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Home My WebLink About204-1477. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU U-12A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-147 50-029-21409-01-00 14600 Conductor Surface Intermediate Scab Liner / Liner Liner 8786 80 2670 9836 7986 3968 14516 20" 13-3/8" 9-5/8" 7" 4-1/2" 8806 31 - 111 30 - 2700 29 - 9865 2829 - 10815 10632- 14600 31 - 111 30 - 2699 29 - 8123 2828 - 8741 8623 - 8786 10855 470 2670 4760 5410 7500 None 1490 4930 6870 7240 8430 11060 - 14505 3-1/2" 9.2# 13Cr80 27 - 10625 8877 - 8808 Structural 4-1/2" Baker S3 Packer 10564 8580 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907.748.8581 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028260 27 - 8619 IC Test Void in Wellhead at Surface Pump 11-cups of Greenstick packing. Final Pressure = 0-psi. 117 150 418 436 1709 2246 1500 1550 220 220 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10564, 8580 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:08 pm, Aug 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.18 13:01:42 - 08'00' Torin Roschinger (4662) J.Lau 11/4/25 RBDMS JSB 082125 DSR-9/11/25 ACTIVITY DATE SUMMARY 7/22/2025 T/I/O = SSV/500/90. Temp = SI. Bleed IAP/ Greenstick IC test void. ALP = 0 psi, SI @ CV. IA FL @ 8541' (sta #2 SO). Bled IAP to OT from 500 psi to 10 psi in 4 hrs. RU packing gun to IC void and pumped 5 1/2 gun loads of liquid greenstick. Final WHPs = SSV/10/90. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU U-12A 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: Producer U-12A (PTD #2041470) anomalous OA pressure over MOASP Date:Thursday, July 10, 2025 11:15:10 AM Attachments:U-12A TIO plot 250710.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, July 10, 2025 10:12 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) anomalous OA pressure over MOASP Mr. Regg, Producer U-12A (PTD # 2041470) was reported to have OA casing pressure above MOASP on 07/09/25 after the well was shut-in. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Bleed IAP and OAP to 0 psi 2. Wellhead Tech: Greenstick IC-test void 3. DHD: Monitor for IAxOA communication 4. Well Integrity: Additional diagnostics as needed. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, May 13, 2024 11:44 AM To: jim.regg <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Producer U-12A (PTD #2041470) IAxOA resolved post greenstick Mr. Regg, Producer U-12A (PTD # 2041470) greenstick treat was performed on the IC test void on 05/05. In the following 10 days, ~1300 psi differential has been observed between the IAxOA annuli. The well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, April 30, 2024 11:18 AM To: jim.regg <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) anomalous OA pressure over MOASP Mr. Regg, Producer U-12A (PTD # 2041470) was reported to have OA casing pressure above MOASP on 04/30/24 after the well was shut-in. The well has a history of IAxOA communication through the wellhead when cold that has been remedied by re-energizing the secondary Y-seal. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Bleed IAP and OAP to 0 psi 2. Wellhead Tech: Greenstick IC-test void 3. DHD: Monitor for IAxOA communication 4. Well Integrity: Additional diagnostics as needed. 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, 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. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU U-12A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-147 50-029-21409-01-00 14600 Conductor Surface Intermediate Production Liner 8786 80 2670 9836 7986 3968 14516 20" 13-3/8" 9-5/8" 7" 4-1/2" 8806 31 - 111 30 - 2700 29 - 9865 2829 - 10815 10632- 14600 31 - 111 30 - 2699 29 - 8123 2828 - 8741 8623 - 8786 10855 470 2670 4760 5410 7500 None 1490 4930 6870 7240 8430 11060 - 14505 3-1/2" 9.2# 13Cr80 27 - 10625 8877 - 8808 Structural 4-1/2" Baker S3 Packer 10564 8580 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028260 27 - 8619 IC Test Void in Wellhead at Surface Pump 16-cups of Greenstick packing. Final Pressure = 0-psi. 155 153 394 389 1957 2105 1518 1520 219 217 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10564, 8580 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 11:38 am, May 14, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.14 05:11:07 -08'00' Torin Roschinger (4662) DSR-5/14/24 RBDMS JSB 052825 WCB 8-27-2024 ACTIVITY DATE SUMMARY 5/3/2024 T/I/O = 240/1450/370. Temp = 138°. Bleed IAP & OAP to 0 psi (Greenstick IC test void). ALP = 1520 psi, online. SI WV and AL CV. IA FL @ 8541' (sta #2 SO). Bled IAP to OT from 1450 psi to 60 psi in 5 hrs. OA FL @ near surface. Bled OAP to BT from 370 psi to 200 psi in 30 min (FTS). Did not monitor. IA FL unchanged. Final WHPs = SSV/60/200. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:10 5/4/2024 T/I/O = SSV/90/200. Temp = SI. Bleed IAP & OAP to 0 psi (Greenstick IC test void). ALP = 1850 psi, SI @ CV. IA FL @ 8541' (sta #2 SO). Bled IAP to OT from 90 psi to 0 psi in 5 hrs. OA FL @ near surface. Bled OAP to BT from 200 psi to 0 psi in 3 hrs (FTS). Did not monitor. IA FL unchanged. Stung into IC void: 0 psi. Monitored for 10 min, pressure unchanged. Held open bleed on IA & OA, removed LDS from 12:00 side of WH. Removed Alemite fitting from 6:00 side and installed ball valve. RU packing gun and pumped 6 gun loads of greenstick. No returns on 12:00 side, will return following shift to continue pumping. Re-installed LDS and tourqued to 450 Ft/Lbs. Final WHPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 5/5/2024 T/I/O = SSV/0+/30. Temp = SI. Bleed IAP & OAP to 0 psi (Greenstick IC test void). ALP = 1950 psi, SI @ CV. IA FL @ 8541' (sta #2 SO). Bled IAP to OT from 0+ psi to 0 psi in 5 hrs and held open bleed. IA FL unchanged. OA FL @ near surface. Bled OAP to BT from 30 psi to 0 psi in 30 min (gas) and held open bleed. Did not monitor. Stung into IC void: 0 psi. Monitored for 10 min, pressure unchanged. Removed LDS from 12:00 side of WH. RU packing gun and pumped 2 gun loads of greenstick with returns 360° around IC void (visualised by pulling LDS @ 9:00 side) and held pressure to get a good pack. Re-installed LDS and tourqued to 450 Ft/Lbs. Final WHPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 Daily Report of Well Operations PBU U-12A g RU packing gun and pumped 2 gun loads of greenstick withgggg returns 360° around IC void (visualised by pulling LDS @ 9:00 side) and held ( pressure to get a good pack. RU g packing gun and pumped 6 gun loads of greenstick 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:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Torin Roschinger; Oliver Sternicki Subject:OPERABLE: Producer U-12A (PTD #2041470) IAxOA resolved post greenstick Date:Monday, May 13, 2024 11:44:16 AM Attachments:U-12 TIO.docx Mr. Regg, Producer U-12A (PTD # 2041470) greenstick treat was performed on the IC test void on 05/05. In the following 10 days, ~1300 psi differential has been observed between the IAxOA annuli. The well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, April 30, 2024 11:18 AM To: jim.regg <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) anomalous OA pressure over MOASP Mr. Regg, Producer U-12A (PTD # 2041470) was reported to have OA casing pressure above MOASP on 04/30/24 after the well was shut-in. The well has a history of IAxOA communication through the wellhead when cold that has been remedied by re-energizing the secondary Y-seal. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Bleed IAP and OAP to 0 psi 2. Wellhead Tech: Greenstick IC-test void 3. DHD: Monitor for IAxOA communication 4. Well Integrity: Additional diagnostics as needed. PBU U-12A PTD 2041470  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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Torin Roschinger; Oliver Sternicki; PB Wells Integrity Subject:UNDER EVALUATION: Producer U-12A (PTD #2041470) anomalous OA pressure over MOASP Date:Tuesday, April 30, 2024 11:18:34 AM Attachments:U-12A.pdf Mr. Regg, Producer U-12A (PTD # 2041470) was reported to have OA casing pressure above MOASP on 04/30/24 after the well was shut-in. The well has a history of IAxOA communication through the wellhead when cold that has been remedied by re-energizing the secondary Y-seal. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: Bleed IAP and OAP to 0 psi 2. Wellhead Tech: Greenstick IC-test void 3. DHD: Monitor for IAxOA communication 4. Well Integrity: Additional diagnostics as needed. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PBU U-12A PTD 2041470 jbr TIO Pressures PBU U-12A (PTD 2041470) 4/30/2024 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 29, 2018 8:29 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Bergene, Matthew; Draughon,Austin; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson; Wellman,Julie;Youngmun,Alex;Zoesch, Eric Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer U-12A (PTD#2041470)OA repressurization stopped All, Producer U-12A(PTD#2041470)was made Under Evaluation on 04/18/18 for exhibiting sustained OA casing pressure above NOL after it was shut in. On 04/21/18 the Cameron wellhead technician performed a PPPOT-IC that failed.The wellhead secondary seals were re-energized and a follow up LPE showed the secondary seals to be holding.The well was subsequently thermal cycled twice and OA did not repressurize.This indicates the re-energizing of the secondary wellhead seals stopped the source of the OA repressurization.The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg SCANNED Well Integrity Engineer ai1N BP Global Wells Organization-Alaska Office:907-659-8110 OPERABLE: Producer U-12 (PTD#2041470)OA repressurization stopped Fro K GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent: Wedn April 18, 2018 3:42 PM To: AK, OPS EOC Spe ts;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC •• ead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, • ELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area TL;AK, RES GPB East Wells :, Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Bergene, Matthew;Frankenburg, Amy;Peru, Cale;Rupert, C. ' •n;Shriver,Tyson;Wellman, Julie;Youngmun, AIex;Zoesch, Eric;'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well In , ty;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF •is Comp Rep;AKIMS App User;Cismoski, Doug A;Daniel, Ryan;Dempsey, David G;Dickerman, Eric;Hibbert, Michael;Janows , -rrie;Montgomery,Travis J;Munk, Corey;Obrigewitch, Beau;O'connor, Katherine;Romo, Louis A;Sternicki, Oliver R;Te :- Joshua;Worthington, Aras J;'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer U-12 (PTD #2041470) Sustained outer annulus casino essure above NOL 1 M N Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,April 18, 2018 3:42 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD 5;AK, OPS Well Pad SW;AK, OPS WELL PAD W; AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A;Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer U-12 (PTD#2041470) Sustained outer annulus casing pressure above NOL Attachments: U-12A.pdf All, Producer U-12 (PTD#2041470)was reported to have sustained outer annulus casing pressure above NOL on 4/18/2018. The OA pressure was reported to be 1,500psi. The high OA pressure is an indication of a potential loss of the secondary barrier. At this time the well is reclassified as Under Evaluation. Plan Forward: 1. DHD OART 2. Wellhead—PPPOT-IC, LPE,energize secondary seals 3. DHD—Assist wellhead, bleed IA and OAP 4. Ops—POP well to thermal cycle • Please respond with any questions, Joshua Stephens SC Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 W .....r roses.7.wu e.. 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, October 19, 2017 4:48 AM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Frankenburg,Amy; Rupert, C. Ryan; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer U-12A(PTD#2041470) OA Repressurization - Manageable by Bleeds All; Producer U-12A(PTD#2041470)was reported to have OA repressurization when shut in. The secondary seals of the inner casing hanger were plastic packed. The well went through multiple thermal cycles while performing OA repressurization test. The OA has shown an repressurization rate of approximately^'16 psi per day. This repressurization is considered manageable by bleeds. The well is reclassified as Operable,and may remain online as needed. Plan Forward/Work Completed: 1. Downhole Diagnostics:Thermal cycle well while performing OA repressurization test-Complete 2. Well Integrity Engineer:Additional diagnostics as required Please reply if in conflict, Thanks, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED FEB 2 ')!1;R Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, September 20, 2017 12:52 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Frankenburg,Amy; Rupert, C. Ryan; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel, Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVLAUATION: Producer U-12A(PID#2041470) Sustained outer annulus casing pressure above NOL Attachments: U-12A.pdf All, Producer U-12A(PTD#2041470)was reported to have sustained outer annulus casing pressure above NOL on 9/19/17. The pressure were reported to be T/I/0= 190/1960/1360psi. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Downhole diagnostics: Outer annulus repressurization test. 2. Wellhead: Leak pack eval of the inner casing hanger, re-energize secondary seals. 