS ' 2216' I_1 4 -112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 113 -3/8" CSG, 68 #, L -80, ID= 12.415" Ft 2652' ST MD TVD DEV TYPE VLV LATCH PORT DATE IF 4 3133 3130 11 MMG DOME RK 16 07/01/10 3 5904 5415 47 KGB2 SO BK 20 07/01/10 Minimum ID = 3/25" @ 10713' 2 8672 7108 58 KGB2 DMY BK 0 06/29/10 4- 112" HES XN NIPPLE 1 10580 8266 47 KGB2 DMY* BK 0 06/28/10 *MODIFIED DMY VLV *NOTE: BROKEN SO VLV STUCK IN BTM POCKET 1 TOP OF 7" LNR H 4948' 4967' IJ 9-5/8" X 7" ZXP LTP, PBR & FLEX -LOCK LNR HGR, ID = 6.276" ii �' 1 • 4 • MILLOUT WINDOW (Z -14B) 5115' - 5132" ► �• • • ► i 4 �i ►4� • 7916' I-1 HES ES CEMENTER I ► . • • ►• � •• j • j =. 10647' I_14 -112" HES X NIP, ID = 3.813" I • ►4 •� ,• � . 10668' I_1 7" X 4 -1/2" BKR S -3 PKR ID = 3.87" I WHIPSTOCK (07/16/06) H 5115' • 14 •� 10692' I-14 -1 /2" HES X NIP, ID = 3.813" I • / 41 • 4 i I EZSV (07/16/06)1 5137' I i .. 1 0713' _14 - 1/2" HES XN NIP, ID = 3.725" I 14 • • ►• i•• 10725' _14-1/2" WLEG, ID = 3.958" I PERFORATION SUMMARY A •• -. REF LOG: MWD / GR (07/31/06) • • � • !• , 10719' J 7" x 4 -1/2" BKR LTP, ANGLE AT TOP PERF: 29 @ 11373' ID = 4.45" Note: Refer to Production DB for historical perf data , ;;, area SIZE SPF INTERVAL Opn /Sqz DATE + 11259' _ MARKER 2 -7/8" 6 11373 - 11378 0 04/20/09 "•'• 4 /I. •�:• JOINT 2-1/2" 6 11396 - 11410 0 10/29/06 ►••••4.34 ',•�!• 2-1/2" 6 11420 11435 0 10/29/06 • • " �.•# ` • .∎∎∎ • • • ♦ 4 . J 2 -1/2" 6 11448 - 11454 0 10/29/06 ' - : ;:•:; 7' LNR, 26 #, L -80, BTC-M, 11022' .0383 bpf, ID = 6.276" ` 9 -5/8" LNR, 47 #, L -80, .0732 bpf, ID = 8.681" I 9501' m . '•'-'-•. I PBTD I 11493' I4 -1/2" LNR, 12.6 #, L -80, IBT -M, .0152 bpf, ID = 3.9581 11763' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/13/88 ORIGINAL COMPLETION 02/02/07 DBR/ PJC PERF DATE CORRECTIONS WELL: Z -148 03/31/98 CJS CTD SIDETRACK "A" 02/25/07 KSB/TLH GLV CO PERMIT No: '2060990 08/04/06 N7ES SIDETRACK "B" 05/30/09 MV /TLH PERFS (04/20/09) API No: 50- 029 - 21844 -02 10/10/06 DAV/TLH GLV C/O 07/05/10 GJF /SV GLV UPDATE (07/01/10) SEC 19, T11N, R12E, 981' FNL, 3097 FEL 10/29/06 JMF /PAG ADPERFS 12/11/06 DBR/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) OPERABLE: Producer Z -14B (PTD #00990) Verified tubing integrity - PasssTIFL Page 1 oft, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, January 31, 2011 9:09 AM Re‘t/� To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad Z; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Walker, Greg (D &C); Kirchner, Carolyn J Subject: OPERABLE: Producer Z -14B (PTD #2060990) Verified tubing integrity - Passing TIFL All, Producer Z -14B (PTD # 2060990) passed a TIFL on 1/30/11 after it was reported to have sustained casing pressure on the IA. The passing tes` t verifies tubing integrity. The well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, January 29, 2011 8:43 AM To: 'Maunder, Thomas E (DOA)'; AK, D &C Well Integrity Coordinator; AK, OPS GC2 OSM AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad Z; AK, OPS Prod Contro -rs; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well S- ices Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt E - ; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: Walker, Greg (D &C); AK, D &C Well Integrity Coordinator; Kirchner, olyn J Subject: UNDER EVALUATION: Producer Z -14B (PTD #2060990) Ev. date High IA Pressure AII, Producer Z -14B (PTD # 2060990) had sustained casing . essure on the IA during the proration and was reported to the AOGCC by e-mail on 1/18/2011. The , llhead pressures were tubing /IA/OA equal to SSV/2050/180 psi on 1/15/11. The well has been r- classified as Under Evaluation and may be brought online to perform further diagnostics. The plan forward is as follows: 1. DHD: TIFL when online 2. WIE: Eval TIFL results to •etermine GLV work 2/1/2011 UNDER EVALUATION: Producer ZoB (PTD #2060990) Evaluate High IA fissure Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] (7' 2(r ( Sent: Saturday, January 29, 2011 8:43 AM To: Maunder, Thomas E (DOA); AK, D &C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad Z; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Walker, Greg (D &C); AK, D &C Well Integrity Coordinator; Kirchner, Carolyn J Subject: UNDER EVALUATION: Producer Z -14B (PTD #2060990) Evaluate High IA Pressure All, Producer Z -14B (PTD # 2060990) had sustained casing pressure on the IA during the proration and was reported to the AOGCC by e-mail on 1/18/2011. The wellhead pressures were tubing /IA/OA equal to SSV/2050/180 psi on 1/15/11. The well has been reclassified as Under Evaluation and may be brought online to perform further diagnostics. The plan forward is as follows: 1. DHD: TIFL when online 2. WIE: Eval TIFL results to determine GLV work Please call if you have questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) FEB '7 2O1 Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/1/2011 Producers with sustained casing pressen IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, January 18, 2011 1:40 PM 1-?' f Z l 51 C j To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia O; Ramsay, Gavin; Kirchner, Carolyn J; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 15 -18. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 04 -24 (PTD #1853010) K -20C (PTD 5 , 4 - 40 NNEL ) FEB l)E V -02 (PTD #2040770) ✓L -14B (PTD # 2060990) The following producer was found to have sustained casing pressure on the OA during the proration January 15 -18. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. Z -11A (PTD #2050310) All the wells listed above will be classified as Not Operable until start -up operations are complete and are stable or the well ressure a asses test rovin inte rit . After start-up, the wells will then be reclassified P P p 9 9 Y as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/25/2011 UNDER EVALUATION: Z-14B (FT~2060990) Sustained Casing Pressure ~A Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] 2~i~c Sent: Thursday, June 17, 2010 9:06 PM ~~~z ~ I To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS GC2 Facility OTL; AK, OPS GC2 OSM; AK, OPS Prod Controllers; AK, OPS GC2 Wellpad Lead Cc: Kirchner, Carolyn J; AK, D&C Well Integrity Coordinator; Clingingsmith, Mike J (CH2M Hill) Subject: UNDER EVALUATION: Z-146 (PTD #2060990) Sustained Casing Pressure on IA Attachments: Z-14B TIO Plot 06-17-10.doc; Z-14B.pdf All, /~ Producer Z-14B (PTD #2060990) has been found to have sustained casing Pressure on the IA. On 06/14/10, the tubing/IA/OA pressures were 180/2080/180 psi. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. DHD: TIFL 2. Slickline: Change out OGLV (pending TIFL results) 3. DHD: Re-TIFL (pending TIFL results) aA:y.t~ ba~. ~d.'V A TIO plot and wellbore schematic have been attached for reference. «Z-14B TIO Plot 06-17-10.doc» «Z-14B.pdf» ,~- Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~,4 ~C~j~, ~' ,L.~I p~ ~~r~PF7 1~"~t7 ~ b~'G~~'~i J .~- ~'D 4y v 7/20/2010 PBU Z-14B PTD 2060990 6/17/2010 TIO Pressures Plot i Well: ~-14 4000 3,000 ~A00 1,000 -~- Tbg -~- IA -~ OA OOA - OOOA On 0312110 D411011 D D4,'2d110 0510817 0 D5122110 D8105110 • • TREE = 4" CNV WELLHEAD= MCEVOY _. .__ ACTUATOR KB. ELEV = . AXELS_ON ~ ~ 92.04' BF. ELEV = KOP= 56.24. 5115. Max Angle = 59 @ 8566' Datum MD = Datum TV D = 11387' 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" @ 10713' 4-1 /2" HES XN NIPPLE TOP OF 7" LNR -~ 494$' (07/16/06) ~-{ 5115" EZSV (07116/06} ~ 513T PERFORATION SUMMARY REF LOG: MWD / GR (07/31106} ANGLE AT TOP PERF: 29 @ 11373' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11373 - 11378 O 04/20/09 2-112" 6 11396 - 11410 O 10/29/06 2-1J2" 6 11420 - 11435 O 10/29/06 2-112°' 6 11448 - 11454 O 10/29106 ', (9-5i8" LNR, 47#, L-80, .0732 bpf, ID = 8.681" (--~ 8501" SAFE1-Y,ES: ORIGINAL WELLBORE NOT SHOWN 2216' ~_J4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3132 3130 11 MMG DOME RK 16 02/25/07 3 5904 5415 47 KGB2 DOME BK 16 02/25/07 2 8672 7108 58 KGB2 DOME BK 16 02125/07 1 10580 8266 47 KGB2 SO BK 22 02!25107 4867" ~ 9-518" X 7" ZXP LTP, PBR & FLEX-LOOK LNR HGR. ID = 6.276" ~ MILLOUT WINDOW (Z-146} 5115' - 5132" i 7916' HES ES CEMENTER 10647' 4-112°' HES X NIP, ID = 3.813' 10668' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.87" 10692" 4-1/2" HES X NIP, ID = 3.813" 10713' 4-112" HES XN NIP, ID = 3.725" 10725' ~4-1i2" WLEG, ID = 3.958" 10719" 7" x 4-112" BKR LTP, ~ ID = 4.45" MA RKER ~ ''', JOINT 7' LNR, 26#, L-80, BTGM, I--~ .0383 bpf, ID = 6.276" PBTD 4-112" LNR, 12.6#, L-80, IB7-M, .0152 bpf, 10 = 3.958 i-~ 11763" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/13/88 ORIGINAL COMPLETION 02/02(07 DBW PJG PERF DATE CORRECTIONS WELL: Z-146 03/31!98 CJS CTD SIDETRACK "A" 02(25107 KSB/TLH GLV CIO PERMIT No: 2060990 08/04106 N7E5 SIDETRACK "B" 05130109 MV/TLH PERFS (04/20109) API No: 50-029-21844-02 10/10/06 DAVITCH GLV CIO SEC 19, T11N, R12E, 981' FNL, 3097' FEL 10/29!06 JMFlPAG ADPERFS 12111/06 DBWPJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) _: ti '~'~` M1 ~ e i' *' ~M ~" .~ w,, - .,,~.: MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 > "+,~ ` ~ ~~J~~ t M~~~-t it' ~, ~.~ 4~+,yw'~w '~ +''~'~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, CJ ~~ ~~~~~~~~ OCT 0 5 20Q9 alask~ Dil & Gas Cons. Gon~i~~ian AnGhoragA ~0 6~ o~I ~....- / ~ .: ;. Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-Ot8 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-OS 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2,55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 02 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 500292t9380100 NA 02 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-238 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 500292t8790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-326L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 S/S/2009 Z-35 1980930 50029228840000 NA 1.3 NA 1 t.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 1 t.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-t08 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-1 i 2 2071720 50029233s0000o NA surface NA o~~i aios ~C~IC111~b~1'~~~ ~laska Data A~ Gonsuiting Services ?_525 Gambell Street, Suite 400 ,~nchorage, APf 99503-2838 l9TTi~: Se4h ~Ilell Job # `~ jf ~,~,~•, ..~ ~~'ta~t.'~' ii . -, ~ r i ~, . .~ S~ : : ~~+ Log Description Date NO. 5310 Company: State of Alaska Ataska Oii & Gas Cons Comm Attn: Christine Mahnken 3331Mest 7th Ave, Suite> 100 Anchorage, AK 99501 BL Color CD Z-20 AP3Q-00043 SBHP SURVEY - O6/17/09 1 1 P2-31 AZCM-00029 LDL L~ ~ 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15l09 1 1 Z-14~ AYQQ-00036 TEMP SURVEY & BHP 06/23/09 1 1 ft1-16 AP3Q-00042 SBHP SURVEY ` - ~ O6/16/09 1 1 V-QS:....,,, 11999053 USIT 10/12/08 1 1 _._ ,- " P~i-i 1C .'' -° AP3Q-00042 SBHP SURVEY O6/16/09 1 1 ``"°"~3-12 AY3J-00030 LDL .- 06/12/09 1 1 ~_1-30 AVYS-00049 PRODUCTION PROFILE -nj j)~ 06/22/09 1 1 97-078 AY~Q-00031 SBHP SURVEY "3 j C5 O6/11/09 1 1 OS-256 AP3Q-00040 SBHP SURVEY ~ O6/11/09 1 1 B-27A AXBD-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 B14B-00066 CROSSFLOW & IBP L 06/23/09 1 1 ~°21~! 8146-00065 SBHP SURVEY 06/21/09 1 1 3C-17 AYTU-00043 PROD PROFILE -~ 06/08/09 1 1 ~-25 RWlB-OQ018 LDL ()~~ ~'~j - 05/28/09 1 1 02-33~ AYTU-00033 USIT "~ f 05/19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~f t 06/25/09 1 1 13-03 AWLB-00020 LDL 06/01/09 1 1 3-17F/i(-3Q B2NJ-00008 MEM INJ PROFILE ( f 06/15/09 1 1 MPS-08 AYS4-00080 LOL 06/15/09 1 1 i3-12 AV1H-00019 LDL 07/05/09 1 1 01-25 AYTU-00046 USIT - ~,(~ 06/28/09 1 1 W-39,4 AWL8-00023 STATIC TEMP SURVEY ~" , O6/26/09 1 1 Z-35 AYTO-00022 SBHP SURVEY - ~ ~ O6/29/09 1 1 ~-16 AV1H-00017 SBHP SURVEY ~ ~~j O6/29/09 1 1 18-20 B581-00004 LDL ~ O6/27/09 1 1 Z-29 AVY5-00053 SBHP SURVEY ~~ ~~ ~~;~ ~ ``~` ~~ 07/03/09 1 1 LS-09 AYQQ-00032 ~ RST °- ~ C, ~ 06/13/09 1 1 07-10A B1JJ-00022 MCNL -- d( !~ 05/26/09 1 .~_ r......... oe ~~....~`. ..~..~.. .... ..,~.a..~...a ..~.v n~ ~.~nnnv.a v~~~ ~.vr i cn~.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , i ..~ ~ ~ ~~ ~ ~ r i _,.. ,_ ,_A,' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 LJ ~ osloa/os r1 L~ .....mot ~~ SC~b~l'~~1' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~ 05/15/09 1 1 06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK , 05/06/09 1 1 15-45B ANHY-00010 PRODUCTION PROFILE °~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ` 05/08/09 1 1 M-19B AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A 61JJ-00018 MEM CNUSTP 1 05/18/09 1 1 X-30A B2WY-00005 MEM PROD PROFILE ~ 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG ~ ~- 05/20/09 1 1 L1-21 62NJ-00006 PRODUCTION PROFILE 05!24/09 1 1 A-31A AZCM-00023 USIT =~ - (a G 05/22/09 1 1 H-19B' 62WY-00004 MEM PROD PROFILE `- 05/07/09 1 1 G-16 AYKP-00022 SCMT J / - 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE L/GO / 04/21/09 1 1 11-04A AYOO-00028 USIT / L/ - 05/21/09 1 1 18-30 BiJJ-00015 MEM PROD PROFILE JG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ ® I 05/11/09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE - 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL ~ ~$/5 04/26/09 1 1 PLtASt AGKNUWLtUCit FitGtIF' I tfT 51(iNING ANU Fit I UFiNINIi UNt GUF'T tAGti 1 U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ` -" ~ Y +T~" ~j 1~_ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~tv~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ON Ca'>' 0 7 2009 si~`~ REPORT OF SUNDRY WELL OPERATIONS ~i~~id:~ ~;; ~, (;~~ Cons. C©mmission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ ArjCi10r8g8 Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q ` Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 2os-osso - 3. Address: P.O. Box 196612 Stratigraphic Service (® 6. APt Number: Anchorage, AK 99519-6612 50-029-21844-02-00 7. KB Elevation (ft): 9. Well Name and Number. 82.56 RT - PBU Z-14B - 8. Property Designation: 10. Field/Pool(s): ADLO-028262 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11765' ~ feet Ptugs (measured) None true vertical 9229' ~ feet Junk (measured) None Effective Depth measured 11676' - feet true vertical 9145' - feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2652' 13-3/8" 68# L-80 Surface - 2652' Surface - 2652' 5020 2260 Intermediate 5115' 9-5/8" 47# L-80 Surface - 5115' Surface - 4869' 6870 4760 Liner 6083' 7" 26# L-80 4939' - 11022' 4721' - 8580' 7240 5410 Liner 1044' 4-1/2" 12.6# L-80 10719' - 11763' 8362' - 9227' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 10725' Packers and SSSV (type and measured depth) 7"x4-1/2" Bkr S-3 10668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: ~.~ ~ ~~~"~ ~~~$f r ' Intervals treated (measured): == Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 110 388 633 0 300 Subsequent to operation: 213 543 761 0 309 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory ~ Development - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas WAG ~ GINJ ~ WINJ WDSPL 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Engineer Signature _,... - Phone 564-4944 Date 5/7/2009 Form 10-404. ised 04/2006 ~ - - - _ ~- h~i~1 ~" ~ I~Q~ Submit Original Only Z-14B 206-099 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-146 10/29/06 PER 11,396. 11,410. $,890.52 8,902.89 Z-14B 10/29/06 PER 11,420. 11,435. 8,911.75 8,925.08 Z-146 10/29/06 PER 11,448. 11,454. 8,936.67 8,942.03 Z-14B 4/20/09 APF 11,373. 11,378. 8,870.27 8,874.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n I~~ ~~ Z-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/19/2009'""*WELL SHUT IN ON ARRIVAL'"** (PERFORATE) INITIAL T/I/O = 1700 / 1725 / 100 PSI. j RIG UP E-LINE, PRESSURE TESTED LUBRICATOR. SWAB VALVE BEGAN ~ LEAKING. GREASE CREW SERVICED TREE VALVES, FOUND MASTER WAS NOT CYCLING PROPERLY. PUT HEAT ON MASTER FOR A FEW HOURS AND HAD GREASE CREW COME BACK TO SERVICE IT. I RIH WITH 5' GUN, MAX OD = 2.875", TS LENGTH = 25'. ' **"JOB CONTINUED ON 20-APR-2009*'`* 4/20/2009' **"JOB CONTINUED FROM 19-APR-2009**'' 'TAGGED TD AT 11507 (ELM). PERFORATE 1 1 373-1 1 378' WITH 2-7/8" HSD GUNS LOADED WITH 2906 POWERJET HMX CHARGES. TIED INTO SCMT LOG DATED 28-OCT-2006. API DATA: PENETRATION = 25.3", ENTRANCE HOLE = 0.38", EXPLOSIVE 'LOAD = 15 G/CHARGE. ?WELL LEFT SHUT-IN. PAD OP NOTIFIED OF VALVE POSITIONS ON DEPARTURE. FINAL T/I/O = 1700/1725/100. "**JOB COMPLETE*** ~_~ _ ~ __ _ __~.,_~ ~_......... _.~e _~._~ ~.. ~ ~ _____ ___ FLUIDS PUMPED BBLS 1 diesel 1 Total STATE OF ALASKA .309 ALAS~OIL AND GAS CONSERVATION COMMON ~~,~4~ /Q~9 REPORT OF SUNDRY WELL OPERATIONS . ,~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated: e Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Ext~~§~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 2os-peso - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21844-02-00 7. KB Elevation (ft): 9. Well Name and Number: 82.56 RT • Z-14B - 8. Property Designation: 10. Field/Pool(s): ADLO-028262 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11765' - feet Plugs (measured) None true vertical 9229' . feet Junk (measured) None Effective Depth measured 11676' feet true vertical 9145' - feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2652' 13-3/8" 68# L-80 Surface - 2652' Surface - 2652' 5020 2260 Intermediate 5115' 9-5/8" 47# L-80 Surface - 5115' Surface - 4869' 6870 4760 Liner 6083' 7" 26# L-80 4939' - 11022' 4721' - 8580' 7240 5410 Liner 1044' 4-1/2" 12.6# L-80 10719' - 11763' 83 62' - 922 7 ' 7500 843 0 ~~ ff C(} ry } { f~?~"(} y~ }r~ y Perforation depth: Measured depth: SEE ATTACHED _ _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# L-80 Surface - 10725' Packers and SSSV (type and measured depth) 7"x4-1/2" Bkr S-3 10668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 248 450 119 0 264 Subsequent to operation: 248 403 117 0 295 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development r - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG ~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numb r or N!A if C.O. Exempt: ~~' Contact Gary Preble Printed Name Gary Pr ~ Title Data Engineer Signature Phone 564-4944 Date 3/20/2009 Form 10-404 R ised 04/2Q0~ ~""~ (,P" ~ ~ i ~ ~ Submit Original Only ~.~~ Ir~ ~ ~ ~~~ ~, r _ . Z-14B 206-099 PERF ATT~4CHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z-146 10/29/06 PER 11,396. 11,410. 8,890.52 8,902.89 Z-146 10/29/06 PER 11,420. 11,435. 8,911.75 8,925.08 Z-146 10/29/06 PER 11,448. 11,454. 8,936.67 8,942.03 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Z-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/10/2009 CTU#6 1.75"CT Job Scope: Acid Treatment «<InterAct Publishing»> MIRU. Bleed IA to 1000psi. Pump KCL down BS to kill well 2 bpm @ 1276 psi. :'Conduct PJSM with all with all personal on location before pumping acid. Cap 'the well with 55 bbls of diesel. Ems, first staae of acid 36 bbls & first over flush I2% KCL w/ F-103 """Job in progress""""" ._ ~.._, 3/11/2009 CTU #6 1.75"CT Job scope: Acid treatment ««InterAct is publishing»»Pump 40 bbls 2% KCL w/ F-103 for over flush and 4 bbls of clean gel followed by 15 bbls gel w/ 500 Ibs of wax bead slurry. 5 bbls of clean gel behind. 36 bbls 12% HCL. Pump 60 bbls of 2% KCL w / F-103 for over flush. Freeze protect coil POOH Prefom infectivity test 2 bpm 1250 psi. """""'Job complete"""""' 3/11/2009 ASRC Test Unit #2, Acid Flowback, ***Job in Progress""" 3/12/2009 Freeze Protect Flowline of well Z-13A (Testers used for Acid job on Z-14) Road Ito location & standby for testers.**Job in progress continued on 03-13-09"" 3/12/2009'ASRC Test Unit #2, Continue Acid Flowback, *""Job in Progress**" 3/13/2009'*`Job in progress continued from 03-12-09""'T/I/O=SSV/1750/600 Temp=S/I ..Freeze protect F/L of well # Z-13A that well teters used for acid job on Z-146. (Freeze protect) Pumped 16 bbls neat meth down F/L for F/P. FWHP's=SSV/1750/600 DSO notified of following upon departure WV,SWV,SSV=S/I / MV,IAV,OAV=Open Tags hung 3/13/2009 ASRC Test Unit #2, Rig down Complete,'`*"Job Complete*** FLUIDS PUMPED BBLS 55 DIESEL 16 METH 36 2% KCL 72 12% HCL 36 60/40 METHANOL 215 Total X29 rUo .