The URL can be used to link to this page

Home My WebLink About205-020CAUTION: 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: NOT OPERABLE: Injector 17-13A (PTD #2050200) will lapse on AOGCC MIT-IA Date:Friday, October 10, 2025 4:30:10 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, October 10, 2025 3:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 17-13A (PTD #2050200) will lapse on AOGCC MIT-IA Correction: Injector 17-13A (PTD # 2050200) From: Andrew Ogg <andrew.ogg@hilcorp.com> Sent: Friday, October 10, 2025 2:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 17-13A (PTD #2050200) will lapse on AOGCC MIT-IA Mr. Wallace, Producer 17-13A (PTD #2050200) is due for its 2-year AOGCC MIT-IA this month. It is currently shut- in and there are no plans to have the well online before the end of the month. It will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 17-13 (PTD #2050200) Request to leave on MI while AA is processed Date:Monday, November 20, 2023 2:08:03 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Monday, November 20, 2023 12:53 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector 17-13 (PTD #2050200) Request to leave on MI while AA is processed Ryan, An Administrative Approval (AA) application has not made it to me yet, but you are approved for an additional 30 days MI injection while we process the application. 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.govCONFIDENTIALITY 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: Monday, November 20, 2023 12:16 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) Request to leave on MI while AA is processed Mr. Wallace, I believe an AA application / revision to allow continued MI injection on 17-13 was submitted to AOGCC on 11/14/23. The initially approved 30 day online period will expire on Sunday 11/26/23. Would AOGCC grant approval to leave the well on MI while the AA revision is processed? Thanks, 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 Sent: Wednesday, October 25, 2023 5:57 AM To: chris.wallace@alaska.gov Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) Approved for MI 30 days Mr. Wallace, Water alternating gas injector 17-13 (PTD # 2050200) passed AOGCC MIT-IA to 3187 psi on 10/10. The well has been approved by AOGCC for MI trial injection period of up to 30 days. The well is now classified as UNDER EVALUATION and on a 30 day clock for tracking purposes. 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: Alaska NS - PB - Field Well Integrity Sent: Monday, August 10, 2020 4:03 PM To: chris.wallace@alaska.gov Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector 17-13 (PTD #2050200) AA AIO 4G.011 Mr. Wallace, Water alternating gas injector 17-13 (PTD # 2050200) passed an AOGCC witnessed MIT-IA on 07/29/20 which verifies two competent well barriers. Administrative Approval Area Injection Order 4G.010 for continued water injection only has been granted. The well is now classified as OPERABLE under the conditions specified under AA AIO 4G.011. Please respond 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: Alaska NS - PB - Field Well Integrity Sent: Friday, July 17, 2020 3:52 PM To: chris.wallace@alaska.gov Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) anomalous IA casing repressurization Mr. Wallace, WAG Injector 17-13 (PTD # 2050200) was flagged on 07/16/20 for slow IA casing repressurization due to possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T 2. DHD: Monitor IAP for Build-Up Rate 3. Fullbore (pending): AOGCC witnessed MIT-IA 4. Field Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. 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 17-13 (PTD #2050200) Approved for MI 30 days Date:Wednesday, October 25, 2023 8:22:41 AM Attachments:image001.pngFW EXTERNAL RE 17-13A (PTD# 205020) request for temporary authorization for MI service for up to 30 days.msg From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 25, 2023 5:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) Approved for MI 30 days Mr. Wallace, Water alternating gas injector 17-13 (PTD # 2050200) passed AOGCC MIT-IA to 3187 psi on 10/10. The well has been approved by AOGCC for MI trial injection period of up to 30 days. The well is now classified as UNDER EVALUATION and on a 30 day clock for tracking purposes. 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: Alaska NS - PB - Field Well Integrity Sent: Monday, August 10, 2020 4:03 PM To: chris.wallace@alaska.gov Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector 17-13 (PTD #2050200) AA AIO 4G.011 Mr. Wallace, Water alternating gas injector 17-13 (PTD # 2050200) passed an AOGCC witnessed MIT-IA on 07/29/20 which verifies two competent well barriers. Administrative Approval Area Injection Order 4G.010 for continued water injection only has been granted. The well is now classified as OPERABLE under the conditions specified under AA AIO 4G.011. Please respond 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: Alaska NS - PB - Field Well Integrity Sent: Friday, July 17, 2020 3:52 PM To: chris.wallace@alaska.gov Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) anomalous IA casing repressurization Mr. Wallace, WAG Injector 17-13 (PTD # 2050200) was flagged on 07/16/20 for slow IA casing repressurization due to possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T 2. DHD: Monitor IAP for Build-Up Rate 3. Fullbore (pending): AOGCC witnessed MIT-IA 4. Field Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 13, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-13A PRUDHOE BAY UNIT 17-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2023 17-13A 50-029-21200-01-00 205-020-0 W SPT 8657 2050200 3000 1746 1748 1746 1744 420 552 558 562 OTHER P Brian Bixby 10/10/2023 MITIA as per email dated 9/29/23 (Wallace, Rixse, Sternicki), Also AIO 4G.011. 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 17-13A Inspection Date: Tubing OA Packer Depth 917 3286 3205 3187IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB231011070527 BBL Pumped:4.1 BBL Returned:4 Wednesday, December 13, 2023 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, November 24, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-13A PRUDHOE BAY UNIT 17-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ 17-13A 50-029-21200-01-00 205-020-0 W SPT 8657 2050200 3000 1746 1748 1746 1744 420 552 558 562 OTHER P Brian Bixby 10/10/2023 MITIA as per email dated 9/29/23 (Wallace, Rixse, Sternicki), Also AIO 4G.011. 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 17-13A Inspection Date: Tubing OA Packer Depth 917 3286 3205 3187IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB231011070527 BBL Pumped:4.1 BBL Returned:4 Friday, November 24, 2023 Page 1 of 1            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: 17-13A (PTD# 205020) request for temporary authorization for MI service for up to 30 days Date:Friday, September 29, 2023 10:32:02 AM From: Wallace, Chris D (OGC) Sent: Friday, September 29, 2023 10:31 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: 17-13A (PTD# 205020) request for temporary authorization for MI service for up to 30 days Oliver, Your request is approved. 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: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, September 27, 2023 7:25 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: 17-13A (PTD# 205020) request for temporary authorization for MI service for up to 30 days Chris, Mel, 17-13A (PTD# 205020) previously operated as a WAG injector until the well developed slow TxIA repressurization while on water injection in July 2020. AIO 4G.011 was approved for continued operation with slow TxIA comm on 8/10/2020 and limited 17-13A to PWI only. Due to the very slow IA repressurization rate a leak detection log was not attempted at the time of the AA request. We are interested in diagnosing the TxIA repressurization rate on MI service to determine if the well can safely be operated as a WAG well with periodic IA bleeds or if the repressurization rate is high enough to make running a leak detection log a reasonable option. The most recent AOGCC witnessed MIT-IA passed to 2380 psi on 7/18/2022. Maximum expected MI pressure for 17-13A is 3000 psi. Hilcorp request temporary authorization for MI injection into 17-13A for up to 30 days to determine TxIA repressurization rates in support of an amendment to AIO 4G.011 to allow a return to WAG service or to facilitate diagnostics and repair of the well if possible. If approval is granted a passing AOGCC witnessed MIT-IA to 3000 psi will be executed prior to placing the well on MI service. IA pressure will be maintained below MOASP. Thanks, 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 17-13A PRUDHOE BAY UNIT 17-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 17-13A 50-029-21200-01-00 205-020-0 W SPT 8657 2050200 2164 1660 1662 1661 1659 301 408 409 409 REQVAR P Austin McLeod 7/18/2022 2 year MITIA. MAIP is less than packer depth criteria. AIO 4G.011. 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 17-13A Inspection Date: Tubing OA Packer Depth 1318 2429 2389 2380IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220718182535 BBL Pumped:1.8 BBL Returned:2.2 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 MAIP is less than packer depth criteria. James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:22:46 -08'00' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, August 10, 2020 4:03 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Stan Golis; Oliver Sternicki Subject: OPERABLE: Injector 17-13 (PTD #20502 0) AA AIO 4G.011 Attachments: aio4G.011.pdf Mr. Wallace, Water alternating gas injector 17-13 (PTD # 2050200) passed an AOGCC witnessed MIT -IA on 07/29/20 which verifies two competent well barriers. Administrative Approval Area Injection Order 4G.010 for continued water injection only has been granted. The well is now classified as OPERABLE under the conditions specified under AA AIO 4G.011. Please respond 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 F om: Alaska NS - PB -Field Well Integrity Sen . riday, July 17, 2020 3:52 PM To: chris. allace@alaska.gov Cc: jim.regg aska.gov; Bo York <byork@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki 'Icorp.com> Subject: UNDER EVAL TION: Injector 17-13 (PTD #2050200) anomalous IA casing repressurization Mr. Wallace, WAG Injector 17-13 (PTD # 2050200) was gged on 07/16/20 for slow IA casing repressurization due to possible TxIA communication. The well will now be classifie s UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T \ 2. DHD: Monitor IAP for Build -Up Rate 3. Fullbore (pending): AOGCC witnessed MIT -IA 4. Field Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.oRR(@hilcorD.com P: (907) 659-5102 M: (307)399-3816 1 MEMORANDUM TO: Jim Regg (7 P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 17-13A PRUDHOE BAY UNIT 17-13A Src: Inspector Reviewed By: P.I. Supry —) J— Comm Well Name PRUDHOE BAY UNIT 17-13A API Well Number 50-029-21200-01-00 Inspector Name: Guy Cook Permit Number: 205-020-0 Inspection Date: 7/29/2020 Insp Num: mitGDC200729071222 Rel Insp Num: Thursday, July 30, 2020 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well l7 13AType Inj Inj W ;TVD 8657 Tubing i T 1847 1849 - � 1848 1848 - r - i PTD D 2050200 pe SPT Test St p 2164 IA 1034 2406 2351 2339 --- — BBL Pumped: I 2.2 ;BBL Returned: z.1 ' OA 211253 252 I u Interval OTHER IP/F P - -- Notes: MIT -IA for possible TxIA communication to see if they need to seek an AA. Testing was accomplished with a Little Red Services pump truck and calibrated gauges Thursday, July 30, 2020 Page I of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, July 17, 2020 3:52 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Stan Golis; Oliver Sternicki Subject: UNDER EVALUATION: Injector 17-13 (PTD #2050200) anomalous IA casing repressurization Mr. Wallace, WAG Injector 17-13 (PTD # 2050200) was flagged on 07/16/20 for slow IA casing repressurization due to possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Wellhead Technician: PPPOT-T 2. DHD: Monitor IAP for Build -Up Rate 3. Fullbore (pending): AOGCC witnessed MIT -IA 4. Field Well Integrity: Additional diagnostics as needed Please respond if in conflict. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 • MEMORANDUM •State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I. DATE: Wednesday,April 04,2018 Jim Regg PSupervisorlc-eft 4-151 (`43 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 17-13A FROM: Bob Noble PRUDHOE BAY UNIT 17-13A Petroleum Inspector Src: Inspector Reviewed By P.I.Supry , NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 17-13A API Well Number 50-029-21200-01-00 Inspector Name: Bob Noble Permit Number: 205-020-0 Inspection Date: 4/3/2018 Insp Num: mitRCN180403174445 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 17-13A - Type Inj W `TVD 8657 [-Tubing 1424 - 1427 - 1420 - 1421 - PTD 2050200 Type Testl SPT Test psi 2164 IA 699 2500 - 2464 - 2451 YP -L p — — BBL Pumped: f 2.5 - IBBL Returned: 2.8 OA 273 - 302 • _..---- -- - —. 306 309 - Interval 4YRTST P/F P ,/ Notes: 'Ye e st w«5 Atte, os - Su.fCucr c—(e- fxbtde,A.5 -Faun jPKA we4 f Zt s —5130106 'P 'c't. SCANNED Wednesday,April 04,2018 Page 1 of 1 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~OS- O~O Well History File Identifier Organizing (done) o Two-sided III 11111111" 11111I RESCAN ~olor Items: ~reYSCale Items: o Poor Quality Originals: DI<JTAL DATA ·\Ø'Diskettes, No. ~ o Other, NolType: o Other: NOTES: Dale fi/dEJOJ DalesjJ-5!D7 ~ x30= Date: 6- :)..s- BY: ~ Project Proofing BY: ~ Scanning Preparation BY: Production Scanning Stage 1 ~) (Count does include cover sheet) VYES Page Count from Scanned File: Page Count Matches Number in Scanning preìaration: ~ Date:£!;¡'S 07 Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 11111111I1111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: 1YlP ,:"llllllIli 11111 ýY\ P 151 + 20 = TOTAL PAGES <g 0 (Count does not include cover sheet) \^/\ P 151 , ' I 11111111111111 "III NO 151 vvr P NO YES 151 11111111111111111/1 ReScanned BY: Maria Date: 151 Comments about this file: 11111111111111 I1II1 Quality Checked III "1111I111111111 10/6/2005 Well History File Cover Page.doc MEMORANDUM Toy Jim Re P.I. Supervisor FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 17-13A PRUDHOE BAY UNIT 17-13A Src: Inspector NON-CONFIDENTIAL u Reviewed By: P.I. Suprv J' Comm Well Name: PRUDHOE BAY UNIT 17-13A API Well Number: 50-029-21200-01-00 Inspector Name: John Crisp Insp Num: mitJCr100504080144 Permit Number: 205-020-0 Inspection Date: 4/29/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WC^ 17-13 T Inj. C* TVD ~ IA~ 190 P.T.D~ zoso2oo TypeTest1sPT Test psi z16a ~ OA ]ao L 4000 lao 3920 180 3890 ]so i - - - 2soo P ~ Tubin 2azo 28zo z8zo g Interval a~TST p/F Notes: 5.1 bbls pumped for test ~~ k,~ ~ r, ., ~ ~.;.' I j l ~~ ' ~• } "~^ ~_ _ as_a~.;, Monday, May 24, 2010 Page 1 of 1 • • ~~ ~ .._ MiCR4FILMED DO NC~T PLACE .,> . ;„ __, ANY NEW MATERIAL UNDER THIS PAGE F:1IJaserFicl~lCvrP~s InsertslMicrofilm Maxkerdoc \ ~ t'l-, DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Spud Jò tV{~~r API No. 50-029-21200-01-00 Permit to Drill 2050200 Well NamelNo. PRUDHOE BAY UNIT 17-13A Operator BP EXPLORATION (ALASKA) INC MD 14250 v' ~~ C~:~~~~ion Stat . ~~~~ -~ -' 8763 Completion Date 4/12/2005 Current Status WAGIN 0-- UIC ;:L....¿.. ~~ ;':!I ->..... TVD -~"_._- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~~~~ DATA INFORMATION Types Electric or Other Logs Run: MWD DIR I GR I RES I PWD, MWD DIR I GAB I I RES, US IT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Type Med/Frmt Number Name a,.eD D Asc Directional Survey ~ D Asc Directional Survey D D Lis 13181 I nd u ctionlResistivity , tc 13181 LIS Verification Lis 13715 I nd uctionlResistivity og Sonic Log Log Run Scale Media No Interval OHI Start Stop CH Received Comments 9093 14250 Open 4/27/2005 IIFR - 9093 14250 Open 4/27/2005 MWD 9041 14201 Open 7/14/2005 GR EWR4 ABI PWD ROP ¡ 0 0 7/14/2005 9194 14250 Open 2/22/2006 ROP DGR EWR ALD plus Graphics 8900 10930 Case 6/8/2005 USIT, PDC 4-Apr-2005 , Sample Set Number Comments 5 Col Well CoreslSamples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION ~ Daily History Received? .~ -~ (j)N Well Cored? Chips Received? -y I N Formation Tops Analysis Received? ~.. Comments: ~---~--"..__._- .....