3. Well Integrity Engineer:Additional diagnostics as needed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCOW SEP 2 1201.7. vva - ergrors .. • • Wallace, Chris D (DOA) From: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com> Sent: Saturday, October 15, 2016 1:51 PM To: AK, GWO SUPT Well Integrity; AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad HUQ; Bergene, Matthew; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy;Worthington, Aras J; AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer U-12A (PTD #2041470)IAxOA communication mitigated Attachments: U-12A.pdf; Producer U-12 (PTD #2041470) TIO Plot 2016-10-15.docx All, Under Evaluation Producer U-12 (PTD#2041470) showed no signs of IAXOA communication when shut in or online after pumping plastic packing on 10/07/16 to re-energize the inner casing hanger secondary seals.This well has two competent barriers to formation and is now re-classified as Operable. A copy of the TIO and wellbore have been included for reference. Please reply with any questions or concerns. Thank you, Ryan Moore Well Integrity/Down Hole Diagnostics (907)659-5525 Office (805)550-5342 Cell Harmony#5415 Alternate:Josh Prowant GJ�� Global Wells U Y Organization From: AK, GWO SUPT Well Integrity Sent: Saturday, October 01, 2016 12:02 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel,Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bergene, Matthew; 'jim.regg@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney,--Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) Sustained OA Casing Pressure Above MOASP All, S • Producer U-12A(PTD#2041470) TIO Plot 10/15/2016 7406 10]4 • `= : ... .._..._ tI'17:i5 C177116 ®7J16 OY4!'M 404?6 067G'M O4Rt'M D]Rm aTmb • 0lQtnb • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Saturday, October 01, 2016 12:02 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bergene, Matthew; Regg, James B (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) Sustained OA Casing Pressure Above MOASP Attachments: Producer U-12A (PTD#2041470) TIO Plot 2016-10-01.docx All, Producer U-12A(PTD#2041470) was reported to have sustained OA casing pressure above MOASP on 09/28/16.The well had recently been shut in. Operations personnel bled the OA pressure from 1780 psi to 280 psi. A follow-up monitor showed the OA pressure stable; wellhead pressures were TBG/IA/OA= 200/1850/300 psi. On 09/29/16,the well was brought back online.Wellhead pressures on 09/30/16 were TBG/IA/OA= 200/1520/630 psi. Downhole Diagnostics bled the OA to 110 psi, and will monitor the OA build-up rate. U-12A has a history of IAxOA communication when shut in with high IA pressure;the most recent occurrence was June 2015.The communication was mitigated by re-energizing the secondary Inner Casing seal. The well is reclassified as Under Evaluation for further diagnostics and repair. Plan Forward: 1. Downhole Diagnostics: Warm OART—In Progress 2. Wellhead: Positive Pressure Packoff Test—Inner Casing, Leak Path Evaluation if fails, Re-energize secondary seals if indicated by LPE 3. DHD: Cold OART 4. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot is attached. Please reply if in conflict with proposed plan. SCANNED FEB 1 32017 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0: (907)659-5102 C: (907)943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 ! • Producer U-12A(PTD#2041470) TIO Plot 10/01/2016 Well U-12 300 —.-110 —0- 2 VJD 0-2.VJ0OA ODA +OOOA On 109 C-:0116 ',Mir'16 0'!15'16 07,2216 0-2916 c805't6 U&'21€ C i9-i6 0876'16 090216 000516 031616 0923'6 098016 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday,July 04, 2015 12:55 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Peru, Cale; Munk, Corey; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE: Producer U-12A (PTD #2041470) Outer Annulus manageable by bleeds Attachments: image001.png; Producer U-12A (PTD #2041470) Wellbore Schematic.pdf; image002.png; Producer U-12A (PTD #2041470) TIO Plot.docx All, Producer U-12A(PTD#2041470) had a passing TIFL performed on June 19, 2015, indicating the presence of competent barriers. Also the secondary seals of the inner casing hanger was re-energized. The OA has shown an repressurization rate of approximately^'50 psi per day. This repressurization is considered manageable by bleeds. The well is reclassified as Operable, and may remain online as needed. A copy of the TIO plot and wellbore have been included for reference. Please call with questions or concerns. Thank you, SattiED JUL 0 62015 Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator G'J�/ Global Wells �/y Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, June 12, 2015 1:36 PM To: AK,Z?PS-GC29514AK OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Welt Opt Engr; AK, OPS Well Pad HUQ; 'chris.wallace@alaska.gov'; Peru, Cale; Munk, Corey Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engirer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; 'jim.regg@alaska.gov'; Weiss, Troy D Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) Outer Annulus exceeded MOASP All, \ III 1 Producer U-12A(PTD#2041470)TIO Plot tM �.Y • Oh ' [aY w;4 w •!.• r.n acix u:1.5 tt'Ic!. da:x a:3.! a]PN .._ ..., 1 ' V LI CNV U 12 A B1FE�1D= 4" � S. Y NOTES:WELL ANGLE 70°@ 11086' ••" ACTUATOR= AXI3SON L1 3-1/2"CHROME TBG•• KB.ELEV= — 77.47 BF.BEV= 48.57 27" 4-1/2"X 3-1/2 RJP,D=2.992" KOP= 3100' Max Angle= 103°@ 14510' 2198' H3-1/2"FES X NP,D=2.813" Datum MD= 11058' Datum TVD= 8800'SS 2829' H9-5/8"X 7"BKR ZXP LTP&I-DR,D=6.276' 13-3/8'CSG,72#,L-80,1D=12.347" --1 2700' GAS UFT MANDRELS j ST M31 V I) DEVTYPE VLV LATCH FORT DATE Minimum ID =2.78" @ 10610' •4 4 3190 '3186 12 MAG DOME RK 12 07/26/12 3-1/2" XN NIPPLE �s 3 6100 5497 45 MAG DOME RK 16 07/26/12 ••• 2 8541 7207 45 AM SO RK 26 07/02/13 • 7"SCAB LNC 26#,L-80 BTC-M H 9715' eta 1 10482 8528 51 MAG DMY RK 0 10/05/11 .0383 bpf,D=6.276" a4 9-5/8"CSG,47#,L-80,D=8.681" H —9865 --_ 9715' _9-5/8"X 7"BKR ZXP LTP/HDR, 9-5/8"WHIPSTOCK —I 9930' &TRACK SEAL ASSY,D=6.160" MFLOUT WINDOW(U-12A) 9865'-9885' 10541' H3-1/2"FES X NP,D=2.813" 10562' H3-1/2"X 4-1/2"XO,D=2.940" :4 c 10564' -17"X4-1/2"BKR S-3 PKR,D=3.875" 10568' H4-1/2"x 31/2"xo,D=2.940' 10589' H3-1/2"IES X tsP,D=2.813" 10610' -3-1/2"HES XNNP,D=2.750" NOTE 2.78" CATCHER SUB PASS®(07125/12) 10622' H3-1/2"x 41/2"xo,D=2.992" 3-1/2"TBG,9.2#,13CR-80 VAM ACE, 1 10624' \ 10624' H4-1/2"VVLFG,D=3.958" 0087 bpf,D=2.992" \ 10632' I-7"X 5" BKR ZXP LNR TOP PKR, TOP OF 4-1/2"LNR — 10632' C l-GFt w/TRACK SLV,D=4.440" 1 10656' 5'X 4-1/2"XO,ID=3.990" 7"LM,26#,L-80 BTC-M,.0383 bpf,D=6.276" —1 10815' ^10855'SLM