>/ DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2060990 Well Name/No. PRUDHOE BAY UNIT Z-146 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21844-02-00 MD 11765 TVD 9229 Completion Date 10/29/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR !RES / PW D /DEN / NEU, DIR / GR /RES /DEN / N (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data igital Dataset Log Log Run Interval OH / ed/Frmt Number Typ Name _ _ Scale Media No Start Stop CH Received Comments g Cement Evaluation 5 Col 1 4942 10480 Case 8/8/2006 USIT, CEL, DSLT, GPIT, !, GR< CCL, 29-Jul-2006 ~,~/ D Asc Directional Survey 5090 11765 Open 9/14/2006 ', Rpt Directional Survey 5090 11765 Open 9/14/2006 / ', k6g 14167 Induction/Resistivity 5 Blu 1 5010 11765 Open 10/10/2006 MD Composite Final Print 31-Ju I-2006 tog 14167 Ind ction/Resistivity 5 Blu 1 5010 11765 Open 10/10/2006 TVD Composite Final Print 31-Ju I-2006 C Lis 14167 Induction/Resistivity 11023 11765 Open 10/10/2006 GR, ROP, FET, DRHO, NPHI g Lo Cement Evaluation 5 Col 1 10500 11470 Case 1/5/2007 SCMT, Pres, Temp, CCL, GR 28-Oct-2006 g Pressure 1 Blu 1 10420 11509 Case 10/26/2007 SBHPS, Pres, Temp, GR, CCL 2-Oct-2007 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~V Chips Received? '~^P7'id-'~ Analysis ~'?`'/'Id"~- Received? ~~ Sample Interval Set Start Stop Sent Received Number Comments Daily History Received?~ Formation Tops 'LJ" LJ Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2060990 Well Name/No. PRUDHOE BAY UNIT Z-14B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21844-02-00 MD 11765 TVD 9229 Completion Date 10/29/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ---- Compliance Reviewed By: Date: _____ r~ LJ 10/25/07 d~sl'I~~mU~~~ps~ NO. 4464 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, Endicott, Aurora, Milne Pt., Pt. Mac Wall _Inh ~t Inn Dacrrintinn Date BL Color CD W-19AL1 11890312 SBHP & TEMP '" 09/29/07 17-19A 11855512 SBHP SURVEY 09/26/07 V-04 11855513 SBHP SURVEY G 09/27/07 1 Z-21A 11594526 SBHP SURVEY 10/07/07 1 Z-03 11767142 LDL 10/01/07 1 05-38 11686787 LDL ~ ~ 09!27!07 1 Y-29A 11855514 DDL 09/28/07 1 B-16 11676969 PRODUCTION PROFILE 10/12/07 1 Z-22B 11594525 SBHP SURVEY ~-- 10/06/07 1 Z-14B 11849935 SBHP SURVEY (p 10/02/07 1 P2-45A 11594529 SBHP SURVEY ~ - C 10/16107 1 17-09 11846820 LDL j ~j~ - 10/19/07 1 F-33 11661176 MEMORY SBHPS / Gj - 10!19/07 1 4-08/P-27 11630506 LDL ~ 10104/07 1 3-17F/K-30 11649961 MCNL -~ / 04117107 1 1 MPB-50 40011604 OH MWD/LWD EDIT ~ j 02127/05 2 1 S-125 40015467 OH MWDlLWD EDIT ,~ '}_ ~ ~ 07/14/07 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EAGFi TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center 1R2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ' ` Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth j Received by: STATE OF ALASKA ~~~''~~ ALAS OIL AND GAS CONSERVATION COMM~ION ~~~ ~ ,~ ~QQ~ REPORT OF SUNDRY WELL OPERATIONS aly~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 ter Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 2o6-o9so 3. Address: P.O. Box 196612 Stratigraphic "` Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21.844-02-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 82.56 RT ~ Z-14B ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028262 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool ~ 11. Present Well Condition Summary: Total Depth measured 11765' ~ feet Plugs (measured) 9229 true vertical 9229' feet Junk (measured) None Effective Depth measured 11676' ~ feet true vertical 9145' ~ feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2652' 13-3/8" 68# L-80 Surface - 2652' Surface - 2652' 5020 2260 Intermediate 5115' 9-5/8" 47# L-80 Surface - 5115' Surtace - 4869' 6870 4760 Liner 6083' 7" 26# L-80 4939' - 11022' 4721' - 8580' 7240 5410 Liner 1044' 4-1/2" 12.6# L-80 10719' - 11763' 8362' - 9227' 8430 7500 Perforation depth: Measured depth: 11396' - 11454' True Vertical depth: 8891' - 8942' _, Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 10725' Packers and SSSV (type and measured depth) 7"x4-1/2" Bkr S-3 10668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): gt~?~~Ay~yy y~@~~y(( [ nyI Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 782 909 92 0 254 Subsequent to operation: 780 916 93 0 248 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Servjce ; Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ WINJ WDSPL 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: Contact Gary Preble Printed Name Gary Pr Title Data Engineer Signature .~~ Phone 564-4944 Date 2/16/2007 `dry Form 10-404 f~evised 04/20 ~ ~ ~ ` ~ ©( Submit Original Only • Z-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY `ACTIVITYDATE SUMMARY 2/9/2007 CTU #5 ~~"Job objective: Acid stim""" MIRU, MU BHA w/ 2.5" BDN, Tag TD C«~ 11559' recip cooling across perfs 11396'-11454' +20' above and below. Continue job on 2/10/2007 WRS... 2/10/200T**'`Continue job from 2/9/2007 WRS*"* Washed across perfs 1 1 376-1 1 476 CTM '°`with the following stages: ''24 bbls of HCI w/8% L66 '30 bbls of 3% NH4C1 w/8% L66 '~;°,70 bbls of 3% NH4CI Overflush 7 bbls of 30 ppt HEC gel w/200 # of wax beads -During wax bead stage saw no 'indication of diversion once @ perfs 5 bbls of 3% NH4C1 w/8% L66 Spacer "24 bbls of HCI w/8% L66 30 bbls of 3% NH4C1 w/8% L66 '1170 bbls of 3% NH4C1 Overflush 'Turned well over to ASRC test unit for flow back ""`*Job Complete"*" _. _ 2/11/2007 ASRC Well Test 1776 bfpd '! 1133 bopd °".36.92 % w/c ;,2.34 mmscf/d 0 mm G/L ':642 GOR "108 deg. F wht 128 beans FLUIDS PUMPED BBLS 132 3% NH4C1 35 3% NH4C1 w.8% L66 SCALE INHIBITOR 24 12% HCI 52 60/40 METHANOL 243 TOTAL 1 v2~/os Schlamherger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4087 Company; Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Prudhoe Bay Date BL Color CD Z-14B 11414770 SCMT ___ 10/28!06 1 V-211 10919914 CH EDIT USIT PDC-GR 11I19I04 1 1 V•221 10919949 CH EDIT USIT P( OC-GRj(prints sent 3N6/O6) 03107!05 1 _ L-200 11555032 LDL 12I21I06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ~~ , BP Exploration (Alaska) Inc. ' ~~ '"'-9 ~; ... ~. ~ ~ - _. _.. Petrotechnical Data Center LR2-1 ~ ~ ~~' ~ "-'~ ~"~ ~ -'-- ~ - 900 E Benson Blvd. Anchorage AK 99508-4254 6.,. A A~~I ~~ ~'~ ~~ ~i~l~, Dale Delivered. nt ' ~ - j~14r:~'7~"- - Schlumberger-DCS 2525 Gambell 51, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth ~,,.-T~'~ ~.. Received by: ~ - ~9 i STATE OF ALASKA ALASKA OTC AND GAS CONSERVATION COMMI -ION ~~~~~V~ NU ~ ~ ~ 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LO~iaska Oil & G as Cons. Co--~missiop An~hor~,,,, 1a. Well Status: Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended WAG 1b. ell Class: zoAACZS.,os zoAACZS.,,o Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other Stratigraphic Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10!29/2006 206-099 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/18/2006 50-029-21844-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 7/31/2006 PBU Z-14B FNL, 1856 981 FWL, SEC. 19, T11N, R12E, UM Top of Productive Horizon: 8. KB Elevation (ft): 15. Field /Pool(s): 1989' FSL, 1324' FWL, SEC. 17, T11 N, R12E, UM 82.56' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 2060' FSL, 1546' FWL, SEC. 17, T11 N, R12E, UM 11676 + 9145 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 599580 y- 5959100 Zone- ASP4 11765 + 9229 Ft ADL 028262 TPI: x- 603950 y- 5962130 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 604171 y- 5962204 Zone- ASP4 None MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES / PWD /DEN /NEU, DIR / GR /RES /DEN /NEU, CAL-Y / GR / DSLT / GPIT, USIT, SCMT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP. BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 8 cu ds Concrete 13-3/8" 68# L-80 Surface 2652' Surface 2652' 17-1/2" 3585 cu ft Permafrost 9-5/8" 47# L-8 Surface 1 rf ce 4869' 12-1/4" 1939 ft Class' ' 7" 26# L-80 4939' 11022' 4721' 8580' 8-1/2" 396 cu ft LiteCrete, 177 cu ft Class'G' 4-1/2" 12.6# L-80 10719' 11763' 8362' 227' 6-1/8" 191 cu ft Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 6 spf 4-112", 12.6#, L-80 10725' 10668' MD TVD MD TVD 11396' - 11410' 8891' - 8903' 2j CEMENT SQUEEZE ETC ACID FRACTURE 11420' - 11435' 8912' - 8925' , , , . , 11448' - 11454' 8937' - 8942' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10780', 10861', 10866' Perf for 7" Cement Squeeze Job Attempt to Squeeze Cement into 7" annulus w/ 60 Bbls Class 'G', Failed Freeze Protect w/ 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 9, 2006 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/13/2006 4 TEST PERIOD 564 1,215 111 114 2,154 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) Press. 400 900 24-HOUR RATE• 3,386 7,292 666 31 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit cor ~L~, state "none". ; ' ~ ~~ E ~ None r /emu T e0 e GG/l iw~ / l~~Al~ % l ~lj '~"1/,,,~ ,:... .Ct Form 10-407 ReviSec~"~i"2' fit' ~ ~~ ~ ~ CONTINUED ON REVERSE SIDE ~r~~,, ~~jJ~' ~ ~ ~QQ~ ~~~ ~ G 28 ' GEOLOGIC MARKERS 29. NATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted state "None". Sag River 11015' 8574' None Shublik 11060' 8608' Eileen 11188' 8711' Sadlerochit 11222' 8740' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. l l Si d ` ~ ~ gne Title Technical Assistant Date ! Terrie Hubble PBU Z-146 206-099 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permi No. / A royal No. Drilling Engineer: Ken Allen, 564-4366 INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. 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). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only r l T O ~ I Q ' d d '` 5 ` ~ _ ^Y '' W .. T a x, m~ ' a oa oa 3I N ' v ° N . d O c o M j a N ~ 0 Y R N J i ~' 7f . '. N N N N Q a Q ~ I L a °m °m ~, m ~ U R 7 N I L ~ a z a a ~ ~ W Q ~/ ~ /1 ~.. X l w ~ i 0 O ~ ~ .., ~ ~ O O m Y ~ (~ d W ~ ~ ~ ~ J ~I ' o ~ $ ~ 0 0 s ~ ~ °' d o D Sri ~I T I d ~ d' ~ T 1 T 1 _ N it N N Q~ ~, ~ ~ F- I- H ~ LL LL LL z i ~ ~ Z O N O O O ~ ~ 0' N N N m i U y' o J ' ~ n i M r ~ ~ BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task i Code NPT Phase Description of Operations 7/14/2006 00:00 - 06:00 6.00 RIGD P PRE ND/NU/Secure well Z-18. Release rig at 06:00. 06:00 - 14:00 8.00 RIGU P PRE Pull pits away and RD Z-18. Move over well and spot pits on Z-14. Spot new tree and adaptor flange in cellar. Take on fluid. Accept rig on Z-14 at 14:00. 14:00 - 15:30 1.50 WHSUR P DECOMP RU Drill Site Maintenance and pull Back Pressure Valve. RD lubricator. 15:30 - 16:00 0.50 WHSUR P DECOMP Prespud meeting w/WSL, all hands, mudman. 16:00 - 17:00 1.00 W HSUR P DECOMP Test lines to 3500 psi. OK. reverse circulate 38 bbls. 8.5 ppg seawater down annulus to jet cut at 5400' taking returns up the tubing to cuttings box to circulate diesel out of tubing. 138 gpm, 220 psi. 17:00 - 18:30 1.50 WHSUR P DECOMP Switch lines over to tubing and circulate 430 bbls. 8.5 ppg seawater down tubing to jet cut at 5400' and take returns up the annulus to cuttings box to circulate diesel out of annulus. 250 gpm, 300 psi. 18:30 - 19:00 0.50 BOPSU P DECOMP RD lines. Set Two Way Check Valve. Test f/below to 1000 psi. OK. 19:00 - 21:00 2.00 BOPSU P DECOMP ND adaptor flange and tree. Check threads in tubing hanger and confirm by making up x-over that thread is correct. Makeup turns = 11.5. 21:00 - 23:00 2.00 BOPSU P DECOMP NU BOP stack. 23:00 - 00:00 1.00 BOPSU P DECOMP RU w/4-1/2" test jt. to test BOPS. Hold prespud/PJSM at pre-tourmeeting w/WSL/Tourpusher/Crew/Mudman and discuss general aspects of upcoming well. Discuss specifics of decompletion phase and next 24 hrs. plan forward. Discuss importance of verbal Task Hazard Assessment for routine work and written Task Hazard Assessment for non-routine or hi-risk work. 7/15/2006 00:00 - 03:00 3.00 BOPSU P DECOMP Test BOPS to 250 psi low side pressure and 4000 psi high side pressure. Witnessed by Lowell Anderson BP WSL and Chris Weaver Nabors tourpusher. AOGCC representative Chuck Scheve waived AOGCC attendance of the test. Pull 4.5" test joint and RD BOP test equipment. BD choke and kill lines. 03:00 - 04:30 1.50 BOPSU P DECOMP Install lubricator extension. CO tugger line. PU lubricator. Pull Two Way Check Valve. LD lubricator and LD lubricator extension. 04:30 - 05:00 0.50 BOPSU DECOMP MU landing jt. and x-over. Sting into hanger. Back out lock down screws and pull hanger to the floor. Pull the hanger free w/90K up. PU wt. 90K. 05:00 - 06:00 1.00 BOPSU P DECOMP RU Drill Site Maintenance and pull Two Way Check Valve w/lubricator. RD lubricator. RU to pull tubing. 06:00 - 08:00 2.00 PULL P DECOMP CBU. 372 bbls. at 485 gpm, 550 psi. While circulating RU control line spooling unit. LD landing jt. and hanger. Monitor well. OK. 08:00 - 11:00 3.00 PULL P DECOMP LD 4.5" 12.60# AB MOD BTT tubing jts 1 thru 47. Spool control line. Found 4 stainless steel bands and 23 clamps. Terminate control line and LD SSSV nipple. RD spooling unit. 11:00 - 14:30 3.50 PULL P DECOMP LD 4.5" 12.60# AB MOD BTT tubing jt # 48 thru jt # 134 and 23.11' of cutoff jt. LD one GLM. 14:30 - 15:30 1.00 PULL P DECOMP RD tubing handling equipment and clean floor. 15:30 - 16:30 1.00 PULL P DECOMP MU new 4.5" IF Saver Sub to top drive. 16:30 - 17:30 1.00 BOPSU P DECOMP RIH w/test plug and 5" test jt. RU to test BOPS. 17:30 - 20:00 2.50 BOPSU P DECOMP Test Annular BOP to 250 psi low side test, 3500 psi high side Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Page 2 of 14 Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: -- Date From - To ;Hours Task Code NPT 7/15/2006 117:30 - 20:00 ~ 2.50 ~ BOPSU P 20:00 - 20:30 0.50 BOPSU P 20:30 - 22:00 1.50 CLEAN P 22:00 - 22:30 I 0.50 I CLEAN I P 22:30 - 00:00 I 1.501 CLEAN I P 7/16/2006 00:00 - 07:00 7.00 CLEAN ~ P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 11:30 I 2.501 CLEAN I P 11:30 - 12:30 I 1.001 CLEAN I P 12:30 - 15:00 2.50 CLEAN P 15:00 - 15:30 0.50 CLEAN P 15:30 - 17:00 1.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 19:30 0.50 CLEAN P 19:30 - 20:00 0.50 STWHIP P 20:00 - 22:00 I 2.001 STWHIPI P 22:00 - 00:00 2.00 STW H I P I P 7/17/2006 00:00 - 01:30 1.50 STW H I P P 01:30 - 02:00 0.50 STWHIP P 02:00 - 03:00 I 1.001 STWHIPI P 03:00 - 09:00 I 6.001 STWHIPI P Phase Description of Operations DECOMP test. Test bottom and top pipe rams 250 psi low side test, 4000 psi high side test using 5" test jt. DECOMP RD test equipment and set wear ring. DECOMP RU and test 9-5/8" casing f/top of cement to surface w/4000 psi. DECOMP Move 40 stands of 4" drill pipe f/off drillers side pipe rack to drillers side pipe rack in derrick. DECOMP PU cleanout BHA # 1 including: Baker starter mill w/8.438" OD, bit sub, upper string mill w/8.5" OD, lubricated bumper sub, X-Over sub, nine 6.375" drill collars, X-Over sub. DECOMP PU and rabbit 5" drill pipe singles and RIH w/cleanout BHA #1 to 5300'. Single in last 30 jts and stand back in derrick. Total jts picked up = 201. DECOMP Cut and slip drilling line. DECOMP PU RTTS stormpacker w/single jt. drill pipe and TIW valve on jt. MU to string and set stormpacker 35' below floor per Halliburton representative with PU wt. 145K, SO wt 115K. Sting out of RTTS and LD running tool. Pull wear bushing. DECOMP MU packoff running tool and sting into 9-5/8" packoff. Back off lock down screws. Pull 105K # over to free packoff. POH packoff intact. Install new packoff. C/O lock down screw. Run in lock down screws. LD packoff running tool. Test packoff to 4000 psi and hold for 30 mins. DECOMP PU RTTS stormpacker running tool, RIH and sting in to RTTS, release packer, pull and LD packer. DECOMP POH w/drillpipe from 4760'. MW = 8.5 ppg seawater. DECOMP LD cleanout BHA #1. Clear floor. DECOMP RU Schlumberger wireline unit. DECOMP RIH w/9-5/8" Halliburton EZSV CIBP. Log and set above collar w/top of EZSV at 5137' (top of EZSV 7' above collar). DECOMP POH. DECOMP RD Schlumberger wireline unit. DECOMP RU and test casing f/EZSV to surface 3500 psi. OK. WEXIT PJSM handling of whipstock equipment on skate and running of whipstock. WEXIT Function test blind rams and PU Whipstock BHA #2 including: 9-5/8" OD bottom trip anchor (3 screws/shear 20K), Gen. II whipstock slide (35K shear bolt), 8-7/16" OD starter mill (checked w/gage ring), bit sub, upper string mill 8.5" OD (checked w/gage ring), 1 jt. 5" HWDP, float sub, MWD, UBHO sub, Bowen bumper sub, X-over sub, nine 6-3/8" drill collars, X-over sub. WEXIT RIH f/384' and surface test MWD 451 gpm, 480 psi at 1328'. OK. Cont. RIH to 2562'. WEXIT RIH to 5057'. WEXIT Orient whipstock to 36 deg. right of high side and RIH to tag up on top of plug at 5137' drillers measurement. SO and see bottom trip anchor shear and set w/15K. PU 10K over string wt. Anchor in place and set. SO and see bolt shear w/35K down wt. WEXIT Swap out seawater to 9 ppg LSND milling fluid. Circulate 353 bbls, 560 gpm, 980 psi. WEXIT Mill window + 20' OH to 5144' w/502 gpm, 825 psi, tq. on 5-6K, Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Page 3 of 14 Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABORS 7ES Rig Number: Date From - To ~ Hours ~ Task Code NPT Phase Description of Operations ---- 7/17/2006 03:00 - 09:00 6.00 STWHIP P WEXIT 75 rpm. PU wt. 145K, SO wt., 135K, Rot. wt. 140K. Recovered 204 lbs. of metal cuttings. Top of window = 5115' MD/4869' TVD. Middle of window = 5123.5. Bottom of window = 5132' MD/4883' TVD. 09:00 - 10:00 1.00 STWHIP P WEXIT Circulate 40 bbl. super sweep surface to surface. 540 gpm, 940 psi. 10:00 - 11:00 1.00 STWHIP P WEXIT RU and perform FIT 4883' TVD w/9.0 ppg LSND mud to 11.6 ppg EMW w/660 psi at surface. 11:00 - 12:30 1.50 STWHIP P WEXIT Pump dry job. Monitor well, OK. MW = 9.0 ppg. POH to BHA at 384'. 12:30 - 15:00 2.50 STWHIP P WEXIT LD window milling BHA #2. Both mills checked and within gage. 15:00 - 15:30 0.50 STWHIP P WEXIT Pull wear bushing and flush stack w/jetting tool to clear cuttings. 15:30 - 16:30 1.00 BOPSU P WEXIT Set test plug and rig up to perform BOP test w/4" test jt. 16:30 - 17:30 1.00 BOPSU P WEXIT BOP test. Annular BOP to 250 psi low side pressure and 3500 psi high side pressure. Top and bottom pipe rams, TIW and Dart Valve to 250 psi low pressure and 4000 psi high pressure. 17:30 - 18:00 0.50 BOPSU P WEXIT RD test equipment, pull test jt. and test plug. Install wear bushing. 18:00 - 22:00 4.00 STWHIP P WEXIT PJSM w/Schlumberger, all hands on nuke safety. PU BHA, install float, load nuke source, PU 23 jts. 4" HW DP. Surface test MW D at 917', OK. 22:00 - 00:00 2.00 STWHIP P WEXIT RIH f/917' to 4749', fill drill pipe at 4269'. 187 gpm, 360 psi. 7/18/2006 00:00 - 00:30 0.50 STWHIP P WEXIT Orient MWD tools to 36 deg. right of high side. RIH f/4749' to 5144'. No trouble running through window. 