~- Date: ~~~7 ~-_._---~_. Compliance Reviewed By:~__. . - 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA . Al Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: De\Æ3lopment Stratigraphic Stimulate 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0020 """' P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Exploratory Service 6. API Number: 50-029-22571-01-00 3. Address: 9. Well Name and Number: 57.05 KB PBU E-37 A ADLO-028280 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Effective Depth measured true vertical 13130' feet 8939.73' feet 13038' feet 8939.47' feet Plugs (measured) Junk (measured) 12435' None Total Depth measured true vertical Casing Conductor Surface Liner Liner Length 73' 3766' 10183' 3090' Size MD TVD Burst Collapse 20" 91.5# H-40 32' - 105' 32' - 105' 1490 470 10-3/4" 45.5# NT-80 32' - 3798' 32' - 3615.19' 5210 2480 7-5/8" 29.7# L-80 32' - 10215' 32' - 8703.00' 6890 4790 4-1/2" 12.6# L-80 10039' - 13129' 8592.17' - 8939.73' 8430 7500 Perforation depth: Measured depth: 11340' - 12340' True Vertical depth: 8993.46' - 8963.24' 12710' - 13030' 8943.56' - 8939.45' 10785' - 10910' 8975.24' - 9001.35' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 32' - 10048' Packers and SSSV (type and measured depth) BKR 7-5/8"x4-1/2" S-3 o o o 9989' o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): (,-'RD"· u"'" SFI t"\~f< . !1fI~, :~ I) 6 2006 Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 3039 3 0 o 0 0 15. Well Class after proposed work: Exploratory De\Æ3lopment 16. Well Status after proposed work: Oil Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 215 o Tubing pressure 164 o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x Contact Karn MacClean WINJ WDSPl Printed Name Karn MacClean Signature J( lOM Title Data Engineer - Phone (907) 564-4424 Date 111'2/2006 Form 10-404 Revised 04/2004 Submit Original Only I" . . E-37A Description of Work Completed NRWO Operations Event Summary I ACTIVITYDATE I SUMMARY 10/25/2006 MIRU CTU #5. Perform BOP tests. MU PDS memory log tools in 2.2" carrier wi 3.0" JSN. RIH. Log from 11075' to 9750'. Paint coil flag @ 10800'. POOH. *** Job in progress*** 10/26/2006 *** Job continued from 10-25-06 WSR*** POOH with PDS logging tools. No data. RIH with new logging tool string. Log from 11,000' to 9750' (pipe flagged at 10,799'). POOH. RIH wi 2718" guns. Perf from 10,885' - 10,910'. POOH. *** Job in progress*** 10/27/2006 *** Job continued from 10-26-06 WSR*** Perforate 10,860' - 10,885' interval. POOH. Cut 50' coil for pipe management. MU Weatherford 2.375" MHA. MU PDS logging tools with 2.5" JSN. RIH. Log perf interval. Paint flag at 10,774.7'. POOH. MU perf guns for run #3 and RIH. Perf from 10,835' - 10,860'. POOH. RIH with gun run #4.*** Job continued on 10-28-06 WSR*** 10/28/2006 ***Job continued from 10-27-06 WSR*** RIH with gun run #4. Perforate 10,810' - 10,835'. POOH. RIH with gun run #5. Perforate from 10,785' - 10,810'. RDMO. *** Job complete*** FLUIDS SUMMARY BBLS 100 60/40 Methanol 23 Diesel 123 Total e 0 og escrlptlon ae o or 17-13A RÚc; - ("):::)(\ 11001218 USIT 04/04/05 1 NK-65A AtJ:r;; -{l/:'?' 11084270 SCMT 07/05/05 1 02~10B {.)tx....- (-¡~ '-I 10964140 LDL 04/06/05 1 01-11 (""}. -:t .. ¡""'J£:::-'¡" 11051039 INJECTION PROFILE (. '. ;:)., - (',""1<' '..J C,/::!-;../,.,,, 04/29/05 1 01-09A I e¡-:..¡- ð:i~ 10559825 INJECTION PROFILE 07/31/03 1 01-11 ,::¡..+ -,-...,... '-:+- 10662950 INJECTIO~ PROFILE Q.0P~I - (' "c..e\Ú~ :J I;;JiC~ 09/16/03 1 11-34 ì Dj4/ - t:=~ 'i< 10687720 LDL 12/31/04 1 A-07 î '7.? - O<..t f 9153241 PRODUCTION'PROFILE (!., 1.")< -(.;>C'o> ,.,,;.) -¡ii~l" 02104/03 1 B-36 I q 1/1 - 0(05" 10563182 LDL C' " ,,,. I - r 0 r· ',.. i ' e ~ Î I ;::¡ ~ I ñ ~' 07/09/03 1 01:20 Î"7r:':l - J4 f.~ 10687694 PRODUCTION PROFILE 07/16/04 1 K-01 í 1r,~ - / :~. t 11211415 SCMT 06/01/06 1 H-31) l ~7r - (";~~:., 11217253 USIT 06/01/06 1 D.S:09-06 ¡<¡"(", - ;-¡"/~ 11258699 US IT 04/13/06 1 Scblumbel'gel' RECEIVE'D II !~' 0 . " ,.'...¡i j ö L006 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 6. Gas Ceos. Cçrnmissicn ,ÄJ1ct1<:re<;-e ·,~JZSl.a WII L D D t BL J b# . . Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , Anchorage, Alaska 99508 "\ t,! ' (] .vtt~ 06/05-06/06 NO. 3835 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .....--, ., k~, .( /0." I, ,_. j ~;.-- ~--"~.......; I....t ~,6 , ..... /'-/ ¡ f tJ I ' DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 17-I3A PRUDHOE BAY UNIT 17-13A 'J1) r¡.,tft"q ~" FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvl1-=?R:- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT I7-I3A API Well Number 50-029-2 I 200-0 1-00 Inspector Name: Chuck Scheve Insp Num: mitCS060516063 I I I Permit Number: 205-020-0 Inspection Date: 5/15/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I7-I3A ¡Type Inj. I G ,-- ! IA I Well ,TVD 8656 ! 1550 3020 i 2960 2960 ; I 2050200 ITypeTest ! SPT : Test psi ! I ! I ! P.T. I 2164 OA 150 150 ! 150 150 i I - . I : Tubing i 2950 2950 2950 2950 I Interval INITAL PIF P I I i I Notes Pretest pressures were observed for 1 + hour and found stable. Well demonstrated good mechanical integrity. Wednesday, May 17, 2006 Page 1 of I ,... ,'a STATE OF ALASKA .11(, S/¿/áb ... ..ALAS~ILAND GAS CONSERVATION CO~SION WêLÆ..COMPLETION OR RECOMPLETION REPORT AND LOG . 05/03/06: Revised, Put on Injection 1a. Well Status: 0 Oil o GåSÔPlugged o Abandoned o Suspended ~WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 o Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/12/2005 205-020 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/30/2005 50- 029-21200-0 1-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/7/2005 PBU 17-13A 2944' SNL, 1078' EWL, SEC. 22, T10N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 52' SNL, 2984' WEL, SEC. 21, T10N, R15E, UM 64.9' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 291' NSL, 749' WEL, SEC. 17, T10N, R15E, UM 14164 + 8767 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 709343 y- 5927703 Zone- ASP4 14250 + 8763 Ft ADL 028330 -------- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 705198 y- 5930482 Zone- ASP4 Total Depth: x- .. (Nipple) 2238' MD 702144 y- 5930742 Zone- ASP4 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost ~Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD DIR I GR I RES I PWD, MWD DIR I GABII RES, USIT 22. CASING, LINER AND CEMENTING RECORD i ·i'C~f~G .. ::)ETTING DEPTH MD . ~EITINGUEPTtl TVD HoLE ..iy'·····'··' <, )NT. PER Fr. GRADE SIZE .... jj ,-;Þ(;fl.~6 IÖP II:SOtTOM lOP II:SÖTTOM .... 20" 91.5# H-40 Surface 112' Surface 112' 30" 1900 # Poleset (Approx.) 13-3/8" 72# L-80 Surface 2503' Surface 2503' 17-1/2" 2300 sx CS III, 400 sx CS II 9-518" 47# L-80 Surface 9166' Surface 7883' 12-1/4" 550 sx Class 'G', 300 sx CS II 7" 26# L-80 2626' 10958' 2626' 8755' 8-1/2" 376 sx 'G', 449 sx 'G', 129 sx 'G' 4-1/2" 12.6# L-80 10777' 14250' 8677' 8763' 6-1/8" 427 sx Class 'G' 23. Perforations op'en to Production (MD + TVD of Top and 24. .... .. it ...... . in .. lIJalNG r> ;, Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10785' 10728' MD TVD MD TVD 11100' - 11180' 8783' - 8784' 25. AC'().;. '<. '; 11280' - 11360' 8783' - 8781' '.. . "'''''v,'''~. '. ... .... >i ,< .«ii' 11460' - 11550' 8778' - 8775' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12100' - 12600' 8771' - 8768' 12850' - 13350' 8766' - 8765' Freeze Protect wI 150 Bbls of Diesel 13550' - 13700' 8765' - 8769' 13900' - 14000' 8771' - 8770' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 19, 2006 Gas Injection Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl GAs-McF WATER-BBl Oil GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8Ft MAY (I 8 2006 Form 10-407 Revised 12/2003 n P ;,.) , \ c. 'CONTINUED ON REVERSE SIDE \.... G ,'" 28. GEOLOGIC MARK 29. ORMATION 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". CM1 9450' 8080' None Top HRZ 10114' 8405' Base HRZ 10512' 8566' LCU I JB 10595' 8601' JA 10756' 8668' Sag River 11001' 8771' Sag River 14248' 8763' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I ~erebY certify that th~oin: is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 05/03/0 PBU 17-13A Well Number 205-020 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced. showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection. Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . rJ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West th Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1'~1\S- RE: MWD Formation Evaluation Logs 17 -13A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 17-13A: LAS Data & Digital Log Images: 50-029-21200-01 ~'5 - ð IJ{) 1 CD Rom r::n NO V 02 2007 SGANNlØtof ~lh 2-\ ~~IC(o . . WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ;fa ) - a ').. ~ RE: MWD Formation Evaluation Logs: 17-13A, July 14, 2005 -:/þ /3/ f( AK-MW-3607846 1 LDWG formatted Disc with verification listing. API#: 50-029-21200-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITIAL LETfER TO THE ATfENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 Date:'}, ~~r JLJ (j jLJ Signed: ALAsAL AND ~~;~g~S~':';~ON COMflslON RE CE IV ED WELL COMPLETION OR RECOMPLETION REPORT AND LOG Mß,y 1 1. 2005 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended IS! WAG 1 b.WäJì611iØs~ bm, LOnS. ¡';OmmISSI( 20AAC 25.105 20AAC 25.110 o Developme!J\ n ÐJc#lJolPratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic IS! Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/12/2005 205-020 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/30/2005 50- 029-21200-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 4/7/2005 PBU 17-13A 2944' SNL, 1078' EWL, SEC. 22, T10N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 52' SNL, 2984' WEL, SEC. 21, T10N, R15E, UM 64.9' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 291' NSL, 749' WEL, SEC. 17, T10N, R15E, UM 14164 + 8767 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 709343 y- 5927703 Zone- ASP4 14250 + 8763 Ft ADL 028330 --~ -------- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 705198 y- 5930482 Zone- ASP4 Total Depth: x- 702144 y- 5930742 Zone- ASP4 (Nipple) 2238' MD _ ___ _____n_ --- - -- ---------- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IS! Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD DIR I GR I RES I PWD, MWD DIR I GAB I I RES, USIT ::>2. CASING, LINER AND CEMENTING RECORD CASING SETTING EPTH MD SETTING DEPTH TVD HOLE AMoUNT SIZE WT. PER FT. GRADE lOP I::SOTTOM lOP II::SOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 112' Surface 112' 30" 1900 # Poleset (Approx.) 13-3/8" 72# L-80 Surface 2503' Surface 2503' 17-1/2" 2300 sx CS III, 400 sx CS II 9-5/8" 47# L-80 Surface 9166' Surface 7883' 12-1/4" 550 sx Class 'G', 300 sx CS II 7" 26# L-80 2626' 10958' 2626' 8755' 8-1/2" 376sx 'G', 449 sx 'G', 129 sx 'G' 4-1/2" 12.6# L-80 1 0777' 14250' 8677' 8763' 6-1/8" 427 sx 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) 2-7/8" Gun Diameter, 4spf 4-1/2", 12.6#, L-80 10785' 1 0728' MD TVD MD TVD 11100' - 11180' 8783' - 8784' 25. ACID, FRACTURE, CEMENTSQUEEZE,ETC. 11280' - 11360' 8783' - 8781' 11460' - 11550' 8778' - 8775' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12100' - 12600' 8771' - 8768' 12850' - 13350' 8766' - 8765' Freeze Protect wI 150 Bbls of Diesel 13550' - 13700' 8765' - 8769' 13900' - 14000' 8771' - 8770' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ~mit core chips; if none, state "none". (! COMPLEtJOÑi' RBDMS BFL MAY 1 6 2005 NO..~" , .." I ¡ ') ¡ ;~"'i-D I ¿ 'nt:' I 6~ ,-Ç,. I ~''-'')~'~-'' >__,~:..::.~:- i n Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 26. GEOLOGIC MARKERS 29. ORMATION 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". CM1 9450' 8080' None Top HRZ 10114' 8405' Base HRZ 10512' 8566' LCU I JB 10595' 8601' JA 10756' 8668' Sag River 11001' 8771' Sag River 14248' 8763' 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram, Surveys 31. I ~erebY certify that the ~ng ~s true and correct to the best of my knowledge. Signed Terrie Hubble J Title Technical Assistant Date tE//1 /OS PBU 17-13A Well Number Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 205-020 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Printed: 4/18/2005 9:36:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 3/23/2005 06:00 - 00:00 18.00 MOB N WAIT PRE Rig on standby with full crews, waiting on prep for next well. Crew doing maint on rig. Repaired back stop on skate. Check shaft sizes on dwks. Perform lifting equipment inspection. Inspect and service top drive. Repair skate rail stop. Disassemble hopper & inspect. CIO high pressure bleeder valve. Replace shaker cam springs. Rig maint & inventories. 3/24/2005 00:00 - 00:00 24.00 MOB N WAIT PRE Rig on standby with full crews waiting on well # 17-13Ai to be preped. Crews performing rig maint. Clean all sumps on rig floor. Check bearings on dwks. Install new counter balance with new bearings on skate ramp. Change out rod wash pump on mud pump # 2. Replace tension springs on shaker # 2. Weld on pipe machine back stop & rig floor exit door. Install brine pump in tank # 1. Weld hinges on exit door to tool slide landing. Prepare to move rig, bridle up, secure board, take down geronimo line, snow removal. 3/25/2005 00:00 - 12:00 12.00 MOB N WAIT PRE Rig on standby with full crews waiting for well #17-13Ai to be preped. Crews performing rig maint & preparing for rig move. UD pipe shed cattle chute wind wall. Pull derrick "A" leg pins and lay derrick over. Blow down pits & disconnect. Inspect & service man rider tugger sheaves in derrick. Disconnect & load maintanance shop. Pull cuttings tank away from rig. Repair hinges on doghouse door. 12:00 - 19:30 7.50 MOB P PRE Tie trucks onto pits & camp, transport to DS # 17 and stage at end of pad. 19:30 - 22:30 3.00 MOB P PRE PJSM with drill crew, security and power line crew. Move sub base from DS # 3 to DS # 17, stage on pad. 22:30 - 00:00 1.50 MOB P PRE PJSM. Prepare to and raise derrick. 3/26/2005 00:00 - 05:00 5.00 MOB P PRE Rig waiting for well # DS #17-13Ai. Bridle down derrick, RIU topdrive and rig floor. 05:00 - 10:00 5.00 MOB P PRE Lay herculite, set matting boards and spot sub base over well # 17-13Ai. Prep rig for accept. Spot camp & shop. Rig accepted @ 10:00 hrs 3/26/2005. This rig move went on an exception move rate as the pad was not preped. 10:00 - 10:30 0.50 MOB P PRE Hold pre-spud meeting with all personell. 10:30 - 11 :00 0.50 BOPSU P DECOMP Install 3 1/8" secondary annulus valve. 11 :00 - 12:00 1.00 WHSUR P DECOMP RlU Drill Site Maint and pull BPV with lubricator, RID DSM. 12:00 - 13:00 1.00 PULL P DECOMP Rig up lines to tree and test surface equipment to 4000 psi. 13:00 - 17:00 4.00 PULL P DECOMP Reverse circulate diesel from tubing. Circulate down tubing, pump soap pill and seawater to displace diesel freeze protect from annulus. Pump @ 6 bpm @ 430 psi. Called 5700 [ACS] and reported a mist of precipitation from steam off of cuttings tank. The mist consisted of a mix of seawater/crude/diesel. ACS investigated. Considered a non-reportable release. 17:00 - 18:00 1.00 PULL P DECOMP Set BPV and test from below to 1000 psi. Blow down and rig down all circ lines. 18:00 - 19:00 1.00 PULL P DECOMP Nipple down tree 19:00 - 21 :00 2.00 PULL P DECOMP Nipple up 13 5/8" BOPE. 21 :00 - 00:00 3.00 PULL P DECOMP Test BOPE to 250 psi low and 4000 psi high. Test annular preventor to 250/3500 psi. Witness of test was waived by AOGCC Rep John Crisp. Test was witnessed by WSL James Willingham. 3/27/2005 00:00 - 03:00 3.00 BOPSU P DECOMP Test BOPE to 250 psi low test and 4000 psi high. Upper rams = 3.5" X 6", blind shears, 27/8" X 5" rams in bottom. Tested Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: with 5 112" test joint. Rig down test equipment. Witness of test was waived by John Crisp with the AOGCC. Test was witnessed by WSL James Willingham. 03:00 - 04:00 DECOMP PJSM. Pull tubing hanger blanking plug with drill pipe. RlU drill site maint and pull BPV valve from tubing hanger with lubricator. Rig down DSM. 04:00 - 06:00 2.00 PULL P DECOMP BOLDS and pull 5 1/2" tubing and hanger to rig floor. UD landing joint and hanger, clear rig floor. 06:00 - 10:00 4.00 PULL P DECOMP PJSM with drill crew and Schlumberger. RlU control line spooling unit and POH with 5 1/2", 17 # tubing from 9410' to 7166'. 10:00 - 10:30 0.50 PULL P DECOMP UD SSSV. Rig down control line spooling unit. Clear rig floor. 10:30 - 11 :00 0.50 PULL P DECOMP POH UD tubing frpom 7166' to 6600'. 11 :00 - 12:00 1.00 PULL P DECOMP Took 1 bbl gain in pits. Monitor well. Rig up to circulate. CBU @ 6600' @ 10.5 bpm @ 830 psi. Intermittent gas bubbles to surface. Well stable. 12:00 - 18:30 6.50 PULL P DECOMP POH with 51/2" 17 # tubing from 6600'. Recovered 221 jts, 9 GLM, 1 SSSV and 1, 20' cut joint. Recovered all control line clamps and bands. 18:30 - 20:00 1.50 PULL P DECOMP Clear & clean rig floor. RID tubing tools. 20:00 - 21 :30 1.50 PULL P DECOMP R/U and test BOPE. Tested to 250 psi low and 4000 psi high. Test annular preventor to 250/3500 psi. Pull test plug, RID test equipment. Tested with 4" test joint. Test was witnessed by WSL James Willingham. 21 :30 - 23:00 1.50 PULL P DECOMP MIU whipstock string & starting mills on 6 1/2" drill collars, PIU jars & HWDP. 23:00 - 00:00 1.00 PULL P DECOMP RI H picking up 4" HT 40 drill pipe to tubing cut @ 9410'. Clean out/gauge trip. 3/28/2005 00:00 - 04:30 4.50 PULL P DECOMP RIH picking up 4" HT40 drill pipe, tagged 5 1/2" tubing stump @ 9400'. 04:30 - 06:30 2.00 PULL P DECOMP Cut & slip drill line. Service rig & top drive. Inspect brakes. 06:30 - 10:00 3.50 WHSUR P DECOMP POH from 9400' to BHA @ 904', change elevators. 10:00 - 11 :00 1.00 DHB P DECOMP MIU HES RTTS and RIH, set with 50K of BHA weight 5' below wellhead. 11 :00 - 13:00 2.00 WHSUR P DECOMP Nipple down BOPE & 135/8" tubing spool. 13:00 - 17:00 4.00 WHSUR P DECOMP Remove tubing spool, pull and replace pack-off. Nipple up new 135/8" 5M two step split speed head. Test all to 5000 psi, OK. 17:00 - 18:00 1.00 WHSUR P DECOMP Nipple up BOPE. 18:00 - 20:00 2.00 WHSUR P DECOMP Set test plug, test break @ tubing spool and body test BOPE to 250/4000 psi, OK. Test witnessed by WSL James Willingham. Pull test plug & set wear ring. 20:00 - 21 :00 1.00 DHB P DECOMP MIU RTTS retreiving tool on drill pipe, engage RTTS and release, POH with RTTS. 21 :00 - 22:00 1.00 DHB P DECOMP POH with BHA and rack back. UD gauge mills. 22:00 - 00:00 2.00 DHB P DECOMP PJSM, R/U Schlumberger E-line unit. MIU 9 5/8", HES CIBP, RIH with CCL and CIBP [to be set @ +- 9220'.] 3/29/2005 00:00 - 02:00 2.00 DHB P DECOMP PJSM: RIH with CIBP and CCL on E-line, set plug, top @ 9200' 4" above collar. POOH with wire line and rig down. 02:00 - 03:00 1.00 DHB P DECOMP PJSM: TEST 9 518" casing and CIBP to 4000 psi for 30 min on chart, good test. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 312912005 03:00 - 05:30 2.50 STMILL P WEXIT PJSM: PIU 95/8" whip stock BHA, up load MWD tools. BHA total length 955'. 05:30 - 06:30 1.00 STMILL P WEXIT Shallow hole test MWD at 955' depth. 