H FISH-BTT WF-PSTOCK(TAGGED 12/27/11) PERFORATION SUMAAARY REF LOG:DGR DUAL GAM%RAY ON 09/14/04 , A�LOUT WINDOW(U 12AL1) 10871'- 70879' ANGLE AT TOP FERE:NA Note:Refer to Production DB for historical perf data 10904' —2.70'BKR OEFLOY SLV,13=1.920' SIZE SPF INTERVAL I Opn/Sqz I DATE SEE PAGE 2 FOR FORATION t'FORMATION — — _ _ F BTD —1 14516' ii 2-3/8"BKR 0 WJG,D=1.00" —1 13036' 2-3/8'LNC,4.7#,L-80 STL,.0039 bpf,D=1.995" 13057' 41/2"LNR, 12.6#,L-80 BTC-M —I 14600' r•-•-•-• P' .0152 bpf,ID=3.958" DATE REV BY COMVU'TTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/30/85 INTIAL COMPLETION 11/25/13 DIS/PJC MN D CORRECTDN WELL: U-12A 09/19/04 DAV/TLH SIDETRACK(U-12A) • PERMT No: 2041470/2111070 12/07/11 NORDIC 1 CTD ML STRCK(U-12A LI) AR No: 50-029-21409-01(60) 01/02/12 PJC FINAL DRLG CORRECTIONS SEC 18,T11N,R13E,467 FSL&2275'FEL 07/31/12 DJS/JMD GLV GO(07/26/12) 07/28/13 CJNPJC GLV C/O(07/12/13) BP Exploration(Alaska) U -12A jLl ( I' I FERFORATION SUMMARY REF LOG:DGR DUAL GAMMA RAY ON 09/14/04 ANGLE AT TOP FEHF:WA Note:Refer to Ftoduction DB for historical pert data SIZE SPF INTERNAL Opn/Sqz DATE U-12A 7 6 11060-11080 0 10/20/09 7 6 11140-11160 0 10/20/09 2-1/7 6 11174-11184 0 09/24/11 2-1/7 6 11240-11260 0 09/21/11 2-1/7 4 11350- 11540 0 09/16/04 2-1/7 4 11575-11675 0 09/16/04 2-1/7 4 11970- 12125 0 09/16/04 2-1/7 6 12350-12380 0 09/20/11 2-1/7 6 12380-12410 0 09/20/11 2-1/7 4 12850-12900 0 09/16/04 2-1/7 4 13050-13150 0 09/16/04 2-1/7 4 13850-13990 0 09/16/04 2-1/7 4 14010-14025 0 09/16/04 2-1/7 4 14440- 14505 0 09/16/04 U-12A11 2-3/8" SLID 12461- 13036 SLOT 11/28/11 11114 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/30/85 INTIAL COMPLETION 11/25/13 DJS/PJC MN ID CORRECTION WELL- U-12A 09/19104 DAV/TLH SIDETRACK(U-12A) PER IT No: 2041470/2111070 12/07/11 NORDIC 1 CTD ML STRCK(U-12A L1) AR No: 50-029-21409-01(60) 01/02/12 PJC MAL DRG CORRECTIONS SEC 18,T11N,R13E,467 FSL&2275'FEL 07/31/12 DJS/JMD GLV C/O(07/26/12) 07/28/13 CJNYPJC GLV C/O(07/12/13) BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, June 12, 2015 1:36 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Wallace, Chris D (DOA); Peru, Cale; Munk, Corey Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA); Weiss, Troy D Subject: UNDER EVALUATION: Producer U-12A (PTD #2041470) Outer Annulus exceeded MOASP Attachments: image001.png; Producer U-12A (PTD #2041470) TIO Plot.docx; Producer U-12A (PTD # 2041470) Wellbore Schematic.pdf All, Producer U-12A(PTD#2041470) was reported to have sustained outer annulus casing pressure above MOASP after being shut in on June 09, 2015. The pressures were reported to be TBG/IA/OA= 2000/1960/1960 psi. Operations bled the OA from 1960 to 200 psi on June 09, 2015 and a subsequent follow up monitor obtained on June 10, 2015 showed the pressures to be TBG/IA/OA= 1720/1720/370 psi. At this time the well has been reclassified as Under Evaluation for additional diagnostics. Please leave the well shut in for initial evaluation. Plan Forward: 1. Operations: Leave well shut in 2. Wellhead: Obtain PPPOT-T& PPPOT-IC 3. Operations: Bring well online 4. Downhole Diagnostics: Shut in well after 1 to 3 days and monitor outer annulus pressure trends 5. WIE: Additional diagnostics as needed A copy of the TIO plot and wellbore have been included for reference. Please call with any questions of concerns. Thank you, SCANNED JUN 3 0 2015 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator • Ofganuatxyi WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 Producer U-12A(PTD#2041470) TIO Plot June 12, 2015 U,7 IMO —0-111 1-IMON ooa aooa aoo 0t2,5 to0916 0.76.6 05U3'15 OS-O,5 051.1 0514',5 16211s aims 1.044044 NII_ oN O N N° E 0 o C 7 O N U t y mU atA m t 21301'‹ u)0 L 5i2 157.01 ; 0 C o o r Y L V y S -- g 4 g M C () ES O V)QQMQ Hl my Cil co co n Q 110 0 c O N A Lial Cli C` N O. O - n- �c U oCNI E V I m N . ZZ Z V I Q N Q 0 = •m Ct V C C o 222244774E2 C1 N N Oo 'N' N N N V1 M 11v] 0 `+J O 1- `o ¢ -1 CI. W t _ o 0 N 14. LL U aa J W( ~j W W c� 3 o W W --W F 0 W 0 J 3 J W Z J Z M 'LED Q LL 1-0 O0 '- 0 Z CC pa aaWw3a 11-z-1 o 0 -§O > > 31J, ,o Z 0pu )U 00~00 Z a'W 2f Wr2Ha'OW Z Q a N 2 f 7 d o= I 2 Z % C S N O C C e^0 N O'-o o a 0 0 o p 0 o o o O o m o 9999949994 m v m .+ a z w t m m m m m m M m m m U N N O a -J O 01 E 23 ", C E 7 :4! . 0 co N C N O -J11,0 OS n .11 <IyY C m e��l��`o�a 01 0< cpm Q w p O O Q J =• N 3 Y O O W 0 5 in m JAZ • + gn w N V Z W O W N ` _10. 15§ < ,44 ‹ a m a W K e e 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. <Q..O l} - L ~ '7 Well History File Identifier Organizing (done) D Two-sided 111111111111111111I D Rescan Needed II II11111111 1111111 RESCAN ~olor Items: D Greyscale Items: DI~AL DATA v1" Diskettes, No. ~ D Other, Norrype: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date uJ /3/ Dc' I Date \I ~Dro ~ ' x 30 =~ +~ = TOTAL PAGES ~4- \ 3 f (Count does not include cover sheet) Date: lID 10 151 D Other:: BY: ~ 151 V\ttp Project Proofing 11111111111111 11111 y1Il,f BY: ~ 151 Scanning Preparation BY: Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: <1? 5 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:11113/0(p If NO in stage 1, page(s) discrepancies were found: YES NO 151 JAA P yvv NO BY: Stage 1 BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 11111 BY: Maria Date: 151 Comments about this file: Quality Checked 11111111I11I" 1111I 10/6/2005 Well History File Cover Page.doc . STATE OF ALASKA pp � p • ALASKA *AND GAS CONSERVATION COMMISSIO. 1� E ` REPORT OF SUNDRY WELL OPERATIONS OCT 19 ?()i 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate IDI Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver 114,1961tarthlArfiss Cims. Commission Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspendeti(h 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to n u er: Name: Development 0 Exploratory ❑ , 204 -1470 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21409 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028260 0 U -12A 10. Field /Pool(s): P PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14600 feet Plugs (measured) None feet true vertical 8785.97 feet Junk (measured) None feet Effective Depth measured 14516 feet Packer (measured) 2828. 