00:30 - 06:00 5.50 DRILL P INT1 Drill 8.5" directional hole f/5144' to 5767' w/1.5 deg. PDM motor assy. PU wt. 138K, SO wt. 128K, Rot. wt 120K, 550 gpm, 1750 psi off, 1950 psi on, 4000 tq. off, 6000 tq, on, 100 rpm. ECDs calc. 9.5 ppg, ECDs actual 10.1 ppg. MW In 9.0. ppg. Out 9.0 ppg. 06:00 - 00:00 18.00 DRILL P INT7 Drill 8.5" directional hole (/5767' to 7039' w/1.5 deg. PDM motor assy. PU wt. 160K, SO wt. 130K, Rot. wt 140K, 548 gpm, 2510 psi off, 2720 psi on, 4000 tq. off, 5000 to 7000 tq. on, 100 rpm. Used 580 bbl of 12.2 ppg LSND Spike fluid to weight up to a 10.8 ppg. ECDs calc. 11.55 ppg, ECDs actual 11.64 ppg. MW In 10.8 ppg. Out 10.8 ppg. ART = 5.48 Hrs. AST = 1.97 Hrs. ADT = 7.45 Hrs. Jar Hrs 88.3 7/19/2006 00:00 - 06:00 6.00 DRILL P INT1 Drill 8.5" directional hole f/7039' to 7535' w/1.5 deg. PDM motor assy. PU wt. 170K, SO wt. 140K, Rot. wt 143K, 535 gpm, 2680 psi off, 2920 psi on, 5000 tq. off, 5000 to 7000 tq. on, 100 rpm. WOB 10000 to 12000. Printed: S/7/2006 10:50:05 AM BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT 7/19/2006 00:00 - 06:00 6.00 ~ DRILL P 06:00 - 15:00 I 9.001 DRILL I P 15:00 - 17:00 I 2.001 DRILL I P 17:00 - 00:00 ~ 7.00 DRILL P 7/20/2006 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:30 1.00 DRILL N RREP INT1 03:30 - 10:30 7.00 DRILL P INT1 Spud Date: 7/25/1988 Start: 7/12/2006 End: 7/31/2006 I Rig Release: 7/31/2006 Rig Number: Phase Description of Operations INT1 ECDs talc. 11.45 ppg, ECDs actual 11.44 ppg. MW In 10.8. ppg. Out 10.8 ppg. INT1 Drill 8.5" directional hole f/7535' to 8159' w/1.5 deg. PDM motor assy. PU wt. 185K, SO wt. 140K, Rot. wt 150K, 550 gpm, 2800 psi off, 2943 psi on, 6000 tq. off, 8000 tq. on, 100 rpm. WOB 10000 to 12000. ECDs talc. 12.14 ppg, ECDs actual 11.56 ppg. MW In 10.8. ppg. Out 10.8 ppg. ART = 1.65 Hrs. AST = 6.53 Hrs. ADT = 8.18 Hrs. Jar Hrs = 96.2 INT1 Mad pass from 7975' to 7781' Across KUP formation, at 65 rpm, 546 gpm 2880 psi, 6000 tq. Run in the hole from 7781' to 8159'. INT1 Drill 8.5" directional hole f/8159' to 8750' w/1.5 deg. PDM motor assy. PU wt. 200K, SO wt. 145K, Rot. wt 155K, 550 gpm, 3140 psi off, 3460 psi on, 8000 tq. off, 8000 to 10000 tq. on, 100 rpm. WOB 10000 to 12000. Weight up to 11.2 ppg at 8650' md. 7701' tvd. ECDs talc. 12.6 ppg, ECDs actual 11.72 ppg. MW In 11.2. PP9. Out 11.2 pP9• ART = 3.87 Hrs. AST = 2.3 Hrs. ADT = 6.17 Hrs. Jar Hrs = 102.7 INT1 Drill 8.5" directional hole f/8759' to 9013' w/1.5 deg. PDM motor assy. PU wt. 200K, SO wt. 145K, Rot. wt 155K, 550 gpm, 3140 psi off, 3460 psi on, 8000 tq. off, 8000 to 10000 tq. on, 100 rpm. WOB 10000 to 18000. Weight up to 11.2 ppg at 8650' md. 10:30 - 11:00 0.50 DRILL N RREP INTi 11:00 - 12:00 1.00 DRILL P INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 ECDs talc. 12.6 ppg, ECDs actual 11.72 ppg. MW In 11.2. ppg. Out 11.2 ppg. Change out swab and liner #1 mud pump #3 cly. Drill 8.5" directional hole f/9013' to 9510' w/1.5 deg. PDM motor assy. PU wt. 205K, SO wt. 148K, Rot. wt 158K, 500 gpm, 2800 psi off, 3020 psi on, 9000 tq. off, 9000 to 10000 tq. on, 100 rpm. W OB 10000 to 18000. Change out swab #1 mud pump #2 cly. Drill 8.5" directional hole f/9510' to 9577' w/1.5 deg. PDM motor assy. PU wt. 205K, SO wt. 150K, Rot. wt 150K, 500 gpm, 3010 psi off, 3200 psi on, 10000 tq. off, 12000 tq. on, 100 rpm. WOB 10000 to 15000. ECDs talc. 11.92 ppg, ECDs actual 12.34 ppg. MW In 11.2. ppg. Out 11.2 ppg. ART = 6.77 Hrs. AST = .75 Hrs. ADT = 6.02 Hrs. Jar Hrs = 110.3 Drill 8.5" directional hole f/9577' to 10712' w/1.5 deg. PDM motor assy. PU wt. 255K, SO wt. 150K, Rot. wt 173K, 500 gpm, 2730 psi off, 2985 psi on, 13000 tq. off, 14000 tq. on, 100 rpm. WOB 5000 to 10000. Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Page 5 of 14 Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task ~ Code NPT Phase Description of Operations 7/20/2006 112:00 - 00:00 ~ 12.00 DRILL ~ P ~ ~ INT1 7/21/2006 100:00 - 03:00 I 3.001 DRILL I P I I INT1 03:00 - 05:00 I 2.001 DRILL I P I I INT1 05:00 - 09:00 I 4.001 DRILL P I INT1 09:00 - 11:00 I 2.001 DRILL I N I DPRB I INTi 11:00 - 13:00 I 2.001 DRILL I N I DPRB I INT1 13:00 - 19:30 I 6.501 DRILL I N I DPRB I INT1 19:30 - 20:30 I 1.001 DRILL I N I DPRB I INT1 20:30 - 21:00 0.501 DRILL I P I INT1 21:00 - 22:30 1.50 DRILL P INT1 22:30 - 00:00 1.50 DRILL P INT1 7/22/2006 100:00 - 02:00 I 2.001 DRILL I P I I INT1 02:00 - 03:00 I 1.001 DRILL I P I I INT1 ECDs talc. 12.01 ppg, ECDs actual 12.47 ppg. MW In 11.2. PPg• Out 11.2 PPg• ART = 7.53 Hrs. AST = .32 Hrs. ADT = 7.85 Hrs. Jar Hrs = 118.7 Drill 8.5" directional hole f/10712' to 11023' w/1.5 deg. PDM motor assy. PU wt. 260K, SO wt. 150K, Rot. wt 180K, 500 gpm, 2760 psi off, 2970 psi on, 14000 tq. off, 15000 tq. on, 100 rpm. WOB 5000 to 10000. ECDs talc. 11.91 ppg, ECDs actual 12.46 ppg. MW In 11.2. ppg. Out 11.2 ppg. ART = 2.38 Hrs. AST = 0 Hrs. ADT = 2.38 Hrs. Jar Hrs = 121 Rotate and reciprocate pipe. Circulate up sample per Geologist to cofrim casing point at top of Sag River with 480 gpm 2785 psi. 95 rpm. Pump 40 bbl Hi-Vis sweep around. Monitor well bore for 5 minutes. Pull out of the hole from 11023' to 8980'. Encountering 25K to 50K over pulls at 9165', 9088', 9055', 9000', 8990', 8980', 8965', 8955', 8945', and 8930'. Back ream from 8980' to 8442'. Hoie packing off and pipe sticking at 8545', 8445' and 8465'. Work pipe down with torge reestablish circulation and work pipe. Rotate and reciprocate pipe from 8980' to 8442' at 100 rpm, 8000 tq, 440 gpm at 2150 psi. Run in the hole from 8442' to 8725'. Rotate and reciprocate pipe from 8725' to 8630'. Pump a 40 bbl Hi-Vis sweep around at 498 gpm at 2580 psi. 100 rpm, 8000 tq. A 300% increase in cuttings was observed at bottoms up. Cuttings consist of a mix of all formations, mostly reground and no large amounts of splinters or cavings Back ream from 8347' to 5138' to just below the 9 5/8" window at 100 rpm, 500 gpm at 2530 psi. Circulate bottoms up at 450 gpm 1940 psi. Bit at 5120', TOW at 5115'. No noticeable increase in cuttings or cuttings structure at bottoms up. Pull out of the hole above TOW at 5115'. Service top drive and crown section. Cut and slip 100' of drilling line. Run in the hole from 5115' to 8100'. No problems. Fill drill pipe at 8010'. Continue to run in the hole from 8100' to 10993'. Taking 25k down weight at 10414', 10494' and 10564'. Wipe tight areas with out any problems. Break circulation, working pipe from 10993' to 11023'. Staging pumps up slowly to 400 gpm 2380 psi. After circulating 230 bbls slight pack off was encountered at 10970', decrease pumps to 300 gpm 1920 psi for 20 minutes, slowly staging pumps back up to 400 gpm 2380 psi, 100 rpm, 14000 tq. Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Page 6 of 14 Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To i Hours Ta Code NPT Ph tion of O erations ase Descri ~ p p 7/22/2006 02:00 - 03:00 1.00 DRILL P INT1 ECDs talc. 12.55 ppg, ECDs actual 11.88 ppg. MW In 11.2. ppg. Out 11.3 ppg. 03:00 - 05:00 2.00 DRILL P INT1 Circulate and condition mud. Pumping a 40 bbl Hi-Vis sweep 05:00 - 13:30 1 8.501 DRILL I P I I INT1 13:30 - 16:30 I 3.001 DRILL I P I I INT1 16:30 - 17:30 1.00 BOPSU P LNR1 17:30 - 19:00 1.50 BOPSU P LNR1 19:00 - 19:30 0.50 BOPSU P LNR1 19:30 - 20:00 0.50 BOPSU P LNR1 20:00 - 22:00 2.00 CASE P LNR1 22:00 - 00:00 2.00 CASE P LNR1 7/23/2006 100:00 - 03:00 I 3.001 CASE I P I I LNR1 03:00 - 04:00 1.00 CASE N RREP LNR1 04:00 - 12:00 8.00 CASE P LNR1 12:00 - 13:00 1.00 CASE P LNR1 13:00 - 14:00 1.00 CASE P LNRi 14:00 - 15:00 1.00 CASE P LNR1 15:00 - 18:30 3.50 CASE P LNR1 18:30 - 20:00 1.50 CASE N DPRB LNR1 around at 480 gpm 2970 psi, 100 rpm, 14000 tq. Up wt. 190k. SO wt. 155k. Pior to sweep coming back to surface a 400% in cuttings was observed. Cutting structure small shale and clay. No Mud lost while circulaing ECDs talc. 12.06 ppg, ECDs actual 11.98 ppg. MW In 11.2. ppg. Out 11.2 ppg Monitor well bore for 10 minutes. Pull out of the hole from 11023' to 228'. No problems. Pump dry job and drop 3 1/32" drift in 5" dp at 9957'. Recovered drift at 5" x 4" cross over. Change out elevators to 4". Pre job safety meeting. Lay down Jars, Float, NM DC, NM String Stab, Remove RA Source from ADN, 2 NM DC, ADN, MWD, ARC, PDM Motor, and Bit. Pull wear bushing. Install test plug. Rig up test equipment. Remove 3 1/2" x 6" variable rams and install 7" hard body rams in top pipe rams. Test door seals to 3500 psi against hydril. Test 7" rams to 4000 psi. Rig down test equipment. Pull test plug and install wear bushing. Pre job safety meeting. Rig up 7" casing equipment. Remove bails and install long bails. Rig up franks fill up tool. Run 7" 26# L-80 BTC-Mod liner to 552'. Baker lot shoe track. Check floats OK. Average make up tq 7800 fUlbs. Filling every joint on the run and filling every 10 joints run. Run 7" 26# L-80 BTC-Mod liner from 552' to 2140'. Average make up tq 7800 ft/Ibs. Filling every joint on the run and filling every 10 joints run. Trouble shoot pipe handler. Pipe kickers inoperable. Replace 5 amp fuse in control panel. Run 7" 26# L-80 BTC-Mod liner from 2140' to 6041' (70 Jts ). Average make up tq 7800 ft/Ibs. Filling every joint on the run and filling every 10 joints run. Place 2 ea straight bladed centralizers on either site of stop collar in middle of joint from 74 to 77. Place 1 free floating centralizer from joint 77 to joint 139 and from 143 to 144. Ran a total of 144 joints of 7" 26# L-80 BTC-Mod Liner (72) 7 1/8" x 8 1/4" straight bladed centralizers were used. Circulate 1 1/2 liner volume at 6041'. TOW at 5115', 248 gpm 680 psi. Up wt. 160k. Down wt. 130k. Rig down franks fill up tool. Remove 7" casing elevators. Make up Bakers 9 5/8" x 7" C-2 Flex Loc liner hanger and ZXP liner top packer. Rig down casing equipment. Remove long bails and install short bails. Run 7" 26# L-80 BTC-Mod liner on 5" dp from 6041' to 10956'. Breaking circulation every 10 stands run. 7' liner began taking wt. Set 75K down wt. at 10956' in an attempt to push 7" liner through tight area. Work 7" liner from Printed: 8/7/2006 10:50:05 AM i` J BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 7/23/2006 18:30 - 20:00 1.50 CASE N DPRB LNRi 10956' to 10933'. Continue working 7" liner from 125k down wt. to 375k up wt. Attempt to establish circulation. String packing off. Down movement of liner regained with no circulation. Work 7" liner to 11005'. No fluid was lost to well bore while attemting to circulate. 20:00 - 21:00 1.00 CASE N DPRB LNR1 Make up cement head and single of drill pipe and run 7" liner to TD at 11023' with no problems 125k down wt. Unable to circulate leaving 500 to 800 psi on 7" liner in an attempt to create a fluid path to gain circulation. Work liner at 11023' no movement, working 7" liner from 400k up wt. to 125k down wt. Pressure slowly started to fall off. Flow show indicated a small amount of returns. Continue applying small amount of pressure on 7" liner at 1 bbl /min 685 psi at 6% flow 21:00 - 00:00 3.00 CASE P LNRi Circulate bottoms up. Slowly stage pumps up from 1 bbl /min 685 psi at 6% returns to 2.4 bbl/ min 625 psi at 10% returns. Pumped 239 bbls of 11.2 ppg mud when pack off reoccurred. 7/24/2006 00:00 - 00:30 0.50 CASE N DPRB LNR1 Working 7" liner from 375k to 125k, pipe movement restricted. Circulation regained at 1 bbl /min 459 psi with 7% returns. Staging pumps up to 1 1/2 bbl /min 440 psi with 10% returns. Pack off reoccurring after pumping 13 bbls. Circulated a total of 252 bbls. No fluid was lost while circulating. 00:30 - 06:00 5.50 CASE N DPRB LNR1 Attempt to gain circulation. Continuing to work 7" liner with limted movement. Consulat with Engineer in town. 06:00 - 11:00 5.00 CASE N DPRB LNR1 Attempt to establish an injection rate. Pressured up to 1542 psi. Bleed off pressure. Pressure up to 2500 psi and set Bakers 7" x 9 5/8" Flex-Lock liner hanger. Verify hanger set by setting 145k down weight. First attempt to open Halliburton ES cementer failed at 3.5 bpm at 2840 psi, pumping 25 bbts away with a very small amount of returns. Establish an injection rate at 1 bpm 2006 psi pumping away 26 bbls in 30 minutes, .75 bpm 2060 psi pumping away 30 bbls in 30 minutes. Drop bottom plug from TDS head and displace w/ 11.1 ppg LSND mud at 2.5 bpm 2418 psi. With no returns. 11:00 - 13:00 2.00 CEMT N DPRB LNR1 Continue pumping plug down 5" drill pipe. Gradually increase pump rate to 5.5 bpm at 2200 psi. Latch at 87 bbls and kick liner wiper plug out at 3100 psi. Bump plug with 321 bbls and open ES cementer at 3600 psi. Circulation was regained after ES cementer was opened. Bull headed a total of 360 bbls of 11.1 mud while displacing plug. 13:00 - 15:00 2.00 CEMT P LNR1 Circulate and condition mud pumping thru ES cementer at 7319'. Staging pumps up slowly from 173 gpm at 675 psi to 260 gpm at 875 psi. Pre job safety meeting held with Schlumberger and all personal involed. 15:00 - 17:00 2.00 CEMT P LNR1 Pressure test lines to 4000 psi Ok, Bleed off pressure. Pump 50 bbl 11.3 mud push. Mix and pump 70.5 bbls Lite Crete cement at 11.5 ppg followed by 31.6 bbl class G cement Tail slurry at 15.8 ppg. Drop top plug from TDS head. Pump 5 bbl Printed: 6/7/2006 10:50:05 AM t , BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To ~ Hours Task Code ( NPT - ___-- 7/24/2006 15:00 - 17:00 2.00 ~ CEMT P 17:00 - 17:30 I 0.501 CEMT I P 17:30 - 18:30 1.00 CEMT P 18:30 - 19:00 0.50 CEMT P 19:00 - 21:30 2.50 CEMT P 21:30 - 00:00 2.50 CEMT P 7/25/2006 00:00 - 01:00 1.00 BOPSUFj P 01:00 - 02:30 1.50 BOPSU~j P 02:30 - 03:30 I 1.00 I BOPSUR P 03:30 - 04:00 I 0.50 I BOPSUR P Phase I Description of Operations LNR1 water. Displace with rig pump at 287 gpm 280 psi. Closing ES cementer with 191 bbls of 11.1 ppg LSND mud at 1800 psi. LNR1 Bleed off pressure. Check floats. Remove cement hose. Release from hanger by rotating 15 RH turns. Pick up 15' to verify released from hanger and circulate 50 bbls at 229 gpm 420 psi. Comfrim hanger set with 75k dwn wt. LNR1 Circulate bottoms up at 447 gpm 680 psi. Dumping 50 bbls mud push, 25 bbls 11.5 ppg cement and 55 bbls of contaminated 11.1 ppg mud. Mud weight In 11.1 ppg. Out 11.1 PPg• LNR1 Break and lay TDS cement head and 1 single of 5" drill pipe. LNR1 Pump dry job. Pull out of the hole from 4922' to 1797' LNR1 Lay down 57 joints of 5" drill pipe and Bakers C2 running tool. Clear rig floor. LNR1 Pull wear bushing. Install test plug. Rig up test equipment. LNR1 Remove 7" hard body rams and install 3 1/2" x 6" variable pipe rams in top pipe rams. LNR1 Test door seals to 3500 psi against hydril. Test 3 1/2" x 6" variable rams to 4000 psi. LNR1 Rig down test equipment. Pull test plug and install wear bushing. 04:00 - 07:30 3.50 CEMT N DPRB LNR1 Pick up clean out assy. Consisting of a Huges 6.125" ATJ-4 bit, 4 3/4" near bit, (3) 4 3/4" steel drill collars, Circ sub, jars. 07:30 - 10:30 3.00 CEMT N DPRB LNR1 Pick up 81 joints of 4" HT-40 drill pipe 2558'. 10:30 - 12:00 1.50 CEMT N DPRB LNR1 Run in the hole from 2732' to 5120'. 12:00 - 14:30 2.50 CEMT N RREP LNR1 Replace hydraulic service loop to top drive. 14:30 - 15:30 1.00 CEMT N RREP LNR1 Repair electrical short in off driller side lights in derrick. 15:30 - 17:30 2.00 CEMT N DPRB LNR1 Run in the hole from 5120' to 7842'. Tagging firm cement. Filling drill pipe at 6542'. 10k, 400 gpm, 2210 psi, 30 to 70 rpm, 10k tq. Up wt. 250k, SO wt. 135k, Rot wt 145k. Rotation was stopped due torque limitations. Unable to proceed any futher than 10908'. Pull up to 10805'. 02:00 - 02:30 0.50 CEMT N DPRB LNR1 Circulate bottoms up at 460 gpm 3125 psi. A small amount of rubber and a trace of cement was observed at bottoms up. 02:30 - 04:00 1.50 CEMT N DPRB LNR1 Rig up test equipment and test 7" 26# BTC-Mod Liner and liner top packer to 4000 psi for 30 minutes. Rig down test equipment. 04:00 - 10:00 6.00 CEMT N DPRB LNR1 Pump dry job. Pull out of the hole from 10805' to 818' SLM. Drill pipe talley corrected 16'. 10:00 - 11:00 1.00 CEMT N DPRB LNR1 Stand back 4" HWDP and 1 stand of 4 3/4" dc. Break bit. Lay down near bit stab, circ sub and float sub. 11:00 - 11:30 0.50 CEMT N DPRB LNR1 Clean and clear rig floor. 17:30 - 21:00 3.50 CEMT N DPRB LNR1 Drill cement stringers from 7842' to 7898'. Drill ES cementer at 7899' with 10k to18k WOB, 5k tq, 30 rpm, 400 gpm, 2160 psi. 21:00 - 00:00 3.00 CEMT N DPRB LNR1 Run in the hole pushing ES cementer closing plug from 7901' to 10514'. Setting 15k down wt. on closing plug in an attempt to push it to landing collar. Screw into top drive and began rotating at 35 rpm, 10k tq, 400 gpm, 2160 psi, UP wt. 230k, SO 120k, RT wt. 150k. Push closing plug with rotation and 5 to 8k W OB from 10514' to 10615'. Run in the hole from 10615' to 10854'. Taking 15k dwn wt at 10854'. 7/26/2006 00:00 - 02:00 2.00 CEMT N DPRB LNR1 Screw into top drive and wash from 10854' to 10908' with 5 to Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date ;From - To I Hours I Task Code NPT I Phase __~_ ___ 7/26/2006 11:30 - 12:00 0.50 CEMT N 12:00 - 13:00 1.00 CEMT N 13:00 - 14:00 1.001 CEMT N 14:00 - 15:30 1.501 CEMT N 15:30 - 16:00 I 0.50 I CEMT I N 16:00 - 17:00 1.00 CEMT N 17:00 - 17:30 0.50 CEMT N 17:30 - 00:00 6.50 CEMT N 7/27/2006 00:00 - 00:30 0.50 CEMT N 00:30 - 01:00 0.50 CEMT N 01:00 - 01:30 0.50 CEMT N 01:30 - 03:00 1.50 CEMT N 03:00 - 04:30 1.50 CEMT N 04:30 - 06:30 2.00 CEMT N 06:30 - 08:00 1.50 CEMT N 08:00 -.09:30 1.50 CEMT N 09:30 - 10:00 0.50 CEMT N 10:00 - 11:00 1.00 CEMT P 11:00 - 17:30 6.50 CEMT N DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNRi DPRB ILNR1 DPRB LNR1 DPRB LNR1 DPRB ILNR1 DPRB LNRi DPRB LNR1 DPRB ILNR1 DPRB ILNR1 DPRB ILNR1 LNR1 DPRB LNR1 Description of Operations Mobilize Schlumberger wire line tools to the rig floor. Pre job safety meeting with Schlumberger wire line on perforating. Rig up Schlumberger pressure control lubricator. Run in the hole with Schlumberger 3 3/8" pert guns on E-Line to 10866' ELM and perforate 5 hole in 7" 26# BTC-Mod liner. Pull out of the hole with E-Line. Rig down Schlumberger and stand by. Close blind rams and perform infectivity test. Started injecting at 1 bpm 2470 psi. 1.5 bpm at 2500 psi. 2 bpm at 2750 psi. Bullheading 10 bbls away. Rig down Schlumberger and clear floor of Schlumberger tools. Pick up Halliburton 5.80" OD fasdrill cement retainer. Run in the hole with Halliburton fasdril cement retainer on 4" x 5" drill pipe to 10848'. Up wt. 280k. SO wt 135k. Verify abilty to circulate at 1 bpm 316 psi. Attempt to rotate mechanical setting tool 55 RH turns. Only able to get 2 RH turns in drill string exceeding torque limitations on 3 1/2 IF connection on Halliburton's mechanical setting tool by 5K. Consultant with engineer in town about options. At a depth of 10685' while pulling out of the hole with Halliburton 7" fast drill cement retainer 15k overpull was encountered setting cement retainer. Set 30k down wt. and verifed set. Attempt to pump, drill string pressured up to 550 psi. Bleed off pressure. Shear off retainer at 350k Up wt. Continue to pull out of the hole from 10699' to 8965'. Rotation of drill pipe was sucssefuly accomplished by rotating 61 RH turns on mandrel. Verified mandrel opened by pumping down the drill string at 2 bpm 325 psi. Up wt. 215k. SO 120k. 9k tq. Run in the hole from 8965' to 10685' Verify the ability to pump thru stinger at 1.5 bpm at 335 psi. Test cement retainer U 3500 psi for 5 minutes. Space out drill pipe and rig up cement hose. Tag retainer at 10684'. Inserting stinger 2' into cement retainer. Setting 20k down wt. on cement retainer. Establish injection rate at 1 bpm at 2510 psi. 1.5 bpm at 2560 psi. 2 bpm at 2560 psi. 2.5 bpm at 2590 psi. 3 bpm at 2675 psi. Bleed off pressure. Unsting from cement retainer. Pre job safety meeting with Schlumberger / Dowell. Close hydril and establish a base line for back pressure by pumping thru choke. Pump 5 bbls of water, test lines to 4000 psi, mix and pump 60 bbls of 15.8 ppg class G cement followed by 5 bbl of water to wash up lines. Holding 750 psi back pressure. Switch over to rig pump, clearing drill pipe of 126 bbls of 10.9 ppg mud, leaving 10 bbls of 10.9 ppg mud in drill pipe, sting into cement retainer. Once stung into cement retainer returns were still present in the annulus. Bleed pressure off open hydril. Circulate 60 bbls of 15.8 ppg class G cement from the well bore at 6 bpm 1570 psi. Pull out of the hole to 10591' (1 stand) Rig down and blow down lines. Cut and slip 129' of drilling line. Service top drive. Pump dry job. Pull out of the hole. Lay down Halliburton mech setting tool. Seals gone on the stinger. Function blind rams. Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task Code NPT ~ Phase ---- - - - ___ l -- --- --} 7/27/2006 17:30 - 18:30 1.00 CEMT N I DPRB ~ LNR1 18:30 - 00:00 I 5.501 CEMT I N I DPRB I LNR1 7/28/2006 100:00 - 01:30 l 1.501 CEMT N DPRB LNR1 01:30 - 02:00 I 0.501 CEMT I N I DPRB I LNR1 02:00 --03:00 I 1.001 CEMT I N I DPRB I LNR1 03:00 - 05:30 2.50 CEMT N DPRB LNRi 05:30 - 06:00 0.50 CEMT N DPRB LNR1 06:00 - 10:00 4.00 CEMT ~ N DPRB ~ LNR1 10:00 - 12:00 2.00 CEMT N DPRB LNR1 12:00 - 14:00 2.00 CEMT N DPRB LNR1 14:00 - 14:30 0.50 CEMT N DPRB LNR1 14:30 - 16:30 2.00 CEMT N DPRB LNRi 16:30 - 18:30 2.00 CEMT N DPRB LNR1 18:30 - 19:00 0.501 CEMT N DPRB LNR1 19:30 - 21:00 10.50 BOPSU P DPRB I LNR1 21:00 - 00:00 3.00 BOPSU P 7/29/2006 ~ 00:00 - 01:30 ~ 1.50 ~ BOPSUFj P 01:30 - 02:30 I 1.001 BOPSUFI P LNR1 LNRi Description of Operations Run in the hole with clean out assembly, consisting of RR 6.125 Hughes ATJ-4 bit, bit sub. (3) 4 3/4" steel drill collars, jars and HWDP. Run in the hole from 814' to 10685'. Tagging cementer at 10685'. Up wt. 285k. So wt. 125k. Pump a 50 bbl steel tube sweep and displace well bore out with new 11.0 ppg LSND mud at 262 gpm 933 psi. Pre treated with 1.5% tubes. Allow new fluid to get above TOL at 4949'. Obtain parameters, Up wt. 210k. So wt 145k, Rot 170k with 8k of rotary tq at 70 rpm. Lost 75k hole drag by displacing wellbore. Drilf retainer at 10685' and push to 10906'. Up wt. 210k. So 145k, Rot wt. 170k. WOB 5k to 10k while drilling retainer. Tq 5 to 6k. 270 gpm 955 psi. Pull out of the hole from 10906' to 10431'. Mud wt In 11.0 ppg. Out 11.0 ppg. Attempt to establish an injection rate, pumping 1 bpm. Pressuring up to 3000 psi, shut down pumping. Pressure falling to 2600 psi. Pressure stabilzing at 2600 psi. Monitor pressure for 10 minutes,. No change. Bleed off pressure. Pump dry and pull out of the hole to 7507'. Attempt to establish an injection rate, pumping 1 bpm. Pressuring up to 3800 psi. with no pressure loss. Bleed off pressure. Continue to pull out of the hole, standing back HWDP and 4 3/4" drill collars. Pre job safety meeting w/ Schlumberger wire line and rig up. Run in the w/ 3 3/8" perforating guns. Perforating 7" 26# BTC-Mod liner at 10861'. Pull out of the hole. Lay down spent guns. Attempt to establish an injection rate, pumping 1 bpm. Pressuring up to 3800 psi. with no pressure loss. Bleed off pressure. Pick up 3 3/8" guns and arm firing head. Run in the w/ 3 3/8" perforating guns. Perforating 7" 26# BTC-Mod liner at 10780'. Pull out of the hole. Lay down spent guns. Attempt to establish an injection rate, pumping 1 bpm. Pressuring up to 3800 psi. with no pressure loss. Bleed off pressure. Rig down Schlumberger wire line. Pull wear bushing. Install test plug and rig up test equipment. Test BOPS to 250 psi low side pressure and 4000 psi high side pressure. 250 psi low side pressure 3500 psi high side on Hydril. Using 5" and 4" test joints. Witnessed by Wade Frame BP WSL and Lenward Toussant Nabors tourpusher, AOGCC representative John Crisp waived AOGCC attendance of the test. Test BOPS to 250 psi low side pressure and 4000 psi high side pressure. 250 psi low side pressure 3500 psi high side on Hydril. Using 5" and 4" test joints. Witnessed by Wade Frame BP WSL and Lenward Toussant Nabors tourpusher. AOGCC representative John Crisp waived AOGCC attendance of the test. Pull 4" test joint and test plug. Install wear bushig. Blow down Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/29/2006 01:30 - 02:30 02:30 - 04:30 04:30 - 12:00 12:00 - 12:30 12:30 - 13:30 13:30 - 17:00 Z-14 Z-14 REENTER+COMPLETE NABOBS ALASKA DRILLING NABOBS 7ES Hours Task Code ~ NPT 1.00 BOPSU P 2.00 CEMT P 7.50 CEMT P 0.50 CEMT P 1.00 CEMT P 3.50 EVAL N DPRB 17:00 - 17:30 0.50 CEMT N DPRB 17:30 - 22:30 5.00 CEMT N DPRB 22:30 - 23:00 0.50 CEMT N DPRB 23:00 - 23:30 0.50 CEMT N DPRB 23:30 - 00:00 0.50 CEMT P 7/30/2006 100:00 - 02:00 I 2.001 CEMT I P Page 11 of 14 Spud Date: 7/25/1988 Start: 7/12/2006 End: 7/31 /2006 I Rig Release: 7/31/2006 Rig Number: Phase Description of Operations LNR1 choke. LNR1 Pre job safety meeting with Schlumberger wire line. Rig up. Make up CAL-Y, GR, DSLT, GPIT, and USIT, wire line cased hole logging tools. LNR1 Run in the hole with Schlumberger logging tools. Logging down from 4970' to 10376 encountering tight area at 10376', work thru tight area continue to 10475' WLM. Logging up from 10475' to 4949' TOL. Pull out of the hole with logging tools. LNR1 Pull out of the hole with logging tools. LNR1 Rig down Schlumberger wire line. Clear floor of logging tools. LNR1 Evaluate logs, Consult with Engineering in town. Mobilize casing equipment and 3 1/2" tubing work string for PA plug. Rig up casing equipment. Asset made the decison to continue with present wellbore. Rig down casing equipment. LNR1 Make up clean out assembly #3 BHA #7 consisting of a 6 1/8" ATJ-4 Hughes bit, bit sub, float sub, Run in the hole with (3) 4 3/4" drill collars, jars, and HWDP to 126' LNR1 Run in the hole from 126' to 10821'. Install blower hose on top drive. Up wt. 220k. So wt. 145k. Rot wt. 160k. Filling drill pipe every 3000'. LNR1 Continue to run in the from 10821' tagging up on junk ie cement retainer and ES cementer closing plug. at 10906' LNR1 Drill and push junk to top of landing collar at 10932'. 210 gpm at 1500 psi. 70 rpm 6 U 8k tq. LNR1 Drill Landing collar from 10932' to 10934'. 210 gpm 1500 psi, 70 rpm 9 U 10k tq. Up wt. 220k. So wt. 145k. Rot wt. 160k. WOB 10 U 20K LNR1 Continue to drill the shoe track from 10934'U 11012'. Shoe at 11022'. Up wt. 200k. So wt. 155k. Rot wt. 175k. 70 rpm. 9 U 10k tq. 347 gpm1215 psi. While drilling float collar had pumped 213 bbls, before bottoms up, returns immediately started to show signs of Bar greasing out. Screens blinding off completely after another 50 bbls was pumped. Pump rate was reduced to a manageable rate until bottoms up passed at 390 bbls. Treated with Bicarb, Sapp, and Citric Acid 02:00 - 04:00 2.00 CEMT N 04:00 - 06:00 2.00 CEMT P 06:00 - 07;30 1.50 CEMT P 07:30 - 08:30 1.00 CEMT P 08:30 - 09:30 1.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 15:00 5.00 DRILL P WAIT LNR1 Rotating and reciprocating pipe, pumping at 347 gpm 1215 psi. Wait on Veco vac trucks to arrive on location with 8.4 ppg Flo-Pro SF drilling mud to commence with fluid displacement. LNR1 Displace wellbore out with 8.4 ppg Flo-Pro SF drilling mud. Pumping 100 bbls of water, 50 bbl Hi-Vis - Hi- Lube spacer followed by 530 bbl 8.4 ppg Flo-Pro mud at 420 gpm 1365 psi. Up wt. 200k. So wt. 175k. Rot wt. 175k. 80 rpm 2 U 3k tq. Mud wt. In 8.4 ppg. Out 8.4 ppg. LNR1 Clean out under shale shakers and surface equipment. LNR1 Drill 7" shoe at 11022'. 487 gpm 1615 psi. 3 U 6k tq. PROD1 Drill 20' of 6 1/8" hole from 11022' to 11042'. Pull to inside 7" liner at 11010'. PROD1 Perform FIT to equivalent mud wt. of 9.7 ppg. to 580 psi. PROD1 Pump dry job, Remove blower hose from top drive. Pull out of the hole from 11010' to 815'. Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRiLLtNG t Rig Name: NABOBS 7ES Date From - T~Hours ~ Task Code ~ NPT I Spud Date: 7/25/1988 Start: 7/12/2006 End: 7/31 /2006 Rig Release: 7/31/2006 Rig Number: Phase Description of Operations 7/30/2006 15:00 - 16:00 1.00 DRILL P PROD1 Stand back HWDP. Lay down (3) 4 3/4" steel drill collars. Clear floor. 16:00 - 16:30 0.50 DRILL P PROD1 Pre job safety meeting with Schlumberger / MW D on installing radioactive source. 16:30 - 18:00 1.50 DRILL P PROD1 Pick up BHA #8 consisting of Hughes MX-18HDX 6 1/8" bit, 1.50 deg. PDM, float sub, NM stab, NM flex lead collar, MWD, ADN4, Load radioactive source. 18:00 - 19:00 1.00 DRILL P PROD1 Pick up (3) 4 3/4" NM flex drill collars, circ sub, jars. Run in the hole with HWDP to 907'. 19:00 - 20:00 1.00 DRILL P PROD1 Attempt to shallow pulse test MWD at 907'. NO good. Run in the hole to 1380' and shallow pulse test MWD. Good. 20:00 - 00:00 4.00 DRILL P PROD1 Run in the hole from 1380' to 11007'. Filling every 3000'. Up wt. 210k So wt. 160k. 7/31/2006 00:00 - 00:30 0.50 DRILL P PROD1 Run in the from 11007' to 11042'. Up wt. 200k. So wt. 165k. 00:30 - 12:00 11.50 DRILL P PROD1 Drill 6 1/8" directional hole from 11042' to 11645' w/ 1.5 deg. PDM motor assembly. Up wt. 245K, So wt. 170K, Rot. wt 195K, 295 gpm, 1845 psi off, 1950 psi on, 7 to 8k tq. off, 7 to 9k tq, 100 rpm. WOB 18 to 20k. ART = 7.08 hrs. AST = 1.33 hrs ADT = 8.24 hrs Jar hrs 94.82 12:00 - 13:00 1.00 DRILL P PROD1 Drill 6 1/8" directional hole from 11645' to 11708' w/ 1.5 deg. PDM motor assembly. 13:00 - 14:30 1.50 DRILL P PROD1 Circulate bottoms up for Geologist at 290 gpm 1650 psi. 14:30 - 15:00 0.50 DRILL P PROD1 Short trip to 7" shoe at 11022'. No problems. Up wt. 245k. So wt. 170k. 15:00 - 15:30 0.50 DRILL P PROD1 Drill 6 1/8" directional hole from 11708' to 11765' w/ 1.5 deg. PDM motor assembly. Up wt. 245K, So wt. 170K, Rot. wt 195K, 290 gpm, 1750 psi off, 1950 psi on, 7 to 8k tq. off, 8 to 10k tq, 100 rpm. WOB 18 to 20k. ART = 1.85 hrs. AST = 1.33 hrs ADT = 10.27 hrs Jar hrs = 96.67 15:30 - 17:30 2.00 DRILL P PROD1 Circulate sweep around rotating and reciprocating pipe at 120 rpm 10k tq. 290 gpm 1700 psi. 17:30 - 18:30 1.00 DRILL P P ROD1 Pull out of the hole from 11765' to 11100'. Mad pass from 11100' to 11007'. 18:30 - 19:00 0.50 DRILL P P ROD1 Drop dart to open cir sub. Pump dry job. Drop 2 1/4" rabbit. 19:00 - 22:00 3.00 DRILL P P ROD1 Pull out of the hole from 11100' to 4949'. Placing circ sub at 7" liner top at 4949'. Bit depth 5133' MW 8.5 ppg in/out 22:00 - 22:30 0.50 DRILL P PROD1 Circulate bottoms up at 4949' to clean up 7" liner top. 510 gpm 950 psi. No increase in cuttings. 22:30 - 00:00 1.50 DRILL P PROD1 Pull out of the hole from 5133' to 2129'. MW 8.5 ppg in/out 8/1/2006 00:00 - 00:30 0.50 DRILL P P ROD1 Pull out of the hole from 2129' to 907'. 00:30 - 04:30 4.00 DRILL P P ROD1 Lay down 23 joints HWDP, jar (recover 2.25" rabbit from top of jars), Circ sub, (3) 4 3/4" NM flex drill collars. PJSM 200' prior to removal of source. Remove radioactive source. Lay down ADN, MWD, NM flex lead collar, NM stab, float sub, PD Motor, Bit. Clean and clear floor. 04:30 - 06:00 1.50 CASE P RUNPRD Rig up 4-1/2" casing running equipment equipment. Hold PJSM w/WSL, tourpusher, all hands. 06:00 - 09:30 3.50 CASE P RUNPRD Run 24 full jts. + 1 marker jt. of 4 1/2" 12.6# L-80 IBT-M liner. Bakerlok shoe track. Incorrect centralizers were previously installed on shoe track w/OD of 6.375" and were cut off. Installed4 1/2" x 5 3/4" free floating centralizers on joints 3 thru Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To -- 8/1/2006 06:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 17:00 17:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 21:30 21:30 - 22:30 Z-14 Z-14 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABORS7ES Start: 7/12/2006 Rig Release: 7/31 /2006 Rig Number: Hours ; Task j Code NPT ~ Phase _ __ 1 - _ - 3.50 ~ CASE P ~ RUNPRD 0.50 CASE P 0.50 CASE P 6.50 CASE P 1.50 CASE P 1.00 CASE P 0.50 CASE P RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD 0.501 CASE I P 1.001 CASE I P 1.001 CASE I P 22:30 - 23:30 1.00 CASE P 23:30 - 00:00 0.50 CASE P 8/2/2006 00:00 - 01:00 1.00 CASE P 01:00 - 02:00 1.00 CASE P 02:00 - 16:00 14.00 CASE P RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD 16:00 - 17:00 I 1.001 CASE I P i I RUNPRD 17:00 - 18:00 1.001 RUNCOI~VIN' RUNCMP 18:00 - 20:30 2.501 RUNCOI~ RUNCMP 20:30 - 21:00 I 0.501 RUNCOWIP I I RUNCMP Page 13 of 14 Spud Date: 7/25/1988 End: 7/31 /2006 Description of Operations 15, 19 to 23. PU 5" x 7" Flexlock liner hanger2XP liner top packer assembly and load 4.5" liner wiper plug on plug holder bushing. RIH w/1 stand drill pipe. RD casing running equipment. Circ. Flo-pro mud 1-1/2 liner volume at 126 gpm, 100 psi. Up wt. 45K, SO wt. 45K. RIH w/ liner on drill pipe filling every 10 stands to 10980' above 7" shoe at 11022'. Up wt 200K, SO wt. 155K. CBU staging pumps up to 6 bpm. 4 bpm, 480 psi. 5 bpm, 575 psi. 6 bpm, 675 psi. RIOH to 11735'. PU single and TD cementing head. RU hoses. RIH and tag bottom at 11765'. PJSM w/WSL, Schlumberger, all hands. Circ. 6 bpm, 920 psi and reciprocate 20' strokes while batch mixing cement. Up wt. 220K, SO wt. 160K. Schlumberger pump 5 bbls. water. Pressure test lines to 4500 psi. Pump 20 bbl Mudpush II 10 ppg, 4.9 bpm. Pump 33 bbls of 15.8 ppg G cement w/Gasblok and additives, 5.8 bpm. Wash up lines thru Tee to flowline. Drop wiper dart from TD head and displace w/rig pumps a 20 bbl. pert pill and follow w/8.5 ppg Flo-Pro mud. Latch plugs at 2300 strokes. Bump plugs at 2552 strokes. Pump displacement at 6 bpm and slow before plug bump to 2 bpm. FCP = f070 psi. CIP at 21:14. Continue pressuring up against plug to 4200 psi. SO liner wt + 20K to check hanger set. OK. Bleed off pressure and check floats. OK. Rotate 15 turns at the liner top. Pressure up to 1000 psi and pull packoff out extension sleeve. Leave stinger inside liner top and circulate 30 bbls at 6 bpm to clear off liner top and up annulus. Slow to 2 bpm and SO 30K to set ZXP packer. Rotate at 2 rpm and slack of 30K again on ZXP packer w/rotating dog sub. Top of liner at 10719'. PU 40' to clear liner top w/stinger and put no go mark on pipe. CBU at 10 bpm, 1650 psi. 1 i bbls good cement returned to surface. RD cement head head, LD 2 jts of drill pipe. Displace Flo-Pro mud to 8.5 ppg seawater. 10 bpm 1200 psi. Continue displacement of wel- to 8.5 ppg. seawater. 10 bpm 1200 psi. Clear rig floor of cementing equipment. Pump dry job. POH laying down drill pipe. Leave 40 stds 4" in derrick. LD liner running tool. Indicator screws sheared on rotating dog sub indicating good set on ZXP liner top packer. Test casing/liner lap surface to 4.5" shoe at 11765' to 4000 psi, hold 30 mins., record on chart. OK. Pull wear bushing and RIH w/tubing hanger f/dummy run. OK. Pull tubing hanger. RU to run 4.5" L-80 TC-II completion w/compensator equipment. C/O saver sub to 4" HT-40. C/O worn pipe grabber blocks on TD head. Night tour crew, PJSM. Discuss control of pipe while on pipe skate, use of compensator and single jt. elevators, and pipe shed procedures w/WSL, Baker, Nabors casing hand, Printed: 8/7/2006 10:50:05 AM BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: Z-14 Common Well Name: Z-14 Spud Date: 7/25/1988 Event Name: REENTER+COMPLETE Start: 7/12/2006 End: 7/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/31/2006 Rig Name: NABOBS 7ES Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase 8/2/2006 20:30 - 21:00 0.50 21:00 - 23:30 2.50 23:30 - 00:00 I 0.50 8/3/2006 00:00 - 13:30 13.50 13:30 - 15:30 I 2.00 15:30 - 16:00 0.50 16:00 - 18:00 2.00 18:00 - 20:30 I 2.50 20:30 - 21:30 1.00 BUNCO 21:30 - 22:00 0.50 WHSUR P 22:00 - 00:00 2.00 WHSUR P 8/4/2006 00:00 - 01:00 1.00 WHSUR P 00:00 - 05:00 5.00 WHSUR P 05:00 - 05:30 I 0.501 WHSUR I P 05:30 - 08:00 I 2.50 I W HSUR I P 08:00 - 10:00 I 2.001 WHSUR I P Description of Operations RUNCMP tourpusher and all hands. RUNCMP RIH w/4.5" L-80 TC-II completion. Jt. # 2 bad pin. Baker-Lok all connections from packer to muleshoe W LEG. Measure and confirm W LEG will drift thru 5.75" ID Baker liner top extension sleeve. RUNCMP Day tour, PJSM. Discuss control of pipe while on pipe skate, use of compensator and single jt. elevators, and pipe shed procedures w/WSL, Baker, Nabors casing hand, tourpusher and all hands. RUNCMP Continue to RIH w/4.5" L-80 TC-II completion to 10720' and tag liner top. Up wt. 145K, SO wt. 110K. RUNCMP RIH 11' and tag bottom at 10731'. PU and spaceout 5' off bottom w/6' of tailpipe inside liner top. Space out and place pup one jt. below hanger and land hanger. RUNCMP Run in lock down screws and RU to reverse circulate. RUNCMP Reverse circulate 203 bbls. inhibited seawater to annulus. Follow wl168 bbls seawater at max rate 3 bpm, 200 psi. RUNCMP Drop 1.875" ball and rod. Pressure up on drill pipe below blind rams to 4000 psi to set pkr. Slight leak off. Open blind rams and RIH w/landingt jt. and MU to hanger. Test to 4000 psi down tubing. Chart and hold for 30 mins. OK. Bleed pressure to 1500 psi on tubing. Pressure annulus to 4000 psi. Chart and hold for 30 minutes. OK. Bleed both tubing and annulus to zero. Pressure up on annulus and see DCR valve shear at 2450 psi. Pump two bbls. seawater each way through GLM #4 to confirm valve open. RUNCMP BD lines and RD/LD landing jt. RUNCMP MU Type H Two Way Check valve and install. Cameron hand counted turns and checked for proper installation. OK. Test f/below to 1000 psi. OK. RUNCMP ND BOP stack. WHDTRE Continue to ND BOP. WHDTRE NU adaptor flange and tree. Test tree and packoff to 5000 psi. OK. WHDTRE RU drill site maintenance lubricator. Pull two way check valve. RD drill site maintenance. WHDTRE RU Little Red Hot Oil Svc. and reverse circulate and U-tube155 bbls. of diesel freeze protection down annulus. WHDTRE Set BPV. Test BPV to 1000 psi. Secure well and release rig ~ 10:00 hours Printed: 8/7/2006 10:50:05 AM Digital Wellfile Page 1 of 1 Well Events for SurfaceWell - Z-1~ • Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> Z -> Z-14 Date Range: 10/Oct/2006 to 29/Oct/2006 Data Source(s): DIMS, AWGRS Events Source Well Date Description AWGRS Z-14B 10/29/2006 PERFORATED (3) INITIAL INTERVALS RAN THREE RUNS OF 2.5" HSD 6SPF PJ OMEGA GUNS OVER INTERVALS :11396'-11410' 11420'-11435' 11448'-11454' ALL SHOTS FIRED. DEPTH CORRECTED TO SLB MEASURED DEPTH LOG DATED 31-JULY-06. USED GAMMA RAY TO CORRELATE TO OPEN HOLE LOG. ***]OB COMPLETE*** AWG.R..S... Z-146 10/29/2006 *** CONT WSR FROM 10-28-06 *** TROUBLE SHOOT GAS LIFT MANDRELS U-TUBE A/L GAS TO TBG TO CHECK FOR TBG/IA COMM. INITIAL PSI = 400/180/0 .FINAL PSI = 1550/180/0 (NO COMUNICATION) RIG D/N GO BACK TO SLB CAMP *** LEFT WELL SHUT IN *** TURNED OVER TO OPERATOR AWGRS Z-14B 10/28/2006 ***WELL SHUT IN ON ARRIVAL*** (TROUBLE SHOOT GLV'S IN STA # 3&4) RAN 4-1/2" OM1, AND PINNED RK1 RUNNING TOOL TO ST#4. TOOL SHOWS VALVE IN POCKET. RAN 4- 1/2" OK6, AND PINNED JK RUNNING TOOL TO ST#3. TOOL SHOWS VALVE IN POCKET. *** CONT WSR ON 10-29-06 *** AWGRS Z-14B 10/28/2006 **JOB CONTINUED FROM 10/27/06** LOG SLIM CEMENT MAPPING TOOL FROM TD UP TO TOP OF CEMENT. TOP OF CEMENT FOUND AT 10726'. TD TAGGED AT 11493'. VERY STICKY OFF BOTTOM. NUMEROUS RESTRICTIONS. WHP = 900 PSI DURING LOGGING. ATTEMPT TO PERF. BLEED IAP &TBG PRESSURE TRACKED. DECIDE NOT TO PERF, POOH. ***JOB INCOMPLETE*** A....W.GRS Z-14B 10/27/2006 WELL SHUT IN ON ARRIVAL. INITIAL T/ I / O = 150/ 150/ 0. LOG SLIM CEMENT MAPPING TOOL (SCMT) FROM TD @ 11,493' UP TO ABOVE TOP OF CEMENT. TOC ~ 10,726'. *****JOB CONTINUED ON 28-OCT-2006 AWGRS***** AWGRS Z-14B 10/21/2006 T/I/O = 220/160/20. Temp = S/I. ALP = 1750 psi, AL S/I at casing valve. WHPs &TBG FL (pre-Eline). TBG FL @ 102' (2 bbLs). AWGRS Z-14B 10/14/2006 ATTEMPTED SCMT/ ADD PERF- UNABLE TO SPOT DUE TO ACRS EQUIPMENT BLOCKING WELL. JOB POSTPONED. AWGRS Z-146 10/10/2006 **WELL SHUT IN UPON ARRIVAL** {post sdtrk} PULLED B&R FROM 10711' SLM. PULL 1" BK DGLV FROM STA. # 3 @ 5,904', PULL 1.5" RKP SHEAR VALVE FROM STA. # 4 @ 3,133' SET 1.5" RK DOME 1500# 1/4" PORTS IN STA. # 4 @ 3,133', SET 1" BK S/O 5/16" PORTS PULL EMPTY RHC @ 10,716' SLM (USING THIS MEASUREMENT TO CORRECT) DRIFT W/ 20' X 2 7/8" DMY GUN TO 11457' SLM, - 4' = 11453' CORRECTED,STICKY BTM. ** TURNED WELL OVER TO PAD OP, LEFT SHUT IN** Refresh List http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 11/20/2006 ~ ~i ~~~ . ~i. Z-14B Survev Resort Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: Z-PAD / Z-14 Well: Z-14 Borehole: Z-146 UWI/API#: 500292184402 Survey Name /Date: Z-14B current /August 1, 2006 Tort /AHD / DDI / ERD ratio: 208.867° / 5903.66 tt / 6.196 / 0.640 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 7029768537, W 149.19358626 Location Grid NIE Y/X: N 5959100.020 ftUS, E 599579.930 ttUS Grid Convergence Angle: +0.75920951 ° Grid Scale Factor: 0.99991126 Sehlumberger Vertical Section Azimuth: 58.530° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 82.56 ft relative to MSL Sea Bed /Ground Level Elevation: 54.34 ft relative to MSL Magnetic Declination: 24.040° Total Field Strength: 57622.773 nT Magnetic Dip: 80.861 ° Declination Date: July 25, 2006 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +24.040° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n ft tt n n ft de 00 ft ftUS ftUS YroleClea-Up U.VV U.U4 1tS/.UV -tSY.bb U.VU -V.Z3 V.VU V.J/ -U.3b -V.U4 V.VV J`JD`JU`J`J.bb baab/a.ua rv /v.za/bb4aa vv 14`J.17.Sbt5bb3 GCT-MS 90.56 0.42 187.00 8.00 90.56 -0.45 0.36 0.73 -0.72 -0.09 0.42 5959099.29 599579.85 N 70.29768339 W 149.19358698 190.56 0.42 190.89 108.00 190.56 -0.93 1.10 1.46 -1.45 -0.20 0.03 5959098.57 599579.75 N 70.29768141 W 149.19358791 290.56 0.45 182.69 207.99 290.55 -1.40 1.85 2.22 -2.20 -0.29 0.07 5959097.82 599579.67 N 70.29767936 W 149.19358862 390.56 0.43 204.39 307.99 390.55 -1.93 2.61 2.97 -2.93 -0.46 0.17 5959097.08 599579.51 N 70.29767735 W 149.19359002 490.56 0.27 156.11 407.99 490.55 -2.27 3.19 3.53 -3.49 -0.52 0.32 5959096.52 599579.45 N 70.29767583 W 149.19359050 590.56 0.40 140.61 507.99 590.55 -2.25 3.77 3.98 -3.98 -0.21 0.16 5959096.04 599579.78 N 70.29767451 W 149.19358794 690.56 0.38 129.20 607.98 690.54 -2.09 4.45 4.46 -4.46 0.27 0.08 5959095.57 599580.26 N 70.29767320 W 149.19358406 790.56 0.23 130.81 707.98 790.54 -1.92 4.98 4.84 -4.80 0.68 0.15 5959095.23 599580.67 N 70.29767227 W 149.19358075 890.56 0.30 153.31 807.98 890.54 -1.88 5.44 5.25 -5.16 0.95 0.12 5959094.87 599580.95 N 70.29767127 W 149.19357857 990.56 0.47 137.50 907.98 990.54 -1.83 6.11 5.85 -5.70 1.35 0.20 5959094.34 599581.35 N 70.29766980 W 149.19357537 1090.56 0.47 123.70 1007.98 1090.54 -1.58 6.92 6.53 -6.23 1.96 0.11 5959093.82 599581.98 N 70.29766836 W 149.1 1190.56 0.55 147.61 1107.97 1190.53 -1.40 7.80 7.32 -6.86 2.56 0.23 5959093.19 599582.58 9 N 70.29766663 W 149.19 1290.56 0.57 130.90 1207.97 1290.53 -1.24 8.77 8.24 -7.59 3.19 0.16 5959092.47 599583.22 N 70.29766463 W 149.19 1390.56 0.40 145.90 1307.96 1390.52 -1.07 9.61 9.03 -8.21 3.77 0.21 5959091.86 599583.80 N 70.29766295 W 149.19355577 1490.56 0.43 136.81 1407.96 1490.52 -0.98 10.33 9.73 -8.77 4.22 0.07 5959091.31 599584.26 N 70.29766141 W 149.19355210 1590.56 0.37 121.40 1507,96 1590.52 -0.76 11.03 10.36 -9.21 4.75 0.12 5959090.87 599584.80 N 70.29766021 W 149.19354779 1690.56 0.48 150.81 1607.96 1690.52 -0.63 11.75 11.06 -9.74 5.23 0.24 5959090.35 599585.29 N 70.29765875 W 149.19354391 1790.56 0.35 124.31 1707.95 1790.51 -0.52 12.47 11.75 -10.28 5.69 0.23 5959089.81 599585.75 N 70.29765728 W 149.19354021 1890.56 0.52 161.70 1807.95 1890.51 -0.49 13.20 12.47 -10.89 6.08 0.32 5959089.22 599586.16 N 70.29765563 W 149.19353701 1990.56 0.42 127.50 1907.95 1990.51 -0.47 14.00 13.25 -11.54 6.52 0.29 5959088.57 599586.60 N 70.29765384 W 149.19353350 2090.56 0.35 163.61 2007.95 2090.51 -0.41 14.65 13.89 -12.06 6.89 0.25 5959088.06 599586.98 N 70.29765243 W 149.19353045 2190.56 0.37 153.50 2107.94 2190.50 -0.52 15.27 14.51 -12.64 7.12 0.07 5959087.48 599587.22 N 70.29765084 W 149.19352859 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-14~Z-14~Z-146~Z-14B current Generated 8/29/2006 10:06 AM Page 1 of 4 Measured Vertical Along Hole Comments Inclination Azimuth SulsSea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft n tt ft ft ft de 100 ft ttUS ttUS L19V.56 0.52 1/2.40 2"LU/.94 L29U .5U -U./3 16.04 15.25 -13.38 /.33 V.21 5959086.74 59958/.43 N/V.29/Ei4883 W149.19352694 2390.56 0.48 150 .70 2307 .94 2390 .50 -0.93 16.91 16.09 -14 .19 7 .59 0.19 5959085.93 599587.71 N 70.29764660 W 149.19352479 2490.56 0.67 169 .61 2407 .93 2490 .49 -1.16 17.90 17.07 -15 .13 7 .90 0.27 5959085.00 599588.03 N 70.29764403 W 149.19352228 2590.56 0.33 151. 