500 GPM = 900 psi. MWD not detecting, trouble shoot and fix connection at surface. 06:30 - 11 :30 5.00 STMILL P WEXIT Run in hole from 955 to 9150'. Break circulation every 3000' and test MWD. Install blower hose and ready top drive. 11 :30 - 12:30 1.00 STMILL P WEXIT PJSM: Orient whipstock to 60 degrees left of high side at 9150 feet. Slack off to 9187' Set whipstock at 60 degrees left of high side. Slack off weight = 165,000# Pick up weight = 195,000# Rotating weight = 180,000# 490 GPM = 2100 psi. 12:30 - 13:00 0.50 STMILL P WEXIT Displace well to 11.5 ppg LSND mud at 490 GPM = 2000 psi. 13:00 - 20:30 7.50 STMILL P WEXIT Mill window from 9166to 9194' Milling torque 8,000 - 11,000# Weight on mills = 8-10,000# RPM=90-100 Flow rate = 490 GPM and 2600 psi. Average ROP milling 4.02 feet per hour. 20:30 - 21 :00 0.50 STMILL P WEXIT Circulate sweep as working through window. Window clean pumps on and off. Have recovered 170# total metal. Circulate hole until clean. 21 :00 - 21 :30 0.50 STMILL P WEXIT PJSM: Pull to above top of window and perform FIT. TOW = 9166' MD = 7884' TVD BOW = 9183" MD = 7896' TVD FIT test to 12.8 PPG with 11.5 PPG mud in well = 535 psi surface pressure. Took 27 strokes (1.46 bbl's) to achieve 535 psi. Bleed down in 10 minute to 340 psi equal to 12.35 PPG. Flow checked well. Pump dry job. 21 :30 - 00:00 2.50 STMILL P WEXIT PJSM: Pull out of hole from 9166 to 2245' Well taking correct fill up. 3/30/2005 00:00 - 01 :30 1.50 STMILL P WEXIT Pull out of hole to from 2245 to 5" HWDP 955'. 01 :30 - 04:30 3.00 STMILL P WEXIT PJSM: Lay down drill collars and stand back HWDP. Down load MWD and handle BHA. 04:30 - 06:30 2.00 STMILL P WEXIT PJSM: Clear rig floor. Claiper Mills I Full Gauge. Pull and service wear ring. Fuction rams and flush stack. Rig up super sucker and clean drain pans on rig floor and steam table. 06:30 - 08:30 2.00 STMILL P WEXIT PJSM: Make up drilling BHA. Calculate MWD / motor tool face offset and pick up non mag drill collars. Shallow hole test at 500 GPM = 1000 psi. RIH to 755 feet picking BHA and HWDP. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 313012005 08:30 - 12:00 3.50 STMILL P WEXIT Trip in hole from 755 feet to 9158 feet just above whip stock. 12:00 - 13:00 1.00 STMILL P WEXIT PJSM & review procedure: Service top drive & draw works. 13:00 - 14:00 1.00 STMILL N RREP WEXIT Rig repair: Found bad valve on torque boost top drive and replaced. 14:00 - 14:30 0.50 STMILL P WEXIT PJSM: Resumed operations. Set tool face to 60 degrees left of high side and exit window. Wash hole to 9194' 450 GPM 3100 psi off bottom. 14:30 - 00:00 9.50 DRILL P INT1 Drill 9194 feet to 9625 feet. 4.75 sliding hours 1.8 rotating hours String weight up = 185,000# Slack off weight = 140,000# Rotating weight = 160,000# Torque 7500 - 10,000 ft/# @ 60 RPM. Mud weight 11.6 ppg runniing water @ 12 bph. viscosity 46. YP =40 Reducing YP to target of 28 - 30 #/100 cuft 430 feet drill in the last 24 hours with and averge ROP of 65 FPH 293 feet slide at 61 FPH in 4.75 sliding hours 137 feet rotated in 1.8 hours with rotating ROP average of 57 FPH Jars have 16.15 total hours with 9.6 hours this well. 3/31/2005 00:00 - 06:00 6.00 DRILL P INT1 Drill 9625 feet to 9910 feet. I String weight up = 185,000# Slack off weight = 140,000# I Rotating weight = 160,000# Torque 7500 - 10,000 ft/# @ 80 RPM. Mud weight 11.6 ppg runniing water @ 12 bph. viscosity 42. YP =38 Directional work mostly done. Inclination @ 64 degrees azimuth @ 294 and will require turning to 300 to stay close to line. 9880 feet: Hole tight after shutting down pumps for survey. Worked free without firing jars. 06:00 - 12:00 6.00 DRILL P INT1 Drill 9910 to 10230' MD From Midnight to noon: 4.8 slide hours 3.33 rotating hours String weight up = 185,000# String weight down +140,000# String weight rotating = 160,000# Torque 6,000 off 9,000 on bottom. 510 GPM = 4000 psi off botton and 4150 psi on bottom. 12:00 - 00:00 12.00 DRILL P INT1 Noon to Midnight: Drill from 10230 to 10898' 1.89 sliide hours 8.34 rotaing hours String weight up = 185,000# String weight down + 140,000# String weight rotating = 160,000# Torque 7,500 off 10,000 on bottom. 510 GPM = 4000 psi off botton and 4200 psi on bottom. Last 24 hours: Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 3/3112005 12:00 - 00:00 12.00 DRILL P INT1 1274 feet drill in the last 24 hours with and averge ROP of 69 FPH 375 feet slide at 56 FPH in 6.69 sliding hours 899 feet rotated in 11.67 hours with rotating ROP average of 77 FPH Jars have 35 total hours. 4/1/2005 00:00 - 01 :30 1.50 DRILL P INT1 Drill from 10898' to 10958' TD 7" Casing point. .84 Rotaing Hours String weight up = 185,000# String weight down =140,000# String weight rotating = 160,000# Torque 7,500 off 10,000 on bottom. 510 GPM = 4000 psi off botton and 4200 psi on bottom. Midnight intill 1 :30 60 feet drilled in .85 drilling hours. Avergage ROP = 70 prh RPM 100/WOB 12-15K Maximum stand pipe pressure reached with depth and mud weight. \ BHA drilled 1764 feet in 25.74 hours. Average ROP = 68 FPH. 01 :30 - 02:45 1.25 DRILL P INT1 Circulate bottoms up to look at samples. Geology confirm Sag River and casing point. 02:45 - 04:30 1.75 DRILL P INT1 Circulate and condition mud. Weight up from 11.6 to 11.8 ppg. 04:30 - 05:30 1.00 DRILL P INT1 Short Trip to window at 9166' Short Trip was wet. Called 5700 and notified of wet trip and mud release of 1.5 barrel into secondary containment. 05:30 - 07:00 1.50 DRILL P INT1 MADD Pass from 9230' to 9060' logging up for tie in data @ 180 FPH. 07:00 - 08:00 1.00 DRILL P INT1 Service Top Drive and Rig. 08:00 - 09:00 1.00 DRILL P INT1 Slip & Cut drilling line. 09:00 - 09:30 0.50 DRILL P INT1 PJSM: Trip in hole from 9166 (window) to 10958" No tight spots or fill. 09:30 - 11 :00 1.50 DRILL P INT1 Circulate Sweep 500 GPM @ 4130 PSI. Spot Liner running pill with 4% lube and pump dry job. 11 :00 - 15:30 4.50 DRILL P INT1 PJSM: Pull out of hole from TD @ 10958 to 755'. No tight spots seen in open hole or at window. 15:30 - 18:30 3.00 DRILL P INT1 PJSM: Lay down BHA Flush tools, and read MWD. Grade bit 0-3-CT-G-X-I-WT-TD 18:30 - 19:30 1.00 RIGU P LNR1 PJSM: Rig up to run 7" liner. 19:30 - 22:00 2.50 RIGU P LNR1 Pick Up and run 7" liner to hanger @ 1950' I 46 Joints 7" 26 #/ft BTC-M 22:00 - 22:30 0.50 RIGU P LNR1 PJSM: Make up Baker liner hanger. 22:30 - 23:00 0.50 RIGU P LNR1 Circulate liner volume 8 BPM @ 400 psi. Rig down handling tools, blow down top drive. Estibilish liner weight: 70K up / 65K down. 23:00 - 00:00 1.00 RIGU P LNR1 RIH from 2072 feet to 4315. Hole not any taking fluid and correct displacement. 4/2/2005 00:00 - 03:00 3.00 CASE P LNR1 RIH from 4315 to 9076' to above window. 03:00 - 03:30 0.50 CASE P LNR1 Circulate Liner volume before going into open hole. 8 BPM 1400psi Circulating at shoe. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 412/2005 03:00 - 03:30 0.50 CASE P LNR1 135,000 down weight 180,000# Up weight 03:30 - 04:30 1.00 CASE P LNR1 Trip into open hole with liner from 9166 tp 10560'. 04:30 - 06:00 1.50 CASE P LNR1 Work casing through Kingak without pumping from 10560 to 10958' Free up I stacking out down. Work casing to bottom. Pick up cementing head. Break circulation. 06:00 - 07:30 1.50 CASE P LNR1 Stage up pumps starting at 1/2 BPM. @ 450 psi Getting full returns and no packing off at 1 BPM @ 560 psi Continue to stage up slowly. 1.5 BPM @ 640 PSI Good job by rig crew working pipe to bottom. 07:30 - 09:30 2.00 CASE P LNR1 PJSM: Cement Job: Pump 5 bbl's H2O Test lines to 4500 psi. Have leeak / check and repair. Re-test lines to 4500. Flush lines / no water down hole. Pump 35 bbl's Mud Push XL @ 12.8PPG Pump 74 BBL's Class G Cement at 15.8ppg Wash line I drop dart. Displace with Schlumberger 90 bbl's to latch Displace 161 bbls to bump plug to 3500 psi. Set hanger Bleed offf and check float equipment I holding. Pressure up to 1000 psi. Unsting and pump 500 strokes @ 220 psi. Set down 65,000# and rotate to set packer. Cement in place @ 9:10 hrs 09:30 - 11 :00 1.50 CASE P LNR1 Circulate bottoms up at 200 spm 3800 psi. 20 BBL's cemenet to surface. 155,000# Up weight! 130,000# down weight Pump dry job to pull out of hole. 11 :00 - 12:00 1.00 CASE P LNR1 Pull out of hole 8990 to 6910 feet. 12:00 - 12:30 0.50 CASE P LNR1 Inspect and adjust brakes. / Rig Service. 12:30 - 15:00 2.50 CASE P LNR1 Pull out of hole from 6910 to running tool. Lay down running tool. Clear rig floor. 15:00 - 16:00 1.00 CASE P LNR1 PJSM: to rig up and run casing. 16:00 - 16:30 0.50 CASE P LNR1 Rig up casing equipment and test casing 3000 psi. Chart and hold 5 minutes. 16:30 - 21 :30 5.00 CASE P LNR1 Pick up 7" 26#/ft BTC-M Scab liner to 6337' 159 joints Joints #2 and 109 - 159 are new & Joints # 1,3-108 are condition Bused. 21 :30 - 22:00 0.50 CASE P LNR1 Make up liner hanger and liner top packer. 22:00 - 00:00 2.00 CASE P LNR1 Circulate liner volume and condition mud. Rig down handling equipment. Started in hole and mud flowing over top drill pipe onto rig floor into secondary containment. Aprox 8 bbi's. Called 5700 and notified. 4/3/2005 00:00 - 02:00 2.00 CASE P TIEB1 Run in hole with 7" scab liner. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 413/2005 00:00 - 02:00 2.00 CASE P TIEB1 215,000# Up 145,000 # Down 02:00 - 03:00 1.00 CASE TIEB1 Adjust Time for Daylite savings 03:00 - 04:00 1.00 CASE P TIEB1 Tag up to nogo at 8990. Presure up and pull to expose ports. Circulate @ 5 bpm 1120 psi. 04:00 - 05:30 1.50 CASE TIEB1 Circulate at 5.5 bpm to condition hole for cement. PJSM: Prime & ready cementers. 05:30 - 08:00 2.50 CEMT TIEB1 Pump 5 bbls water test lines to 4500 psi. Pump 20 bbls 12.8 ppg Mud push. Pump 144 bbls lead cement @ 13.5 ppg class G cement. 27 bbls class G @ 15.8 ppg Wash line through T at rig floor. Dispace with 272 bbls and plug did not bump. Set down to seal tie back. Cement in place at 07:30 hrs Pressure up to 4500 psi to set hanger and packer. Bleed off pressure and check seals. Holding. Pressure up to 1000 psi and pick up out of liner. 07:30 - 08:00 0.50 CEMT P TIEB1 Set liner hanger and packer. 08:00 - 09:00 1.00 CASE P TIEB1 Circulate bottoms up at 200 spm @ 2400 psi. 2 bbls cement to surface. 09:00 - 09:30 0.50 CASE P TIEB1 Pump dry job. Blow down surface equipent and lay down cement head. 09:30 - 11 :00 1.50 CASE P TIEB1 Pulll out of hole from 2625' to running tool. Lay down running tool and clear rig floor. 11 :00 - 13:00 2.00 CASE P TIEB1 PJSM: Pick up cleanout BHA and drill pipe to 1309 feet. 13:00 - 15:30 2.50 P TIEB1 Run in hole from 1309 to 8815'. Break circulation every 3000' 15:30 - 16:00 0.50 CASE P TIEB1 PJSM: Test casing to 4000 PSI chart and hold 10 minutes. Blow down top drive and install blower hose. 16:00 - 19:30 3.50 CASE P TIEB1 Drill cement at 8880. Drill float equipment on depth. Tag liner landing collar 10871. 19:30 - 20:30 1.00 CASE P TIEB1 Circulate bottoms up 9 bpm 3600 psi to even mud weight in and out. 20:30 - 21 :30 1.00 CASE P TIEB1 PJSM: Test casing to 4000 psi for 30 minutes and chart. Blow down surface equipment. 21 :30 - 23:00 1.50 CASE P TIEB1 Drill float equipment to 10950' 23:00 - 00:00 1.00 CASE P TIEB1 Pump 75 bbl's water. 40 bbls hi-vis spacer with lube. Displace well to Flo-pro 8.5 ppg mud at 520 GPM 2150 psi. 4/4/2005 00:00 - 01 :30 1.50 CEMT P TIEB1 Displace to Flo-pro mud @ 520 gpm 2150 psi. Drill shoe track and circulate bottoms up. 01 :30 - 02:30 1.00 CASE P TIEB1 Slip and cut drill line and service draw works. Service top drive. 02:30 - 06:30 4.00 DRILL P TIEB1 Pump dry job. POOH from 10958 to BHA. 06:30 - 07:00 0.50 DRILL P TIEB1 Lay down BHA from 375 to 190 feet. Stand back remaining BHA in derrick. 07:00 - 07:30 0.50 DRILL P TIEB1 PJSM: Rig up Schlumberger wire line to run USIT log. 07:30 - 11 :00 3.50 DRILL P TIEB1 RIH and log with Schlumberger for cement quality USIT log. Log showed good. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 414/2005 11 :00 - 14:00 3.00 DRILL P TIEB1 PJSM: Make up Directional BHA. Orient MWD to motor. Upload MWD and shallow hole pulse test 250 GPM @ 1060 psi Blow down top drive. 14:00 - 17:30 3.50 DRILL P TIEB1 PJSM: Run in hole to 10959 breaking circulation and testing MWD every 3000 feet. Install blower hose. Estabilish String weight: 170,000# Up 145,000# down 160,000# Rotating slowly. Torque = 4-6000 ft# 17:30 - 19:00 1.50 DRILL P PROD1 Drill Curve with 2.12 bend motor and Hughes MX09 tricone from 10958 to 10979. Drill 20 feet for FIT test. BHA hanging up in shoe track while sliding. 19:00 - 19:30 0.50 DRILL P PROD1 Preform FIT test to 10.0 PPG equivlant mud weight. TVD = 8760' @ 7" casing shoe. Mud weight 8.4 PPG. Surface pressure taken to 730 psi. Chart and record. 19:30 - 00:00 4.50 DRILL P PROD1 Drilled from 10979 to 11086 with 2.12 bend slow speed motor. 119 feet slide in 4.42 hours average ROP = 26.92 fph 9 feet rotated at 3 rpm in .22 hours average ROP 40.91 fph Motor yielding 24-dergee doglegs in full slide. Flowing 275 gpm at 2130 psi off bottom and 2300 psi on bottom. Geology came in lower than expected and the planned dip down into shublik was not required. At 11077 locked in at 89-90 degrees inclination and hole till BHA is in reduced dogleg. Rotaing slowly (3 - 5 RPM) to allow BHA to exit 24 degree doglegs. 4/5/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill from 11086 to 11192' WOB = 20 - 25K RPM 3 - 5 Torque 6000ft# String weight: 175,000# Up 140,000# Down 160,000# Rotating BHA building slightly when rotated Slide hours = 0 Rotating hours = 2.61 03:00 - 03:30 0.50 DRILL P PROD1 Circulate and pull to casing shoe at 10958'. No tight spots seen. 03:30 - 04:30 1.00 DRILL P PROD1 Pull to casing shoe open cir-sub. Circulate with cir-sub open at 11 BPM 1520 psi. Monitor well & pump dry job. 04:30 - 08:00 3.50 DRILL P PROD1 Pull out of hole from 10912 to 362' to change BHA to 5" motor and PDC bit. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 415/2005 08:00 - 09:30 1.50 DRILL P PROD1 PJSM: Change out handling tool. Pull BHA, and astand back HWDP & Jars. Flush motor and MWD with fresh water. Down load MWD & lay down motor & MWD tools. MX09DX graded 1-2-CT -H-E-I-ER-BHA 09:30 - 12:00 2.50 DRILL P PROD1 PJSM: Make up BHA. Uplaod MWD tool. Surface test MWD and motor 250 GPM @ 910 psi. Install nukes and make up BHA from derrick. Change out handling tools. 12:00 - 14:00 2.00 DRILL P PROD1 Pick up singles of drill pipe to allow drilling to TD of 14,292' plus 200' extra. Depth = 3551 ' 14:00 - 17:00 3.00 DRILL P PROD1 Trip in hole form 3551 to 10958' at 7" casing shoe. Filling pipe every 3000' and testing MWD. 17:00 - 19:00 2.00 DRILL P PROD1 At casing shoe hole became tight and required reaming and working. Had some packing off and showed signs of open Kingak. Washed and reamed through from 10958 to 10998' after which hole was clean. Bottoms up showed 80% small Kingak shale, no large slivers. Looked like swelling rather than sluffing. Worked tight hole and cleaning up from 17:30 to 18:45 hours 18:45 to 19:00 tripped to bottom. Hole from 10998 to 11192' looked good. 19:00 - 00:00 5.00 DRILL P PROD1 Drilled form 11192 to 11579' in 2.59 total drilling hours. 73 feet slide in 1.1 hours with avergae ROP = 66 FPH 315 feet rotated in 1.49 hours with an average ROP of 211 FPH rotating at a controled rate of 225 fph maximum for log quality. WOB = 8 - 12K RPM 30-80 Torque 6-8000ft# String weight: 180,000# Up 135,000# Down 160,000# Rotating BHA dropping slightly when rotated as a result of control drilling. Stable at full weight on bit. 4/6/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill from 11579 to 11762'. 1.56 rotating hours .22 sliding hours ROP rotating is 200 FPH controlled String weight: 180,000# Up 160,000# Rotating 145,000# Down Torque = 6 - 8000 ft# Flow 295 gpm 2300 psi off bottom 2800 on bottom. 03:00 - 04:00 1.00 DRILL P PROD1 Circulate hole clean before short trip @ 300 GPM 2400 PSI Spot Safe-carb pill in open home to help with open hole Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 416/2005 03:00 - 04:00 1.00 DRILL P PROD1 sticking. Monitor well. 04:00 - 05:00 1.00 DRILL P PROD1 Short trip to casing shoe 9 stands. Short trip wet of bottom. 04:00 Call 5700 and notify of wet trip and 2 barrel release into secondary containment / controlled. Short trip went well with NO TIGHT SPOTS. No over pull through or back into Kingak section. 05:00 - 00:00 19.00 DRILL P PROD1 Drill 11762 t013380' Geology instructions to hold 90 degrees and allow dip of 1.5 degrees up to come up to us. Looks as if we are very close to the top of zone. Last 24 Hours: Drilled from 11579 - 13380' (1801 ') in 12.51drlling hours 435 feet slide in 5.47 slide hours with average ROP 79 FPH sliding. 1366 feet rotated in 8.04 rotating hours with a average ROP 170 fph rotating. 21 :00 hrs added 3000 barrels mud to reduce mud weight fron 8.7 to 8.6 ppg holding. 190,000# Up 150,000# Rotating 120,000# Down Torque = 9 - 11000 ft# @ 80 RPM Torque increase quickly after adding black products building tougher skin. Flow 295 gpm 2300 psi off bottom 2800 on bottom. 4/7/2005 00:00 - 06:00 6.00 DRILL P PROD1 Drill 13380 to 14100. Mostly rotating @ 80 RPM. Bumping for inclination correction only. Torque @ 11,000 ft# Up drag increase to 195,000# Down 145,000# Rotating 150,000# WOB 8- 15,000 No losses at fault. Mud weight @ 8.6^ with 48 vis holding while adding water @ 20 bph. Running all rig solid control. ABI quit working at 03:00 hrs. 06:00 - 09:00 3.00 DRILL P PROD1 Continue drilling ahead to TD at 14250' MD. Geologist called TD approx 40' short of plan. 195k up. 115k down. 155k Rot. Torque 9k off. 11 k on btm. 300 gpm @ 3150 psi. 80 RPM. 10k WOB. 24 Hour Drilling Summary: Drilled 870 feet in 4.94 drilling hours; 86 feet sliding in 1.06 hours averge 81 fph 784 feet rotated 3.88 hours 202 fph average rotating ROP. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 4/7/2005 09:00 - 11 :00 2.00 DRILL P PROD1 Circ Hi Vis sweep around Surf to Surf. Hole condition good. No inication of any problems/sloughing with exposed Kingak. 310 gpm @ 2775 psi. Rotary at 100 rpm. Monitor well - OK. 11 :00 - 13:00 2.00 DRILL P PROD1 Made 36 stand wet trip up to 7" casing shoe to check hole condition. Hole in very good shape with no overpulls and no indication of any deterioration of Kingak shale. During the wet trip, spilled 36 bbls drilling mud into secondary containment and 5 bbls wash water contaminated with mud from cleaning off rig floor. Total spill volume of 41 bbls called in to 5700. 13:00 - 15:00 2.00 DRILL P PROD1 Service top drive. slip and cut driling line & Adjust brakes 15:00 - 16:30 1.50 DRILL P PROD1 RIH 10958 to 14226 tag up. Ream from 14226 to 14250. 16:30 - 18:30 2.00 DRILL P PROD1 Circulate @ 305 GPM 2750 psi. Pump hi-vis sweep and spot liner running pill. Monitor well. 18:30 - 20:30 2.00 DRILL P PROD1 PJSM: Pull out og hole wet for 34 stands: Call 5700 and report controlled discharge of drilling mud, 33 barrels into secondary containment. No problem tripping through open hole. 20:30 - 21 :00 0.50 DRILL P PROD1 Drop dat open cir-sub and pump dry job. Remove blower hose and prepare for trip. 21 :00 - 00:00 3.00 DRILL P PROD1 PJSM: Pull out of hole from casing shoe @ 10958 to 1683'. 4/8/2005 00:00 - 01 :30 1.50 DRILL P PROD1 Pull out of hole to BHA. Flush tools with fresh water. 01 :30 - 03:00 1.50 DRILL P PROD1 PJSM: Unload nuke sources. Down load tool Lay down BHA Bit in good contition for rerun 1-2-CT-N-X-I-ER-TD 03:00 - 03:30 0.50 CASE P RUNCMP PJSM: Rig up liner running tools. 03:30 - 04:30 1.00 CASE P RUNPRD Make up shoe track 4.5" liner. Baker lock as required. 04:30 - 08:00 3.50 CASE P RUNPRD Make up 4.5" liner and run in hole. 79 total joints Centralizers on every joint floating. 08:00 - 09:00 1.00 CASE P RUNPRD Make up hanger and liner top packer. Run 1 stand DP to 3587' Liner weight up = 70K Liner weight down = 70K 09:00 - 10:00 1.00 CASE P RUNPRD Safety "Session" with Mike Schultz 10:00 - 10:30 0.50 CASE P RUNPRD Circulate liner volume. 6BPM = 270 psi. Blow down top drive and prepare to run in hole. 10:30 - 14:30 4.00 CASE P RUNPRD Run liner in on drill pipe from 3587 to 10958. Fill pipe every 10 stands 14:30 - 15:00 0.50 CASE P RUNPRD Circulate liner and drill pipe volume at 5 BPM 730 psi String weight up = 170,000# Down = 140,000# 155,000# rotating at 20 rpm 4500 ft3 torque. Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 4/812005 14:30 - 15:00 15:00 - 16:30 0.50 CASE P 1.50 CASE P RUNPRD RUNPRD Run in open hole with liner from 10958 to 14229 fill on fly. No tight spots or resistance seen through open Kingak section. 16:30 - 17:30 1.00 CASE P Make up cement head. RUNPRD Break circulation 1 bpm and tag bottom 14250 on depth. 190,000# up 130,000# down Bring up rate staging to 6 bpm @ 1360 psi. No packing off. Circulate 3 times bottoms up. WAIT RUNPRD Circulate while waiting on trucks. Hold PJSM prior to batching up. RUNPRD Circulate while batchmixing cement RUNPRD Pump 5 bbls water to test lines. Test lines to 4500 psi. Pump 25 bbl's 9.5 ppg mud push Pump 89 bbl's Class G cement @ 15.8 ppg Drop dart Pump perf pill 60 bbl's Cement turned corner plus 40 bbls drag increase and went to bottom and parked I ended reciprocation of 20 feet stroke. 108 bbls total displacement dart latch up seen. 156 total barrels plug bumped to 3,500psi Pressure up to 4,500 psi to set hanger. Bleed off pressure and check float equipment! holding. Pick up to check hanger setting. Hanger did not set. Re-pressure to 4,600 psi and attempt to set hanger again. Bleed off pressure. Check up weight and hanger did not release. Pressure up and work string with pressure on string. Bleed off pressure. Check string weight. Hanger released and set. Release from hanger 80,000 down Pressure up to 1000 psi and pull up out of packer. Rotate to confirm. Cement on place @ 21 :20 hrs. 17:30 - 19:00 1.50 CASE N 19:00 - 20:00 20:00 - 21 :30 1.00 CASE P 1.50 CEMT P 21 :30 - 22:30 1.00 CEMT P RUNPRD Circulate bottoms up at 11 bpm = 2600 psi. 25 total barrels cement & contaminated mud back to surface. 22:30 - 23:00 0.50 CASE P RUNPRD Break down cement head and lay down with single of drill pipe. 23:00 - 00:00 1.00 CASE N WAIT RUNPRD Circulate while waiting on trucks for sea water. Clean out shakers and return equipment. 4/9/2005 00:00 - 02:00 2.00 CASE N WAIT OTHCMP Waiting on trucks for sea water displacement 02:00 - 03:30 1.50 CASE P OTHCMP Circulate well to sea water at 10 bpm = 1700 psi. Pump dry job and blow down top drive. Printed: 4/18/2005 9:37:04 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 419/2005 03:30 - 05:30 2.00 CASE P OTHCMP Pull out of hole laying down single drill pipe (114 joints) from 10779 to 7180' 05:30 - 08:30 3.00 CASE P OTHCMP Pull out of hole from 7180 to liner running tools. Change out handling tools and lay down liner running tool. 08:30 - 09:00 0.50 CASE P OTHCMP Test casing to 4000 psi hold for 30 minutes and chart - good test. 09:00 - 15:00 6.00 CASE OTHCMP Make up perf guns and space out with 2 7/8" drill pipe. 15:00 - 20:00 5.00 PERFO OTHCMP Run in hole with perf guns. from 3481 to 14163 feet. Tag up on depth at landing collar and pick up to space out 163 feet. Bottom shot at 14000' . 20:00 - 20:30 0.50 PERFO OTHCMP Break circulation and line up to fire guns. 20:30 - 21 :00 0.50 PERFO OTHCMP PJSM: Close pipe rams and open kill line. Pressure up to 3000 psi Bleed off to 0 psi. open well wait 5 minutes and both set guns fire. Fluid dropped 6 - 7 barrels first fire and 3 - 4 barrels second fire. Perf Intervals: 11100- 11180' (80') 11280 - 11360' (80') 11460 - 11550' (90') 12100 - 12600' (500') 12850 - 13350' (500') 13550 - 13700' (150') 13900 - 14000' (100') total perf @ 4 spf = 1500' 21 :00 - 22:00 1.00 PERFO P OTHCMP Pull out of hole to above perf's to 11045 Pump dry job Lost 4 barrels while pulling. 22:00 - 23:00 1.00 PERFO OTHCMP Lay down 4" drill pipe singles from 11045 to 9547' 23:00 - 00:00 1.00 PERFO OTHCMP Slip and cut 92' drilling line and service drwworks. 4/10/2005 00:00 - 04:30 4.50 PERFO OTHCMP Pull out of hole and lay down drill pipe from 9570' to 3481' Change out handling tools. 04:30 - 15:30 11.00 PERFO OTHCMP PJSM: Lay down perf guns all shots fired. 15:30 - 16:30 1.00 PERFO OTHCMP Rig down handling tools and clean I clear rig floor. 16:30 - 17:30 1.00 PERFO OTHCMP Make up mule shoe and run 4" drill pipe from derrick / 3172'. 17:30 - 19:30 2.00 PERFO OTHCMP Lay down 4" drill pipe. 3172 feet 1102 joints. 19:30 - 20:00 0.50 PERFO OTHCMP Pull wear ring and install test plug. 20:00 - 00:00 4.00 PERFO OTHCMP PJSM: Test BOPE. 250 low and 4000 psi high. Test witnessed waived by Chuck Scheve with AOGCC. Witnessed by WSL Mark Milam. Choke valve leaking pull apart and repair. 21 :00 - 24:00 Replace ring gasket 4/11/2005 00:00 - 01 :30 1.50 P OTHCMP Repair choke valve on BOP test. BOPE test witness waived by Chuck Scheve AOGCC. 01 :30 - 06:00 4.50 BOPSU OTHCMP Test BOPE 250 low and 4000 psi high. 250 psi low and 4000 psi high annular test to 3000 psi and 250 low. 06:00 - 07:30 RUNCMP PJSM: Pick up tongs to torque turn tubing and ready rig floor Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 18:30 - 19:00 equipment to run completion tubing. PJSM: Make up wire line entry guide and packer assembly Run 244 joints 4 .5" TCII tubing total. 4.5" WLEG 4.5" 12.6# 13Cr-80 Pup TC II 4.5" HES 'XN' Nipple: 9Cr. 3.725" No Go 4.5" 12.6# L-80 TC II Pup 4.5" 12.6# 13Cr TC II Pup 4.5" HES 'X' Nipple 9Cr. 3.813" ID 4.5" 12.6# L-80 TC II Pup 4.5" 12.6# L-80 Pup Jt TC II 7"x 4.5" Baker S-3 Permanent Packer 4.5" 12.6# L-80 Pup Jt TC II 4.5" 12.6# L-80 Pup Jt TC II 4.5" HES 'X' Nipple 9Cr 3.813" ID 4.5" 12.6# L-80 pup TC II 194 Jts 4.5" 12.6# L -80 TC II Tubing 4.5" 12.6# L-80 pup TC II 4.5" HES 'X' Nipple: 3.813" ID 4.5" 12.6# L-80 Pup TC II 49 Jts 4.5" 12.6# L-80 TC II Tubing 4.5" 12.6# L-80 TC II Spaceout Pups 18.83' 4.5" 12.6# L-80 TC II Spaceout Pups 3.79' 1 Jt (#244) 4.5" 12.6# L-80 TC II Tubing 4.5" 12.6# L-80 TC-II Hanger Pup (NSCT x TC-II) FMC Tubing Hanger Body - 4.5" NSCT Lift Thread RUNCMP Space out tubing landing to land. Add two pup joints 18.83' & 3.79' and landing tubing 140,000# up weight 115,000# down weight Landed 7' into tie back sleeve. 19:00 - 20:00 RUNCMP 20:00 - 23:00 RUNCMP 23:00 - 23:30 RUNCMP 23:30 - 00:00 0.50 WHSUR P RUNCMP 4/12/2005 00:00 - 01 :30 1.50 BOPSU P RUNCMP 03:00 - 06:00 3.00 WHSUR P OTHCMP 06:00 - 07:00 1.00 WHSUR P OTHCMP 07:00 - 13:00 6.00 WHSUR N SFAL OTHCMP Make up landing joint and tubing hanger and land tubing in well head. Rig up and reverse circulate sea water with corrosion inhibitor at 3 BPM = 200 psi. Dry rod TWC (cameron) test from below to 250 psi. Blow down all surface equipment 13:00 - 14:00 14:00 - 16:00 1.00 WHSUR P 2.00 WHSUR P Nipple down BOP's NID BOPE. Install adaptor flange, NIU tree. Test void to 5000 psi for 30 min, OK. Tree will not test. R/U drill site maint lubricator, change out two way check.Test tree to 5000 psi, no test. Install sensor & isolation valve on top of tree, pressure up to 500 psi and open & close tree valves, observe pressure drop each time a valve is cycled. Pressure up to 5000 psi on tree & hold for 30 min, pressure dropped to 4500 psi. Bleed off pressure & change TWC. Pressure up to 500 psi & cycle all valves. Test tree to 5000 psi, isolate tree & hold test for 30 min, OK. Test verified with town. OTHCMP Pull TWC with DSM lubricator. OTHCMP PJSM with LRHOS & Drill crew, R/U circulation lines & Printed: 4/18/2005 9:37:04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-13 17-13 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/23/2005 Rig Release: 4/12/2005 Rig Number: Spud Date: 12/26/1984 End: 4112/2005 14:00 - 16:00 2.00 WHSUR P 19:30 - 20:00 20:00 - 21 :00 0.50 WHSUR P 1.00 WHSUR P OTHCMP LRHOS. Reverse circ 150 BBL of diesel freeze protect @ 2.5 bpm @ 750 psi. OTHCMP Allow diesel to U-tube from annulus to tubing. OTHCMP Drop 1 7/8" ball & rod, test tubing to 4000 psi for 30 min, OK. Bleed off pressure, test annulus to 4000 psi for 30 min, OK. OTHCMP Set BPV with dry rod. OTHCMP RID circ lines. Remove 2nd annulus valve, secure well. Release rig @ 21 :00 hrs 4/12/2005 16:00 - 17:00 17:00 - 19:30 1.00 WHSUR P 2.50 WHSUR P Printed: 4/18/2005 9:37:04 AM Halliburton Sperry-Sun DEFINITIVE North Slope Alaska BPXA 17 ~ 13A . Job No. AKZZ3607846, Surveyed: 7 April, 2005 Survey Report 11 April, 2005 Your Ref: API 500292120001 Surface Coordinates: 5927702.54 N, 709343.74 E (70012' 20.7914" N, 148018'43.5930" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 64.90ft above Mean Sea Level . sper""ï"Y-SUI! DFtII...I...ING SEFtVIt::eS A Halliburton Company Survey Ref: svy4518 Halliburton Sperry-Sun Survey Report for 17-13A Your Ref: API 500292120001 Job No. AKZZ3607846, Surveyed: 7 April, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9093.90 41.420 307.580 7764.98 7829.88 2074.22 N 2656.57 W 5929702.33 N 706630.70 E 3272.39 Tie On Point MWD+IIFR+MS 9166.00 41.920 307.700 7818.84 7883.74 2103.49 N 2694.52 W 5929730.54 N 706591.95 E 0.702 3319.00 Window Point 9189.03 42.690 306.650 7835.87 7900.77 2112.86N 2706.88 W 5929739.56 N 706579.34 E 4.538 3334.10 9279.24 45.900 302.760 7900.44 7965.34 2148.65 N 2758.67 W 5929773.91 N 706526.57 E 4.660 3396.01 9372.79 47.670 299.080 7964.51 8029.41 2183.65N 2817.16 W 5929807.27 N 706467.14 E 3.434 3463.69 . 9467.42 50.770 294.880 8026.32 8091.22 2216.08N 2881.01 W 5929837.92 N 706402.42 E 4.692 3535.22 9501.37 52.580 293.440 8047.38 8112.28 2226.98 N 2905.31 W 5929848.14 N 706377.82 E 6.284 3561.85 9531.09 52.910 294.610 8065.37 8130.27 2236.61 N 2926.91 W 5929857.17 N 706355.96 E 3.324 3585.51 9561.05 53.980 294.300 8083.21 8148.11 2246.57 N 2948.82 W 5929866.52 N 706333.79 E 3.667 3609.57 9595.48 55.240 293.860 8103.15 8168.05 2258.02 N 2974.45 W 5929877 .26 N 706307.85 E 3.805 3637.64 9626.93 55.450 293.260 8121.04 8185.94 2268.37 N 2998.16 W 5929886.94 N 706283.86 E 1.705 3663.51 9655.81 57.570 292.960 8136.97 8201.87 2277.82 N 3020.31 W 5929895.77 N 706261.46 E 7.392 3687.59 968939 60500 292.990 8154.25 8219.15 2289.06 N 3046.82 W 5929906.27 N 706234.65 E 8.726 3716.37 9720.97 61.570 292.770 8169.54 8234.44 2299.80 N 3072.28 W 5929916.30 N 706208.90 E 3.443 3744.00 9749.75 63.240 293.200 8182.87 8247.77 2309.76 N 3095.76 W 5929925.61 N 706185.16 E 5.952 3769.50 9784.08 63.580 293.680 8198.24 8263.14 2321.97 N 3123.92 W 5929937.03 N 706156.66 E 1.595 3800.19 9814.96 63.330 293.760 8212.04 8276.94 2333.08 N 3149.21 W 5929947.44 N 706131.07E 0.842 3827.82 9843.33 63.110 293.600 8224.82 8289.72 2343.25 N 3172.41 W 5929956.97 N 706107.61 E 0.925 3853.14 9936.19 63.930 296.360 8266.23 8331.13 2378.36 N 3247.74 W 5929989.97 N 706031.33 E 2.803 3936.24 10028.49 65.430 299.360 8305.71 8370.61 2417.35 N 3321.48 W 5930026.90 N 705956.54 E 3.357 4019.48 10121.42 66.100 300.490 8343.86 8408.76 2459.63 N 3394.92 W 5930067.13 N 705881.96 E 1.323 4103.79 10214.54 65.840 300.560 8381.78 8446.68 2502.82 N 3468.18 W 5930108.28 N 705807.52 E 0.288 4188.31 . 10307.77 66.930 303.370 8419.13 8484.03 2548.05 N 3540.63 W 5930151.48 N 705733.84 E 2.999 4272.92 10401.11 66.040 303.580 8456.37 8521.27 2595.25 N 3612.03 W 5930196.69 N 705661.17 E 0.976 4357.37 10495.34 65.490 302.840 8495.05 8559.95 2642.32 N 3683.92 W 5930241.74 N 705588.01 E 0.924 4442.22 10587.96 65.390 303.060 8533.55 8598.45 2688.14 N 3754.61 W 5930285.58 N 705516.07 E 0.242 4525.46 10681.76 65.170 303.170 8572.77 8637.67 2734.68 N 3825.97 W 5930330.13 N 705443.44 E 0.258 4609.62 10775.54 64.880 303.300 8612.37 8677.27 2781.28 N 3897.08 W 5930374.74 N 705371.08 E 0.334 4693.56 10869.29 64.490 303.210 8652.46 8717.36 2827.75 N 3967.94 W 5930419.23 N 705298.95 E 0.425 4777.23 10895.31 64.330 303.180 8663.70 8728.60 2840.60 N 3987.58 W 5930431.53 N 705278.96 E 0.624 4800.41 10958.00 64.000 303.120 8691.01 8755.91 2871.45 N 4034.82 W 5930461.06 N 705230.88 E 0.533 4856.13 10971.83 67.140 302.420 8696.73 8761.63 2878.27 N 4045.41 W 5930467.58 N 705220.11 E 23.167 4868.58 11003.51 73.740 303.440 8707.33 8772.23 2894.49 N 4070.45 W 5930483.10 N 705194.63 E 21.053 4898.07 11031.44 79.960 302.880 8713.69 8778.59 2909.36 N 4093.21 W 5930497.33 N 705171.47 E 22.355 4924.91 11064.58 87.590 301.550 8717.28 8782.18 2926.90 N 4121.06 W 5930514.10 N 705143.14 E 23.366 4957.51 11 April, 2005 - 15:32 Page 2 of5 Dri//Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 17-13A Your Ref: AP/500292120001 Job No. AKZZ3607846, Surveyed: 7 April, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11095.77 89.380 301.010 8718.10 8783.00 2943.09 N 4147.71 W 5930529.54 N 705116.06 E 5.994 4988.44 11124.30 89.320 301.790 8718.42 8783.32 2957.96 N 4172.06 W 5930543.73 N 705091.30 E 2.742 5016.74 11139.44 88.830 302.050 8718.67 8783.57 2965.96 N 4184.90 W 5930551.37 N 705078.24 E 3.664 5031.74 11172.89 87.650 301.810 8719.70 8784.60 2983.64 N 4213.28 W 5930568.26 N 705049.38 E 3.600 5064.86 11204.22 89.690 300.320 8720.42 8785.32 2999.80 N 4240.11 W 5930583.67 N 705022.12 E 8.062 5095.95 11232.71 91.670 300.440 8720.09 8784.99 3014.21 N 4264.68 W 5930597.39 N 704997.15 E 6.963 5124.27 . 11266.13 91.230 300.000 8719.24 8784.14 3031.02 N 4293.55 W 5930613.40 N 704967.83 E 1.862 5157.49 11297.22 91.050 298.660 8718.62 8783.52 3046.25 N 4320.65 W 5930627.87 N 704940.32 E 4.348 5188.44 11325.58 91.790 297.890 8717.92 8782.82 3059.68 N 4345.62 W 5930640.60 N 704914.99 E 3.765 521672 11358.68 91.730 298.080 8716.90 8781.80 3075.20 N 4374.83 W 5930655.31 N 704885.35 E 0.602 5249.73 11390.36 91.610 298.120 8715.98 8780.88 3090.12 N 4402.77 W 5930669.45 N 704857.02 E 0.399 5281.32 11418.44 91.670 298.920 8715.17 8780.07 3103.52 N 4427.43 W 5930682.16 N 704831.99 E 2.856 5309.31 11452.17 91.790 298.750 8714.16 8779.06 3119.78N 4456.96 W 5930697.59 N 704802.02 E 0.617 5342.91 11483.26 92.100 297.700 8713.10 8778.00 3134.48N 4484.34 W 5930711.52 N 704774.25 E 3.520 5373.90 11511.50 92.530 294.140 8711.96 8776.86 3146.81 N 4509.72 W 5930723.15 N 704748.54 E 12.688 5402.10 11545.03 92.650 293.340 8710.44 8775.34 3160.29N 4540.38 W 5930735.78 N 704717.52 E 2.410 5435.59 11603.89 92.710 292.180 8707.69 8772.59 3183.04N 4594.59 W 5930757.01 N 704662.69 E 1.971 5494.37 11696.38 91.600 291.850 8704.21 8769.11 3217.68 N 4680.28 W 5930789.27 N 704576.08 E 1.252 5586.73 11790.09 90.310 293.980 8702.65 8767.55 3254.16 N 4766.57 W 5930823.34 N 704488.81 E 2.657 5680.40 11884.05 89.510 298.260 8702.80 8767.70 3295.52 N 4850.92 W 5930862.35 N 704403.35 E 4.634 5774.28 11978.01 88.460 298.860 8704.46 8769.36 3340.43 N 4933.43 W 5930904.95 N 704319.62 E 1.287 5867.94 12071.94 89.510 297.670 8706.13 8771.03 3384.90 N 5016.14 W 5930947.12 N 704235.71 E 1.689 5961.61 12164.81 89.750 293.720 8706.73 8771.63 3425.16 N 5099.81 W 5930985.04 N 704150.96 E 4.261 6054.43 . 