9715 10564 10632 feet true vertical 8805.06 feet (true vertical) 2827, 8013 8580 8623 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 31 - 111 31 - 111 1490 470 Surface 2670' 13- 3/8 "72# L -80 30 - 2700 30 - 2700 4930 2670 Production 9836' 9 -5/8" 47# L -80 29 - 9865 29 - 8123 6870 4760 Scab Liner 6898' 7" 26# L -80 2817 - 9715 2816 - 8013 7240 5410 Liner 1110' 7" 26# L -80 9705 - 10815 9006 - 8741 7240 5410 Liner 3977' 4 -1/2" 12.6# L -80 10623 - 14600 8617 - 8786 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ - 1 Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# 13Cr80 27 - 10625 27 - 8619 n true vertical depth) 7" Baker ZXP Top and SSSV (type, measured and ue e p ) a Packer 2828 2827 7" Baker ZXP Top Packer 9715 8013 4 -1/2" Baker S -3 Perm Packer 10564 8580 4 -1/2" Baker ZXP Mech Set LT Packer 10632 8623 12. Stimulation or cement squeeze summary: Intervals treated (measured): }, 1 t fj Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 114 260 834 187 Subsequent to operation: 128 52 212 196 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development- 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na , - •e Last 1 - _ , Title Petrotechnical Data Technologist Signatu \WWI Phone 564 -4091 Date 10/19/2011 Nr RED MS OCT 2 0 XP-ks. r�l to. /9. // Form 10-404 Revised 10/2010 Submit Original Only U -12A 204 -147 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base U -12A 9/16/04 PER 11,350. 11,540. 8,923.76 8,942.12 U -12A 9/16/04 PER 14,440. 14,505. 8,821.87 8,807.56 U -12A 9/16/04 PER 13,830. 13,990. 8,945.44 8,914.14 U -12A 9/16/04 PER 13,050. 13,150. 9,025.47 9,020.83 U -12A 9/16/04 PER 14,010. 14,025. 8,910.2 8,907.22 U -12A 9/16/04 PER 11,970. 12,125. 8,981.11 8,991.98 U -12A 9/16/04 PER 11,575. 11,675. 8,945.59 8,954. U -12A 9/16/04 PER 12,850. 12,900. 9,021.13 9,022.64 U -12A 10/19/09 APF 11,060. 11,080. 8,877.43 8,884.61 U -12A 10/19/09 APF 11,140. 11,160. 8,901. 8,904.87 U -12A 9/20/11 APF 12,350. 12,380. 9,002.6 9,004.02 U -12A 9/20/11 APF 12,380. 12,410. 9,004.02 9,005.4 • U -12A 9/21/11 APF 11,240. 11,260. 8,915.16 8,916.79 1 U -12A 9/24/11 APF 11,174. 11,184. 8,907.11 8,908.59 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • U -12A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY „. Y 9/19/2011 CTU #9 Job Scope: Jewelry Log and Adperf MIRU BOT on location MU MHA and PDS logging tools. * * * * ** Job Continued on 9/20/11 * * * * ** 9/20/2011 CTU #9 Job Scope: Jewelry Log and Adperf * * * ** Continued from 9/19/11 * * * ** Load well with Kcl w /safe lube. RIH w/ PDS logging tools in carrier with 2.68" nzl. Drift to i 12,500' start logging pass at 40 fpm. Paint a yellow and blue flag at 12400' log to 10450' POOH Tag at surface BD tools check for data. Good data, make up BOT connector, SLB firing head w/ 2.5" 2506 PJ HMX with 6 SPF gun #1, RIH, tied into !flag w/ MWD log field print and corrected to 12388' ctm, ran past top shot depth and {puh to 12380' and shot gun from 12380' - 12410'. POOH, gun fired, MU SLB firing head and 2.5" 2506 PJ - HMX 6 SPF gun #2 , RIH tied into flag w/ MWD log field print and corrected to 12388' ctm, ran past top shot depth and puh to 12350' and shot 'gun from 12350' - 12380'. POOH. gun fired,. * * * * * * ** i Job Continued * * * * * * ** 9/21/2011; CTU #9 Job Scope: Jewelry Log and adperf * * * * * ** Continued from 9/20/11 * * * * * ** 1 POOH tag at surface. MU RIH with PDS logging tools, Log 11300 to 11200, flag pipe, .log to 10450, POOH, MU BOT MHA w/ SLB firing head and 20' of 2506 PJ 6 SPF +gun, RIH, perforate from 11240' - 11260, POOH. Found a bad spot in the coil at 3800'. `Blow reel down .Well freeze protected to 2875' with 25 bbls of 50/50 methonal. Well left shut in. * * * * ** Job Incomplete, RDMO * * * * ** 9/23/2011 CTU #9 w 1.75" ct. Job scope: Depth log & perforate: Pump 1 1/4" ball to drift coil. RIH w / PDS logging tools 2.125" & 2.70" nz for drift. Logged from 11300' to 10450' «< Job continued on 9/24/2011 »> 9/23/2011 T /I /O= SSV/1100/280 Temp =Si PPPOT -T (FAIL) (Pre CTD) PPPOT-T : RU 1 HP BT onto THA 1100 psi unable to bled to 0 psi, Re torqued LDS "Standard" to max which slowed down gas but was un able to stop it. Attempted to pressure to 5000 psi for 30 minute test would not go above IA pressure which indicates primary seal is leaking when well is shut in. 9/24/2011 CTU #9 w 1.75" ct. Job scope: Depth log & perforate: «< Continue WSR from ;9/23/11 »> At surface confirmed good DATA. RIH w / 2 1/2" x 10' 2506 PJ- HMX 6 ;SPF gun.Top shot 11174' bottom shot 11184'.POOH, Freeze protect well with 25 i bbls of 50/50 methanol. BOP test. Well left shut in. «< Job complete »> • • • FLUIDS PUMPED BBLS 705 1% KCL 27 60/40 METH 7 METH 275 50/50 METH 1014 TOTAL TREE _ CAMERON SAFETY N: 70° @ 11100' & 90° @ 12629' WELLHEAD = 4" 12A ACTUUATTORR - = AXELSON ***3-1/2" Ni lo: KB. ELEV = 77.07' BF. ELEV = 48,57' 1 27' H4 -1/2" X 3 -1/2" XO, ID = 3.598" 1 KOP = 3100' Max Angle = 103 @ 14600' I 2198' 1-13 1/2" HES X NIP, ID = 2.813" 1 Datum MD = 11067 � 1 Datum 1VD = 8800' SS ' 1 2829' H9 -5/8" X 7" BKR ZXP LTP &HGR, ID = 6.276" 1 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2700' ∎11 GAS LIFT MANDRELS cl 11 ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2.75" @ 10610' . � 4 3190 3185 52 MMG DMY RK 0 10/05/11 3 -1/2" HES XN NIPPLE 1 I 3 6100 5496 45 MMG DMY RK 0 10/05/11 .' 1 .4 2 8541 7207 45 MMG DMY RK 0 10/05/11 ++ *: 1 10482 8528 14 MMG DMY RK 0 10/05/11 7" SCAB LNR, 26 #, L -80, --J 9715' 1. 1 .0383 bpf, ID = 6.276" tt; laS, 1 9715' I 9 -5/8" X 7" BKR SLZXP LTP HGR, 1 /C1 w / TIEBACK SEAL ASSY, ID = 6.160" 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1 - 1 — 9865 I 19 -5/8" WHIPSTOCK (—f 9930 ?? I MILLOUT WINDOW (U - 12A) 9865 - 9885' ?? PERFORATION SUMMARY REF LOG: DGR DUAL GAMMA RAY ON 09/14/04 ANGLE AT TOP PERF: 68" @ 11060' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 11060 - 11080 0 10/20/09 ( 10541' H3-1/2" HES X NIP, ID = 2.813" 1 2" 6 11140 - 11160 O 10/20/09 2-1/2" 6 11174 - 11184 O 09/24/11 10562' H3-1/2" X 4 -1/2" XO, ID = 2.940" 1 2 -1/2" 6 11240 - 11260 0 09/21/11 14 Or_ 10564' 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 2 -1/2" 4 11350 - 11540 0 09/16/04 2 -1/2" 4 11575 - 11675 0 09/16/04 ( 10568' H4 -1/2" X 3 -1/2" XO, ID = 2.940" 1 2 -1/2" 4 11970 - 12125 0 09/16/04 2 -1/2" 6 12350 - 12380 0 09/20/11 2 -1/2" 6 12380 - 12410 0 09/20/11 1 10589' 1- 13 -1/2" HES X NIP, ID = 2.813" I 2 -1/2" 4 12850 - 12900 0 09/16/04 2 -1/2" 4 13050 - 13150 0 09/16/04 2 -1/2" 4 13850 - 13990 0 09/16/04 10610' H3 -1/2" HES XN NIP, ID = 2.750" 1 2 -1/2" 4 14010 - 14025 0 09/16/04 2 -1/2" 4 14440 - 14505 0 09/16/04 10622' H3-1/2" X 4 -1/2" XO, ID = 2.992" 1 13 -1/2" TBG, 9.2 #, 13CR, .0087 bpf, ID = 2.992" H 10622' 1 f 10625' — 4 -1/2" WLEG, ID = 3.958" 1, 10623' — 7" X 5" BKR ZXP LNR TOP PKR, HGR w /TIEBACK SLV, ID = 4.420" 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I-L 10815' 10656' 1-15" X 4-1/2" XO, ID = 3.990" 1 1 1 (PBTD H 14516' 1 ••••■ 14 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1--1 14600' ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/30/85 ORIGINAL COMPLETION 10/12/11 SJW /PJC ADPERFS (09/20- 