50 2507 .93 2590 .49 -1.38 18.77 17.92 -15 .96 8 .15 0.37 5959084.17 599588.29 N 70.29764177 W 149.19352031 2690.56 0.47 162. 70 2607 .93 2690 .49 -1.50 19.46 18.61 -16 .60 8 .40 0.16 5959083.53 599588.55 N 70.29764001 W 149.19351821 2790.56 1.25 68. 80 2707 .92 2790 .48 -0.53 20.71 19.15 -16 .60 9 .54 1.37 5959083.55 599589.69 N 70.29764001 W 149.19350899 2890.56 4.43 61. 30 2807 .78 2890 .34 4.40 25.66 20.01 -14 .35 13 .95 3.19 5959085.85 599594.07 N 70.29764616 W 149.19347331 2940.56 5.83 68. 00 2857 .58 2940 .14 8.84 30.13 21.90 -12 .47 18 .00 3.04 5959087.79 599598.09 N 70.29765129 W 149.19344053 2990.56 7.70 66. 00 2907. 23 2989 .79 14.67 36.02 25.52 -10 .16 23 .41 3.77 5959090.17 599603.47 N 70.29765761 W 149.19339669 3090.56 9.95 56. 30 3006. 05 3088. 61 29.94 51.32 36.82 -2. 64 36. 72 2.69 5959097.87 599616.68 N 70.29767816 W 149.19328891 3190.56 11.97 44. 89 3104. 23 3186 .79 48.66 70.27 52.11 9 .50 51. 23 2.95 5959110.20 599631.03 N 70.29771133 W 149.19317143 3290.56 15.25 41. 00 3201. 41 3283 .97 71.28 93.79 72.32 26 .78 67. 18 3.40 5959127.69 599646.75 N 70.29775853 W 149.19304226 3390.56 18.92 42. 80 3296 .98 3379 .54 99.44 123.16 99.51 48 .61 86. 83 3.71 5959149.77 599666.11 N 70.29781817 W 149.19 3490.56 20.92 42. 80 3390 .99 3473 .55 132.23 157.23 132.34 73 .61 109. 98 2.00 5959175.07 599688.92 N 70.29788646 W 149.19269571 3590.56 22.23 42. 39 3483 .98 3566 .54 167.59 194.00 168.30 100 .68 134. 87 1.32 5959202.47 599713.44 N 70.29796041 W 149.19249422 3690.56 23.68 42. 69 3576. 06 3658 .62 205.08 233.00 206.75 129 .41 161 .24 1.45 5959231.54 599739.42 N 70.29803891 W 149.19228069 3790.56 26.37 41. 89 3666. 67 3749. 23 245.69 275.30 248.61 160. 71 189. 69 2.71 5959263.21 599767.45 N 70.29812441 W 149.19205032 3890.56 28.62 43. 89 3755. 37 3837. 93 290.14 321.46 294.50 194. 51 221. 12 2.43 5959297.42 599798.44 N 70.29821674 W 149.19179575 3990.56 29.77 45. 19 3842. 66 3925. 22 337.47 370.24 343.16 229. 27 255. 34 1.31 5959332.63 599832.19 N 70.29831169 W 149.19151867 4090.56 30.77 45. 50 3929. 03 4011. 59 386.55 420.64 393.52 264. 69 291. 20 1.01 5959368.52 599867.57 N 70.29840847 W 149.19122830 4190.56 32.62 45. 69 4014. 11 4096. 67 437.76 473.18 446.03 301. 45 328. 74 1.85 5959405.77 599904.61 N 70.29850889 W 149.19092435 4290.56 33.93 46. 10 4097. 71 4180. 27 491.29 528.05 500.87 339 .63 368. 13 1.33 5959444.47 599943.50 N 70.29861320 W 149.19060531 4390.56 33.62 45. 89 4180. 84 4263. 40 545.56 583.64 556.45 378. 26 408. 12 0.33 5959483.62 599982.97 N 70.29871870 W 149.19028149 4490.56 33.85 46. 10 4264. 00 4346. 56 599.77 639.17 611.98 416. 84 448. 07 0.26 5959522.72 600022.39 N 70.29882410 W 149.18995801 4590.56 33.47 46. 00 4347. 23 4429. 79 653.89 694.60 667.40 455. 30 487. 97 0.38 5959561.71 600061.78 N 70.29892918 W 149.18963487 4690.56 33.85 46. 30 4430. 47 4513. 03 708.03 750.03 722.82 493. 70 527. 94 0.41 5959600.63 600101.24 N 70.29903407 W 149.18931117 4790.56 33.25 46. 19 4513 .81 4596 .37 762.03 805.29 778.08 531 .92 567. 86 0.60 5959639.37 600140.64 N 70.29913848 W 149.18898790 4890.56 33.22 46. 50 4597 .45 4680 .01 815.60 860.10 832.88 569 .76 607. 51 0.17 5959677.72 600179.79 N 70.29924183 W 149.18866677 4990.56 32.57 46. 60 4681. 42 4763. 98 868.73 914.41 887.19 607 .11 646. 94 0.65 5959715.59 600218.71 N 70.29934386 W 149.18834747 Tie-In Survey 5090.56 32.35 46. 50 4765. 79 4848. 35 921.23 968.08 940.86 644. 02 685. 91 0.23 5959753.01 600257.18 N 70.29944469 W 149.188 Top Window (Blind) 5115.00 32.29 46. 55 4786. 45 4869. 01 934.01 981.15 953.93 653. 01 695. 39 0.27 5959762.12 600266.54 N 70.29946925 W 149.18 Base Window (Blind) 5132.00 33.90 48. 70 4800 .69 4883 .25 943.12 990.43 963.21 659. 26 702. 25 11.72 5959768.47 600273.32 N 70.29948633 W 149.187 9 Inc+Trend 5159.71 35.05 52. 00 4823 .53 4906 .09 958.64 1006.11 978.86 669 .26 714. 32 7.91 5959778.62 600285.26 N 7029951364 W 149.18780178 Inc+Trend 5253.61 40.66 60. 00 4897 .69 4980 .25 1016.09 1063.65 1035.63 701 20 762. 13 7.93 5959811.19 600332.63 N 70.29960089 W 149.18741462 MWD+IFR+MS 5350.80 46.08 67 .47 4968 .36 5050 .92 1082.42 1130.32 1099.65 730 .49 821. 97 7.67 5959841.27 600392.07 N 70.29968088 W 149.18693004 5442.08. 49.82 67. 58 5029. 49 5112. 05 1149.35 1198.09 1163.88 756 .39 884 .59 4.10 5959868.00 600454.34 N 70.29975163 W 149.18642291 5537.56 49.60 62. 92 5091 .25 5173 .81 1221.65 1270.90 1234.09 786 .86 950. 70 3.73 5959899.34 600520.03 N 70.29983485 W 149.18588753 5632.47 49.49 57. 70 5152 .86 5235 .42 1293.78 1343.10 1305.24 822 .61 1013. 40 4.19 5959935.91 600582.25 N 70.29993248 W 149.18537976 5727.78 49.72 52. 73 5214 .64 5297 .20 1366.21 1415.67 1377.60 864 .00 1072. 98 3.98 5959978.08 600641.27 N 70.30004554 W 149.18489724 5820.71 47.89 46 .46 5275 .88 5358 .44 1435.23 1485.56 1447.43 909 .24 1126. 21 5.44 5960024.02 600693.89 N 70.30016911 W 149.18446612 5916.24 46.88 41 .18 5340 .59 5423 .15 1503.19 1555.84 1517.15 959 .91 1174 .87 4.20 5960075.33 600741.87 N 70.30030752 W 149.18407198 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-14~Z-14~Z-146~Z-146 current Generated 8/29/2006 10:06 AM Page 2 of 4 Comments Measured Inclination Azimuth SutrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft n ft tt ft ft ft de 100 ft ftUS ftUS bU11.4t5 4(i.:3'L :iS .U/ 54Uti.Uli 54tftS .(iL 1511/.yy lti'L5.U1 15ti4.tiy 1U14.'Ly 1'Ll /.5/ 4./U SytiUl;fU.Lt5 IiUV/25:8.154 N /U.JUU45liU5 W 14y.ltfi/"LFi15 6104.96 45.81 28. 89 5470.95 5553. 51 1628.16 1692.29 1648.71 1071.32 1253.20 4.79 5960187.76 600818.71 N 70.30061186 W 149.18343752 6199.38 47.22 24. 43 5535.94 5618. 50 1686.29 1760.78 1712.02 1132.53 1283.89 3.74 5960249.36 600848.59 N 70.30077905 W 149.18318886 6292.81 48.12 19. 42 5598.88 5681. 44 1741.69 1829.83 1773.97 1196.57 1309.65 4.08 5960313.73 600873.49 N 70.30095401 W 149.18298020 6388.34 48.08 18. 73 5662.68 5745. 24 1796.59 1900.94 1836.76 1263.77 1332.88 0.54 5960381.23 600895.83 N 70.30113758 W 149.18279192 6482.24 48.07 15. 38 5725.43 5807. 99 1848.92 1970.79 1897.88 1330.55 1353.37 2.65 5960448.26 600915.43 N 70.30131999 W 149.18262592 6576.25 48.05 15. 30 5788.26 5870. 82 1899.91 2040.72 1958.67 1397.98 1371.87 0.07 5960515.93 600933.03 N 70.30150421 W 149.18247600 6672.75 47.63 14. 87 5853.03 5935. 59 1951.84 2112.25 2021.31 1467.05 1390.49 0.55 5960585.23 600950.73 N 70.30169289 W 149.18232513 6766.54 48.57 15. 41 5915.67 5998. 23 2002.57 2182.06 2083.02 1534.43 1408.72 1.09 5960652.85 600968.07 N 70.30187697 W 149.18217735 6862.10 48.42 15. 29 5978.99 6061. 55 2054.76 2253.63 2146.92 1603.45 1427.67 0.18 5960722.10 600986.10 N 70.30206549 W 149.18202382 6957.80 50.22 16. 98 6041.37 6123. 93 2108.36 2326.19 2212.62 1673.15 1447.85 2.31 5960792.06 601005.35 N 70.30225591 W 149.18186027 7054.64 50.45 21. 81 6103.21 6185. 77 2166.15 2400.72 2282.12 1743.43 1472.59 3.85 5960862.65 601029.16 N 70.30244789 W 149.18 7146.71 51.49 24. 60 6161.19 6243. 75 2224.50 2472.24 2350.61 1809.15 1500.78 2.61 5960928.73 601056.47 N 70.30262741 W 149.18 4 7242.60 52.83 31. 94 6220.07 6302. 63 2289.86 2547.92 2424.80 1875.74 1536.64 6.20 5960995.78 601091.45 N 70.30280931 W 149.18114078 7337.75 54.36 37. 73 6276.57 6359. 13 2359.94 2624.48 2501.10 1938.53 1580.38 5.15 5961059.14 601134.35 N 70.30298082 W 149.18078640 7433.81 54.45 42. 67 6332.50 6415. 06 2434.05 2702.57 2579.16 1998.15 1630.78 4.18 5961119.42 601183.94 N 70.30314369 W 149.18037815 7526.42 55.08 47. 26 6385.95 6468. 51 2507.56 2778.20 2654.40 2051.64 1684.22 4.10 5961173.61 601236.66 N 70.30328978 W 149.17994524 7622.30 55.04 52. 55 6440.89 6523. 45 2585.22 2856.78 2731.67 2102.24 1744.31 4.52 5961224.99 601296.07 N 70.30342796 W 149.17945846 7716.65 55.13 56. 90 6494.91 6577. 47 2662.38 2934.14 2806.42 2146.90 1807.44 3.78 5961270.48 601358.61 N 70.30354993 W 149.17894699 7810.06 55.69 61. 29 6547.95 6630. 51 2739.25 3011.02 2879.21 2186.37 1873.40 3.91 5961310.82 601424.03 N 70.30365772 W 149.17841268 7904.78 55.73 65. 50 6601.33 6683. 89 2817.19 3089.27 2951.48 2221.40 1943.35 3.67 5961346.77 601493.50 N 70.30375338 W 149.17784609 7999.15 54.95 66. 24 6655.00 6737. 56 2894.18 3166.89 3022.18 2253.14 2014.19 1.05 5961379.44 601563.90 N 70.30384002 W 149.17727226 8092.99 55.54 69. 94 6708.51 6791. 07 2970.18 3243.98 3091.46 2281.89 2085.70 3.30 5961409.13 601635.02 N 70.30391852 W 149.17669298 8188.32 55.66 72. 97 6762.38 6844. 94 3046.83 3322.63 3160.46 2306.90 2160.26 2.63 5961435.13 601709.24 N 70.30398679 W 149.17608902 8283.14 55.03 73. 21 6816.29 6898. 85 3122.33 3400.63 3228.26 2329.59 2234.88 0.70 5961458.80 601783.55 N 70.30404871 W 149.17548453 8377.57 57.54 73. 93 6868.70 6951. 26 3198.18 3479.17 3296.67 2351.79 2310.22 2.73 5961482.00 601858.58 N 70.30410932 W 149.17487428 8471.59 57.17 73. 38 6919.42 7001. 98 3274.60 3558.34 3366.02 2374.07 2386.19 0.63 5961505.28 601934.24 N 70.30417012 W 149.17425892 8566.15 58.65 75. 92 6969.66 7052. 22 3351.55 3638.45 3435.95 2395.26 2463.43 2.76 5961527.49 602011.19 N 70.30422794 W 149.17363319 8660.04 58.21 75. 76 7018.82 7101. 38 3427.92 3718.44 3505.43 2414.83 2541.00 0.49 5961548.09 602088.48 N 70.30428133 W 149.17300489 8755.79 57.34 75. 49 7069.87 7152. 43 3505.34 3799.44 3576.38 2434.94 2619.46 0.94 5961569.23 602166.66 N 70.30433619 W 149.1 8851.04 56.51 75. 85 7121.86 7204. 42 3581.61 3879.26 3646.67 2454.70 2696.79 0.93 5961590.01 602243.72 7 N 70.30439008 W 149.17 8945.05 55.78 76. 33 7174.23 7256. 79 3656.04 3957.33 3715.53 2473.46 2772.57 0.88 5961609.78 602319.23 N 70.30444128 W 149.17112903 9040.51 56.59 74. 83 7227.35 7309. 91 3731.86 4036.64 3786.17 2493.22 2849.38 1.56 5961630.55 602395.77 N 70.30449517 W 149.17050684 9134.69 55.96 74. 73 7279.64 7362. 20 3807.07 4114.97 3856.75 2513.78 2924.96 0.67 5961652.11 602471.06 N 70.30455127 W 149.16989457 9228.82 55.32 71. 88 7332.78 7415 .34 3882.19 4192.67 3927.86 2536.09 2999.38 2.59 5961675.40 602545.17 N 70.30461215 W 149.16929171 9324.66 55.00 72 .31 7387.53 7470 .09 3958.65 4271.33 4000.74 2560.28 3074.23 0.50 5961700.57 602619.69 N 70.30467813 W 149.16868536 9418.67 54.27 72. 27 7441.94 7524. 50 4033.11 4347.99 4071.88 2583.60 3147.26 0.78 5961724.86 602692.40 N 70.30474176 W 149.16809375 9513.32 53.98 72. 66 7497.41 7579. 97 4107.55 4424.68 4143.17 2606.71 3220.39 0.45 5961748.93 602765.21 N 70.30480480 W 149.16750132 9606.80 53.56 72. 74 7552.66 7635. 22 4180.66 4500.09 4213.33 2629.13 3292.39 0.45 5961772.30 602836.89 N 70.30486598 W 149.16691809 9702.76 52.68 72. 37 7610.25 7692. 81 4255.13 4576.85 4285.00 2652.14 3365.61 0.97 5961796.28 602909.80 N 70.30492875 W 149.16632488 9797.67 51.83 72 .68 7668.34 7750 .90 4327.95 4651.89 4355.25 2674.68 3437.20 0.93 5961819.76 602981.08 N 70.30499023 W 149.16574496 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-14~Z-14~Z-14B~Z-146 current Generated 8/29/2006 10:06 AM Page 3 of 4 Comments Measured Inclination Azimuth SuaSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de n n ft tt tt tt tt de 00 ft ttUS ttUS 9892.14 51.02 72.57 7727.25 7809.81 4399.58 4725.75 4424.50 2696 .73 3507. 68 9986.92 50.22 72.69 7787.38 7869.94 4470.64 4799.01 4493.33 2718 .60 3577. 60 10080.63 49.79 73.16 7847.61 7930.17 4540.17 4870.80 4560.79 2739 .68 3646. 23 10175.42 49.01 72.76 7909.30 7991.86 4609.87 4942.77 4628.54 2760 .77 3715. 04 10269.16 48.12 73.04 7971.33 8053.89 4677.95 5013.05 4694.84 2781. 44 3782. 21 10365.73 47.33 73.12 8036.29 8118.85 4747.12 5084.50 4762.29 2802. 23 3850. 57 10460.46 46.47 73.48 8101.02 8183.58 4814.00 5153.67 4827.61 2822. 11 3916. 82 10554.92 47.07 73.58 8165.72 8248.28 4880.48 5222.49 4892.61 2841. 62 3982. 82 10648.15 46.02 73.29 8229.84 8312.40 4945.88 5290.17 4956.67 2860. 92 4047. 69 10742.99 45.18 73.50 8296.19 8378.75 5011.37 5357.93 5020.92 2880. 28 4112. 62 10838.00 44.40 73.54 8363.62 8446.18 5076.02 5424.87 5084.43 2899. 27 4176. 81 10932.66 43.51 73.59 8431.77 8514.33 5139.48 5490.57 5146.84 2917. 86 4239. 82 10959.21 43.32 73.64 8451.05 8533.61 5157.10 5508.81 5164.19 2923. 01 4257. 33 11048.95 42.31 73.89 8516.88 8599.44 5215.94 5569.80 5222.15 2940. 06 4315. 89 11087.07 39.01 72.76 8545.79 8628.35 5239.95 5594.64 5245.82 2947. 18 4339. 68 11119.56 34.55 72.20 8571.81 8654.37 5258.82 5614.09 5264.46 2953. 03 4358. 23 11144.67 33.64 72.19 8592.60 8675.16 5272.50 5628.16 5277.97 2957. 33 4371. 63 11245.16 31.77 71.99 8677.16 8759.72 5325.28 5682.46 5330.13 2974. 03 4423. 29 11334.54 29.46 72.79 8754.07 8836.63 5369.47 5727.97 5373.84 2987. 81 4466. 67 11429.38 27.27 72.39 8837.52 8920.08 5413.18 5773.02 5417.08 3001. 28 4509. 66 11524.51 24.54 71.84 8923.09 9005.65 5453.57 5814.58 5457.08 3014. 03 4549. 21 11618.44 22.05 71.85 9009.35 9091.91 5489.71 5851.72 5492.90 3025. 61 4584. 51 11660.80 21.31 72.72 9048.72 9131.28 5504.91 5867.37 5507.97 3030. 37 4599. 41 Last MWD+IFR+MS 11716.78 20.04 73.01 9101.09 9183.65 5524.06 . 5887.14 5526.95 3036. 19 4618. 30 TD (Projected) 11765.00 20.04 73.01 9146.39 9228.95 5540.06 5903.66 5542.81 3041. 02 4634. 10 Survey Type: Definitive Survey NOTES: GCT-MS - ( Schlumberger GCT mu ltishot -- GCT surveys in casing or open hole. GCT = "Gyro Continuous Tooi" . ) MWD +IFR + MS - (In-field referenced MWD with mull-stati on analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Descriation: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4298 FSL 3098 FEL S19 T11 N R12E UM 5959100.02 599579. 93 Tie-In : 4298 FSL 3098 FEL S19 T11 N R12E UM 5959099.66 599579. 89 BNL : 2058 FSL 3732 FEL S17 Ti 1 N R12E UM 5962201.90 604172. 91 0. 86 5961842.74 603051.26 N 70.30505039 W 149.16517394 0. 85 5961865 .54 603120.87 N 70.30511005 W 149.16460751 0. 60 5961887 .52 603189.21 N 70.30516755 W 149.16405155 0. 88 5961909 .52 603257.73 N 70.30522507 W 149.16349409 0. 98 5961931 .07 603324.61 N 70.30528144 W 149.16294993 0.82 5961952.77 0.95 5961973.52 0.64 5961993.91 1.15 5962014.05 0.90 5962034.28 0.82 5962054.11 0.94 5962073.53 0.73 5962078.91 1.14 5962096.74 8.87 5962104.17 603392.69 603458.66 603524.39 603588.99 603653.66 603717.58 603780.34 603797.77 603856.09 603879.79 N 70.30533816 W 149.16239611 N 70.30539237 W 149.16185940 N 70.30544558 W 149.16132470 N 70.30549819 W 149.16079917 N 70.30555100 W 149.16027311 N 70.30560277 W 149.15975311 N 70.30565346 W 149.15 N 70.30566750 W 149.15 N 70.30571399 W 149.15862634 N 70.30573340 W 149.15843358 13.77 5962110.26 3.62 5962114.74 1.86 5962132.12 2.62 5962146.47 2.32 5962160.51 2.88 5962173.79 2.65 5962185.83 1.90 5962190.79 2.28 5962196.86 0.00 5962201.90 603898.25 603911.59 603963.03 604006.22 604049.02 604088.40 604123.53 604138.37 604157.18 604172.91 N 70.30574935 W 149.15828332 N 70.30576109 W 149.15817474 N 70.30580661 W 149.15775617 N 70.30584419 W 149.15740473 N 70.30588093 W 149.15705642 N 70.30591571 W 149.15673598 N 70.30594727 W 149.15645003 N 70.30596025 W 149.15632926 N 70.30597613 W 149.15617624 N 70.30598930 W 149.15604821 • SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-14~Z-14~Z-146~Z-146 current Generated 8/29/2006 10:06 AM Page 4 of 4 TREE = 4" CNV ,,,,,__, WELLHEAD= MCEVOY ACTUATOR = KB. ELEV = BF. ELEV..- KOP= Max Angle = -Datum MD = Datum TV D = 8800' SS ~CtaIC71 ®RL~a DRAFT 13-3/8" CSG, 68#, L-80, ID = 12.415" I-I 2652' 4-1/2" 12.6# L80, TCII Freeze protect prior to setting the packer PERFORATION SUMMARY REF LOG: ?????? ANGLE AT TOP PERF: 28° (~ 11396` Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 11396 - 11410 O 10129106 2-112" 6 11420 - 11435 O 10129!06 2-112" 6 11448 - 11454 O 10129!06 Whipstock KOP at --5115`MD ~- HES EZSV -5137`MD Z-146 • 2215` - 4 1/2" X Nipple (3.813" ID) Pre-rig tubing cut/ at 5400` 9115' 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9190' 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 4.0" / 9170' TIW PBR SEAL ASSY 9-518" X 7" LINDSEY LNR TOP 9230' PKR/HGR WlTIEBACK j 9-518" csg, 47#, L-80, .0732 bpf, ID = 8.681" 9501' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3133 3130 11 MMG DOME RK 16 10/10/06 3 5904 5415 47 KBG2 SO BK 20 10/10!06 2 8672 7108 58 KBG2 DMY BK 0 08!02/06 1 10580 8266 47 KBG2 DMY BK 0 08/02/06 4939` - 9-5/8" X 7" Baker Packer/Hanger (6/25" ID) 10647' - 4-1/2" X Nipple (3.813" ID) 10668` - 7" X 4-1/2" Baker S3 Packer 10692` - 4-1/2" X Nipple (3.813" ID) \ / 10712` - 4-1/2" XN Nipple (3.725" ID) // 10725` - 4-1 /2" W LEG 7" 26# L80 BTC-M shoe at 11022` in top Sag River / 4-1/2" 12.6# L80 IBT-M 11763`MD I 11590' I T' LNG 26#, L-80, .0383 bpf, ID = 6.276" ~-~ 10325' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" 11652' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/88 ORIGINAL COMPLETION 09/25/01 JLG/KK PERFS 03/31/98 CJS CTD SIDETRACK 6/23/06 KWA Proposed Sidetrack WP-08 03/13101 SIS-QAA CONVERTEDTOCANVAS 08!04!06 LV ACTUALCOMPLETION 03!15/01 SIS-MD FINAL 10/10!06 DAV/TLH GLV C/O 07/02/01 CH/KAK CORRECTIONS 10/29/06 JMF/PAG ADPERFS 08703/01 DV/DK/T CHANGE MIN ID/SET IBP PRUDHOE BAY UNrT WELL: Z-14B PERMfr No: API No: 50-029-xxxxx SEC 19, T11 N, R12E, 981' FNL, 3097' FEL BP Exploration (Alaska) ~~r~r :~. ~ zoo NO. 2 398 /~~ Alaska Data 8: Consulting Services _,-r )~ -Oa ~ Company: State of Alaska 2525 Gambell Street, Suite 400 C/~ [ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Loa Description Data at r..,i..