12256.57 89.570 289.960 8707.27 8772.17 3459.29 N 5184.97 W 5931016.80 N 704064.89 E 4.102 6146.10 12350.29 90.370 290.350 8707.32 8772.22 3491.58 N 5272.95 W 5931046.64 N 703976.04 E 0.950 6239.59 12442.99 90.430 288.350 8706.68 8771.58 3522.30 N 5360.41 W 5931074.91 N 703887.77 E 2.158 6331.96 12538.12 91.230 283.080 8705.30 8770.20 3548.05 N 5451.94 W 5931098.12 N 703795.56 E 5.603 6426.02 12571.08 90.990 280.610 8704.66 8769.56 3554.81 N 5484.19 W 5931103.99 N 703763.13 E 7.528 6458.22 12602.38 91.170 280.960 8704.07 8768.97 3560.67 N 5514.93 W 5931108.99 N 703732.24 E 1.257 6488.67 12630.73 90.990 280.270 8703.53 8768.43 3565.89 N 5542.79 W 5931113.44 N 703704.25 E 2.515 6516.23 12664.38 90.310 278.440 8703.15 8768.05 3571.36 N 5575.99 W 5931117.98 N 703670.91 E 5.801 6548.76 12695.59 90.370 278.430 8702.97 8767.87 3575.94 N 5606.86 W 5931121.71 N 703639.92 E 0.195 6578.81 12723.51 90.740 276.390 8702.70 8767.60 3579.54 N 5634.54 W 5931124.54 N 703612.15 E 7.425 6605.54 12757.36 90.800 272.130 8702.24 8767.14 3582.05 N 5668.29 W 5931126.11 N 703578.35 E 12.585 6637.37 12788.60 91.230 272.580 8701.69 8766.59 3583.34 N 5699.50 W 5931126.53 N 703547.12 E 1.992 6666.37 11 April, 2005 - 15:32 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 17-13A Your Ref: API 500292120001 Job No. AKZZ3607846, Surveyed: 7 April, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 12816.94 90.310 268.920 8701.31 8766.21 3583.71 N 5727.83 W 5931126.12 N 703518.79 E 13.315 6692.38 12851 .1 5 89.940 265.230 8701.23 8766.13 3581.96 N 5761.99 W 5931123.43 N 703484.69 E 10.840 6722.84 12882.88 90.060 264.740 8701.23 8766.13 3579.19 N 5793.59 W 5931119.78 N 703453.17 E 1.590 6750.55 12911.03 89.510 261.090 8701.34 8766.24 3575.72 N 5821.52 W 5931115.53 N 703425.35 E 13.112 6774.62 12944.43 89.750 258.650 8701.55 8766.45 3569.84 N 5854.40 W 5931108.75N 703392.65 E 7.340 6802.23 12974.29 90.000 258.750 8701.62 8766.52 3563.99 N 5883.68 W 5931102.09 N 703363.54 E 0.902 6826.56 . 13002.71 89.880 257.170 8701.65 8766.55 3558.06 N 5911.48W 5931095.39 N 703335.92 E 5.575 6849.50 13096.20 89.810 256.170 8701.90 8766.80 3536.51 N 6002.45 W 5931071.33 N 703245.58 E 1.072 6923.71 13190.25 90.370 255.780 8701.75 8766.65 3513.72N 6093.69 W 5931046.01 N 703155.00 E 0.726 6997.66 13282.79 90.560 254.900 8701.00 8765.90 3490.30 N 6183.21 W 5931020.12 N 703066.16 E 0.973 7069.79 13377.27 90.990 254.440 8699.72 8764.62 3465.32 N 6274.32 W 5930992.63 N 702975.78 E 0.666 7142.73 13470.77 89.570 255.820 8699.27 8764.17 3441.33 N 6364.69 W·· 5930966.14 N 702886.12 E 2.118 7215.39 13564.40 88.520 255.590 8700.83 8765.73 3418.21 N 6455.40 W 5930940.52 N 702796.08 E 1.148 7288.73 13656.84 88.460 254.820 8703.26 8768.16 3394.62 N 6544.75 W 5930914.46 N 702707.42 E 0.835 7360.62 13750.60 89.260 254.800 8705.13 8770.03 3370.05 N 6635.21 W 5930887.40 N 702617.67 E 0.854 7433.14 13843.59 89.260 254.840 8706.33 8771.23 3345.71 N 6724.95 W 5930860.57 N 702528.64 E 0.043 7505.08 13936.55 90.620 254.680 8706.43 8771.33 3321.27 N 6814.64 W 5930833.66 N 702439.67 E 1 .473 7576.94 14030.10 90.120 254.650 8705.82 8770.72 3296.53 N 6904.86 W 5930806.43 N 702350.17 E 0.535 7649.16 14124.49 91.730 253.980 8704.30 8769.20 3271.02 N 6995.72 W 5930778.41 N 702260.05 E 1.847 7721.65 14183.04 93.150 253.430 8701.81 8766.71 3254.61 N 7051.86 W 5930760.45 N 702204.38 E 2.601 7766.18 14250.00 93.150 253.430 8698.13 8763.03 3235.54 N 7115.95 W 5930739.61 N 702140.85 E 0.000 7816.87 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 294.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14250.00ft., The Bottom Hole Displacement is 7816.99ft., in the Direction of 294.451° (True). 11 April, 2005 - 15:32 Page 4 of 5 DrillQuest 3.03.06.008 . Halliburton Sperry-Sun Survey Report for 17-13A Your Ref: API 500292120001 Job No. AKZZ3607846, Surveyed: 7 April, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9093.90 9166.00 14250.00 7829.88 7883.74 8763.03 2074.22 N 2103.49N 3235.54 N 2656.57 W 2694.52 W 7115.95W Tie On Point Window Point Projected Survey . Survey tool program for 17-13A Fro m Measured Vertical Depth Depth (ft) (ft) To r',ê:35:W"Ó Vertical Depth Survey Tool Description (ft) (ft) 0.00 9093.90 0.00 9093.90 7829.88 14250.00 7829.88 BP Conventional Gyro - GCT-MS (17-13) 8763.03 MWD+IIFR+MS (17-13A) . 11 April, 2005 - 15:32 Page 5 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun North Slope Alaska BPXA 17-13A (mwd) . Job No. AKMW3607846, Surveyed: 28 March, 2005 Survey Report 11 April, 2005 Your Ref: API 500292120001 Surface Coordinates: 5927702.54 N, 709343.74 E (70012' 20.7914" N, 148018'43.5930" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 64. 90ft above Mean Sea Level SIOE!f""'If""'IY-SUI"1 DFUI...I...ING SeRVICeS A Halliburton Company Survey Ref: svy4519 Halliburton Sperry-Sun Survey Report for 17-13A (mwd) Your Ref: API 500292120001 Job No. AKMW3607846, Surveyed: 28 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9093.90 41 .420 307.580 7764.98 7829.88 2074.22 N 2656.57 W 5929702.33 N 706630.70 E 3272.39 Tie On Point MWD Magnetic 9166.00 41 .920 307.700 7818.84 7883.74 2103.49 N 2694.52 W 5929730.54 N 706591.95 E 0.702 3319.00 Window Point 9189.03 42.690 306.650 7835.87 7900.77 2112.86 N 2706.88 W 5929739.56 N 706579.34 E 4.538 3334.10 9279.24 45.900 302.760 7900.44 7965.34 2148.65 N 2758.67 W 5929773.91 N 706526.57 E 4.660 3396.01 9372.79 47.670 299.080 7964.51 8029.41 2183.65 N 2817.16 W 5929807.27 N 706467.14 E 3.434 3463.69 . 9467.42 50.770 296.550 8026.31 8091.21 2217.04N 2880.53 W 5929838.89 N 706402.86 E 3.851 3535.18 9501.37 52.580 294.840 8047.37 8112.27 2228.58 N 2904.53 W 5929849.77 N 706378.55 E 6.636 3561.80 9531.09 52.910 296.910 8065.36 8130.26 2238.91 N 2925.82 W 5929859.49 N 706356.99 E 5.654 3585.44 9561.05 53.980 294.070 8083.21 8148.11 2249.26 N 2947.54 W 5929869.24 N 706334.99 E 8.410 3609.50 9595.48 55.240 296.390 8103.15 8168.05 2261.22 N 2972.92 W 5929880.50 N 706309.29 E 6.600 3637.56 9626.93 55.450 296.200 8121.03 8185.93 2272.69 N 2996.12 W 5929891.31 N 706285.78 E 0.832 3663.41 9655.81 57.570 294.640 8136.97 8201.87 2283.02 N 3017.87 W 5929901.04 N 706263.75 E 8.612 3687.49 9689.39 60.500 294.060 8154.24 8219.14 2294.89 N 3044.10 W 5929912.18 N 706237.20 E 8.850 3716.28 9720.97 61.570 294.020 8169.53 8234.43 2306.14 N 3069.33 W 5929922.73 N 706211.67 E 3.390 3743.91 9749.75 63.240 294.430 8182.87 8247.77 2316.61 N 3092.59 W 5929932.55 N 706188.13 E 5.938 3769.41 9784.08 63.580 295.880 8198.23 8263.13 2329.66 N 3120.38 W 5929944.82 N 706159.99 E 3.905 3800.10 9814.96 63.330 294.180 8212.03 8276.93 2341.35 N 3145.41 W 5929955.81 N 706134.65 E 4.991 3827.72 9843.33 63.110 293.130 8224.82 8289.72 2351.51 N 3168.61 W 5929965.32 N 706111.18 E 3.394 3853.05 9936.19 63.930 294.970 8266.22 8331.12 2385.38 N 3244.50 W 5929997.08 N 706034.37 E 1.981 3936.16 10028.49 65.430 299.920 8305.72 8370.62 2423.84 N 3318.50 W 5930033.47 N 705959.34 E 5.112 4019.42 10121.42 66.100 304.070 8343.88 8408.78 2468.73 N 3390.34 W 5930076.36 N 705886.28 E 4.135 4103.33 10214.54 65.840 301.150 8381.80 8446.70 2514.56 N 3461.97 W 5930120.18 N 705813.40 E 2.877 4187.44 . 10307.77 66.930 303.560 8419.15 8484.05 2560.28 N 3534.12 W 5930163.88 N 705740.02 E 2.641 4271.97 10401.11 66.040 304.250 8456.40 8521.30 2608.02 N 3605.16 W 5930209.64 N 705667.68 E 1.170 4356.32 10495.34 65.490 304.180 8495.08 8559.98 2656.34 N 3676.21 W 5930255.96 N 705595.32 E 0.588 4440.92 10587.96 65.390 303.300 8533.57 8598.4 7 2703.12 N 3746.26 W 5930300.79 N 705524.00 E 0.871 4523.97 10681.76 65.170 304.710 8572.80 8637.70 2750.77 N 3816.89 W 5930346.47 N 705452.07 E 1.385 4607.91 10775.54 64.880 304.580 8612.40 8677.30 2799.10 N 3886.83 W 5930392.84 N 705380.82 E 0.334 4691.50 10869.29 64.490 305.500 8652.48 8717.38 2847.76 N 3956.22 W 5930439.55 N 705310.12 E 0.980 4774.71 10895.31 64.330 305.290 8663.72 8728.62 2861.35 N 3975.35 W 5930452.61 N 705290.62 E 0.953 4797.73 10958.00 64.000 303.120 8691.04 8755.94 2893.07 N 4022.01 W 5930483.02 N 705243.09 E 3.160 4853.27 10971.83 67.140 305.790 8696.76 8761.66 2900.19 N 4032.38 W 5930489.86 N 705232.52 E 28.711 4865.66 11003.51 73.740 307.000 8707.37 8772.27 2917.90 N 4056.40 W 5930506.89 N 705208.03 E 21.141 4894.81 11031.44 79.960 307.070 8713.72 8778.62 2934.27 N 4078.10 W 5930522.66 N 705185.88 E 22.271 4921.31 11064.58 87.590 306.490 8717.31 8782.21 2953.98 N 4104.46 W 5930541 .63 N 705158.98 E 23.089 4953.43 11 April, 2005 - 15:32 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 17-13A (mwd) Your Ref: API 500292120001 Job No. AKMW3607846, Surveyed: 28 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 11095.77 89.380 305.680 8718.13 8783.03 2972.35 N 4129.66 W 5930559.29 N 705133.28 E 6.299 4983.93 11124.30 89.320 305.670 8718.46 8783.36 2988.98 N 4152.83 W 5930575.28 N 705109.66 E 0.213 5011.88 11139.44 88.830 304.200 8718.70 8783.60 2997.65 N 4165.24 W 5930583.60 N 705097.01 E 10.233 5026.75 11172.89 87.650 303.920 8719.73 8784.63 3016.38 N 4192.94 W 5930601.55 N 705068.81 E 3.626 5059.68 11204.22 89.690 302.230 8720.45 8785.35 3033.47 N 4219.19 W 5930617.90 N 705042.10 E 8.454 5090.62 11232.71 91.670 302.200 8720.12 8785.02 3048.65 N 4243.29 W 5930632.42 N 705017.59 E 6.951 5118.83 . 11266.13 91.230 303.620 8719.27 8784.17 3066.81 N 4271.33 W 5930649.78 N 704989.05 E 4.447 5151.84 11297.22 91.050 303.210 8718.65 8783.55 3083.92 N 4297.28 W 5930666.18 N 704962.64 E 1.440 5182.52 11325.58 91.790 300.610 8717.95 8782.85 3098.91 N 4321.34 W 5930680.49 N 704938.17 E 9.529 5210.61 11358.68 91.730 300.670 8716.93 8781.83 3115.77N 4349.81 W 5930696.55 N 704909.24 E 0.256 5243.48 11390.36 91.610 301.190 8716.01 8780.91 3132.05 N 4376.97 W 5930712.07 N 704881.64 E 1.684 5274.92 11418.44 91.670 300.370 8715.21 8780.11 3146.41 N 4401.09 W 5930725.76 N 704857.14 E 2.927 5302.80 11452.17 91.790 302.120 8714.19 8779.09 3163.90N 4429.91 W 5930742.44 N 704827.84 E 5.198 5336.25 11483.26 92.100 301.480 8713.13 8778.03 3180.27N 4456.32 W 5930758.08 N 704800.99 E 2.286 5367.05 11511.50 92.530 302.220 8711.99 8776.89 3195.16 N 4480.29 W 5930772.30 N 704776.62 E 3.029 5395.01 11545.03 92.650 285.960 8710.47 8775.37 3208.79 N 4510.76 W 5930785.07 N 704745.78 E 48.445 5428.39 11603.89 92.710 287.160 8707.71 8772.61 3225.54 N 4567.12 W 5930800.26 N 704688.98 E 2.039 5486.67 11696.38 91.600 285.750 8704.24 8769.14 3251.72 N 4655.75 W 5930823.97 N 704599.65 E 1.939 5578.27 11790.09 90.310 282.280 8702.67 8767.57 3274.41 N 4746.65 W 5930844.13 N 704508.16 E 3.950 5670.49 11884.05 89.510 298.320 8702.82 8767.72 3306.90 N 4834.48 W 5930874.18 N 704419.46 E 17.092 5763.94 11978.01 88.460 298.970 8704.49 8769.39 3351.94 N 4916.93 W 5930916.91 N 704335.80 E 1.314 5857.59 12071.94 89.510 297.710 8706.15 8771.05 3396.52 N 4999.58 W 5930959.18 N 704251.94 E 1.746 5951.25 12164.81 89.750 293.820 8706.75 8771.65 3436.88 N 5083.20 W 5930997.21 N 704167.23 E 4.197 6044.06 . 12256.57 89.570 290.200 8707.29 8772.19 3471.26 N 5168.26 W 5931029.22 N 704081.26 E 3.950 6135.74 12350.29 90.370 290.650 8707.34 8772.24 3503.96 N 5256.09 W 5931059.48 N 703992.56 E 0.979 6229.26 12442.99 90.430 288.640 8706.70 8771.60 3535.13 N 5343.38 W 5931088.21 N 703904.43 E 2.169 6321.67 12538.12 91.230 283.250 8705.32 8770.22 3561.25 N 5434.81 W 5931111.79 N 703812.31 E 5.727 6415.79 12571.08 90.990 281.040 8704.68 8769.58 3568.18 N 5467.02 W 5931117.83 N 703779.92 E 6.743 6448.02 12602.38 91.170 281 .400 8704.09 8768.99 3574.27 N 5497.72 W 5931123.06 N 703749.07 E 1.286 6478.52 12630.73 90.990 280.640 8703.55 8768.45 3579.69 N 5525.54 W 5931127.71 N 703721.10 E 2.754 6506.13 12664.38 90.310 278.930 8703.17 8768.07 3585.41 N 5558.70 W 5931132.50 N 703687.80 E 5.468 6538.73 12695.59 90.370 278.970 8702.99 8767.89 3590.26 N 5589.53 W 5931136.50 N 703656.85 E 0.231 6568.85 12723.51 90.740 277.380 8702.72 8767.62 3594.23 N 5617.16 W 5931139.71 N 703629.12 E 5.847 6595.69 12757.36 90.800 272.660 8702.26 8767.16 3597.19 N 5650.87 W 5931141.73 N 703595.34 E 13.944 6627.66 12788.60 91.230 273.060 8701.71 8766.61 3598.75 N 5682.07 W 5931142.42 N 703564.11 E 1.880 6656.77 11 April, 2005 - 15:32 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 17-13A (mwd) Your Ref: API 500292120001 Job No. AKMW3607846, Surveyed: 28 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12816.94 90.310 269.410 8701.33 8766.23 3599.36 N 5710.39 W 5931142.25 N 703535.78 E 13.281 6682.87 12851 .1 5 89.940 265.910 8701.25 8766.15 3597.97 N 5744.57 W 5931139.91 N 703501.66 E 10.288 6713.49 12882.88 90.060 264.960 8701.25 8766.15 3595.44 N 5776.20 W 5931136.51 N 703470.11 E 3.018 6741.32 12911.03 89.510 261.450 8701.36 8766.26 3592.11 N 5804.15 W 5931132.40 N 703442.27 E 12.621 6765.4 7 12944.43 89.750 259.090 8701.57 8766.47 3586.47 N 5837.06 W 5931125.85N 703409.52 E 7.102 6793.20 12974.29 90.000 259.210 8701.64 8766.54 3580.84 N 5866.39 W 5931119.42 N 703380.36 E 0.929 6817.66 . 13002.71 89.880 257.650 8701.67 8766.57 3575.14 N 5894.23 W 5931112.95 N 703352.69 E 5.505 6840.74 13096.20 89.810 256.420 8701.92 8766.82 3554.17N 5985.33 W 5931089.46 N 703262.20 E 1.318 6915.31 13190.25 90.370 256.570 8701.77 8766.67 3532.21 N 6076.78 W 5931064.97 N 703171.39 E 0.616 6989.79 13282.79 90.560 255.590 8701.02 8765.92 3509.95 N 6166.60 W 5931040.22 N 703082.23 E 1.079 7062.66 13377.27 90.990 254.950 8699.75 8764.65 3485.93 N 6257.97 W 5931013.68 N 702991.56 E 0.816 7136.22 13470.77 89.570 256.320 8699.29 8764.19 3462.73 N 6348.54 W 5930987.98 N 702901.67 E 2.110 7209.40 13564.40 88.520 255.930 8700.85 8765.75 3440.28 N 6439.42 W 5930963.02 N 702811.44 E 1.196 7283.16 13656.84 88.460 254.960 8703.29 8768.19 3417.06 N 6528.86 W 5930937.33 N 702722.68 E 1.051 7355.30 13750.60 89.260 255.240 8705.15 8770.05 3392.95 N 6619.45 W 5930910.73 N 702632.79 E 0.904 7428.11 13843.59 89.260 254.710 8706.35 8771.25 3368.85 N 6709.26 W 5930884.14 N 702543.69 E 0.570 7500.22 13936.55 90.620 254.940 8706.45 8771.35 3344.52 N 6798.97 W 5930857.33 N 702454.68 E 1.484 7572.15 14030.10 90.120 254.590 8705.84 8770.74 3319.93N 6889.23 W 5930830.26 N 702365.14 E 0.652 7644.47 14124.49 91.730 253.940 8704.32 8769.22 3294.34 N 6980.07 W 5930802.16 N 702275.05 E 1.839 7716.91 14183.04 93.150 253.480 8701.83 8766.73 3277.93 N 7036.22 W 5930784.20 N 702219.38 E 2.549 7761.44 14250.00 93.150 253.480 8698.15 8763.05 3258.92 N 7100.32 W 5930763.42 N 702155.83 E 0.000 7812.17 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 294.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14250.00ft., The Bottom Hole Displacement is 7812.49ft., in the Direction of 294.654° (True). 11 April, 2005· 15:32 Page 4 of 5 Dri/lQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 17-13A (mwd) Your Ref: API 500292120001 Job No. AKMW3607846, Surveyed: 28 March, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9093.90 9166.00 14250.00 7829.88 7883.74 8763.05 2074.22 N 2103.49 N 3258.92 N 2656.57 W 2694.52 W 7100.32 IN Tie On Point Window Point Projected Survey . Survey tool program for 17-13A (mwd) Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9093.90 0.00 9093.90 7829.88 14250.00 7829.88 BP Conventional Gyro - GCT-MS (17-13) 8763.05 MWD Magnetic (17-13A (mwd)) . 11 April, 2005 - 15:32 Page 5 of 5 Dril/Quest 3.03.06.008 17 -13 133/8",72#, L-80, --1 Casing 10 = 12.347" I 2503' /1 5 1/2", 17#, L-80, Î 9976' Tbg-PC 10 = 4,892" I Top of 7" liner H 10036' 41/2", 12.6#, L-80, 10074' Tbg-PC 10 = 3.958" 95/8",47#, L-80, 10334' Casing 10 = 8.681" IFOC H 10450' I CTM Cement retainer 1--1 10510' I Baker bridge plug H 10634' I PBTD H 10965' 7",29#, L-80, Liner, --1 11055' 10 = 6.184" I DATE 01/19/85 02/20/86 12/10/00 02/02/01 07/16/01 TREE = McEVOY GEN 3 WELLHEAD = McEVOY A CTUA TOR = AXELSON KB. ELEV = BF. ELEV = KOP= 9166' ·"_·_,_",,,,,~..,,w·,,,.=.,,_·_..,,_·_"'__,_,,_,,=,,=,,,,,,,,=_,,_=_·_~=_,,_,_y,''''''''''''.". Max Angle = 93 @ 14250' Datum MD = 10495' Datum 1VD = 8800' SS ompletion 2,238' H 41/2" 'X' landing nipple 1.0. 3.813" 95/8" X 7" Baker Flex-Lock hngr, ZXP pkr with TBS 2626' ~ 95/8" X 7" Baker HMC hngr, ZXP pkr with TBS 10707' 1--1 41/2" 'X' landing nipple I.D. 3.813" I 10728' 1--1 7" X 4 1/2" Baker S-3 permanent packer I I 10,751' H 41/2" 'X' landing nipple I.D. 3.813" I I 10,772' H 41/2" 'XN' landing nipple 1.0. 3.725" I 10,757' H 41/2",12.6#, L-80, TC-lItubing ~ 7" X 5" Baker Flex-Lock hngr, ~ ZXPpkr with TBS I 10,958' H 7",26.0#, L-80, BTC-M liner I 14,250' H 41/2",12.6#, L-80, IBT-M liner I REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-MWH CONVERTED TO CANVAS SIS-MD INrrlAL REVISION RNJTP CORRECTIONS PRUDHOE BA Y UNrr WELL: 17-13Ai ÆRMrr No: 205-026 API No: 50-029-21200-01 SEC 22, T10N, R15E, 2523.46' FEL & 5143.4' FNL BP Exploration (Alaska) DATE 11/01/04 04/12/04 REV BY dew CRM COMMENTS 17-13A Proposed Completion Actual Completion . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 17 -13A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,093.90' MD 9,166.00' MD 14,250.00' MD (if applicable) 24-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date J. ì rJ., d ò-\) i- Signed ~J ði£/ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) .Aò)"-öÀD . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 17 -13A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,093.90' MD 9,166.00 I MD 14,250.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 (1 / Date;17 /tO~\~ Signed /~ ð.1Jh'~ I I Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) 24-Apr-05 ;;z~ ç -ò;t(:) r . . ~, H,u "-"" '1""1\) ø '1rrF I ~ I? Ulb If.· I l[j\ Lru FRANK H. MURKOWSKI, GOVERNOR ÀltASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 17-13A BP Exploration (Alaska) Inc. Permit No: 205-020 Surface Location: 2944' SNL, 1078' EWL, SEC. 22, TlON, RI5E, UM Bottomhole Location: 257' NSL, 789' WEL, SEC. 17, TI0N, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission t itn ss any required test. Contact the Commission's petroleum field inspector 7) 9- 07 (p er). DATED thisi¥day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work o Drill II Redrill 11b. Current Well Class o Exploratory. (¡jl1tºi\'Bty'wt~~."" ORe-Entry o Stratigraphic Test II Service ./ 0 Developmen~ Ga~ Sìrig è 'ZoriÈf .. . 