24/11) WELL: U -12A 09/19/04 N7ES SIDETRACK (U -12A) 10/12/11 CDJ/ PJC GLV C10 (10!5/811) PERMIT No: ® 2041470 10/20/04 SGS/TLH GLV C/O AR No: 50- 029 - 21409 -01 11/10/08 KJB /SV GLV C/O (10/30/08) SEC 18, T11N, R13E 10/24/09 MV /PJC PERFS (10/20/09) 05/16/11 GJB/ PJC GLV C/0 (5/13/11) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. -"4= Attn: Well Integrity Coordinator, PRB -20 i3 Post Office Box 196612 Anchorage, Alaska 99519-6612 j A {) -3 A CaliSeCCrr assn CLIcetP ‘4 December 20, 2010 work* Mr. Tom Maunder '1 Alaska Oil and Gas Conservation Commission QED JAN 333 West 7 Avenue 0 Anchorage, Alaska 99501 "f / Subject: Corrosion Inhibitor Treatments of GPB U Pad 19 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from U Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) U -pad I Date: 12/20/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal U - 1920110 50029222440000 N A 0.8 NA 3.4 1/12/2010 U -02A 1982390 50029211700100 NA 0.6 NA 1.7 1/12/2010 U -03 1841470 50029211730000 NA 0.4 NA 1.7 1/12/2010 U -05A 2090700 50029211920100 NA 0.6 NA 3.4 1/12/2010 1/13/2010 U -06B 2050640 50029211170200 NA 1.9 NA 15.3 U-07 1840900 50029211270000 NA 0.6 NA 5.1 1/13/2010 U -08A 6. 1982020 50029211360100 NA 1.4 NA 8.5 1/13/2010 U -09A 1982120 50029211440100 NA 0.2 NA 1.7 1/13/2010 U -10 1851970 50029214230000 NA 7.7 NA 57.8 12/28/2009 U -11B 1931080 50029214200200 NA 0.8 NA 5 . 1 1/13/2010 U -12A 2041470 50029214090100 NA 0.6 NA 3.4 1/12/2010 U -13 1781010 50029203550000 NA 0.1 NA 3.4 1/12/2010 U -14 1931000 50029223860000 NA 0.1 NA 1.7 1/13/2010 U -15B 2011970 50029225650200 NA 1.4 NA 13.6 1/13/2010 Producers with sustained casing presson IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) PM'j xl- _ /47 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] )(4 Sent: Tuesday, January 11, 2011 6:58 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA due to proration Jim /Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 14 -24 (PTD #1830910) W -26A (PTD #1990810) The following wells was found to have sustained casing pressure on the OA during the proration January 10. The immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. U -06B (PTD #2050640) U -12A (PTD #204170 JAN 0 2011 Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/11/2011 OPERABLE: U-12A (PTD #2041470) OA Repressurization Manageable Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, November 07, 2008 7:23 PM ~~~ 1((~'~~Z To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad HU; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Hibbert, Nancy Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: U-12A (PTD #2041470) OA Repressurization Manageable All, U-12 (PTD #2041470) passed an MIT-T and CMIT-TxIA on 10/28/08 proving the well has two competent barriers. In addition, an OA repressurization test passed on 11/g7/08 indicating the OA pressure can be maintained below MOASP with infrequent ee Ing. a weN has been reclassified as Operable. Please contact the Well Integrity Engineer if the OA repressurization rate does become unmanageable. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, October 13, 2008 11:06 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad HU; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Hibbert, Nancy Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: U-12A (PTD #2041470) Sustained OA Casing Pressure All, Well U-12A (PTD #2041470) has been found to have sustainey d casing Dressure on the OA. The TIOs were SSV/1980/2000 psi when an OA bleed was performed. The OA was bleed to 450 psi and repressured 850 psi in 1 hour. The well is currently being tested with a portable unit and the crew will maintain a bleed on the OA to ensure it does not exceed MAASP. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. T: Test well 2. D: OART 3. W: PPPOT-IC 11/28/2008 OPERABLE: U-12A (PTD #2041470) OA Repressurization Manageable • • A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Page 2 of 2 11/28/2008 TREE= CAMERON WELLHEAD - 4" ACTUATOR - AXELSON KB, ELEV = 77.07' BF. ELEV = 4$.5T KOP = 3100' Max Angie = 103 @ 14600' Datum MD = 11067 Datu m TV D = 8800' SS ~ U-12A S NOTES: 70° @ 11100' & 90° @ 12629' *** "CH320METBG"** 13-318" CSG, 72#, L-80, ID = 12.347" ~-~ 2700' Minimum ID = 2.75" @ 10610' 3-1 /2" HES XN NIPPLE ~ 7" SCAB LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ PERFORATION SUMMARY REF LOG: ???? ON XXr"XXIXX ANGLE AT TOP PERF: 85 @ 11350' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 4 11350 - 11540 O 09/16/04 2-112" 4 11575 - 11675 O 09116/04 2-112" 4 11970 - 12125 O 09/16/04 2-1l2" 4 12850 - 12900 O 09116/04 2-112" 4 13050 - 13150 O 09/16/04 2-112" 4 13850 - 13990 O 09/16/04 2-112" 4 14010 - 14425 O 09/16104 2-1l2" 4 14440 - 14505 O 09/16/04 4-112" TBG, 12.6#, L-80, ID = 3.958" ~ 10466' 9-518° csG, 47#, L-8o, ID = 8.x81" 10680' 7" LNR; 26#; IJ4S; ID = 6,276" 112$0` 3-112" TBG, 9.2#, 13CR, .0087 bpf. ID = 2.992" ~--~ 10622' 7" LNR, 26#, L-80, .0383 bpf. ID = 6.276" ~1 10815' PBTD 1451 s' 4-1t2" LNR; 12.6#, L-80, .0152 bpf, ID = 3.958" 14600' 27' 4-112" X 3-112" XO, iD = 3.59$" 2198' 3-112" HES X NIP; ID = 2.813" 2$29' ~ 9-5/8" X 7" BKR SLZXP LNR TOP PKR &HGR, ID = 6.276" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3190 3185 52 MMG DOME RK 16 10115104 3 6100 5496 45 MMG DOME RK 16 10/15/04 2 8541 7207 45 MMG DOME RK 16 10/15/04 1 10482 8528 14 MMG SO RK 16 10/15/04 9715' 9-518" X 7" BKR SLZXP LNR TOP PKR HGR, w! TIEBACK SEAL ASSY, iD = 6.160" WINDOW 9865' - 9885' WHIPSTOCK SET" ON IBP @ 9930' 10541' 1 3-1I2" HES X N1P, ID = 2.813" 10562' 3-1/2" X 4-1t2" XO, ID = 2.940" 10564' 7" X 4-112" BKR S-3 PKR, ID = 3.875" . 1056$' 4-1/2" X 3-1i2" XO; ID = 2.940" 10589` H 3-112" HES X NIP, iD = 2.813" 10610' (3-112" HES XN NIP, ID = 2.754"' 10622' 3-112" X 4-112" XO: ID = 2.992" 10$25' 4-112" WLEG, iD = 3.958" 10623` 7" X 5" BKR ZXP LNR TOP PKR, HGR w /TiEBA CK SLV , ID = 4.424" 10656' (--~ 5" X 4-112" XO, iD = 3.994" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/30/85 ORIGINAL COMPLETION WELL: U-12A 09119/04 DAViTL SIDETRACK (U-12A) PERMfT No: 2041470 10/20/04 SGSITLH GLV CIO API No: 50-029-21409-41 SEC 18; T11 N; R13E SP Exploration (Alaska) • • .. MICROFILMED 03/01 /2008 DO NOT PLACE ~~F~. _ s ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc E<: C ~~ BVF D...-.'" , .., ,,,,.,. ~..,jJ fL.,. 11 \.. t!,...."., Schlumbepger APR 2 U Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i~~ Oil & Gas Coos. COmm!~~' l\nçhQr~ SCANNED APR 2 5 2007 ¿)OL(--!'