~ r_n 10/06/06 3-29/J-32 11414759 SBHP SURVEY 09/04/05 1 L4-10 11285941 MEM PROD PROFILE 09115/06 1 L2-21A 11421023 LDL 09111106 1 C-18A 11285934 MEM PROD & INJECTION 07/29108 1 Y-24 NIA INJECTION PROFILE 09/03/08 1 Z-31 11414379 INJECTION PROFILE 09/04/08 1 S-276 11285940 MEM PROD PROFILE 09!14!06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/08 1 Z-19A NIA MDT 09/08106 1 A-17 11414381 USIT 09107106 1 X-01 11422981 USIT 09109106 1 H-04A 11285942 SCMT 09/17/06 1 15-39A 11212888 SCMT 09/18/06 1 C-09A 11209608 MCNL 06/16/06 1 1 C-18A 11285934 MCNL 07129106 1 1 Z-146 40013765 OH EDIT OF MWDILWD 07/31106 1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. BenSOn Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth :] SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Prudhoe Bay Well ...................... Z-14B API number ...............: 50-029-21844-02 Engineer .................. F. Medina RIG :...................... Nabors-7ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drillers Pipe Tally GL above permanent.......: 54.34 ft KB above permanent.......: NA Top Drive DF above permanent.......: 82.56 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: 58.53 degrees 1-Aug-2006 10:16:33 Page 1 of 4 Spud date ................. 14-Jul-06 Last survey date.........: 31-Jul-06 Total accepted surveys...: 78 MD of first survey.......: 5090.56 ft MD of last survey........: 11765.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 15-Jul-2006 Magnetic field strength..: 57582.49 GAMA Magnetic dec (+E/W-).....: 24.22 degrees Magnetic dip .............: 80.84 degrees ----- MWD survey Reference Reference G ............... Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 57622.50 GAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.05 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.05 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • c~ ~. SCHLUMBERGER Survey Report 1-Aug-2006 10:16:33 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 5090.56 32.35 46.50 0.00 4848.35 921.23 644.02 685.91 940.87 46.80 0.00 TIP None 2 5115.00 32.29 46.55 24.44 4869.00 934.01 653.01 695.39 953.94 46.80 0.27 Top of Window 3 5132.00 33.90 48.70 17.00 4883.25 943.13 659.26 702.25 963.22 46.81 11.72 Bow of Window 4 5159.71 35.05 52.00 27.71 4906.09 958.65 669.26 714.33 978.87 46.87 7.91 INC+TREND 5 5253.61 40.66 60.00 93.90 4980.25 1016.10 701.20 762.13 1035.63 47.38 7.93 INC+TREND 6 5350.80 46.08 67.47 97.19 5050.92 1082.42 730.49 821.97 1099.66 48.37 7.67 INC+TREND • 7 5442.08 49.82 67.58 91.28 5112.05 1149.36 756.39 884.59 1163.89 49.47 4.10 MWD+IFR+MS 8 5537.56 49.60 62.92 95.48 5173.81 1221.65 786.86 950.70 1234.10 50.39 3.73 MWD+IFR+MS 9 5632.47 49.49 57.70 94.91 5235.42 1293.79 822.61 1013.40 1305.25 50.93 4.19 MWD+IFR+MS 10 5727.78 49.72 52.73 95.31 5297.20 1366.21 864.00 1072.98 1377.60 51.16 3.98 MWD+IFR+MS 11 5820.71 47.89 46.46 92.93 5358.44 1435.23 909.24 1126.21 1447.44 51.08 5.44 MWD+IFR+MS 12 5916.24 46.88 41.18 95.53 5423.15 1503.19 959.91 1174.87 1517.16 50.75 4.20 MWD+IFR+MS 13 6011.48 46.32 35.07 95.24 5488.62 1567.99 1014.29 1217.57 1584.70 50.20 4.70 MWD+IFR+MS 14 6104.96 45.81 28.89 93.48 5553.51 1628.16 1071.33 1253.20 1648.71 49.47 4.79 MWD+IFR+MS 15 6199.38 47.22 24.43 94.42 5618.50 1686.30 1132.53 1283.90 1712.02 48.58 3.74 MWD+IFR+MS 16 6292.81 48.12 19.42 93.43 5681.44 1741.70 1196.58 1309.65 1773.97 47.58 4.08 MWD+IFR+MS 17 6388.34 48.08 18.73 95.53 5745.24 1796.60 1263.78 1332.89 1836.77 46.52 0.54 MWD+IFR+MS 18 6482.24 48.07 15.38 93.90 5807.99 1848.93 1330.55 1353.37 1897.89 45.49 2.65 MWD+IFR+MS 19 6576.25 48.05 15.30 94.01 5870.82 1899.91 1397.99 1371.87 1958.67 44.46 0.07 MWD+IFR+MS 20 6672.75 47.63 14.87 96.50 5935.59 1951.85 1467.05 1390.49 2021.31 43.47 0.55 MWD+IFR+MS 21 6766.54 48.57 15.41 93.79 5998.22 2002.58 1534.44 1408.73 2083.03 42.55 1.09 MWD+IFR+MS • 22 6862.10 48.42 15.29 95.56 6061.55 2054.76 1603.45 1427.67 2146.93 41.68 0.18 MWD+IFR+MS 23 6957.80 50.22 16.98 95.70 6123.93 2108.36 1673.15 1447.85 2212.63 40.87 2.31 MWD+IFR+MS 24 7054.64 50.45 21.81 96.84 6185.77 2166.16 1743.43 1472.60 2282.13 40.19 3.85 MWD+IFR+MS 25 7146.71 51.49 24.60 92.07 6243.75 2224.51 1809.15 1500.78 2350.61 39.68 2.61 MWD+IFR+MS 26 7242.60 52.83 31.94 95.89 6302.62 2289.86 1875.74 1536.65 2424.81 39.33 6.20 MWD+IFR+MS 27 7337.75 54.36 37.73 95.15 6359.12 2359.95 1938.53 1580.39 2501.10 39.19 5.15 MWD+IFR+MS 28 7433.81 54.45 42.67 96.06 6415.06 2434.06 1998.16 1630.78 2579.16 39.22 4.18 MWD+IFR+MS 29 7526.42 55.08 47.26 92.61 6468.51 2507.56 2051.65 1684.22 2654.40 39.38 4.10 MWD+IFR+MS 30 7622.30 55.04 52.55 95.88 6523.45 2585.22 2102.24 1744.31 2731.67 39.68 4.52 MWD+IFR+MS SCHLUMBERGER Survey Report 1-Aug-2006 10:16:33 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 7716.65 55.13 56.90 94.35 6577.47 2662.39 2146.90 1807.45 2806.43 40.09 3.78 MWD+IFR+MS 32 7810.06 55.69 61.29 93.41 6630.51 2739.25 2186.37 1873.41 2879.21 40.59 3.91 MWD+IFR+MS 33 7904.78 55.73 65.50 94.72 6683.89 2817.20 2221.40 1943.35 2951.48 41.18 3.67 MWD+IFR+MS 34 7999.15 54.95 66.24 94.37 6737.56 2894.19 2253.14 2014.19 3022.18 41.80 1.05 MWD+IFR+MS 35 8092.99 55.54 69.94 93.84 6791.07 2970.19 2281.89 2085.70 3091.47 42.43 3.30 MWD+IFR+MS 36 8188.32 55.66 72.97 95.33 6844.94 3046.84 2306.90 2160.26 3160.46 43.12 2.63 MWD+IFR+MS . 37 8283.14 55.03 73.21 94.82 6898.85 3122.33 2329.59 2234.89 3228.27 43.81 0.70 MWD+IFR+MS 38 8377.57 57.54 73.93 94.43 6951.26 3198.18 2351.80 2310.22 3296.68 44.49 2.73 MWD+IFR+MS 39 8471.59 57.17 73.38 94.02 7001.98 3274.61 2374.08 2386.19 3366.03 45.15 0.63 MWD+IFR+MS 40 8566.15 58.65 75.92 94.56 7052.22 3351.55 2395.27 2463.44 3435.96 45.80 2.76 MWD+IFR+MS 41 8660.04 58.21 75.76 93.89 7101.38 3427.92 2414.83 2541.00 3505.44 46.46 0.49 MWD+IFR+MS 42 8755.79 57.34 75.49 95.75 7152.43 3505.34 2434.94 2619.46 3576.39 47.09 0.94 MWD+IFR+MS 43 8851.04 56.51 75.85 95.25 7204.41 3581.61 2454.70 2696.80 3646.68 47.69 0.93 MWD+IFR+MS 44 8945.05 55.78 76.33 94.01 7256.79 3656.05 2473.47 2772.58 3715.54 48.26 0.88 MWD+IFR+MS 45 9040.51 56.59 74.83 95.46 7309.91 3731.87 2493.22 2849.38 3786.18 48.81 1.56 MWD+IFR+MS 46 9134.69 55.96 74.73 94.18 7362.20 3807.07 2513.79 2924.97 3856.75 49.32 0.67 MWD+IFR+MS 47 9228.82 55.32 71.88 94.13 7415.34 3882.19 2536.10 2999.39 3927.86 49.78 2.59 MWD+IFR+MS 48 9324.66 55.00 72.31 95.84 7470.09 3958.66 2560.28 3074.24 4000.75 50.21 0.50 MWD+IFR+MS 49 9418.67 54.27 72.27 94.01 7524.50 4033.12 2583.60 3147.27 4071.89 50.62 0.78 MWD+IFR+MS 50 9513.32 53.98 72.66 94.65 7579.97 4107.56 2606.71 3220.40 4143.17 51.01 0.45 MWD+IFR+MS 51 9606.80 53.56 72.74 93.48 7635.21 4180.67 2629.13 3292.39 4213.33 51.39 0.45 MWD+IFR+MS • 52 9702.76 52.68 72.37 95.96 7692.80 4255.14 2652.14 3365.62 4285.00 51.76 0.97 MWD+IFR+MS 53 9797.67 51.83 72.68 94.91 7750.90 4327.96 2674.68 3437.20 4355.26 52.11 0.93 MWD+IFR+MS 54 9892.14 51.02 72.57 94.47 7809.81 4399.59 2696.74 3507.69 4424.51 52.45 0.86 MWD+IFR+MS 55 9986.92 50.22 72.69 94.78 7869.94 4470.64 2718.61 3577.61 4493.34 52.77 0.85 MWD+IFR+MS 56 10080.63 49.79 73.16 93.71 7930.17 4540.18 2739.69 3646.23 4560.80 53.08 0.60 MWD+IFR+MS 57 10175.42 49.01 72.76 94.79 7991.86 4609.88 2760.78 3715.04 4628.55 53.38 0.88 MWD+IFR+MS 58 10269..16 48.12 73.04 93.74 8053.89 4677.96 2781.44 3782.21 4694.84 53.67 0.98 MWD+IFR+MS 59 10365.73 47.33 73.12 96.57 8118.85 4747.12 2802.24 3850.57 4762.30 53.95 0.82 MWD+IFR+MS 60 10460.46 46.47 73.48 94.73 8183.58 4814.00 2822.12 3916.82 4827.61 54.23 0.95 MWD+IFR+MS SCHLUMBERGER Survey Report 1-Aug-2006 10:16:33 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) (f t) (f t) (ft) (ft) (ft) (deg) 100f) type (deg) 61 10554.92 47.07 73.58 94.46 8248.28 4880.48 2841.63 3982.82 4892.62 54.49 0.64 MWD+IFR+MS 62 10648.15 46.02 73.29 93.23 8312.40 4945.88 2860.92 4047.69 4956.68 54.75 1.15 MWD+IFR+MS 63 10742.99 45.18 73.50 94.84 8378.75 5011.37 2880.29 4112.63 5020.93 54.99 0.90 MWD+IFR+MS 64 10838.00 44.40 73.54 95.01 8446.18 5076.03 2899.27 4176.81 5084.44 55.23 0.82 MWD+IFR+MS 65 10932.66 43.51 73.59 94.66 8514.32 5139.48 2917.86 4239.83 5146.85 55.46 0.94 MWD+IFR+MS 66 10959.21 43.32 73.64 26.55 8533.61 5157.10 2923.01 4257.33 5164.19 55.53 0.73 MWD+IFR+MS 67 11048.95 42.31 73.89 89.74 8599.44 5215.95 2940.06 4315.89 5222.15 55.74 1.14 MWD+IFR+MS 68 11087.07 39.01 72.76 38.12 8628.35 5239.96 2947.18 4339.68 5245.83 55.82 8.87 MWD+IFR+MS 69 11119.56 34.55 72.20 32.49 8654.37 5258.83 2953.03 4358.23 5264.46 55.88 13.77 MWD+IFR+MS 70 11144.67 33.64 72.19 25.11 8675.16 5272.51 2957.33 4371.63 5277.97 55.92 3.62 MWD+IFR+MS 71 11245.16 31.77 71.99 100.49 8759.72 5325.29 2974.03 4423.29 5330.14 56.08 1.86 MWD+IFR+MS 72 11334.54 29.46 72.79 89.38 8836.63 5369.48 2987.81 4466.67 5373.84 56.22 2.62 MWD+IFR+MS 73 11429.38 27.27 72.39 94.84 8920.08 5413.18 3001.28 4509.66 5417.08 56.36 2.32 MWD+IFR+MS 74 11524.51 24.54 71.84 95.13 9005.64 5453.57 3014.04 4549.22 5457.09 56.47 2.88 MWD+IFR+MS 75 11618.44 22.05 71.85 93.93 9091.91 5489.72 3025.61 4584.51 5492.91 56.58 2.65 MWD+IFR+MS 76 11660.80 21.31 72.72 42.36 9131.27 5504.92 3030.37 4599.42 5507.97 56.62 1.90 MWD+IFR+MS 77 11716.78 20.04 73.01 55.98 9183.65 5524.07 3036.20 4618.30 5526.95 56.68 2.28 MWD+IFR+MS 7S 11765.00 20.04 73.01 48.22 9228.95 5540.07 3041.03 4634.10 5542.81 56.73 0.00 Projection to TD [(c)2006 IDEAL ID10_ZC_O1] • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No Z-14B Installation/Rig Nabors 7ES Dispatched To: AOGCC Library Date Dispatched: 17-Aug-06 Dispatched By: Melyssa Schaaf Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: ,lames H. Johnson Received By: I BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) ~ f 900 E. Benson Blvd. `mo ~ t/, Anchorage, Alaska 99508 1 Fax: 907-5644005 e-mail address: johnsojhC~3bp.com LWD Log DeliveryV1.1,10-02-03 a„o~- 6~9 ~v~ ~ ~~ A~JG 0 8 20QS oslol/os Ssbtum~erger ai ~ Gas Cons. Comini~~gt; NO.3883 Anchol'ag~ Alaska Data 8 Consulting Services ~'1 ~ Company: State of Alaska 2525 Gambell Street, Suite 400 ~ !j ~-, ~ "-~1~ ~~- ~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 //~J Attn; Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WBII _Inh $ 1 nn rlccrrinfinn n~~e Q~ ~.. ~... rn • • 3 11211388 D FIL 4 0 1 K- 10568415 D P W/D 0212610 1 L4-12 NIA WFL/LDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28!06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE WIDEFT 03/22/06 1 18-036 11057071 SBHP 12/02/05 1 X-15A 11212877 USIT 07/18/06 1 J-016 11511430 USIT 07/24/06 1 15-12A 11221595 USIT 07/25/06 1 Z-146 11217268 USIT 07129!06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26106 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Hlaslca uata ~ t;onsw[mg cervices 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Re: Well Z-146 for BP Alaska ~ ~~~, ~? ~~ ~ ~ 1 ~ ~ Subject: Re: Well Z-14B for BP Alaska From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Tue, 25 Jul 2006 12:36:50 -0800 To: "Allen, Kenneth W" <Kenneth.Allen@bp.com> Ken, Pursuant to 20 AAC 25.412 (b), a packer depth variance is approved for well Z-146 (PTD 206-099), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Allen, Kenneth W wrote: Winton, We encountered some problems after running our 7" liner to TD at the Top Sag River formation. Once the liner was on bottom we were packed off and could not circulate or move the pipe. We could not pump our 1St stage cement job as planned due to this packoff. The ES cementer at the Base of the Kuparuk formation (7900' md) was opened and the 2nd stage cement job was pumped as planned to the top of the 7" liner. In order to get isolation between the production interval and the Kuparuk formation we will perforate the 7" liner and squeeze cement behind pipe. The plan is to perforate 150' above the 7" shoe and attempt to squeeze cement from this depth. If unsuccessful at that depth, we will move the perforations up hole and reattempt a squeeze. The squeeze operations will require placing the production packer higher than originally planned and we will require a dispensation from the 200' rule. The estimated depths and volumes are as follows: 7" shoe -11,023' and Estimated 7" liner perforation depth (to be covered by 4.5" liner lap) - 10,873' and Estimated 4.5" liner top - 10,793' and Estimated Production Packer depth - 10,713' and Estimated Top Sag River - 11,023' and Estimated Top Ivishak - ~ 11,295' and Estimated Packer depth above top perforated zone - 582' If you need any further information please let me know. Thanks for the help, Ken Allen Operations Drilling Engineer GPB Rotary Mobile: 907.748.3907 Office: 907.564.4366 e-mail: Kenneth.Allen(cc~BP.com 1 of 1 7/25/2006 12:38 PM a • ~"' ~ ' '~ ~ I,J,' a::m»~ _.. ~~a ,~ ,}~;~ ~ .v,~ ~ ~ ~j~1~~ !' FRANK H. MURKOWSKI, GOVERNOR ~i ~~ OI~ ~ ~ ~' 333 W. T" AVENUE, SUITE 100 COI~TSERQATIOI~T CO1~ID'IISSIOI~T !' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Dave Wesley FAx (so7) 27s-7542 Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-14B BP Exploration (Alaska) Inc. Permit No: 206-099 Surface Location: 981' SNL, 1856' EWL, SEC. 19, T11N, R12E, UM Bottomhole Location: 2069' NSL, 1534' EWL, SEC. 17, T11N, R12E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless- the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ~,L, DATED this day of July, 2006 Sincere , Dan T. Seamount Commisssioner cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA.~OIL AND GAS CONSERVATION COM~ION PERMIT TO DRILL 20 AAC 25.005 ,~tJL U li LUU6 nla~ka Oi18t Gas Gons. Gimxnissnln Sn~iinranP. 1 a. Type of work O Drill ®Redrill ^ Re-Entry 1 b. Current Well Class O Exploratory O Development Gas ®Service ~ O Multiple Zone O Stratigraphic Test Q 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 Z-14B ~ j2.k vG 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11750 TVD 9197 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 981' SNL 1856' EWL SEC R12E UM 19 T11N 7. Property Designation: ADL 028262 Pool , , . , , , Top of Productive Horizon: 1985' NSL, 1242' EWL, SEC. 17, T11N, R12E, UM 8. Land Use Permit: 13. Approximate Sp , te: Ju 14,2b06 Total Depth: 2069' NSL, 1534' EWL, SEC. 17, T11N, R12E, UM 9. Acres in Property: 2560 14. Distance to crest Property: 11,850' 4b. Location of Well (State Base Plane Coordinates): Surface: x-599580 y-5959100 Zone-ASP4 10. KB Elevation Plan (Height above GL): 82.84 feet 15. Distance to Nearest We11 within Pool: 1,050' 16. Deviated Wells: Kickoff Depth: 5118 feet Maximum Hole Angle: 59 de rees 17. Maximum Anticipated Pressures in psig (see 20 5. 35) Downhole: 3700 Surface: 850 18. Casin Pr ram: S ecifications To - Settin De th -Bottom Quanti of ent, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD ZS includin sta a data 8-1/2" 7" 26# L-80 BTC-M 6089' 4968' 4745' 11057' 8583' cu ft LiteCrete, ~cu ft Class' 6-1l8" 4-1/2" 12.6# L-80 IBT-M 843' 10957' 8512' 11750' 9197' 135 cu ft Class'G' X04 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11652 Total Depth TVD (ft): 9150 Plugs (measured): 9229 Effective Depth MD (ft): 11590 Effective Depth TVD (ft) 9094 Junk (measured): None `Casing. Length Size Cement Volume MD TVD Conductor /Structural 110' 20" 8 cu ds Concrete 110' 110' Surface 2652' 13-3/8" 3585 cu ft Permafrost 2652' 2652' Intermediate 9501' 9-5/8" 1939 cu ft Class'G' 9501' 8542' Production Liner 299' 7" 366 cu ft Class 'G' 9231' - 9530' 8317' - 8566' Liner 2414' 2-7/8" 129 cu ft Class'G' 9238' - 11652' 8323' - 9150' Perforation Depth MD (ft): 11050' - 11508' Perforation Depth TVD (ft): 8790' - 9023' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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. Printed Name ve Wesley Si nature Contact Ken Allen, 564-4366 Title Senior Drilling Engineer Prepared By Name/Number: Phone 564-5153 Date /L?Ej Terrie Hubble, 564-4628 Commission Use Only . Permit To Drill Number: '~ p ~ ,p API Number: 50- 029-21844-02-00 Permit Approval Date: -j . See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes ~No ~eS ~" j3 O (~ ~ fo 4v v o ~ ~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No O her: ~ ~ z T CP- tvt. ~(.~-'~ t~.a.~G (,0 rt c~ rtl~ l.~.P d ~ • t~s~e ~ • ~u v ~, u aK.~ >~'o ZD ~ Z5 .O 3 ~ ~ ~) r! f ~ ~~ e^'~C~ ~ t~ ~ l' ~ 't< rl~Ya Cpl Lc/a.-~ ~ S ~/ ~evC~ r1~wC..(7") vq,w~. t~nl~E cocle.~ r~yt.~~t.~~ . APPROVED BY THE COMMISSIO Date ,COMMISSIONER ~ Fo`rm `ttT/~01 Revised 12/2005 ~ O~1G1~iAL Submit In Duplicate kLfsl~ • • Planned Well Summary Well Z-14B Well Water & MI Target Ivishak Zones T e Injector Ob'ective 4,3 and 2 AFE Number: PBD 4P2231 API Number: 50-029-21844-02 Surface Northin Eastin Offsets TRS Location 5,959,100.02' 599,579.93' 981.3' FNL / 3097.4' FEL 11 N, 12 E, 19 Target Northin Eastin Offsets TRS Location 5,962,124.5' 603,867.8' 3294' FNL / 4038' FEL 11 N, 12 E, 17 To Sa River Bottom Northin Eastin Offsets TRS Location 5,962,212.9' 604,158.5' 3210' FNL / 3745' FEL 11 N, 12 E, 17 TD Planned KOP: 5,118' and Planned S ud: 07/14/06 Ri Nabors ES/ .~ Planned TD: 11,750' and Planned TVD: 9,197' tvd GL: 54.34' Directional Program RTE: 82.84' A roved Well lan: WP08 KOP: 5,118' and / 4,871' tvd Maximum Hole Inclination: ~34° at 4,300' in the original well bore, ~59° at 7,747' in the planned 8-1/2 hole. Proximity Issues: All wells pass BP's major risk criteria scan. Details are listed in the attached Anti-Collision re ort. Surve Pro ram: Standard MWD+IIFR+MS Nearest Well: Well Z-100, with acenter-to-center distance of 109' at 5,514' md. Nearest Property Line 11,850' Wells within ~/a mile of this Well Name Distance Comments injection well @ top of reservoir Z-15 i ~~ o $$ 1050' 01/11/02 passed MIT- IA to 3000 si t~G~- ~~a~~' I $q oS z. r Z-14B Permit to Drill Page 1 • • Logging Program Hole Section: Required Sensors /Service 8-1/2" intermediate MWD DIR/GR/RES/PWD/DEN/NEU throughout the interval all in real-time mode. 6-1/8" production: DIR/GR/RES/DEN/NEU throughout the interval all in real-time mode. Two sam le catchers will be re wired at com an man call out. Cased Hole: USIT w/CBL Lo tanned from 7" drillin liner shoe to the to of the 7" liner. r' O en Hole: None tanned Mud Program Fresh water LSND Hole Section / o eration: 8-1/2" Intermediate Hole 2 Depth Density LOW PV YP API FL ft () (ppg) Gravity (cp) (Ib/100ft2) (mU30min) pH MBT Solids 5,118 window 9.0 <6.0 15-22 30-40 NC 9.0-9.5 <20.0 millin 5,150' - 9.0-9.2 <6.0 15-22 22-30 <8.0 9.0-9.5 <20.0 7,128' 7,128' - 1.2 <6.0 18-28 22-28 <6.0 9.0-9.5 <20.0 11,057' FloPro SF Hole Secti on / o eration: 6-1/8" Production Hole Depth Density LSRV PV YP 2 API FL H p Chlorides MBT (ft) (ppg) (cP) (Ib/100ft) (ml/30min) (mg/I) 11, 057' - 8.4 >20,000 8-15 24-30 <7.0-9.0 9.0-9.5 <600 <20.0 11,750' Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade i Connection Length Top and / tvd Bottom and / tvd 8-1 /2" 7" 26.0# L-80 BTC-M 6,089' 4,968' / 4,745' 11,057'/ 8,583' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 793' 10,957'/ 8,512' 11,750'/ 9,197' Tubin 4-1/2" 12.6# L-80 IBT-M 10,957' Surface 10,957'/ 8,512' Z-146 Permit to Drill Page 2 • • Cementing Program Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner (1S Sta e) Slurry Design Basis: Lead slurry: 2,195' of 8-1/2" x 7" annulus with 40% excess. Tail slurry: 1,000' of 8-1/2" x 7" annulus with 40% excess, plus 100' of 7", 26# shoe track Pre-Flush None Planned Fl id S /V l S acer 30bbls MudPUSH II at 11.6 u equence ume: s o Lead Slur 63bbls / 354 ft / 148 sx Lite Crete, 12.0 ; 2.39 ft /sk. Tail Slur 36bbls / 202 ft / 174 sx Class `G', 15.8 ; 1.16 ft /sk. BHST: 200° ill b fl C t i th d BHCT: 137° emen w y e m xe on e Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner (2S Sta e) Slurry Design Basis: Lead slurry: 1,744' of 8-1/2" x 7" annulus with 40% excess, plus 150' of 9-5/8" X 7" liner lap, plus 200' of 9-5/8" X 4" drill pipe annulus. Tail slur :1,000' of 8-1/2" x 7" annulus with 40% excess. Pre-Flush None Planned Fl id S /V l S acer 30bbls MudPUSH II at 11.6 equence u s o ume: Lead Slur 71 bbls / 399 ft / 168 sx Lite Crete, 12.0 ; 2.39 ft /sk. 753 Tail Slur 36bbls / 202 ft / 174 sx Class `G', 15.8 ; 1.16 ft /sk. 404 BHST: 170° ill b fl C t i h d BHCT: 115° emen w y e m xe on t e Casin Strin 4-1 /2", 12.6#, L-80, IBT-M solid roduction liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 693' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 100' of 4; 1/2 , 12.6# shoe track, plus 100 of 7 X 4-1/2 liner lap, plus 200 of 7 X 4 drill i e annulus. Pre-Flush 10bbls CW 100 Fl id S /V l S acer 10bbls MudPUSH II at 10.5 u s equence o ume: Lead Slur None tanned Tail Slur 24bbls / 135 ft / 11 sx Class `G', 15.8 ; 1.1 t /sk. BHST: 230° ill b t i C t b h i d b f BHCT: 141 ° emen w ore pump ng e a c m xe e Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9-5/8" Casin to surface Landin collar to surface 30 min recorded 4,000 si surface 9-5/8" Casin shoe 20' be and middle of window FIT 11.6 EMW 7" Casin to surface Liner Landin collar to surface 30 min recorded 4,000 si surface 7" shoe 20' be and shoe FIT 9.7 EMW 4-1/2 liner to surface Liner Landin collar to surface 30 min recorded 4,000 si surface Z-146 Permit to Drill Page 3 • Well Control • Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8-1/2" intermediate interval Maximum antici ated BHP: 3,700 psi at 8,500' TVD. Maximum surface ressure: 2,850 Si (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 117 BBLS with 11.6 EMW FIT FIT TO 11.6 PPG EMW Planned BOPE test pressure: 250 psi low / 4,000 psi high - 7 day test cycle until the whipstock is icked u .Once whi stock is icked u a 14 da test c cle be ins. BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Well Interval: 6-1/8" production section Maximum antici ated BHP: 3,700 psi at 8,500' TVD. Maximum surface ressure: 2,850pS1 (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 9.7 EMW FIT FIT to 9.7 EMW Planned BOPE test pressure: 250psi low / 4,000psi high Planned com letion fluid: 8.4 p seawater / 7.Op Diesel Planned BOPE test ressure: 250 si low / 4,000 si hi h -14 da test c cle. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling; Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. j)e,~~ ,---- Z-14B Permit to Drill Page 4 • Geologic Prognosis • Formation ssTVD ft MD ft Est. Pressure PSI OBf 4775 5102 OBf base 4830 5168 CM2 5200 5673 CM1 5810 6570 THRZ 6310 7328 BH RZ 6520 7690 TKUP 6550 7747 2800 si TMLV 6610 7862 TKG 7250 9097 TJF 7500 9556 TJE 7610 9742 TJD 7930 10244 TJC 8165 10583 TJB 8315 10795 TJA 8430 10958 TSGR 8500 11057 3700 si TSHU 8530 11099 TEIL 8640 11238 TSAD 8690 11296 45P 8720 11329 3580 si 44P 8750 11362 3600 si 43P 8785 11399 3601 si PGOC 8800 11415 3602 si 42P 8820 11437 3603 si 41 P 8860 11479 3604 si 31 P 8890 11511 3605 si OWC 8940 11564 3606 si 27P 8950 11575 3607 si TD Criteria TD Criteria: Drill to the Top of the Sag River Formation. Intermediate TD Criteria: Drill to TD of plan. Minimum of 100' and below the original OWC (8975' ssTVD) Production needed to get logs across. Z-14B Permit to Drill Page 5 • • Fault Prognosis Formation where encounter the Est. MD SSTVD Est. Throw Throw Uncertainty Fault Intersect Intersect Direction Fault #1 - CM2 5732' 5240' 40' D to W 100' Fault #2 -above ~g397' 7410 75' D to W 100' Kin ak TJF Fault #3 -Kingak 10952' 8426' 30' D to E 100' TJA Fault #2 was crossed byZ-14 without incident in 1988. Z-14 had losses of 1000 bbls at 10,325 ft. MD (in the 14N). This is most likely related to a series of N-S striking faults crossed in the lower Ivishak. Z-i46 is not expected to cross any of these faults. Fault #3 is prognosed in Kingak TJA and may add uncertainty to correlations in Lower Kingak on approach to intermediate casin t. Operations Summary Pre-Rig Work: 1. Rig up slickline. Pull PX plug from TP. Drift 4-1/2" x 2-7/8" tubing. Tag and record PBTD below 2-7/8" liner top. 2. Fluid pack the tubing and inner annulus. 3. P&A perfs in 2-7/8" liner from PBTD to 9,000' MD. RIH with coil to PBTD (11,590' MD). Lay in 22.2 bbls of cement to 9,000' MD (Above top of production packer). Attempt to squeeze 5 BBLS into perforations. Wash down to confirm TOC is no deeper than 9,000'. POH with coil. a. Cement Calculations: • 2-7/8" liner = 11,590' - 9,230' or 2,360' 013.7 BBLS) • 4-1/2" tubing = 9,230' - 9,000' or 2230' (--3.5 BBLS) • Squeeze = 5 BBLS • Total cement volume of 22.2 BBLS 4. Rig up slickline, drift 4-1/2". Tag & record TOC. 5. Jet cut the 4-1 /2" tubing at ~ 5,400' MD. 6. Pressure test T X IA to 4,000 psi for 30 minutes. Pressure test the OA to 2,000 psi for 30 minutes. 7. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to 2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 4,000 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from above pre-rig cut at 5400'. 5. RU a-line. Run GR/JB for 9-5/8", 47# casing to just above the tubing stub at ~5400'MD. 6. MU 9-5/8", 47# bridge plug on a-line with CCL & GR. RIH and set at 5138' MD, set as needed to avoid cutting a casing collar during window milling operations. 7. Pressure test casing to 4,000 psi for 30 minutes. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Swap over to 9.0 ppg LSND drilling and milling fluid. ~ 10. Mill window in 9-5/8" casing at 5118' MD (top of window) plus 20' past middle of window. Perform FIT to 11.6 ppg EMW. POOH. 1~~ l~ - ~~ 1 ~~-rotla. ( . Z-14B Permit to Drill -' Page 6 • • 11. MU 8-1/2" drilling assembly with Dir/GR/RES/DEN/NEU and RIH. Kick off and drill the 8-1/2" intermediate interval to 200' above the TOP of the HRZ. Weight up to 11.2 ppg mud and drill ahead to 7" casing point, section TD, at Top Sag River. ~ 12. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150' ° of overlap. 13. Test BOPE, then MU 6-1/8" BHA with Dir/GR/RES/DEN/NEU and RIH to the landing collar. 14. Pressure test wellbore to 4,000 psi for 30 minutes. ~ 15. Drill shoe track. Swap over to 8.4 ppg FloPro SF mud and drill 20' of new formation. Perform FIT to 9.7 ppg EMW. 16. Drill the 6-1/8" production interval dropping angle to TD. TD will be 100' and below the original OWC that was at 8975' ssTVD. Condition well bore for the 4-1/2" solid, cement liner. POOH, LD DP and ~- drilling assembly. 17. RU e-line. RIH w SI to 7" shoe. Log USIT from 7" shoe to top of 7" liner. POOH and RD a-line. ~ 18. Run and cement 4-1/2" solid liner extending the liner lap 100' into the 7" drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. Note: A perf pill will be left in " j' the 4-1/2 liner. 19. Run 4-1/2", 12.6#, L80, TCII completion tying into the 4-1/2" liner top. Note: Well maybe pre-produced and require 3 GLM's. The decision will be made after determining the oil column thickness with MWD logs. 20. Freeze protect the well to 2,000' and then set 7" x 4-1/2" packer and individually test the tubing to/- 4,000 psi and annulus to 4000 psi for 30 minutes each. 21. Set and test TWC. 22. ND BOPE. NU and test the tree to 5000 psi. 23. RDMO Post-Rig Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 3. Perforate the well f Z-14B Permit to Drill Page 7 • r Job 1: Move In / Rig Up /Test BOPE Reference RP • "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. • "Hydrogen Sulfide"SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto Z-14A. However, Z-13 is about 35' to the West and Z-15 is about 35' to the East of Z-14A. Z-13 and Z-15 are the closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - The Z-14A well bore will be secured with the following barriers: • Note on barriers during MIRU procedures: ^ Tubing -Tested Cement plug (P&A perfs), Kill weight fluid and a BPV. ^ IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. ^ OA -Tested OA, Kill weight fluid, zero pressure on annulus and annular valve. • Note on barriers during ND Tree / NU BOP Procedures ^ Tubing -Tested Cement plug (P&A perfs), Kill weight fluid and a TWC. ^ IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. ^ OA -Tested OA, Kill weight fluid, zero pressure on annulus and annular valve. - Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. - Verify the tubing hanger type and connection during ND. Z-pad is not considered as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL with H2S Readin Z-13 10 m 6/8/2005 #2 Closest SHL with H2S Readin Z-15 10 m 7/2/2005 #1 Closest BHL with H2S Readin Z-24 5 m 1/31/2005 #2 Closest BHL with H2S Readin W-44 NA H2O in' Max Recorded H2S Readin on the Pad Z-35 20 8/17/2000 • Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Z-14B Permit to Drill Page 8 r ~ Job 2: De-complete Well Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static prior to pulling the completion. - Note and record required PU weight to pull tubing from cut point (5,400'). - Have all wellhead and completion equipment NORM-tested, following retrieval. - The existing wellhead is a McEvoy completed in 1988. The historic records are unclear, but it appears to have the 9-5/8" casing set on a mandrel hanger and packoff. The current completion is a 4-1/2" 12.6#, L-80, AB-Mod Buttress thread tubing. The top lift threads are unknown at this time. Have a spear on location as a contingency to pull the Hanger to the floor. Ensure Baker has contingency grapples on location for different weight tubing pups. - There is a 4-1/2" Camco Ball Valve Nipple (BVN) at 1,932'. There should be 2, ~/a" encapsulated control lines run to surface from the BVN. There should be 23 control line of protectors and 4 SS bands securing these control lines. Job 3: Run Whip Stock Reference RP • "Whipstock SidetracK' RP. • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards - BOP test interval during this phase is 7 days until the whipstock is picked up. Once the whipstock is picked up the 14 day test cycle starts and continues until the rig moves off the well. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. - A 9-5/8" whip stock will be run and set in the existing 9-5/8" 47# casing. A 8-1 /2" window will then be milled in the 9-5/8" 47# casing. Ensure entire wellbore has been circulated to 9.0 ppg mud before milling commences. - Cement is expected behind the 9-5/8" casing at the sidetrack point. - Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. - Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Z-146 Permit to Drill Page 9 • • Job 5: Drill Intermediate (8-1/2") Hole Reference RP • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "Shale Drilling- Kingak &HRZ" Issues and Potential Hazards - Z-14B is expected to cross three mapped faults in the 8-1/2" intermediate hole section. Losses and/or well bore stability is not expected from these faults. If losses/breathing are encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. - KICK TOLERANCE: In the worst case scenario of 9.0 ppg pore pressure at the 7" TD depth, gauge hole, a fractur -gradient of 11.6 ppg at the 8-1/2" casing window, 11.2 ppg mud in the hole, the kick tolerance i 117 ~$LS. FIT will be to 11.6 ppg. - Ensure Mud Weigh _& Out, are recorded in DIMS before every trip. - Ensure the ROPE function tests are recorded in DIMS every 7 days. Phase 6: Run and Cement Intermediate Liner Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Hazards and Contingencies - Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ/Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the liner is left stationary across permeable formations. Proper casing centralization and keeping the liner moving will facilitate minimizing the potential for differential sticking. - Z-146 has the possibility of crossing three faults in the 8-1/2" interval. Detailed depth listed on page 6. - 7" drilling liner will be cemented in 2 stages. Cement will be brought up to the top of the 7" liner. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. - Ensure there is a Halliburton representative on location for the entire 7" liner job. Z-14B Permit to Drill Page 10 • r Job 7: Drill Production Hole Interval Reference RP • "Leak-off and Formation Integrity Tests" SOP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - The Z-14B wellbore does not cross any mapped faults in the production interval. - Differential sticking is a concern. The 8.4 ppg mud will be 310 psi over balanced to the Ivishak formation when static. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). - An EMI-920 sweep will be pumped just ahead of the new Flo-Pro mud during displacement after drilling the shoe track. - A liner running pill will be left in the open hole on the final trip out of the hole to run the solid liner. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Job 9: Run Production Liner Reference RP • "Modified Conventional Liner Cementincf RP • Schlumberger Cement Program. Issues and Potential Hazards - The completion design is to run a 4-1/2", 12.6#, L-80 IBT-M solid liner throughout the production interval - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 310 psi over balanced to the Ivishak formation when static. Minimize the time the pipe is left stationary while running the liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will be run to extend 100' above the bottom of the 7" liner shoe. - A Hi-Vis perforation pill will be spotted in the 4-1/2" liner as per MIDF recommendations. Perforation will be done Post Rig. Drilling Engineer will provide Cost estimate to place in DIM's. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Z-146 Permit to Drill Page 11 • • Job 12: Run Completion Reference RP • "Completion Design and Running' RP • "Casing and Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well to 2,200'. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 psia at 100° F. - The completion, as designed, will be to run a 4-1/2", 12.6#, L-80, TCII production tubing string, stinging into the 4-1/2" production liner tieback sleeve. • There is the possibility that this well will be pre-produced. This decision will be made by the Anchorage ASSET team once the MWD logs are evaluated. If the well is pre- produced then three GLM's will be included in the completion. - This is an injector so pressure test tubing and IA to 4,000 psi. - Ensure Mud Weights, In & Out, are recorded in DIMS before every trip. - Ensure the BOPE function tests are recorded in DIMS every 7 days. Job 13: ND/NU/Release Rig Reference RP • "ADW Rig Move" RP. • "Freeze Protecting an Inner Annulus" RP. Issues and Potential Hazards - No wells will require shut-in for the rig move off Z-146. However, Z-13 is about 35' to the West and Z-15 is about 35' to the East of Z-14B. Z-13 and Z-15 are the closest surface neighboring wells. Care should be taken while moving off the well. Spotters should be employed at all times. - The Z-14B well bore will be secured with the following barriers: • Note on barriers during ND BOPE / NU Tree procedures: ^ Tubing -Tubing -Non-perforated liner, Kill weight fluid on a RHC plug with ball & rod and a TWC. ^ IA -Kill weight fluid, tested annulus and annular valve. ^ OA -Tested OA, Kill weight fluid, zero pressure on annulus and annular valve. • Note on barriers during RDMO Procedures ^ Tubing -Non-perforated liner, Kill weight fluid on a RHC plug with ball & rod and a BPV. ^ IA -Kill weight fluid, tested annulus and annular valve. ^ OA -Tested OA, Kill weight fluid, zero pressure on annulus and annular valve. Z-14B Permit to Drill Page 12 Scer~r Z-14B (P8) Pro posal Report Date: June 28, 2006 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Field: BP Exploration Alaska Prudhoe Bay Unit - WOA Vertical Section Azimuth: O~ Vertical Section Origin: 58.530° N 0.000 ft, E 0.000 ft Structure 1 Slot: Z-PAD / Z-14 ~ O~'Z ' TVD Reference Datum: Rotary Table Well: Z-14 ~OVe TVD Reference Elevation: 82.84 ft relative to MSL Borehole: Plan Z-146 ppp Sea Bed 1 Ground Level Elevation: 54.34 ft relative to MSL UWIIAPI#: 500292185902 Magnetic Declination: 24.061 ° Survey Name 1 Date: Z-14B (P8) /June 6, 2006 Total Field Strength: 57621.705 nT Tort 1 AHD 1 DDI I ERD ratio: 177.968° / 5881.67 ft / 6.126 / 0.64C Magnetic Dip: 80.860° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: July 07, 2006 Location LaULOng: N 70.29768537, W 149.19358626 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5959100.020 ftUS, E 599579.930 ftUS North Reference: True North Grid Convergence Angle: +0.75920951 ° Total Corr Mag North •> True North: +24.061 ° Grid Scale Factor. 0.99991126 Local Coordinates Referenced To: Well Head • Comments Measured InGination Azimuth Sub•Sea TVD TVD Vertical NS EW DLS Mag 1 Grav guild Rate Walk Rate Northing Easting Lathude longitude Depth Section Tool Face ft de de ft ft ft ft ft d 100 ft de d 100 ft de 100 ft ftUS ftUS Tie-In survey bUyU.t34 :i1.:ib 4ti.5U 4/EiS./5 4tl4ti.ti;i y11.1J ti44.U1 (iti5.51 U.'LS 15y./4K -U.1"L -U.1U 5y5y/S;i.U1 tiUULS/.1 ZS N /U.1yy444tiy W 14y.1t12fU31y;S 5100.00 32.31 46.53 4773.53 4856.37 926.02 647.39 689.46 0.46 159.71 R -0.43 0.30 5959756.43 600260.69 N 70.29945390 W 149.18800314 Top Whipstock 5118.00 32.23 46.58 4788.75 4871.59 935.42 654.00 696.44 0.46 32.OOR -0.43 0.30 5959763.13 600267.58 N 70.29947195 W 149.18794663 Base Whipstock 5134.00 33.87 48.41 4802.16 4885.00 943.99 659.89 702.87 12.00 --- 10.26 11.41 5959769.10 600273.93 N 70.29948805 W 149.18789452 KOP Crv 4/100 5146.00 33.87 48.41 4812.12 4894.96 950.57 664.33 707.87 0.00 32.83R 0.00 0.00 5959773.61 600278.88 N 70.29950018 W 149.18785401 Base Oef 5167.62 34.60 49.23 4830.00 4912.84 962.56 672.34 717.03 4.00 32.15R 3.37 3.82 5959781.74 600287.93 N 70.29952206 W 149.18777985 5200.00 35.71 50.41 4856.47 4939.31 980.99 684.37 731.28 4.00 31.18R 3.40 3.65 5959793.95 600302.01 N 70.29955491 W 149.18766449 5300.00 39.18 53.69 4935.86 5018.70 1041.38 721.68 779.24 4.00 28.58R 3.47 3.28 5959831.89 600349.47 N 70.29965683 W 149.18727608 5400.00 42.72 56.51 5011.39 5094.23 1106.78 759.12 833.00 4.00 26.45R 3.55 2.82 5959870.04 600402.73 N 70.29975909 W 149.18684065 5500.00 46.33 58.97 5082.67 5165.51 1176.88 796.49 892.31 4.00 24.69R 3.61 2.46 5959908.19 600461.53 N 70.29986119 W 149.18636033 Crv 4/100 5545.73 48.00 60.00 5113.76 5196.60 1210.40 813.52 921.20 4.00 103.84E 3.64 2.25 5959925.60 600490.19 N 70.29990768 W 149.186 37 5600.00 47.52 57.14 5150.25 5233.09 1250.57 834.46 955.48 4.00 101.92E -0.89 -5.27 5959946.99 600524.19 N 70.29996488 W 149.18 CM2 5673.27 46.98 53.22 5200.00 5282.84 1304.27 865.16 999.64 4.00 99.26E -0.74 -5.36 5959978.27 600567.93 N 70.30004875 W 149.18 3 5700.00 46.81 51.77 5218.26 5301.10 1323.67 877.04 1015.12 4.00 98.27E -0.61 -5.41 5959990.36 600583.25 N 70.30008120 W 149.18536577 Fault #1 5731.71 46.64 50.04 5240.00 5322.84 1346.55 891.60 1033.04 4.00 97.08E -0.53 -5.44 5960005.15 600600.97 N 70.30012096 W 149.18522064 5800.00 46.37 46.30 5287.01 5369.85 1395.27 924.63 1069.94 4.00 94.51 L -0.40 -5.49 5960038.66 600637.43 N 70.30021117 W 149.18492176 5900.00 46.19 40.77 5356.15 5438.99 1465.03 976.98 1119.68 4.00 90.68E -0.18 -5.53 5960091.66 600686.47 N 70.30035417 W 149.18451887 6000.00 46.27 35.23 5425.36 5508.20 1532.60 1033.84 1164.10 4.00 86.85E 0.09 -5.54 5960149.10 600730.13 N 70.30050950 W 149.18415907 6100.00 46.63 29.73 5494.28 5577.12 1597.66 1094.94 1202.99 4.00 83.06E 0.35 -5.50 5960210.71 600768.19 N 70.30067641 W 149.18384412 6200.00 47.24 24.32 5562.60 5645.44 1659.89 1159.98 1236.14 4.00 79.36E 0.61 -5.41 5960276.17 600800.48 N 70.30085407 W 149.18357554 End Bld 6298.59 48.08 19.11 5629.02 5711.86 1718.18 1227.65 1263.06 4.00 --- 0.86 -5.29 5960344.18 600826.50 N 70.30103892 W 149.18335745 CM1 6569.50 48.08 19.11 5810.00 5892.84 1873.90 1418.14 1329.05 0.00 --- 0.00 0.00 5960535.51 600889.95 N 70.30155930 W 149.18282278 Crv 4/100 6983.86 48.08 19.11 6086.81 6169.65 2112.09 1709.49 1429.97 0.00 81.12R 0.00 0.00 5960828.15 600987.00 N 70.30235520 W 149.18200496 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-14\Z-14\Plan Z-14B~Z-146 (P8) Generated 6/28/2006 4:38 PM Page 1 of 3 Comments Measured InGination Azimuth Sub•Sea TVD TVD Vertical NS EW DLS Mag 1 Grav guild Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de 1100 ft d de 100 k de 100 ft ftU5 ftUS THRZ BHRZ TKUP Z-14B Tgt 1 TMLV End Crv Top Kingak Drp 1/100 Fault #2 TJF TJE TJD End Drp TJC TJB / UUU. V U 7100.00 7200.00 7300.00 7328.37 7400.00 7500.00 7600.00 7689.88 7700.00 7746.93 7746.94 7800.00 7862.43 7900.00 8000.00 8100.00 8149.26 9097.14 9143.25 9200.00 9300.00 9398.92 9400.00 9500.00 9556.03 9600.00 9700.00 9742.19 9800.00 9900.00 10000.00 10100.00 10200.00 10243.74 10300.00 10400.00 10500.00 10526.95 10583.19 10795.32 423.1`) -I y.