2. Operator Name: 5. Bond: !HI Blanket o Single Well 11. Well Name åíid Númber: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 17-13A /ílu" 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14292 TVD 8752 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028330 2944' SNL, 1078' EWL, SEC. 22, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 84' NSL, 3206' WEL, SEC. 16, T10N, R15E, UM March 20, 2005 /" Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 257' NSL, 789' WEL, SEC. 17, T10N, R15E, UM 2560 15,100' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance ~ Well Within Pool Surface: x-709343 y-5927703 Zone- ASP4 (Height above GL): 64.90 feet 12-25· 29 ' way at 13682' MD 16. Deviated Wells: Kickoff Depth: 9200 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 105 decrees Downhole: 3250 Surface: 2380 ./ 18. casing program: Specifications Setting Depth uuantity()fce~ent Size TOD Bottom . (c;Lorsacks Hole Casino Weioht Grade CouDling Lenath MD TVD MD TVD (includina staae data) 8-1/2" 7" 26# L-80 BTC-M 1859' 9050' 7798' 10909' 8756' ß53 sx Class 'G' ./ 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3533' 10759' 8689' 14292' 8752' 1416 sx Class 'G' /'"' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (meaSUred): Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 11060 9200 10510 10510 8882 11050 Casino Length Size Cement Volume MD TVD Co.. .^+. ."^I r.nnrl'lI"'tnr 112' 20" 1900# Poleset (Approx.) 112' 112' C. ..4^^^ 2503' 13-3/8" 300 sx CS III, 400 sx CS II 2503' 2503' 10334' 9-5/8" 550 sx Class 'G', 300 sxCS II 10334' 8756' Pror!lJr.tinn '.' I inør 1019' 7" 315 sx Class 'G' 10036' - 11055' 8532' - 9197' Perforation Depth MD (ft): 10392' - 107214' perfOration Depth TVD (ft): 8798' - 9019' 20. Attachments !HI Filing Fee, $100 o BOP Sketch !HI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report !HI Drilling Fluid Program !HI 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Bill Isaacson Title Senior Drilling Engineer l - Jl 1 Date "7."0/0'5 Prepared By Name/Number: Sionature Phone 564-5521 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill I API Number: , I Permit Approval I ,see cover letter for Number:20.Ç - OLd 50- 029-21200-01-00 Date: other requirements Conditions of Approval: Samples Required r~ Yes ß No Mud Log Required n Yes ø No ~e M.asu~es ;R! Yes ;:J No Dr..ctlonal S~",ey Required j?!~es UNo Other: T€ç+ ¡: 0 (,Ç.t. Ml- T) c...e. tv\..>€<A-t /; Ú¿iL It 1:1 loJ rei ~wd. PN7'í [ i~( 1\, ",( \:'v'IM~t<'- go PEl ~ 'ï)I'~O ,J. ¡ I ~ C \ .\ ß \ APPAOVEDBY "f~/ £' ADoroved Bv () n \ _ Ì\ THE COMMISSION Date Form 10-401 ReVised 06/2 ~ '- \.,.) t\ I"'" ¡ ¡... s6bmit fn Duplicate VJ~A- <l/l4-/Z00$ . STATE OF ALASKA . ALAS~OIL AND GAS CONSERVATION C~MISSIOtf:~~ PERMIT TO DRILL 20 AAC 25.005 . . I Well Name: I 17-13A ,/ Planned Well Summary Well Well Type Horizontal Sidetrack Injector 17 -13A Target Objective Sag River I AFE Number: I PBO 4P2317 I I API Number: I 50-029-21200-01 Surface Easti n Offsets TRS Location 709,343.74 2,335' FSL / 1,077' FWL 10 N, 15 E, 22 /' Target Offsets TRS Location 84' FSL / 2,074' FWL 10N,15E,16 Bottom Offsets TRS Location 257' FSL / 789' FEL 10N, 15E, 17 ,/ I Planned KOP: 19,200' md / 7,909' tvd I Planned TD: 114,292' md / 8,752' tvd /" I Rig: I Nabors 2ES I I CBE: 1 36.40' 1 RTE: 164.90' Directional ProQram Proximity Issues: W 06 Exit oint: 9,200' md / 7,844' sstvd -105.0° from -11,100' to -11,200' in the lanned 6 1/8" roduction section. There are two~ close approach issue"'in drilling 17 -13A. W ell 12-06A has a center-to-center distance of 729' feet at 12,521 'md, and well 12-25 has a center-to-center distance of 298' at 13,682'md. These two wells require 1/200 minor risk criteria. All other surroundin wells ass ma·or risk criteria. Standard MWD with IIFR / Cassandra. Well 12-25, with center-to-center distance of -298' at 13,682' md. 15,100' to the nearest PBU propert line. 17 -13A Sidetrack Page 1 e; . LOQclinQ ProQram Hole Section: Required Sensors I Service 81/2" intermediate: Real time MWD Dir/GR/Res/PWD throuqhout the interval 6 1/8" production: Real time MWD Dir/GABI/Res throuahout the interval. Two sample catchers. Cased Hole: USIT Open Hole: None planned Mud ProQram PV 10-15 Densit 8.5- 8.6 PV 12 -16 PV 8 -12 CasinQ I TubinQ PrOQram Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size md I tvd md I tvd 81/2" 7" 26.0# L-80 BTC-M 1,859' 9,050' I 7,798' 10,909' I 8,756' 61/8" 4%" 12.6# L-80 IBT-M 3,533' 10,759'/8,689' 14,292' I 8,752' Tubing 4%" 12.6# L-80 TC-II 10,759' Surface 10,759' I 8,689' 7",26#, L-80, BTC-M scab liner Lead slurry: -5,400' of 7" X 9 5/8" annulus, plus 100' of 9 5/8" X 4" drill pipe Slurry Design Basis: annulus. ,~{g'50' Tail slur : 1,000' of 7" X 9 5/8" annulus, Ius -45' of 7",26.0#, shoe track. Pre-Flush -100bbls fresh water s acer S acer 25bbls MudPUSH at 12.5 Fluids Sequence I Volume: Lead Slur 144.0bbl I 809 cf I 387 sx Class 'G', 12.5 ; 2.09 cf/sk. Tail Slur 27.0bbl I 153 cf 1132 sx Class 'G', 15.8 ; 1.16 cf/sk. Slurry Design Basis: Fluids Sequence I Volume: CementinQ PrOQram 17 -13A Sidetrack Page 2 ·1 Slurry Design Basis: Fluids Sequence / Volume: Test . CasinQ I Formation Intearitv Testina Test Point Test Type 30 min recorded FIT 30 min recorded FIT 30 min recorded Test pressure 4,000 si surface 12.8 EMW 4,000 si surface 10.0 EMW 4,000 si surface 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. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Annular In"ection: Cuttings Handling: --- --- Disposal No annular injection in this well. 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 e Borou h. 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. Fluid Handling: 17 -13A Sidetrack Page 3 . . GeolloQic ProQnosis Formation MD TVDbkb TVI)ss Comments SV1 UG4 UG4A UG3 UG1 WS2 WS1 6,482 CM3 CM2 7,i:.!57 CM1 8,018 THRZ 8,2:54 BHRZ 8,S25 LCU 8,S60 TKNG TJG TJF TJE 8,S,60 TJD 8,S,60 TJC 8,5,60 TJB 8,S,60 TJA 8,6,30 TSGR 8,6,92 TSHU 8,716 TSAD TZ4) TCGL TZ3) BCGL TZ2C) 23SB (TZ2Bu) 22TS (TZ2BI) 22N 21 TS (TZ2A) TZ1B TDF (TZ1 A) BSAD @ landing :rD Criteria TD Criteria: Planned TD will be thE! given coordinates. Minimally, need 2,500 feet of Sag River formation. Fault ProQnosis Fault Formation MD Intersec1t TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 HRZ 10,400' -8,460' -20' Up +/- 150' Fault #2 Sag River 13,500' -8,684' _20' Down +/- 150' 17 -13A Sidetrack Page 4 . . Qperations Summary Pre-RiQ ODerations: 1. The 5 112", 17.0#, L-80 PC tubin~ has a POGLM installed over the #1GLM and an ALPHA soft set patch over the #11 GLM. 2. There is a suspected leak below the POGLM at -3,040'. 3. R/U braided line and recover the POGLM from #1 GLM. 4. R/U coiled tubing. RIH and plug and abandon the open perforations with 15.8ppg class 'G' cement. The estimated cement volume required is 28.0bbls. This is based upon -435' of 7",29.0# liner, -100' of 4 W' tubing tail and -10.0bbls of slurry to squeeze the open perforations. Leave top of cement at -9,975'. POOH. 5. Drift 5 W' tubing to -9,500'md, below the planned tubing cut depth of -9,400'md. 6. R/U SWS E-line. RIH with appropriate chemical cutter and cut the 5 W' tubing at -9,400'md. 7. Circulate the well to seawater through the tubing cut, until returns are clean. Conduct a CMIT T X IA to 3,000psi for 30 minutes. 8. Conduct an MIT-OA to 2,000psi. Last MIT-OA passed to 2,000psi on 10/11/1996. 9. Bleed casing and annulus pressures to zero. Freeze protect to -2,200' MD with diesel. 10. Function all tubing and casing Lock Down Screws. The tubing spool will be replaced during the work over. The 9 5/8" casing pack-off will be changed during spool C/O. 11. Set a BPV. Remove well house and flow line. Level the pad as necessary. RiQ ODerations: 1. MI I RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install BPV. 3. Nipple down the tree. Inspect tubing hanger threads. Install "blanking plug" in hanger running thread. 4. Nipple up and test BOPE to 4,000psi. Pull blanking plug and BPV. 5. R/U. Pull the 5 W' tubing from the tubing cut at -9,400'md and above. Be prepared to spool up the Otis ROM SSSV control lines. 6. M/U a milling assembly and RIH, P/U 4" drill pipe. Tag the tubing stub at 9,400'. POOH. 7. R/U SWS E-line. M/U a HES 9 5/8" EZSV bridge plug. RIH with EZSV and set at -9,220'md. POOH and RID E-line. . 8. R/U and pressure test the 9 5/8" casing to 4,000psi for 30 minutes. Record the test. 9. NID the BOPE stack and the tubing spool. CIO the 9 5/8" pack-off. N/U a new tubing spool. Test the pack-off. . . 10. N/U the BOPE stack and test. TL .. s (0 ~ 4' 0 I t'Jv1) J? rw l/ A.../ . 11. M/U a Baker 9 5/8" whip stock assemb~. RIH to the EZSV bridge þlug. Orient as desired and set the whip stock on the EZSV. 12. Shear free from the whip stock. Displace the well to 11.5ppg LSND milling fluid. 13. Mill a window in the 9 5/8" casing at -9,200'md. Drilllmill approximately 20 feet beyond the middle of the window. 14. Circulate the well clean. Pull into the 9 5/8" casing and attemptan FIT to 12.8ppg EMW. POOH, UD mills assembly. 15. M/U an 8 W' Dir/GR/Res/PWD assembly. RIH to the window. 16. Drill out and drill ahead, according to the directional program to section TD at the top of the Sag River. Circulate and condition the hole. POOH. / 17. Run and cement the 7" liner. POOH with liner running tool. 18. R/U, run and cement the 7" scab liner from the drilling liner top to approximately 2,650'md. / 19. M/U a 6 1/8" Dir/GR/Res/ABI drilling assembly. RIH to the scab liner float equipment. 20. Test the scab liner to 4,000psi. / 21. Drill out the scab liner float equipment, and drill ahead to the drilling liner landing collar. 22. Test the liner to 4,000psi for 30 minutes. Record the test. 23. Drill out the float equipment to the liner shoe. Displace the well to 8.5ppg Flo-Pro drilling fluid. / 24. Drill out the shoe plus -20 feet of new formation. Conduct an FIT to 10.0ppg EMW. 17 -13A Sidetrack Page 5 . . 25. Drill ahead, per directional proposal, to the end of the high dogleg section at -11 ,200'md. POOH for // horizontal BHA. 26. R/U SWS E-line. Run a USIT log from the 7" liner shoe to the top of the drilling liner at -9,050'md. POOH and R/D E-line. 27. M/U a 6 1/8" Dir/Strata-steer drilling assembly. RIH and drill ahead, per directional program, to section TO at -14,292'md. 28. Condition the hole for running 4 1/2",12.6#, L-80, IBT-M liner. POOH. 29. Run and cement the 4 W' production liner, extending the liner lap -150' into the 7" shoe. POOH. / 30. Pressure-test the casing X liner to 4,000psi for 30 minutes. Record the test. 31. P/U and RIH with Schlumberger 27/8" DPC perforating guns. Perforate Sag River injection intervals, per subsurface team. POOH. 32. R/U and run a 41/2",12.6#, L-80, TC-II completion, stinging into the 41/2" liner tie back sleeve. ~. 33. Space out and land the completion. RILDS. 34. Install a TWC. 35. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 36. Reverse circulate the well to seawater with Corrosion Inhibitor. 37. R/U LRHOS. Reverse in sufficient volume of diesel to freeze-protect the well to -2,200'md. Allow the /' diesel freeze protection fluid to U-tube to equilibrium. 38. Drop the ball and rod. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 39. Install BPV. Secure the well. 40. Rig down and move off. Post-RiQ Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 02/20/05 Estimated Spud Date: 03/20/05 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 17 -13A Sidetrack Page 6 . . Phase 1: Move In I RiQ Up I Test BOPE Planned Phase Time 28 hours Planned Phase Cost $70,207 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 17-13. However, 17-12 is -120.0' to the North, and 17-22 is -90.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ During MI/RU operations, the 17-13 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. Last MIT-OA to 2,000psi on 10/11/1996 passed. ~ Prior to pulling the tree, verify there is a static column of kill weight fluid to surface and that no pressure exists. ~ During ND/NU BOPE operations, the 17-13 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a BPV/blanking plug. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 10/11/1996 passed. ~ OS 1?J§J/esignated as an H:ß site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 17-12 44ppm 12-06A 25ppm 17-22 21 ppm 12-25 N/A The maximum level recorded of H2S on the pad w@m, in 04/2004. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 17 -13A Sidetrack Page 7 . . Phase 2: De-complete Well Planned Phase Time 54 hours Planned Phase Cost $200,269 Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ Monitor the well to ensure the fluid column remains static, prior to pulling the completion. ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ Note that this wellhead is McEvoy Gen 3. The tubing hanger is likely a McEvoy Gen. 3, with 6 1/8" LH Acme top thread and 5 W' FMC 'ISA' BPV profile. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. ~ There is a 5W' Otis ROM SSSV landing nipple with dual 14" control lines. There were 28 control line clamps and 2 stainless steel bands (on the SSSV) used in securing the control lines. ~ The 5 W', 17.0#, L-80, 8rd AB-Mod IPC tubing will be chemical cut at -9,400'md. Phase 3: Run Whip Stock Planned Phase Time 42 hours Planned Phase Cost $321,606 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards ~ Based upon the CBL run on 1/11/1985, it appears there will be no cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time 60 hou rs Planned Phase Cost $326,014 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 17 -13A Sidetrack Page 8 . . Issues and Potential Hazards ~ This well bore will exit the original well into the lower CM2 formation. This well bore will drill the remainder of the CM2 and CM1, HRZ and the Kingak, to the top of the Sag River formation. Previous OS 17 wells drilled the Kingak with 9.9 to 10.6ppg mud weights. For this well, the HRZ and the Kingak will require a mud weight of 11.6 - 11.8ppg, due to the inclination and azimuth through the shale. Maintain mud weight at 11.8ppg, minimally, from above the Kingak to the 7" casing point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 8.6ppg pore pressure at the Sag River depth, a fracture gradie 12.1 ppg at the 9 5/8" casing window, and 11 .8ppg mud in the hole, the kick tolerance is' finite ~ The planne e¡1I, 17-13A, is expected to cross one fault while drilling the intermediate interval. The planned trajectory will cross this fault at approximately 10,400'md. Losses are certainly possible, but are not expected to be significant. Phase 6: Run and Cement 7" Intermediate Casina Planned Phase Time 48 hours Planned Phase Cost $468,195 Reference RP .:. "Intermediate Casing and Cementing Guidelines" RP .:. "Freeze Protecting an Outer Annulus" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate Kingak instability problems. ~ Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. ~ During cement displacement of the original 9 5/8" intermediate casing string, returns were nil. A CBL, run on 1/11/1985, confirms that little or no cement was lifted above -1 O,200'md. ~ After running the intermediate drilling liner, a 7" scab liner will be run and cemented from the existing 7" liner top at -9,050'md to -2,650'md. r ~ Currently, there is no known integrity issue with the 9 5/8" casing. Due to the fact that there is little cement behind the original 9 5/8" casing, it has been decided to run and cement a scab liner in preparation for injection service. 17 -13A Sidetrack Page 9 . . Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 156 hours Planned Phase Cost $875,540 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ The parent well, 17-13, experienced no lost circulation events during drilling operations. );> There was one significant lost circulation event in drilling the near surrounding well, 17-19A. It was fault related. );> The planned well, 17-13A, is expected to cross one fault while drilling the production (injection) interval. The planned trajectory will cross this fault at approximately 13,500'md. It will be prudent to avoid entering the Shublik near this fault crossing, as it may increase the likelihood of significant losses. Phase 9: Run 4%" Production Liner Planned Phase Time 34 hou rs Planned Phase Cost $252,758 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a 4 112",12.6#, L-80 solid liner throughout the production (injection) interval. ~ Differential sticking is possible. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Sufficient 4 112" liner will be run to extend -150' back up into the 7" liner shoe. ~ Ensure the 4 112" liner top packer is set prior to POOH. Phase 10: DPC Perforate Planned Phase Time 32 hours Planned Phase Cost $426,077 Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards ~ The well will be DPC perforated, -600psi overbalanced, after running the 4 112" liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities 17 -13A Sidetrack Page 1 ° . . are understood. Only essential personnel should be present on the rig floor while making up DPC guns. ~ Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Phase 12: Run 4 ¥2" L-80 Completion Planned Phase Time 30 hours Planned Phase Cost $406,899 Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ The completion, as designed, will be to run a 4%,',12.6#, L-80, TC-II production tubing string, stinging into the 4 %" liner tieback sleeve. Phase 13: ND/NU/Release Ri~ Planned Phase Time 16 hours Planned Phase Cost $51,618 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ During ND BOPE / NU adapter / tree operations, the 17-13A well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. ~ During RD/MO operations, the 17-13A well bore will be secured with the following barriers: o Tubing: Tree, a TWC and kill weight fluid above the ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. Y No wells will require shut-in for the rig move onto 17-13. However, 17-12 is -120.0' to the North, and 17-22 is -90.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. 17 -13A Sidetrack Page 11 COMPANY DETA[(S ß-PAmoct} REFERENCE INfORMATION SURVEY PROGRAM Plrm: 17~13A wp06 07-!J/Plan 17~13A) 17-JJ,TrueNorth Depth Fm IX:p1h T" SlIfV<.'yíPiau fool Cre¡\kd By: Troy Jakabosky Date:1W/2D04 92ÜO,O(} !429U6 PtamJëd: !7-13/\ wpÛ6 V42 MW); IFR·' MS Chetked: D¡¡t~· -""..._- R~v¡~wt'-d: ---..