-I7- Well Job# Log Description Date BL 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-068 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnìcal Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: f)( 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( ( Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: ¡ ct ô~ ~~bCP DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 5¡t<i.J- ^ ~~y API No. 50-029-21409-01-00 Permit to Drill 2041470 Well Name/No. PRUDHOE BAY UNIT U-12A Operator BP EXPLORATION (ALASKA) INC MD 14600 ,/ TVD 8786 ~ Completion Date 9/19/2004 ~ Completion Status UIC N 1-01L Current Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DDIR I GR / RES Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Typy MedlFrmt Number Name Scale Media No Start Stop CH Received Comments I~D Asc Directional Survey 9799 14600 Open 10/7/2004 IIFR I Directional Survey 9799 14600 Open 10/7/2004 IIFR I ~D Asc Directional Survey 9799 14600 Open 10/7/2004 MWD ] I Directional Survey 9799 14600 Open 10/7/2004 MWD I I Lis 12823 Gamma Ray 9800 14523 Open 11/9/2004 GRlEWR4/ABIIROP/PWD/ I MWD 12823 LIS Verification 9800 14523 Open 11/9/2004 GRlEWR4/ABIIROP/PWD/ ¡ MWD I Lis 13729 Induction/Resistivity 9869 14600 Open 2/22/2006 ROP DGR EWR plus I I Graphics I ~ Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? vGj Chips Received? ~-- f)1N (J)N Daily History Received? Formation Tops Analysis Received? ~ Comments: . . Permit to Drill 2041470 MD 14600 TVD 8786 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well NamelNo. PRUDHOE BAY UNIT U-12A Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L UIC N Date: / / O¡t:-A~~ API No. 50-029-21409-01-00 . . . . WELL LOG TRANSMITTAL ¿¿ 04-- 14-1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 r~1d1 RE: MWD Formation Evaluation Logs U-12A, 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 U-12A: LAS Data & Digital Log Images: 50-029-21409-01 1 CD Rom KóåDQJ ~ ~r~0lD¿ . . ~oo/'-/~7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 01,2004 RE: MWD Fonnation Evaluation Logs: U-12A, AK-MW-3254802 1 LDWG fonnatted Disc with verification listing. PùPI#: 50-029-21409-01 ~ )7-1)) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun 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: /(¡¡<¡hl I '.' A STATE OF ALASKA .. ALASKA-"¡L AND GAS CONSERVATION COMM!SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG . ... ··P Revised: 11/03/04, Put on Production 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/19/2004 204-147 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/2/2004 50- 029-21409-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/13/2004 PBU U-12A 463' NSL, 2276' WEL, SEC. 18, T11 N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4766' NSL, 438' WEL, SEC. 13, T11N, R12E, UM 76.53' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2533' NSL, 1664' WEL, SEC. 12, T11 N, R12E, UM 14516 + 8805 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 631718 y- 5961039 Zone- ASP4 14600 + 8786 Ft ADL 028260 TPI: x- 628535 y- 5965287 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 627257 y- 5968313 Zone- ASP4 (Nipple) 2198' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes ONo NIA MSL 1900' (Approx.) 21. Logs Run: MWD DDIR I GR / RES 22. CASING, LINER AND CEMENTING RECORD CASING < ;:;ETTI;~ P!=J>THMD ;:;ETTINGOEPTHTVD i~~~ <> AMOUNt SIZE . WT·Pf;RFt¡. GRADE TOP 601"'tOM TOþi I. BOTTOM PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2674' Surface 2674' 17-1/2" 3719 cu ft Cold set III & II 9-5/8" 47# L-80 Surface 9869' Surface 8126' 12-1/4" ?056 cu ft Class 'G', 230 cu ft 'G' 7" 26# L-80 2829' 10815' 2828' 8741' 8-1/2" 191 cu ft Class 'G', 1034 cu ft 'G' 4-1/2" 12.6# L-80 10623' 14600' 8618' 8786' 6-1/8" 556 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. iJ 'SING ><. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4spf 3-1/2",9.2#, 13Cr80 10625' 10564' MD TVD MD TVD 11350' - 11540' 8924' - 8942' 25' «ACID,. Yt:.MI¡!!'II' .=m 11575' - 11675' 8946' - 8954' > i·i··.· 11970' -12125' 8981' - 8992' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12850' - 12900' 9021' - 9023' 13050' - 13150' 9025' - 9021' 2200' Freeze Protect with 155 Bbls of Diesel 13830' - 13990' 8945' - 8914' 14010' - 14025' 8910' - 8907' 14440' - 14505' 8822' - 8808' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 21,2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/31/2004 21 TEST PERIOD ... 820 549 1031 95.59° 670 Flow Tubing Casing Pressure CALCULATED ... Oll-BBl GAs-McF W A TER-BBL Oil GRAVITY-API (CORR) Press. 224 1420 24-HoUR RATE 937 628 1178 27.8 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 BFL NOV -~ 7nn4 ORIGINAL (,(r Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE .... 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10830' 8750' None Shublik A 10878' 8780' Shublik B 10957' 8828' Shublik C 10988' 8845' Sadlerochit 11048' 8873' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date } 1- 03 ·D PBU U-12A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 204-147 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 10-407 Revised 12/2003 Submit Original Only ALAS~ AND ~~~~g~S~J:i;ON COM.ION l' 7.0' .0" ~ WELL COMPLETION OR RECOMPLETION REPORT AND LoQ)CT 1" L, t ~Ja::k¡¡ 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well cì~s:;) u 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/19/2004 204-147 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/2/2004 50- 029-21409-01-00 4a. Location of Well (Governmental Section): 7. Date T.o. Reached 14. Well Name and Number: Surface: 9/13/2004 PBU U-12A 463' NSL, 2276' WEL, SEC. 18, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 4766' NSL, 438'WEL, SEC. 13, T11N, R12E, UM 76.53' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2533' NSL, 1664' WEL, SEC. 12, T11N, R12E, UM 14516 + 8805 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 631718 y- 5961039 Zone- ASP4 14600 + 8786 Ft ADL 028260 TPI: x- 628535 y- 5965287 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 627257 y- 5968313 Zone- ASP4 (Nipple) 2198' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: MWD DDIR I GR / RES 22. ?~,~~,L'NER AND CEMENTI~R~Og >~~~~G J$RÂDE SE;T'rtNGQ13f!TH MD . $ETTING[ EPTH TVD'.' ..,> AM2YNT WT.PERFT. TOFt> IBOTTOM Top BOTTOM I> » PUl..l..eD 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" B cu vds Concrete 13-3/8" 72# L-80 Surface 2674' Surface 2674' 17-1/2" 3719 cu ft Cold set III & )I 9-5/8" 47# L-80 Surface 9869' Surface 8126' 12-1/4" 12056 cu ft Class 'G', 230 cu ft 'G' 7" 26# L-80 2829' 10815' 2828' 8741' 8-1/2" 191 cu ft Class 'G', 1034 cu ft 'G' 4-1/2" 12.6# L-80 10623' 14600' 8618' 8786' 6-1/8" 556 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. T JSING- Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 4spf 3-1/2",9.2#,13Cr80 1 0625' 10564' MD TVD MD TVD 11350' -11540' 8924' - 8942' 25. ,.."Ahiììi¡;;:f",.,;, 11575' - 11675' 8946' - 8954' >.".