~U C)Vy/. 523 t7-I 23U.4L LI L1.4J 48.96 25.20 6163. 76 6246.60 2182.10 49.97 30.29 6228. 78 6311.62 2247.37 51.19 35.22 6292. 29 6375.13 2316.91 51.58 36.59 6310. 00 6392.84 2337.37 52.62 39.97 6354. 01 6436.85 2390.39 54.22 44.54 6413. 62 6496.46 2467.44 55.99 48.91 6470. 84 6553.68 2547.70 57.71 52.68 6520. 00 6602.84 2622.25 57.91 53.10 6525. 39 6608.23 2630.77 58.86 55.00 6549. 99 6632.83 2670.61 58.86 55.00 6550. 00 6632.84 2670.62 58.70 58.57 58.53 58.52 58.69 58.84 58.84 58.84 58.27 57.27 56.28 56.27 55.27 54.71 54.27 53.27 52.85 52.27 51.27 50.27 49.27 48.27 47.83 47.27 46.27 45.27 45.00 45.00 45.00 57.47 60.40 62.16 66.85 71.53 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.83 73.84 73.84 73.84 73.84 73.84 6577.50 6610.00 6629.61 6681.84 6733.95 6759.50 7250.00 7273.86 7303.47 7356.80 7411.00 7411.60 7467.85 7500.00 7525.54 7584.64 7610.00 7645:14 7707.02 7770.27 7834.85 7900.76 7930.00 7967.97 8036.47 8106.22 8125.23 8165.00 8315.00 6660.34 6692.84 6712.45 6764.68 6816.79 6842.34 7332.84 7356.70 7386.31 7439.64 7493.84 7494.44 7550.69 7582.84 7608.38 I /LU.23L 1790.00 1857.22 1922.13 1940.09 1984.44 2043.82 2100.00 2147.54 2152.70 2176.16 2176.17 2201.38 2228.89 2244.29 2280.99 2311.30 2323.84 2549.76 2560.75 2574.23 2597.79 2620.84 2621.09 2644.12 2656.90 2666.87 1433.yy 1462.78 1498.16 1539.96 1552.96 1587.98 1641.97 1701.68 1759.99 1766.82 1799.17 1799.18 1836.90 1882.55 1910.66 1987.61 2067.36 2107.57 2886.57 2924.47 2970.96 3052.21 3131.68 3132.54 3211.95 3256.03 3290.40 3367.87 3400.26 3444.34 3519.79 3594.18 7667.48 4276.48 2689.33 7692.84 4309.00 2698.72 7727.98 4353.27 2711.50 7789.86 4429.04 2733.38 7853.11 4503.75 2754.95 7917.69 4577.39 2776.20 7983.60 4649.93 2797.14 8012.84 4681.31 2806.20 8050.81 4721.35 2817.76 8119.31 4791.62 2838.04 8189.06 4860.74 2857.99 8208.07 4879.16 2863.31 8247.84 4917.52 2874.38 8397.84 5062.20 2916.14 2715.95 2769.25 2801.26 2886.05 2969.90 3010.74 3793.10 3831.16 3877.86 3959.45 4039.27 4040.14 4119.88 4164.15 4198.67 WeIlDesign Ver SP 2.1 Bld(doc40x_100 ) 3667.51 3739.74 3770.98 3810.86 3880.84 3949.66 3968.00 4006.20 4150.27 4.VV OU.OJK U.V4 4.00 77.09R 0.78 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 1.00 0.00 0.00 73.77R 70.64R 69.79R 67.71 R 64.99R 62.49R 60.42R 60.20R HS 94.98R 93.70R 92.18R 91.26R 88.81 R 86.37R LS LS LS LS LS LS LS LS LS LS LS LS LS LS LS LS LS LS LS 1.01 1.22 1.35 1.45 1.61 1.77 1.91 1.98 2.02 2.05 -0.30 -0.21 -0.12 0.00 0.17 0.29 0.00 0.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 -1.00 0.00 0.00 Z-14\Z-14\Plan Z-146\Z-146 (P8) V.JV VyOVOJ.7.JJ VVV7.7V.01 IV /V.JVLJOV IJ VV IY~.101y1 LJ.7 5.23 5960909.08 601018.74 N 70.30257513 W 149.18173911 5.09 5960976.75 601053.22 N 70.30275873 W 149.18145245 4.93 5961042.21 601094.15 N 70.30293605 W 149.18111381 4.82 5961060.34 601106.91 N 70.30298510 W 149.18100849 4.72 5961105.14 601141.33 N 70.30310623 W 149.18072482 4.56 5961165.23 601194.53 N 70.30326844 W 149.18028740 4.37 5961222.19 601253.49 N 70.30342189 W 149.17980367 4.20 5961270.49 601311.16 N 70.30355171 W 149.17933131 4.11 5961275.75 601317.92 N 70.30356582 W 149.17927598 4.06 5961299.63 601349.95 N 70.30362988 W 149.17 4.01 5961299.64 601349.96 N 70.30362991 W 149.17 4.66 5961325.35 601387.34 N 70.30369877 W 149.17870830 4.68 5961353.45 601432.61 N 70.30377387 W 149.17833850 4.69 5961369.22 601460.51 N 70.30381593 W 149.17811080 4.69 5961406.94 601536.96 N 70.30391613 W 149.17748749 4.68 5961438.30 601616.30 N 70.30399889 W 149.17684141 4.67 5961451.37 601656.34 N 70.30403312 W 149.17651571 0.00 5961687.57 602432.20 N 70.30464960 W 149.17020544 0.00 5961699.06 602469.95 N 70.30467958 W 149.16989843 0.00 5961713.16 602516.26 N 70.30471637 W 149.16952176 0.00 5961737.79 602597.17 N 70.30478065 W 149.16886363 0.00 5961761.88 602676.33 N 70.30484352 W 149.16821984 0.00 5961762.15 602677.19 N 70.30484420 W 149.16821283 0.00 5961786.22 602756.27 N 70.30490701 W 149.16756957 0.00 5961799.58 602800.17 N 70.30494188 W 149.16721250 0.00 5961810.00 602834.41 N 70.30496907 W 149.16693403 0.00 5961833.49 602911.57 N 70.30503034 W 149.16630643 0.00 5961843.31 602943.83 N 70.30505596 W 149.1 4 0.00 5961856.67 602987.73 N 70.30509082 W 149.1 3 0.00 5961879.54 603062.88 N 70.30515048 W 149.165 574 0.00 5961902.09 603136.97 N 70.30520931 W 149.16447305 0.00 5961924.32 603210.00 N 70.30526729 W 149.16387902 0.00 5961946.21 603281.94 N 70.30532440 W 149.16329386 0.00 5961955.68 603313.06 N 70.30534910 W 149.16304074 0.00 5961967.77 603352.77 N 70.30538062 W 149.16271772 0.00 5961988.97 603422.47 N 70.30543594 W 149.16215080 0.00 5962009.83 603491.02 N 70.30549034 W 149.16159326 0.00 5962015.39 603509.29 N 70.30550484 W 149.16144461 0.00 5962026.97 603547.33 N 70.30553503 W 149.16113517 0.00 5962070.62 603690.82 N 70.30564889 W 149.15996799 Generated 6/28/2006 4:38 PM Page 2 of 3 Measured Vertical Mag 1 Grav Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de 1100 ft de de 100 ft de 1100 ft ftUS ftUS raWI7FJ IV~JDGJU 40.VU /3.tl4 04LO.UV tlOVd.2J4 D70`J.LO LY4/.V4 4ZDb.tf25 V.VV --- V.VU U.UU O`JOLIUL.`JJ OVJ/J/.U7 !V /V.JUD/JJ7J W 74`J.70`J7 U4L0 TJA 10957.96 45.00 73.84 8430.00 8512.84 5173.12 2948.15 4260.72 0.00 --- 0.00 0.00 5962104.10 603800.83 N 70.30573619 W 149.15907313 TSGR 11056.94 45.00 73.84 8499.99 8582.83 5240.63 2967.64 4327.95 0.00 --- 0.00 0.00 5962124.47 603867.79 N 70.30578931 W 149.15852851 Z-146 Tgt 2 11056.95 45.00 73.84 8500.00 8582.84 5240.63 2967.64 4327.96 0.00 --- 0.00 0.00 5962124.47 603867.79 N 70.30578932 W 149.15852845 7" Csg Pt 11056.97 45.00 73.84 8500.01 8582.85 5240.64 2967.64 4327.97 0.00 --- 0.00 0.00 5962124.47 603867.80 N 70.30578933 W 149.15852836 Drp 8/100 11076.95 45.00 73.84 8514.14 8596.98 5254.28 2971.58 4341.54 0.00 LS 0.00 0.00 5962128.59 603881.32 N 70.30580005 W 149.15841840 TSHU 11099.04 43.23 73.84 8530.00 8612.84 5269.11 2975.86 4356.31 8.00 LS -8.00 0.00 5962133.06 603896.03 N 70.30581172 W 149.15829874 11100.00 43.16 73.84 8530.70 8613.54 5269.74 2976.04 4356.94 8.00 LS -8.00 0.00 5962133.25 603896.66 N 70.30581222 W 149.15829365 11200.00 35.16 73.84 8608.18 8691.02 5330.59 2993.60 4417.54 8.00 LS -8.00 0.00 5962151.62 603957.01 N 70.30586011 W 149.15780270 TEIL 11238.22 32.10 73.84 8640.00 8722.84 5351.01 2999.49 4437.86 8.00 LS -8.00 0.00 5962157.78 603977.26 N 70.30587617 W 149.15763800 TSAD 11295.85 27.49 73.84 8690.00 8772.84 5378.62 3007.46 4465.36 8.00 LS -8.00 0.00 5962166.11 604004.65 N 70,30589789 W 149.1574 11300.00 27.16 73.84 8693.68 8776.52 5380.45 3007.99 4467.19 8.00 LS -8.00 0.00 5962166.66 604006.47 N 70.30589934 W 149.15743 45P 11329.28 24.81 73.84 8720.00 8802.84 5392.83 3011.56 4479.51 8.00 LS -8.00 0.00 5962170.40 604018.74 N 70.30590907 W 149.15730062 44P 11362.00 22.20 73.84 8750.00 8832.84 5405.41 3015.19 4492.04 8.00 LS -8.00 0.00 5962174.19 604031.22 N 70.30591897 W 149.15719909 End Drp 11389.45 20.00 73.84 8775.61 8858.45 5414.94 3017.95 4501.53 8.00 --- -8.00 0.00 5962177.07 604040.67 N 70.30592647 W 149.15712218 43P 11399.44 20.00 73.84 8785.00 8867.84 5418.24 3018.90 4504.81 0.00 --- 0.00 0.00 5962178.06 604043.94 N 70.30592906 W 149.15709560 42P 11436.69 20.00 73.84 8820.00 8902.84 5430.52 3022.44 4517.05 0.00 --- 0.00 0.00 5962181.77 604056.13 N 70.30593873 W 149.15699647 41 P 11479.25 20.00 73.84 8860.00 8942.84 5444.57 3026.49 4531.03 0.00 --- 0.00 0.00 5962186.01 604070.05 N 70.30594978 W 149.15688318 31P 11511.18 20.00 73.84 8890.00 8972.84 5455.10 3029.53 4541.52 0.00 --- 0.00 0.00 5962189.18 604080.50 N 70.30595806 W 149.15679821 27P 11575.03 20.00 73.84 8950.00 9032.84 5476.16 3035.61 4562.50 0.00 --- 0.00 0.00 5962195.54 604101.39 N 70.30597463 W 149.15662827 11649.52 20.00 73.84 9020.00 9102.84 5500.73 3042.70 4586.97 0.00 --- 0.00 0.00 5962202.95 604125.76 N 70.30599396 W 149.15643001 TD / 4-1 /2" Lnr 11749.52 20.00 73.84 9113.97 9196.81 5533.72 3052,22 4619.82 0.00 --- 0.00 0.00 5962212.90 604158.48 N 70.30601991 W 149.15616386 Survey Tvge: Definitive Proposal Legal Descriation: Surface : 4298 FSL 3098 FEL 819 T11N R12E UM Tie-In : 4298 FSL 3098 FEL S19 T11 N R12E UM Z-14B Tgt 1 : 1194 FSL 1290 FEL S18 T11 N R12E UM Z-146 Tgt 2 : 1984 FSL 4038 FEL S17 T11 N R12E UM BHL : 2069 FSL 3746 FEL S17 T11 N R12E UM Northing IY) tftUSl Easting (X) fftUSl 5959100. 02 599579. 93 5959099. 66 599579. 89 5961299. 64 601349. 96 5962124. 47 603867. 79 5962212. 90 604158. 48 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-14~Z-14\Plan Z-146~Z-146 (P8) Generated 6/28/2006 4:38 PM Page 3 of 3 • • Schiumherger WELL FIEIU STRUC TiiRE Z-146 (P8) Prudhoe Bay Unit - WOA Z-PAD i 1600 2400 3200 4000 4800 5600 4800 5600 6400 0 0 ao c a> U ~ 7200 H 8000 8800 9600 n Survey p Whipstock Base Whipstock _....Ktlp'CFv~dl1'06 CM2 End Bld CM1 crv e/too i .. _.._..~.._.._.._.._.._.._.._.._.._.._.._.._.._.. _.t... _.. _.. _.. _.. _.._.. _.. ..t.. _.. _.. _.. _.. _.._.._.. _.._~. _.._.. _.._.._.._..~. ._.. _.. _..-..-.. ~..-. _.._.._.._.._..-.._.. _.. _.t-.~.. _.. _.. _.. _.. _.. _.._ t .._.._.._.._.._.._.._.._i._.._.._.._.._.._.._.._.._.i-.. _.._.. _.. _.. _.._.. _.. _.. '. _.._.._.._.._.._i. _.. _.. _.._.. _.. _.._. • -14A -14 TAD End Drp TJC ._.. _..~.. _.. _. .. JB _.. _.. _.. _.. y.. _.. _.. _.. _.. _. ._.. _..~.. _.. _.. _.. bTJA .. _.. ~.. _.. _.. _.._.. _. TSGR Z-14B: Tgt 2 ._.. _. ~.. _.._. ._ .. ._.. _.. a.._.._.. _.._.. _. T`Sa,Ii' .................... Drp 8/100 End Orp / TD / 4712" Lnr 4800 5600 6400 7200 8000 8800 9600 1600 2400 3200 4000 4800 5600 Vertical Section (ft) Azim = 58.53°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-W ~ P Schlumber er 9 WELL Z-14B (P8) FIE If) Prudhoe Bay Unit - WOA SiRUC iIIRE Z-PAD ~, Mayreac Paranwl.as Surface LcaWn NAUI/elasMn Style Plan.,. Cann W.USFmt MnceYaeaxus Motlol BGGM 2005 Uip. BU636 Uafe. June W.2006 N]01I 5166) NalM1ag 'v95•J1W621NS ~01592b151- SbL Z-16 IW RW RuWry iaWu 18284BaW.n MSLI May Uuc ~202'vl' FS 5]5816 nT W1091138.911 EasMg 5995 J9J BUS Scuk Fad 0.9YA1126C0 Plan. Z-1M31Ptlf SrW O&n loon 2B. 2006 600 1200 1800 2400 3000 3600 4200 4800 3000 2400 n n n Z 0 0 co c 1800 a~ m U V V 1200 600 600 1200 1800 2400 3000 3600 4200 4800 «< VN Scale = 1(in):600(ft) E »> 3000 2400 1800 1200 • 600 TREE = 4" CNV WELLHEAD = MCEVOY ACTUAT R = AXELSON KB. ELEV = 92.04' BF. ELEV = 56.24' KOP = 3113' Max Angle = 37 @ 8500' Datum MD = 11482' Datum TV D = 8800' SS Z ~ ~ 4•A '~ GO~ORIZONTAL @ gIX ZEEDS 70° @ 9762' & 1932' 4-1/2" CAMCO SSSV NIP, ID = 3.813" 13-3/8" CSG, 68#, L-80, ID = 12.415" I-I 2652' Minimum ID = 2.37" @ 9237' 2-7/8" LINER TOP GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 5 2999 2907 7 MERLA DOME RA 07/20/98 4 5939 5480 31 MERLA DOME RA 07/20/98 3 7700 6980 34 MERLA DOME RA 07/20/98 2 8773 7848 36 MERLA DV RA 07/20/98 1 9045 8070 34 MERLA SO RA 07/20/98 9115' ~-~4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9-5/8" X 7" LINDSEY LNR TOP 9230' PKR/HGR W/TIEBACK TOP OF 2-7/8" LNR 9237' 4-1/2" TBG, 12.6#, L-80, 9293' 0152 bpf, ID = 3.958" 9-5/8" LNR, 47#, L-80, .0732 bpf, ID = 8.681" ~~ 9501' PERFORATION SUMMARY REF LOG: BHC ACOUSTILOG ON 03/28/98 ANGLE AT TOP PERF: 79 @ 11050' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11050 - 11075 C 09/25/01 2" 6 11095 - 11120 C 09/25/01 2" 6 11190 - 11215 C 09!25/01 2" 6 11260 - 11280 C 09/25/01 2" 6 11310 - 11330 C 09/25/01 2" 6 11350 - 11390 C 09/25/01 2-1/8" 4 11400-11410 C 06/07/98 2-1/8" 4 11418-11428 C 06/07/98 2-1/8" 4 11454-11460 C 06/07/98 2-1/8" 4 11466 - 11480 C 06/07/98 1-11 /16" 4 11493 - 11508 C 03/31 /98 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10325' 9170' I TIW PBR SEAL ASSY I 9190' 9-5/8" X 4-1/2" TNV HBBP PKR, !D = 4.0" 9229' 4-1/2" OTIS X NIP, ID = 3.813" 9229' 4-1/2" PX PLUG SET (05/09/06) 9262' 4-1/2" OTIS XN NIP, ID = 3.725" MILLED OUT TO 3.80" ID BY CTD 9293' 4-1/2" TBG TAIL, ID = 3.958" 9279' ELMD TT NOT LOGGED MILLOUT WINDOW 9530' - 9539' 9539' RA TAG IN WHIPSTOCK \~ PBTD 11590' 2-7/8" LNR 6.16#, L-80, .00579 bpf, ID = 2.37" I-I 11652' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/88 ORIGINAL COMPLETION 03/31/98 CJS CTD SIDETRACK 07/02/01 CWKAK CORRECTIONS 08/03/01 DV/DK/T CHANGE MIN ID/SET IBP 09/25/01 JLG/KK PERFS 05/13/06 TWS/PA SET PX PLUG (05/09/06) PRUDHOE BAY UNIT WELL: Z-14A PERMfT No: 1980510 API No: 50-029-21844-01 SEC 19, T11 N, R12E, 981' FNL, 3097' FEL BP Exploration (Alaska) WELLHEAD= MCEVOY ACTUAT R AXELSON KB. ELEV = 92.04' BF. ELEV = 56.24' KOP= 3113' Max Angle = 37 @ 8500' Datum MD = 11482' Datum TVD = 8800' SS -14A Go~ORIZ NTAL @ g9 2F~EDS 70° @ 9762' & Pre-Rig 1932' 4-1/2" CAMCO SSSV NIP, ID = 3.813" 13-3/8" CSG, 68#, L-80, ID = 12.415" i-i 2652' Cut -5400` Minimum ID = 2.37" @ 9237' 2-7/8" LINER TOP TOC -9000` 9-5/8" X 7" LINDSEY LNR TOP 9230' PKR/HGR W/TIEBACK TOP OF 2-7/8" LNR 9237' 4-1/2" TBG, 12.6#, L-80, 9293' .0152 bpf, ID = 3.958" 9-5/8" LNR, 47#, L-80, .0732 bpf, ID = 8.681" i-i 9501' PERFORATION SUMMARY REF LOG: BHC ACOUSTILOG ON 03/28/98 ANGLE AT TOP PERF: 79 @ 11050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11050 - 11075 C 09/25/01 2" 6 11095 - 11120 C 09/25/01 2" 6 11190 - 11215 C 09/25/01 2" 6 11260 - 11280 C 09/25/01 2" 6 11310 - 11330 C 09/25/01 2" 6 11350 - 11390 C 09/25/01 2-1/8" 4 11400 - 11410 C 06/07/98 2-1/8" 4 11418 - 11428 C 06/07/98 2-1/8" 4 11454 - 11460 C 06/07/98 2-1/8" 4 11466-11480 C 06/07/98 1-11/16" 4 11493 - 11508 C 03/31/98 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10325' ~_ ~~t ~ „.~ ~ •~ • .. , '.. •• s ..~ ~.: Y !+ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2999 2907 7 MERLA DOME RA 07/20/98 4 5939 5480 31 MERLA DOME RA 07/20/98 3 7700 6980 34 MERLA DOME RA 07/20/98 2 8773 7848 36 MERLA DV RA 07/20/98 1 9045 8070 34 MERLA SO RA 07/20/98 9115' E-i4-1/2" OTIS XA SLIDING SLV, ID = 3.813" ~ 9170' r-ITNV PBR SEAL ASSY I 9190' 9-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.0" 9229' 4-1/2" OTIS X NIP, ID = 3.813" 9229' 4-1/2" PX PLUG SET (05/09/06) 9262' 4-1/2" OTIS XN NIP, ID = 3.725" MILLED OUT TO 3.80" ID BY CTD 9293' 4-1/2" TBG TAIL, ID = 3.958" 9279' ELMD TT NOT LOGGED MILLOUT WINDOW 9530' - 9539' 9539' RA TAG IN WHIPSTOCK PBTD 11590' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" ~-~ 11652' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/88 ORIGINAL COMPLETION 03/31/98 CJS CTD SIDETRACK 07/02/01 CH/KAK CORRECTIONS 08/03/01 DV/DK/T CHANGE MIN ID/SET IBP 09/25/01 JLG/KK PERFS 05/13/06 TWS/PA SET PX PLUG (05/09/06) PRUDHOE BAY UNIT WELL: Z-14A PERMff No: 1980510 API No: 50-029-21844-01 SEC 19, T11 N, R12E, 981' FNL, 3097' FEL BP Exploration (Alaska) TREE = 4" CNV WELLHEAD= MCEVOY ACTUAT R = KB. ELEV = BF. ELEV = KOP = Max Angle = Datum MD = Datum TVD = 8800' SS ~Z-14B Proposed Completion 13-3/8" CSG, 68#, L-80, ID = 12.415" I-I 2652' 4-1/2" 12.6# L80, TCII Freeze protect prior to setting the packer GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 1 1/2" 2 1" 1 1" 4968` - 9-5/8" X 7" Baker Packer/Hanger (6/25" ID) 10860' - 4-1/2" X Nipple (3.813" ID) 10880` - 7" X 4-1/2" Baker S3 Packer 10900` - 4-1/2" X Nipple (3.813" ID) 10920` - 4-1/2" X Nipple (3.813" ID) -10940` - 4-1/2" XN Nipple (3.725" ID) \ ~ 10960` - 4-1/2" WLEG Whipstock KOP at -5118`MD l Pre-rig tubing cut at 5400` g~ ~ 5~ 4-1 l2" OTIS XA SLIDING SLV, ID = 3.813" 9190' 9-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.0" / 9170' TNV PBR SEAL ASSY 9-5/8" X 7" LINDSEY LNR TOP 9230' PKR/HGR W/TIEBACK / 9-5/8" csg, 47#, L-80, .0732 bpf, ID = 8.681" 9501' 7" LNG, 26#, L-80, .0383 bpf, ID = 6.276" ~-~ 10325 ` 7" 26# L80 BTC-M shoe at 11057` in top Sag River / 4-1/2" 12.6# L80 IBT-M 11750`MD -.~ ' "" PBTD -~ 11590' ~ 2-7/8" LNG 6.16Y#, L-80, .0057'9 bpf, ID=237" 11652' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/13/88 ORIGINAL COMPLETION 09/25/01 JLG/KK PERFS 03/31/98 CJS CTD SIDETRACK 6/23/06 KWA Proposed Sidetrack WP-08 03/13/01 SIS-QAA CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 07/02/01 CH/KAK CORRECTIONS 08/03/01 DV/DK/T CHANGE MIN ID/SET IBP PRUDHOE BAY UNIT WELL: Z-14B proposed PERMIT No: API No: 50-029-xxxxx SEC 19, T11 N, R12E, 981' FNL, 3097' FEL BP Exploration (Alaska) • • First National Bank Alaska Anchoi`age, AK ~9Q9~501 MEMO ~ ~ ~~~- $ ((~,~' ~:L252000'60~:99L4622?1556~~' 0285 Terri Hubble as-sit2s2 .285 BP Exploration AK Inc. °Mastercard Check." PO Box 1966.12 MB 7-5 Anchorage, AK 995.19 ~7- ~~ DATE • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~~jfjJ ~ ~~/~ PTD# 1c?~ Development Service Exploratory Stratigraphic Test Non-Conventional ell 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 wel l (If Last two digits in permit No. API No 50- - - API number are , . ~ ' between 60-69) i Production should continue to be reported as a function of the ' original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -____) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing ~ exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals 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 welly until after (Compan_y Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25/06 C:\j ody\transmittal_chec kl i st ~..~... _ _T~ ,~ r'°1`~s_4. ('~~ t"e~r I '~ ~ ~FCKL6ST Field °. Pau, PRUt~HOE BAY, PRUDHOE i,iL - 640150_ p' ~N~u Narie PRLiDHOE F3AY UNi i c 1;~ Program S~,~ Well bore seg PT~# ^'':-}c.;~ , =ny Rn EXPL~F.',.;Ci tir;i ii~iC ,nttial ..,ass,T __ -r. __ .~ __ ___ ;•~re . SER / 1-Qh veoHiee E50 i~ni~ ~ io5u On/rJ`" oi~- r1n Annular Disposal .._ ._ ~ _.t-.. _,._ _ _ _ ._~ .- ~.r _ _ I Administratiari 1 _ _ _- _s-._ Fermit fee attached _ Yes , . _ , _x_ 2 Lease number apr.~opriate Yes ~3 :in qGa well nanre a~~d cumber Yes i ~?. I ;~~Cofeo In a. defineG ~iUyl Ye$ _ i to Air Inr~tecl proper distan from d'i!ling unit nnunda ~ Yes I ~ ,~,,:: ~>:, • oa J ~icd prGper tliStanC? from other welts Yes 7 ,,,,~ ~ _rr'~ acreage availaoie to crilfnq unaf Yes 8 'r ~~ viated, is wellbore plat in h ded Yes a ~.~nPratCr CnIV 2i'eCt?d party _ _ _ YPs 1u` "peraor i ins approprhite fond in force Yes ] 11 +' unit can be issued without conservation order Yes 12 '„rmit can k~e issued without administrative. approval Yes Appr Date 13 Can permit be approved before 15-day wait Yes RPC 71101?OOP :,. ~,"Jell located ve ~ ~u r;;a and strata authorized by Inj2c:iun Order";put 10# in comments}_(For Yes AIO N0.3 ] rill wells wither ^14 r^i!e area of review identified (Far esrvice well only)_ Yes Z-15, Z 29 16 Pre ,~rcaaccc ~njecfor: duration ofpre-production less than 3 months. (Forservice well only) NA 17 danconven. gas ronicr,ns to AS31.05 0301j.1.A),(i.2.A-13) NA 18 __ Gonductarstringprovided NA Engineering 19 Surface casing protects all known. USDlr+1s NA 20 CMT voi adequate. to circulate on conductor & surf csg NA ?1 CMT. vol. adequate to tie-in long string to surf csg NA r ^% + w1T vvul cover alt kno.:~n productive horizons Yes Adequate excess. 23 .using u igr•s adequate for C, T, B & pe[mafrost_ Yes 24 Adequate tankage. or reserve pit Yes Nabors 7ES, 25 If a re-drill, has a 1 C-403 for abandonment been approved Yes 6129!2006. 26 Adequate wellbore separation proposed Yes 27 If diverter required, aces it meet. regulations NA SiaetracK. • u '3rtiira fluid rc,~ ~^ schematic ~ equip list adequate p '., Yes Max MW 11.2 ppg. Appr Date , 9 BQPEs, do the meet re ulation Y g Yes inlCA. 7/1212006 g0 ~uPE ~?re~s rating appropriate, test to_(put psig in comments).. Yes Test to 4000 psi. MSP 2850 psi. 31 Choke. manifold complies wlAFi_RP-53 May 84). _ .. Yes 32 Work will occur without operation shutdown.. Yes 333 Is presence of H2S gas_probable _ No_ Not an H2S pad. 34 ~~;anica! ~~ _dit vii of wells wi`~in ACR verified (For service welt only) Yes Records indicate cementing adequate far mech integrity. 35 __ Permit can be issued wlo hydrogen sulfide measures __ _ No Geology 36 Data presented on potential overpressure zones NA 37 Seismic analysis of shallow gas zones NA Appr Date 38 Seabed condition survey (if off-shore) NA RPC 7/10/2006 39 Contact namelphone for weekly progress reports. [exploratory only] NA • Geologic Engineering Public Date: Date Date Commissioner: Co lesion r: Commissioner