-- Date: WELL ÙETAJLS FORMA nON TOP Nan"" Nm1hing Eas!ing Latitude lnugírw.k S!m TVDPath MDPath Formation !7-!3 j455.64 97'\\,63 5927701.54 709343.74 7Ü~!2¡2Ü.791N !4'\\~¡ð'4,1.5ij3\V 13 4 5 6 7 8 9 10 11 TARGET DETAILS 9462.61 Name TVD +N/·S +E/·W Northing Basting Shape CASING DETAILS SECTION No. TVD MD Name Size See MD fne Azi TVD +N/·S +E/-W DLeg TFace VSec Target 7" 41/2" 1 2 4 5 6 7 8 9 10 11 12 T6 1"2 SURVEYFROGRA,M Plan; I7-J3A wp06(l7-J3/Plan J7-13A) >;.I!) Crealed By: Troy Jakabosky Date: ! 1/3/2004 n()(UX) Plmmcd: J7-131\. w11l)6 \142 Cbecked; Date: - - WELL DETAILS Nanw basting Lüng-itmie 17-13 I 13 - - TARGET DETAILS Name TVD +Ni-S +Ei-W Northing Eastîng Shape CASING REFERENCE JNFORI'iÏATION COMPANY DETAILS BPAJ True Nnrth SECTION DETAILS See MD {ne AzÍ TVD +Ni-S +Ei-W DLcg TF ace VSec Target 1 2 3 4 5 6 7 g 7-I3A na 9 [( 11 T6 12 T2 - 42 36 .8 ~. co co ;£ :£ ~ 0 ~ " 0 00 . BP BP Planning Report . Plan: 17-13A wp06 Date Composed: Version: Tied-to: 91212004 42 From: Definitive Path Principal: Yes Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB DS 17 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5926220.53 ft 708405.69 ft Latitude: 70 12 Longitude: 148 19 North Reference: Grid Convergence: 6.476 N 11.993 W True 1.58 deg Well: 17-13 Slot Name: 13 17-13 Well Position: +N/-S 1455.64 ft Northing: 5927702.54 ft Latitude: 70 12 20.791 N +E/-W 978.63 ft Easting : 709343.74 ft Longitude: 148 18 43.593 W Position Uncertainty: 0.00 ft Casing Points 41/2" Formations tvD ft 0.00 WS1 0.00 0.00 0.00 CM2 0.00 0.00 9462.61 8082.40 CM1 0.00 0.00 10164.53 8418.40 THRZ 0.00 0.00 10541.19 8589.40 BHRZ 0.00 0.00 10618.28 8624.40 LeU 0.00 0.00 10618.28 8624.40 TJE 0.00 0.00 10618.28 8624.40 TJD 0.00 0.00 10618.28 8624.40 TJC 0.00 0.00 10618.28 8624.40 TJB 0.00 0.00 10772.47 8694.40 TJA 0.00 0.00 10909.03 8756.40 TSGR 0.00 0.00 0.00 0.00 TSHU 0.00 0.00 17-13A Fault 1 -3463.73 70 12 41.195 N 148 20 24.138 W -Polygon 1 -3463.73 70 12 41.195 N 148 20 24.138 W -Polygon 2 -3592.19 70 12 46.729 N 148 20 27.874 W -Polygon 3 -3900.11 70 1252.125N 148 20 36.821 W -Polygon 4 -3592.19 70 12 46.729 N 148 20 27.874 W 17-13A Fault 2 8728.40 3792.32 -7223.78 5931293.00 702018.00 70 12 58.055 N 148 22 13.331 W -Polygon 1 8728.40 3792.32 -7223.78 5931293.00 702018.00 70 12 58.055 N 148 22 13.331 W -Polygon 2 8728.40 3349.79 -6273.63 5930877.00 702980.00 70 12 53.711 N 148 21 45.734 W -Polygon 3 8728.40 3236.75 -5732.53 5930779.00 703524.00 70 12 52.604 N 148 21 30.021 W -Polygon 4 8728.40 3349.79 -6273.63 5930877.00 702980.00 70 12 53.711 N 148 21 45.734 W 17-13A Poly 8733.40 3775.25 -5453.48 5931325.00 703788.00 70 12 57.902 N 148 21 21.931 W . BP BP Planning Report . ft -Polygon 1 5931325.00 70 12 57.902 N 148 21 21.931 W -Polygon 2 5930834.00 70 12 53.597 N 148 22 19.754 W -Polygon 3 5930478.00 70 12 50.090 N 148 22 19.305 W -Polygon 4 5931015.00 70 12 54.852 N 148 21 22.000 W -Polygon 5 5930158.00 70 12 46.000 N 148 20 36.210 W -Polygon 6 5930513.00 70 12 49.468 N 148 20 33.579 W 17-13A T6 8744.52 3535.03 -5756.27 5931076.50 703492.00 70 12 55.537 N 148 21 30.717 W 17-13A T2 8752.40 3204.60 -7153.03 5930707.50 702105.00 70 12 52.276 N 148 22 11.261 W 17-13A T3 8755.32 2989.17 -4236.24 5930573.00 705026.50 70 1250.178N 148 20 46.577 W 17-13A T3a 8755.32 3030.00 -4290.00 5930612.32 704971.62 70 12 50.580 N 148 20 48.138 W Plan Section Information AzitD. 1VD +Nl:.s +El-W DLS 81Û dE!9 ft ft ft degl100ft·. degl1 9200.00 307.79 7908.86 2117.61 -2712.81 0.00 0.00 0.00 9220.00 306.62 7923.41 2125.90 -2723.74 12.00 11.31 -20.00 9707.17 299.26 8210.77 2335.69 -3053.09 4.00 3.81 -20.00 10908.15 299.26 8756.00 2858.73 -3986.64 0.00 0.00 0.00 10918.15 299.26 8760.54 2863.08 -3994.41 0.00 0.00 0.00 11130.64 299.53 8781.35 2964.50 -4174.41 20.00 20.00 0.38 11189.08 299.53 8765.74 2992.26 -4223.41 0.00 0.00 0.00 11266.57 299.56 8755.32 3030.00 -4290.00 20.00 -20.00 179.88 17-13A T3a 11299.65 297.66 8755.15 3045.84 -4319.05 6.00 1.77 -72.82 12173.47 297.66 8746.21 3451.51 -5092.94 0.00 0.00 0.00 12856.51 256.69 8744.52 3535.03 -5756.27 6.00 -0.13 -91.15 17-13A T6 14291.85 256.69 8752.40 3204.60 -7153.03 0.00 0.00 0.00 17-13A T2 Survey ~a¡)N ft -64.40 5927702.54 709343.74 TSHU 7844.46 5929744.04 706573.42 Start Dir 12/10 7859.01 5929752.03 706562.27 Start Dir 4/100 7914.66 5929784.38 706514.78 MWD+IFR+MS 7979.82 5929825.33 706450.96 MWD+IFR+MS 9462.61 53.61 302.51 8082.40 8018.00 2229.27 -2874.59 4.00 5929851.17 706408.62 CM1 9500.00 55.04 301.97 8104.20 8039.80 2245.47 -2900.28 4.00 5929866.65 706382.49 MWD+IFR+MS 9600.00 58.88 300.60 8158.72 8094.32 2288.98 -2971.92 4.00 5929908.15 706309.68 MWD+IFR+MS 9700.00 62.72 299.35 8207.49 8143.09 2332.57 -3047.52 4.00 5929949.63 706232.89 MWD+IFR+MS 9707.17 63.00 299.26 8210.77 8146.37 2335.69 -3053.09 4.00 5929952.60 706227.24 End Dir : 9707 9800.00 63.00 299.26 8252.91 8188.51 2376.12 -3125.25 0.00 5929991.01 706154.00 MWD+IFR+MS 9900.00 63.00 299.26 8298.31 8233.91 2419.67 -3202.98 0.00 5930032.38 706075.09 MWD+IFR+MS 10000.00 63.00 299.26 8343.71 8279.31 2463.22 -3280.71 0.00 5930073.76 705996.19 MWD+IFR+MS 10100.00 63.00 299.26 8389.11 8324.71 2506.77 -3358.44 0.00 5930115.14 705917.28 MWD+IFR+MS 10164.53 63.00 299.26 8418.40 8354.00 2534.87 -3408.60 0.00 5930141.84 705866.37 THRZ 10200.00 63.00 299.26 8434.50 8370.10 2550.32 -3436.18 0.00 5930156.52 705838.37 MWD+IFR+MS 10300.00 63.00 299.26 8479.90 8415.50 2593.87 -3513.91 0.00 5930197.89 705759.47 MWD+IFR+MS 10398.01 63.00 299.26 8524.40 8460.00 2636.56 -3590.09 0.00 5930238.45 705682.13 17-13A Fault 1 10400.00 63.00 299.26 8525.30 8460.90 2637.42 -3591.64 0.00 5930239.27 705680.56 MWD+IFR+MS 10500.00 63.00 299.26 8570.70 8506.30 2680.97 -3669.37 0.00 5930280.65 705601.66 MWD+IFR+MS 10541.19 63.00 299.26 8589.40 8525.00 2698.91 -3701.39 0.00 5930297.69 705569.16 BHRZ 10600.00 63.00 299.26 8616.10 8551.70 2724.52 -3747.10 0.00 5930322.03 705522.75 MWD+IFR+MS . BP BP Planning Report . 10618.28 63.00 299.26 8624.40 8560.00 2732.48 -3761.31 0.00 5930329.59 705508.33 TJB 10700.00 63.00 299.26 8661.50 8597.10 2768.07 -3824.84 0.00 5930363.40 705443.85 MWD+IFR+MS 10772.47 63.00 299.26 8694.40 8630.00 2799.63 -3881.17 0.00 5930393.39 705386.67 TJA 10800.00 63.00 299.26 8706.90 8642.50 2811.62 -3902.57 0.00 5930404.78 705364.94 MWD+IFR+MS 10847.36 63.00 299.26 8728.40 8664.00 2832.25 -3939.38 0.00 5930424.38 705327.57 17-13A Fault 2 10858.37 63.00 299.26 8733.40 8669.00 2837.05 -3947.94 0.00 5930428.93 705318.88 17-13A Poly 10900.00 63.00 299.26 8752.30 8687.90 2855.17 -3980.30 0.00 5930446.16 705286.04 MWD+IFR+MS 10906.66 63.00 299.26 8755.32 8690.92 2858.07 -3985.47 0.00 5930448.91 705280.79 17-13A T3 10908.15 63.00 299.26 8756.00 8691.60 2858.73 -3986.64 0.00 5930449.53 705279.60 MWD+IFR+MS 10909.03 63.00 299.26 8756.40 8692.00 2859.11 -3987.32 0.00 5930449.90 705278.91 7" 10918.15 63.00 299.26 8760.54 8696.14 2863.08 -3994.41 0.00 5930453.67 705271.71 Start Dir 20/10 11000.00 79.37 299.37 8786.85 8722.45 2900.89 -4061.73 20.00 5930489.59 705203.37 MWD+IFR+MS 11100.00 99.37 299.49 8787.94 8723.54 2949.77 -4148.38 20.00 5930536.05 705115.41 MWD+IFR+MS 11130.64 105.50 299.53 8781.35 8716.95 2964.50 -4174.41 20.00 5930550.06 705088.98 End Dir : 1113 11189.08 105.50 299.53 8765.74 8701.34 2992.26 -4223.41 0.00 5930576.44 705039.23 Start Dir 20/10 11200.00 103.31 299.53 8763.02 8698.62 2997.47 -4232.61 20.00 5930581.40 705029.89 MWD+IFR+MS 11266.57 90.00 299.56 8755.32 8690.92 3030.00 -4290.00 20.00 5930612.32 704971.62 17-13A T3a 11299.65 90.59 297.66 8755.15 8690.75 3045.84 -4319.04 6.00 5930627.35 704942.16 End Dir : 1129 11300.00 90.59 297.66 8755.15 8690.75 3046.00 -4319.35 0.07 5930627.51 704941.84 MWD+IFR+MS 11400.00 90.59 297.66 8754.12 8689.72 3092.43 -4407.92 0.00 5930671.46 704852.03 MWD+IFR+MS 11500.00 90.59 297.66 8753.10 8688.70 3138.85 -4496.48 0.00 5930715.41 704762.22 MWD+IFR+MS 11600.00 90.59 297.66 8752.08 8687.68 3185.28 -4585.05 0.00 5930759.36 704672.41 MWD+IFR+MS 11700.00 90.59 297.66 8751.06 8686.66 3231.71 -4673.61 0.00 5930803.31 704582.59 MWD+IFR+MS 11800.00 90.59 297.66 8750.03 8685.63 3278.13 -4762.18 0.00 5930847.26 704492.78 MWD+IFR+MS 11900.00 90.59 297.66 8749.01 8684.61 3324.56 -4850.74 0.00 5930891.21 704402.97 MWD+IFR+MS 12000.00 90.59 297.66 8747.99 8683.59 3370.98 -4939.30 0.00 5930935.16 704313.15 MWD+IFR+MS 12100.00 90.59 297.66 8746.96 8682.56 3417.41 -5027.87 0.00 5930979.11 704223.34 MWD+IFR+MS 12173.47 90.59 297.66 8746.21 8681.81 3451.51 -5092.94 0.00 5931011.40 704157.36 Start Dir 6/100 12200.00 90.55 296.07 8745.95 8681.55 3463.50 -5116.60 6.00 5931022.73 704133.37 MWD+IFR+MS 12300.00 90.43 290.07 8745.09 8680.69 3502.67 -5208.56 6.00 5931059.33 704040.37 MWD+IFR+MS 12400.00 90.30 284.07 8744.45 8680.05 3532.02 -5304.10 6.00 5931086.02 703944.05 MWD+IFR+MS 12500.00 90.17 278.08 8744.05 8679.65 3551.22 -5402.20 6.00 5931102.49 703845.47 MWD+IFR+MS 12600.00 90.03 272.08 8743.88 8679.48 3560.06 -5501.76 6.00 5931108.57 703745.70 MWD+IFR+MS 12700.00 89.89 266.08 8743.95 8679.55 3558.45 -5601.70 6.00 5931104.19 703645.85 MWD+IFR+MS 12800.00 89.76 260.08 8744.25 8679.85 3546.41 -5700.93 6.00 5931089.41 703547.00 MWD+IFR+MS 12856.51 89.69 256.69 8744.52 8680.12 3535.03 -5756.27 6.00 5931076.50 703492.00 17-13A T6 12900.00 89.69 256.69 8744.76 8680.36 3525.02 -5798.59 0.00 5931065.32 703449.97 MWD+IFR+MS 13000.00 89.69 256.69 8745.31 8680.91 3502.00 -5895.90 0.00 5931039.61 703353.34 MWD+IFR+MS 13100.00 89.69 256.69 8745.86 8681.46 3478.98 -5993.22 0.00 5931013.90 703256.71 MWD+IFR+MS 13200.00 89.69 256.69 8746.41 8682.01 3455.96 -6090.53 0.00 5930988.20 703160.08 MWD+IFR+MS 13300.00 89.69 256.69 8746.95 8682.55 3432.94 -6187.84 0.00 5930962.49 703063.44 MWD+IFR+MS 13400.00 89.69 256.69 8747.50 8683.10 3409.92 -6285.15 0.00 5930936.78 702966.81 MWD+IFR+MS 13500.00 89.69 256.69 8748.05 8683.65 3386.90 -6382.47 0.00 5930911.07 702870.18 MWD+IFR+MS 13600.00 89.69 256.69 8748.60 8684.20 3363.87 -6479.78 0.00 5930885.36 702773.55 MWD+IFR+MS 13700.00 89.69 256.69 8749.15 8684.75 3340.85 -6577.09 0.00 5930859.65 702676.91 MWD+IFR+MS 13800.00 89.69 256.69 8749.70 8685.30 3317.83 -6674.40 0.00 5930833.95 702580.28 MWD+IFR+MS 13900.00 89.69 256.69 8750.25 8685.85 3294.81 -6771.72 0.00 5930808.24 702483.65 MWD+IFR+MS 14000.00 89.69 256.69 8750.80 8686.40 3271.79 -6869.03 0.00 5930782.53 702387.02 MWD+IFR+MS 14100.00 89.69 256.69 8751.35 8686.95 3248.77 -6966.34 0.00 5930756.82 702290.39 MWD+IFR+MS 14200.00 89.69 256.69 8751.90 8687.50 3225.75 -7063.65 0.00 5930731.11 702193.75 MWD+IFR+MS 14291.00 89.69 256.69 8752.40 8688.00 3204.80 -7152.21 0.00 5930707.72 702105.82 41/2" 14291.85 89.69 256.69 8752.40 8688.00 3204.60 -7153.03 0.00 5930707.50 702105.00 17-13A T2 WELL DET/HLS NmùlÎng E"ming L~jtJtudc b!figiiud¢ S Nan~ SURVEY ¡'ROGRAM tkpfh fm !)¡;>pih '() 9 14291.85 pjaJlIK,<i: j7.J:\A\"1¡{6V43 MWD;!FI RE ,\lL'5 COMl'ANYD 75 2: g '" i ~ ;Š 5 en WELL DETAILS Latitude Longiill< 51 7fYI2'10.79JN 14~F!S'43.593W L1 LEGEND 12-06A 12-25 17-02 17-05 17-13 17-19 \V N:m SURVEY ¡~ROGRAM TmeNor1h I Depth Fm DCp1h To SurvcyiP!¡¡¡; 9200.00 14291.85 Plamwd: !ï.UA\'1)Ü6V4 MWn FER Rf COMPANY DETAILS -I â c :¡; +' ~ o ~ ~. o (/) .... . BP Anticollision Report . 17-13A wp06 Date Composed: Version: Tied-to: 9/2/2004 43 From: Definitive Path Yes Summary PB DS 12 12-06 12-06 V1 12450.00 11450.00 1203.89 1153.28 50.62 Pass: Major Risk PB DS 12 12-06A 12-06A V1 12521.36 11600.00 728.76 0.00 728.76 Pass: Minor 1/200 PB DS 12 12-07 12-07 V1 Out of range PB DS 12 12-07A 12-07A V1 Out of range PB DS 12 12-22 12-22 V1 Out of range PB DS 12 12-25 12-25 V1 13682.27 10625.00 298.37 0.00 298.37 Pass: Minor 1/200 PB DS 17 17-05 17-05 V1 9206.79 9125.00 1089.21 193.24 895.97 Pass: Major Risk PB DS 17 17-13 17-13V1 9200.00 9200.00 0.00 0.00 0.00 FAIL: NOERRORS Site: PB DS 12 Well: 12-06 Rule Assigned: Major Risk Wellpath: 12-06 V1 Inter-Site Error: 0.00 ft 12838.02 8744.42 10100.00 7723.98 27.41 301.82 308.61 50.81 4.000 1615.05 811.74 803.31 Pass 12830.98 8744.39 10125.00 7742.55 27.51 302.99 309.49 51.27 4.000 1601.22 819.42 781.80 Pass 12823.88 8744.35 10150.00 7761.03 27.61 304.13 310.38 51.73 4.000 1587.58 827.13 760.45 Pass 12816.73 8744.32 10175.00 7779.42 27.71 305.27 311.27 52.19 4.000 1574.12 834.85 739.28 Pass 12800.00 8744.25 10200.00 7797.72 27.94 306.39 312.74 52.66 4.000 1560.93 842.87 718.06 Pass 12800.00 8744.25 10225.00 7816.04 27.94 307.51 313.23 53.15 4.000 1547.75 850.50 697.26 Pass 12800.00 8744.25 10250.00 7834.39 27.94 308.63 313.72 53.64 4.000 1534.79 858.19 676.61 Pass 12787.87 8744.20 10275.00 7852.78 28.11 309.71 314.95 54.15 4.000 1521.95 866.24 655.71 Pass 12780.66 8744.17 10300.00 7871.20 28.20 310.79 315.90 54.66 4.000 1509.27 874.21 635.06 Pass 12773.42 8744.14 10325.00 7889.60 28.30 311.85 316.86 55.19 4.000 1496.77 882.21 614.56 Pass 12766.16 8744.12 10350.00 7907.97 28.40 312.90 317.83 55.72 4.000 1484.46 890.22 594.24 Pass 12750.00 8744.07 10375.00 7926.29 28.61 313.79 319.33 56.26 4.000 1472.41 898.14 574.27 Pass 12750.00 8744.07 10400.00 7944.59 28.61 314.92 319.89 56.81 4.000 1460.43 906.23 554.20 Pass 12750.00 8744.07 10425.00 7962.96 28.61 316.04 320.45 57.37 4.000 1448.75 914.37 534.37 Pass 12736.95 8744.03 10450.00 7981.41 28.77 316.90 321.81 57.95 4.000 1437.22 922.38 514.84 Pass 12729.70 8744.01 10475.00 7999.96 28.86 317.86 322.84 58.55 4.000 1425.95 930.51 495.44 Pass 12722.48 8743.99 10500.00 8018.60 28.95 318.78 323.89 59.16 4.000 1414.91 938.64 476.26 Pass 12715.29 8743.98 10525.00 8037.34 29.04 319.66 324.94 59.78 4.000 1404.10 946.73 457.36 Pass 12700.00 8743.95 10550.00 8056.16 29.23 320.26 326.50 60.42 4.000 1393.58 954.39 439.19 Pass 12700.00 8743.95 10575.00 8075.07 29.23 321.35 327.16 61.08 4.000 1383.21 962.91 420.30 Pass 12700.00 8743.95 10600.00 8094.06 29.23 322.43 327.83 61.75 4.000 1373.18 971.45 401.73 Pass 12686.80 8743.92 10625.00 8113.02 29.39 323.03 329.30 62.43 4.000 1363.34 979.12 384.22 Pass 12679.65 8743.91 10650.00 8131.93 29.47 323.82 330.42 63.12 4.000 1353.80 987.09 366.72 Pass 12672.47 8743.90 10675.00 8150.79 29.55 324.60 331.55 63.82 4.000 1344.53 994.96 349.57 Pass 12665.25 8743.90 10700.00 8169.59 29.63 325.37 332.69 64.53 4.000 1335.53 1002.80 332.74 Pass 12650.00 8743.88 10725.00 8188.29 29.81 325.76 334.32 65.24 4.000 1326.88 1009.75 317.13 Pass 17 -13 13 3/8", 72#, L-80, Casing ID::: 12.347" 7",26.0#, L-80, BTG- Mliner 41/2", 12.6#, L-80, Thg-PC ID ::: 3.958" 95/8",47#, L-80, Casing ID::: 8.681" ¡FOC H 10450' CTM Cement retainer 1-1 10510' H 10634' I Baker bridge plug I PBTD H 10965' 7",29#, L-80, Liner, -I 11^5S' 10 ::: 6.184" I U REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-MWH CONVERTED TO CANVAS -MD INITIAL REVISION P CORRECTIONS DATE 01/19/85 02/20186 12/10/00 02/02/01 07/16/01 p osed 2,200' 1-1 41/2" 'X' landing nipple I.D. 3.813" 95/8" X 7" Baker HMC hngr, ZXP pkr with TBS ~ 95/8" X 7" Baker HMC hngr, ZXP pkr with TBS 10,690' 1-1 41/2" 'X' landing nipple I.D. 3.813" 10710' 1-1 7" X 41/2" Baker 8-3 permanent packer I I 10,730' H 41/2" 'X' landing nipple I.D. 3.813" I I 10,750' H 41/2" 'X' landing nipple I.D. 3.725" I 10,757' 41/2",12.6#, L-80, rG-lItubing 7" X 5" Baker HMC hngr, ZXP pkr with TBS 10,909" H 7",26.0#, L-80, BTG-M liner I 14,292' H 41/2",12.6#, L-80, IBT-M liner I REV BY dew COMMENTS 17 -13A A-oposed Completion PRUDHOE SA Y UNIT WELL: 17-13A PERMIT No: API No: 50-029-21200-01 SEC22, T10N, R15E, 2523.46' FEL & 5143.4' FNL BP Exploration (Alaska) 133/8",72#, L-80, Casing ID = 12.347" I Top of 7" liner 41/2",12.6#, L-80, Tbg-PC ID " 3.958" 95/8",47#, L-80, Casing ID = 8.681" 17- re 11II 19 NOTES: OBSTRUCTION OR LINE DAM AGE@ NM-16RPOGlM OVER GlM#1,GlM 2 &3 RD VERY DIFFiCULT TO PULL & RUN:POCIŒT ON HIGH SIDE,GlM#4 GLM WASHED OUT, PATCH 1/8/94 2222' H 5-1/2" OTIS RQM SSSV, ID = 4.562" I H 10036' I CTM Cement retainer 1-1 10510' I Baker bridge plug H 10634' 7",29#, L-80, Liner, ID=6.184" DATE 01/19/85 02/20/86 12/10100 01 07/16/01 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-M\lVH CONVERTED TO CANVAS SIS-MD INITIAL REVISION RNlTP CORRECTIONS REV BY dew 3500' 58 @ 1090' 10495' 8800' SS ST MD *1 3030 2 2 4579 23 3 6206 5771 45 4 7545 6697 45 5 7615 6746 45 6 8587 7449 42 7 8658 7502 41 8 9261 7956 42 9 9331 8007 43 10 9807 8357 42 11 9878 8411 42 GAS LIFT MANDRELS TYÆ VLV LATCH PORT DATE DWP BK HES/N-17RP RK CAIIi1I2 RK CAIIi1IRD RK CAIIi1IRD RK CAIIi1IRD RK HES/0220RC RK CAIIi1IRD RK CAIIi1IRD RK CAIIi1I3 RK CAIIi1I4 RK 9870' 5-1/2" A LPHA SOFT SET TBG PA TCH (SET 01/08/94) ID = 3.0 9946' H 5-112" BOT PBRASSY, ID = 4.875" 9965' H 9-5/8" X 5-1/2" BOT 3-H PKR, ID == 4.750" 10061' H 4-1/2"OTISXNNIPNOGO,ID==3.725" I 10073' H 4-1/2" BAKER SHEA ROUT SUB, ID == 4.000" 10074' H 4-1/2" TUBING TAIL I PERFORA TION SUMMARY REF LOG: BHCS ON 01/13/85 ANGLE AT TOP PERF: 43 @ 10392' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 10 10392 - 10413 0 10/20/92 3-318" 4 10437 - 10457 C 08/24/92 3-3/8" 1 10524 - 10540 C 08/24/92 3-3/8" 1 10548 - 10632 S 02/24/88 3-3/8" 1 10644 - 10724 S 02/24/88 11050' H CA -RD (LOST 11/28/93) 11055' H CA-RD-RK (LOST 11/01/92) COMMENTS Proposed Pre rig work PRUDHOE BA Y UNIT WELL: 17-13 PERMIT No: 1841790 API No: 50-029-21200-00 SEC 22, T10N, RiSE, 2523.46' FEL & 5143.4' FNL SP Exploration (Alaska) . . POST THIS NOTICE IN THE DOGHOUSE 17-13Ai Rig site Summary of Drilling Hazards ./ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 107 ppm, measured in April 2004. ./ NORM test all retrieved well head and completion equipment. ./ The closest neighboring wells, at surface, are 17-12 and 17-22. Well 17-12 is approximately 120' to the North. Well 17-22 is approximately 90' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ There is one planned fault crossing in drilling the intermediate interval, at approximately 1 0,400'md. This will be within the HRZ. Losses are not expected, but due preparation is warranted. ./ There is one planned fault crossing in drilling the production (injection) interval, at approximately 13,500'md. Obviously, this should be within the Sag River formation. Any potential for losses could be increased if the well bore is drilled into the underlying Shublik. Take all necessary precautions to remain in the Sag River. ./ Differential sticking may be encountered. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE OS 17 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 17-13Ai 17-13Ai 1/4 mile proximity wells within the zone of injection . . Mr. Crandall, Here is a summary of the wells which are within the 1/4 mile radius of the planned 17 -13Ai sidetrack. 17-13Ai (Sag River injector) TSGR -10,910' md / -8,740' tvd; (BSGR -8,765' tvd) as drilled in Wp06 Well 12-06 is at 1,205' seperation, within the Sag River, at 12,440' md of the drilling well. This is below the 12-06A sidetrack point in the abandoned portion of the 12-06 well. Well 12-06A is at 768' seperation, within the Sag River, at 12,570' md of the drilling well. Well 12-25 is at 340' seperation, within the Sag River, at 13,600' md of the drilling well. ·«17-13A wp06 AC report.pdf» Dav~ Wesley, Jr. Operations Drilling Engineer GPB Rotary Drilling 564-5153 office 440-8631 cell 564-4040 fax 17-13A wp06AC Content-Description: 17-13A wp06 AC Content-Type: application/octet-stream Content-Encoding: base64 10fl 2/11/2005 10:58 AM TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 179 DATEO~~JO~OS 6~i~6r'. ~~œ-r$ {CO, 00 . ~ DOLLAF\S /IJÌ ~ ì:I~ "Mastercard Check" MEMO . Anchorage, AK 99501 I: ¡. 25 2000bOI:lili ¡......Ib 2 27111 ¡. SSb"· 0 ~ 71i . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER /;?-/3A WELL NAME ßCc ;r ð - '.Q!-..Q PTD# ~s-- 02-0 Exploration Stratigraphic Development X Service CHECK WHAT ADD-ONS "'CLUE"· APPLlÉs (OPTIONS) MULTI The permit is for a new weJlbore 'segment of LATERAL existing weD . Permit No, API No. . (If API num ber Produc1ioD. sbould continue to be reponed as last two. (2) digits a function· of tbe original API number. stated are between 60-69) above. . PJLOT HOLE )n accordance witb· 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot bole must be clearJy differentiated In both name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and Jogs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuU EXCEPTION .' compliance witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent UpOD issuance of ~ conservation order approving a spacing ex ception. (CompanY Name) assumes the liabiUty of aDY protest to tbe spacing ,eJeeptioD that may occur. : DRY DITCH AU dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater 1ban 30' ,. sample intervals from below tbe permafrost or from wbere samples are fint caugbt aDd ] 0' sample inter-va)s tbrougb target zones. .. . . Well bore seg Annular Disposal -.-- - Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 17-13A _ Program SER BP EXPLORATION (ALASKA) INC Initial ClassfType SER 11WINJ GeoArea 890 Unit 11650 On/Off Shore .Qn Administration Permit fee attache_d_ - - - - - - - - - - - - _ _ _ _ _ _ _. Yes ~ - - - - - - - 12 leas_enumber _appropriate_ _ - - - - - - - - - - - _ _... _ Yes 3 _Unique weltn_arne_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Yes - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - 4 WeU IQcated in.a. d_efioed pool_ . - - - - - - _.. _ Yes - - - - - - 5 WeJUQcated prJ)per _distance from driJling uoitbJ:>uod_ary_ _ _ Yes. 6 WelUQC<lted prJ)per _distance_ from otber welJs_ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - 7 _S_utficieot acreage_ayailable [ndrilliog unjt _ - - - - - - - · _ Yes - - - - - - - - - - - - - - - - - - - - - - 8 If.deviated, js weJlbQre platiocJuded . - - - - - - - - - - - · _ Yes - - - - - - - - 9 _Operator ool}' affected party _ - - - - - - - - - - - - Yes - - - - - - 10 _Operator bas_apprJ)priate_ b.ond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit c_ao be issued witbout conservation order _ _ _ _ _ _ _ . . _ _ _ Yes - - - - Appr Date 12 Permit cao Þe issued wjthout ad_mioistratÌlle_apprJ)val _ _ _ _ · _ Y_es - - - - - - -- RPC 2/11/2005 13 Can permit be approved before 15-day wait Yes 14 WeU IQcated wi.thio area and strata_authorized by_lojectioo Order # (put 10# in_ cJ)rnrneots) (For _ Yes .Þ.10_4_C_ __ - - - - - - - - - - - - - 15 AJI welJs_within Jl4.mite_are_a_of review jdeotlfied (FJ)r servjceweUool}') _ _ _. . . _ _ _ _ _ _ _ _ . Yes - - - 12_-Q6412-0.6A.ANO 12.-25_ . _ . _ _ - - - - -- 16 Pre-produced injector; duration of pre-productioo less than 3 mootbs (For service well Qnly) . NA . '_ _ _ _ _ r-'- .AÇMP findl"" .'f """.i,tençy ha, þ,en j",ed ""..,,, p'.¡eet .- _ NA - - - - - - -- ~- Engineering 18Cooductor striogprQv[ded . _ __ _ NA _ 19 _Surfacecasiog. protects all_known USOWs' _ . NA 20CMT v_ol adeQuateJo circutate oncood_uctor, 8. surf (;$9 _ NA i21 _CMT vJ)1 adeQuate_ to tie-in long string to_surf ~g - " - - - _. NA - - - - - - - - - - -' 1 22 CMTwilJ CoyeraJl koownpro_ductiye bQrizQm\_ _ _ _ _ _ Yes 23 _Casing designs ad_eQuaJe fJ)r C,T, B,& permafrost _ Yes 24 Adequate.tankageor re_serve pjt _ Yes [\abors:2ES, I~: If.are-drilt hasa 10-403 for abandonment beeo appro\led _ . _ _ _ _ _ Yes 1/26/2005. _Adequate_weUbore sep¡;¡r¡;¡tjo_n_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Ifdjver:ter required, does jtJTleet reguJa.tioos_ _ _ _ - - - - - - - .. NA Sidetrack. . Appr Date 28 _DriUiog fJujd_ program sc.hematic& equip listadequate. . Yes Max MW 11 ,8ppg._ _ _ WGA 2/14/2005 29 _B_OP.Es,dJ)they meetreguJatioo _ _ _ _ _ . - - - - - - - - - - - _.. _ Yes - - - - - 30 _BOP.Epre.ss raJiog appropriate; test to (put psig in _comments) _... Yes Test tJ) 40QO psi.MSF' 23_80 psi. 31 _CJ1okemanjfold complies. w/API RF'-53 (May 84) . . _ _ . _ _ _ _ Yes - - - - - 32 Work wBI occur withoutoperatjonsl1utdown · . .Yes 33 Is. pres.ence of H2S gas_ probable. - - - - Yes 1 07ppm_on pad. _ _ _ _ _ - - - - - - - 34 Mechan[c¡;¡Lc~)I)djtlon J){ wells within .Þ.Oß verified (For. s.ervice welJ only). _ . _ .... _. _ Yes Cmtng records indicate mech_ iot. of all.Þ.OR wells. . Geology 35 Permit c.an Þe issu.ed w!o hydrogen_ sulfide meas!Jres. _ ..... _ _ No_ 36 _D_ata_preseoted on pote_ntial J)verpres.sure _zones _ _ _ _ ... NA Appr Date 37 _Seismic_analysjs of shaJlow gaszJ)oes. . _ _ . ._NA - - - - - - RPC 2/11/2005 38 _Seabedcondjtipo survey (if off-shJ)re) _ _ . . . . . _ _ . . . _ . .. _NA 39 _ Contact nam_elphoneforweekly progres.sreRorts [e¡<ploratpryonlyt ... _ _ _ .NA - - Geologic Date: Engineering Date Public Date Commissioner: Commissioner: C$,i"e, ÐT~ 2-) Icfls 7'lfL/ð...r . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility . ;2.. Q S-- D lÙ # /3 12 ( $Revision: 3 $ LisLib $Revision: 4 $ Fri Jul 08 15:16:14 2005 Reel Header Service name. .......... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... .......... ..UNKNOWN Continuation Number.... ..01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 17-13A 500292120001 BP Exploration Alaska Sperry Drilling Services 08-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003607846 A. SHANAHAN J. RALL MWD RUN 2 MW0003607846 N. WHITE J. RALL MWD RUN 3 MW0003607846 N. WHITE J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003607846 N. WHITE J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 ION 15E 2336 1078 64.90 36.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT sl 8.500 6.125 (IN) SIZE (IN) DEPTH (FT) 9.625 9166.0 7.000 10958.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS FROM 17-13 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 9166'MD/7884'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 3 AND 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 4' DOWNHOLE PER E-MAIL INSTRUCTIONS RECEIVED FROM D.SCHNORR (SIS/BP) ON 30 JUNE 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT WELL 17-13A WITH API#: 50-029-21200-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14250'MD/8763'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . ADTQ AZIMUTHAL BULK DENSITY TOP QUADRANT. ADBQ AZIMUTHAL BULK DENSITY BOTTOM QUADRANT. ADRQ AZIMUTHAL BULK DENSITY RIGHT QUADRANT. ADLQ AZIMUTHAL BULK DENSITY LEFT QUADRANT. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.6 PPG FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name...... .......STSLIB.001 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation.......05/07/08 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP RH03 RHOB DRHO PEF RH02 RHO 1 RH04 $ 1 and clipped curveSj all bit runs merged. .5000 START DEPTH 9041.5 9159.0 9159.0 9159.0 9159.0 9168.5 9170.0 11118.5 11118.5 11118.5 11118.5 11123.0 11148.0 11148.0 STOP DEPTH 14201. 0 14208.0 14208.0 14208.0 14208.0 14208.0 14254.0 14175.0 14175.0 14175.0 14175.0 14175.0 14175.0 14175.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 9041. 5 14254.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: GR 9037.5 14250.0 BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 9166.0 9193.5 10958.0 11191. 0 MERGE BASE 9193.5 10958.0 11191.0 14250.0 # Data Format Specification Record Data Record Type....... ... ...... ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point.... ...... ... .Undefined . . Frame Spacing. . . . . . . . . . . . . . . . . . . . .60 .lIN Max frames per record.. ...........Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 RHOB MWD G/CM 4 1 68 32 9 DRHO MWD G/CM 4 1 68 36 10 PEF MWD BARN 4 1 68 40 11 RHOl MWD G/CM 4 1 68 44 12 RH03 MWD G/CM 4 1 68 48 13 RH04 MWD G/CM 4 1 68 52 14 RHO 2 MWD G/CM 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9041.5 14254 11647.8 10426 9041. 5 14254 ROP MWD FT/H 0.29 4970.38 136.868 10169 9170 14254 GR MWD API 26.82 417.5 125.234 10320 9041.5 14201 RPX MWD OHMM 0.38 1373.47 15.7028 10099 9159 14208 RPS MWD OHMM 0.63 1694.55 15.7038 10099 9159 14208 RPM MWD OHMM 0.52 2000 22.9161 10099 9159 14208 RPD MWD OHMM 0.47 2000 29.3494 10099 9159 14208 FET MWD HOUR 0.19 92.02 1.73229 10080 9168.5 14208 RHOB MWD G/CM 2.199 2.714 2.32366 6114 11118.5 14175 DRHO MWD G/CM -0.085 0.361 0.0556374 6114 11118.5 14175 PEF MWD BARN 1. 08 3.36 1.75092 6114 11118.5 14175 RHOl MWD G/CM 2.2 2.529 2.29975 5110 11148 14175 RH03 MWD G/CM 2.204 2.7 2.3222 5909 11118.5 14175 RH04 MWD G/CM 2.192 2.596 2.31512 5130 11148 14175 RH02 MWD G/CM 2.197 2.611 2.34704 5410 11123 14175 First Reading For Entire File...... ....9041.5 Last Reading For Entire File.......... .14254 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation. ..... .05/07/08 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number...... .... .1.0.0 Date of Generation..... ..05/07/08 Maximum Physical Record..65535 File Type............... .LO . Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9166.0 STOP DEPTH 9193.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined 29-MAR-05 Insite 66.37 Memory 9194.0 9166.0 9194.0 .0 .0 TOOL NUMBER 73906 8.500 9166.0 LSND 11.50 49.0 9.5 800 3.8 .000 .000 .000 .000 .0 146.0 .0 .0 . Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 9166 0.29 Mean 9179.75 4.52429 Nsam 56 56 Max 9193.5 10.62 First Reading For Entire File......... .9166 Last Reading For Entire File.......... .9193.5 File Trailer Service name........ .....STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..... ..05/07/08 Maximum Physical Record..65535 File Type.... .......... ..LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name.... .........STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/07/08 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 . First Reading 9166 9166 Last Reading 9193.5 9193.5 header data for each bit run in separate files. 2 .5000 START DEPTH 9037.5 9155.0 9155.0 9155.0 9155.0 9164.5 9194.0 STOP DEPTH 10926.0 10918.5 10918.5 10918.5 10918.5 10918.5 10958.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 01-APR-05 Insite 66.37 . DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY.. (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point........... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record.......... ...Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Memory 10958.0 9194.0 10958.0 42.7 66.9 TOOL NUMBER 73906 73906 8.500 9166.0 LSND 11.60 44.0 9.4 1000 3.4 1. 000 .480 .700 1. 300 73.0 158.0 73.0 73.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last . . Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9037.5 10958 9997.75 3842 9037.5 10958 ROP MWD020 FT/H 0.44 4970.38 86.215 3529 9194 10958 GR MWD020 API 26.82 417.5 166.903 3778 9037.5 10926 RPX MWD020 OHMM 0.38 1373.47 4.76771 3528 9155 10918.5 RPS MWD020 OHMM 0.63 1694.55 5.44817 3528 9155 10918.5 RPM MWD020 OHMM 0.73 2000 11.0126 3528 9155 10918.5 RPD MWD020 OHMM 0.47 2000 14.285 3528 9155 10918.5 FET MWD020 HOUR 0.34 27.83 1. 20904 3509 9164.5 10918.5 First Reading For Entire File....... ...9037.5 Last Reading For Entire File....... ... .10958 File Trailer Service name..... ........STSLIB.003 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation.......05/07/08 Maximum Physical Record..65535 File Type................ LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name......... ....STSLIB.004 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......05/07/08 Maximum Physical Record. .65535 File Type.... .......... ..LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 10919.0 10919.0 10919.0 10919.0 10919.0 10926.5 10958.5 STOP DEPTH 11145.5 11145.5 11145.5 11145.5 11145.5 11138.5 11191.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 05-APR-05 Insite 66.37 Memory 11191.0 10958.0 11191.0 64.0 . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.. ...0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point. ............ .Undefined Frame Spacing....... ............. .60 .1IN Max frames per record............ .Undefined Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 89.4 TOOL NUMBER 151107 148579 6.125 10958.0 Flopro 8.40 53.0 10.0 3500 8.5 1.300 .750 .700 1. 500 70.0 125.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10919 11191 11055 545 10919 11191 ROP MWD030 FT/H 1. 02 206.51 36.851 466 10958.5 11191 GR MWD030 API 67.23 374.73 110.579 425 10926.5 11138.5 RPX MWD030 OHMM 1. 82 808.26 15.3744 454 10919 11145.5 RPS MWD030 OHMM 1.45 944.89 16.3396 454 10919 11145.5 RPM MWD030 OHMM 0.52 2000 139.682 454 10919 11145.5 RPD MWD030 OHMM FET MWD030 HOUR . 5.22 1. 04 2000 92.02 255.111 17.8934 First Reading For Entire File...... ... .10919 Last Reading For Entire File.......... .11191 File Trailer Service name... ..........STSLIB.004 service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/07/08 Maximum Physical Record. .65535 File Type... ............ .LO Next File Name...... .... .STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/08 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RHOB DRHO PEF RHO 3 RH02 GR RH01 RH04 RPM RPS RPD FET RPX ROP $ 5 . 454 454 11145.5 11145.5 10919 10919 header data for each bit run in separate files. 4 .5000 START DEPTH 11114.5 11114.5 11114.5 11114.5 11119.0 11139.0 11144.0 11144.0 11146.0 11146.0 11146.0 11146.0 11146.0 11191.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: STOP DEPTH 14171.0 14171.0 14171.0 14171.0 14171.0 14197.0 14171.0 14171.0 14204.0 14204.0 14204.0 14204.0 14204.0 14250.0 06-APR-05 Insite 66.37 Memory 14250.0 11191.0 14250.0 87.7 . MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR ASLD EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Azimuthal Litho-Den Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction... ............ ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing..................... 60 .1IN Max frames per record.. ...........Undefined Absent value........... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 93.2 TOOL NUMBER 151107 193134 148579 6.125 10958.0 FloPro 8.50 48.0 9.6 3300 6.5 1. 070 .630 1.680 1.180 90.0 158.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 RHOB MWD040 G/CM 4 1 68 32 9 DRHO MWD040 G/CM 4 1 68 36 10 PEF MWD040 BARN 4 1 68 40 11 RHO 1 MWD040 G/CM 4 1 68 44 12 RH03 MWD040 G/CM 4 1 68 48 13 RH04 MWD040 G/CM 4 1 68 52 14 RH02 MWD040 G/CM 4 1 68 56 15 of . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11114.5 14250 12682.3 6272 11114.5 14250 ROP MWD040 FT/H 0.65 371. 05 174.916 6118 11191. 5 14250 GR MWD040 API 53.29 408.71 100.517 6117 11139 14197 RPX MWD040 OHMM 6.93 36.86 22.034 6117 11146 14204 RPS MWD040 OHMM 7.3 35.57 21.5716 6117 11146 14204 RPM MWD040 OHMM 7.03 33.78 21.1151 6117 11146 14204 RPD MWD040 OHMM 7.64 34.44 21. 282 6117 11146 14204 FET MWD040 HOUR 0.19 17.72 0.83298 6117 11146 14204 RHOB MWD040 G/CM 2.199 2.714 2.32366 6114 11114.5 14171 DRHO MWD040 G/CM -0.085 0.361 0.0556374 6114 11114.5 14171 PEF MWD040 BARN 1. 08 3.36 1.75092 6114 11114.5 14171 RH01 MWD040 G/CM 2.2 2.529 2.29975 5110 11144 14171 RH03 MWD040 G/CM 2.204 2.7 2.3222 5909 11114.5 14171 RH04 MWD040 G/CM 2.192 2.596 2.31512 5130 11144 14171 RHO 2 MWD040 G/CM 2.197 2.611 2.34704 5410 11119 14171 First Reading For Entire File...... ....11114.5 Last Reading For Entire File....... ... .14250 File Trailer Service name........ ... ..STSLIB.005 Service Sub Level Name... Version Number;..... .... .1.0.0 Date of Generation.......05/07/08 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.. ........ .UNKNOWN Comments. ...... ..... ... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/07/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... .......... ..UNKNOWN Continuation Number..... .01 Next Reel Name...... .... .UNKNOWN Comments.... ...... .......STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File