> 11970' - 12125' 8981' - 8992' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12850' - 12900' 9021' - 9023' 13050' - 13150' 9025' - 9021' 2200' Freeze Protect with 155 Bbls of Diesel 13830' - 13990' 8945' - 8914' 14010' - 14025' 8910' - 8907' 14440' - 14505' 8822' - 8808' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet NIA Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL -BSL GAs-McF W A TER-BsL OIL GRAVITY-API (caRR) 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). sUb~;Cþ,iP~s.;.if none, state "none". i' vU^;¡i""i J~ HDH l OR\G\NAL None I Ø;X~ ¡ 'V~Rlc'¡:[I I \~.. i (,(: 1-- ~, A..... . :¡.----'-----~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ -~~ '28. GEOLOGIC MARKERS NAME MD Sag River 10830' Shublik A 10878' Shublik B 10957' Shublik C 10988' Sadlerochit 11048' 29. RMATlON TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8750' None 8780' 8828' 8845' 8873' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date /0-/ PBU U-12A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 204-147 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 10-407 Revised 12/2003 Submit Original Only 9,869.0 (ft) 10,817.0 (ft) 8,126.0 (ft) 8,741.0 (ft) 11.20 (ppg) 8.50 (ppg) 555 (psi) 920 (psi) 5,283 (psi) 4,780 (psi) Printed: 9/20/2004 11: 14:28 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 8/25/2004 00:00 - 03:30 3.50 WHSUR P DECOMP Burm cellar area, rig up high pressure lines to tree, taking returns through choke, take on 9.8 ppg brine in pits. Accept Rig @ 00:00 hrs. 8/25/2004 03:30 - 04:30 1.00 KILL P DECOMP R/U DSM lubricator and pull BPV, UD lubricator. 04:30 - 09:30 5.00 KILL P DECOMP Test lines to 1,000 psi, displace 35 bbls diesel from tubing, switch valves and pump down tubing displacing remaining 118 bbls diesel from annulus @ 5 bpm with 360 psi. Circulate one complete circulation 694 bbls at 5 bpm with 360 psi, shut down and monitor well, hole taking between 8-20 bph. 09:30 - 10:00 0.50 WHSUR P DECOMP Install TWC & test to 1,000 psi from below, blow down circulating lines. 10:00 - 11 :00 1.00 WHSUR P DECOMP Nipple down tree and adapter flange, inspect lifting threads on tubing hanger. 11 :00 - 15:00 4.00 BOPSU DECOMP Nipple up BOP, (fill hole through 4.5" X 9 5/8" annulus, hole taking 8 bph.) 15:00 - 15:45 0.75 BOPSU DECOMP Rig up BOP test equipment 15:45 - 21:15 5.50 BOPSU DECOMP Test BOP to 250 psi low, 3,500 psi high as per testing procedure. ( monitor well while testing hole taking 8-12 bph) Chuck Scheeve with AOGCC waived witness of BOP test. 21: 15 - 22:45 1.50 WHSUR P DECOMP Rig up DSM lubricator and pull TWC 22:45 - 23:00 0.25 PULL P DECOMP Make up XOs to landing joint, screw into tubing hanger (101/2 turns), back out lock down screws. Pull hanger to floor, up weight = 135k 23:00 - 00:00 1.00 PULL P DECOMP Circulate bottoms up, staging up pumps to 6 bpm, @ 110 psi. 20 bph loss at 6 bpm. Increased rate to 12 bpm @ 460 psi. losses stayed at 20 bph. Rig up casing tools and spooling unit while circulating. Total losses = 249 bbls. 8/26/2004 00:00 - 01 :00 1.00 PULL P DECOMP Continue rigging up casing equipment and spooling unit, held PJSM lay down completion, monitor well, hole taking 8 bph. 01 :00 - 14:30 13.50 PULL P DECOMP Lay down landing joint and tubing hanger. POH and lay down 260 joints 4.5" 12.6# L-80 BTC tubing. Recovered 25 control line clamps, 1 SS band, 1 SSSV, 4 gas lift mandrels and 19.62' cut off tubing. The tubing chemical cut was 100% cut. The tubing had 7 badly damaged collars, 15 joints with multiple holes and one joint with a 3' long split between the depths of 4420' and 9512'. Total fluid loss to well while pulling and laying down tubing was 120 bbl. All well head, tree equipment, tubing and down hole tools NORM inspected. 14:30 - 15:30 1.00 PULL P DECOMP Lay down casing equipment, clean floor, install wear ring. 15:30 - 17:30 2.00 FISH P DECOMP Held PJSM, with Baker rep. Pickup fishing assembly consisting of 8.125" overshot with 4.5" grapple, bumper sub, oil jar, XO, 9 - 6.125" DCs, XO, accelerator jar, XO. 17:30 - 00:00 6.50 FISH P DECOMP RIH picking up 4" DP to 6,730'. Losses for the last 12 hrs = 78 bbls. 8/27/2004 00:00 - 03:00 3.00 FISH P DECOMP Continue RIH picking up 4" DP. to 10,074' lossing pipe displacement while RIH. 03:00 - 03:30 0.50 FISH P DECOMP Make up topdrive & break circulation,wash down to top of fish @ 10,100' engage overshot, jar on fish 250k six times, jared once with 325k fish came free, picked up 20' washed back down, saw pressure increase. Up wt = 195k, On wt = 165k, Rt wt = 175k. Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 8/27/2004 03:30 - 04:00 0.50 FISH P DECOMP Pickup to 10,074' lay down single, make up circulating head. 04:00 - 05:00 1.00 FISH P DECOMP Circulate bottoms up 420 gpm @ 2,310 psi. loss rate while circulating 14 bph. Saw a significant amount of sand at bottoms up. 05:00 - 10:00 5.00 FISH P DECOMP Monitor well, POH with fish 10:00 - 11 :00 1.00 FISH P DECOMP Stand back BHA, release overshot grapple. 11 :00 - 12:00 1.00 FISH P DECOMP Rig up tubing handling equipment. 12:00 - 13:30 1.50 FISH P DECOMP Lay down fish, consisting of 4 joints 2 7/8" tubing, 1 chemical cut joint 17.25,' 1 joint 4.5" tubing, 1 GLM, 1 parted joint of 4.5" tubing 12.60'. Estimate top of the fish at 1 0,199'. 13:30 - 14:00 0.50 FISH P DECOMP Rig down tubing handling equipment. 14:00 - 15:30 1.50 FISH P DECOMP Change out swivel packing. 15:30 - 16:30 1.00 FISH P DECOMP Pickup Over shot assembly #2, change out grapple. 16:30 - 19:30 3.00 FISH P DECOMP RIH with fishing assembly, to 10,199', up wt = 200k, dn wt = 160, 19:30 - 21 :00 1.50 FISH P DECOMP Engage overshot, start jaring with 250k indicator reading, increased to 400k in 25k incements, 400k is max hook load for the derrick, no indication of movement. 21 :00 - 21 :30 0.50 FISH P DECOMP Attempt to rotate fish, drill sting torqued up to 15k and dropped off to 7k, several times, unable to break free, slacked off to 160k attempt to release overshot grapple. Pulled 20' above fish, 5-10k over pull. 21 :30 - 22:45 1.25 FISH P DECOMP Circulate bottoms up at 500 gpm, 2,200 psi. had a significant amount of sand, gas and tar back at bottoms up. 22:45 - 00:00 1.25 FISH P DECOMP Monitor well & POH with fishing assembly. 8/28/2004 00:00 - 02:30 2.50 FISH P DECOMP Continue POH with fishing assembly. Lay down jars, stand back DC's. 02:30 - 04:30 2.00 FISH P DECOMP Unabble to release grapple, back out overshot extension, Rig up tubing handling equipment, lay down fish, 1 parted joint 22.80',2 joints 4.5" tubing, 1 sliding sleeve, 1 seal assembly and K anchor. 04:30 - 05:00 0.50 FISH P DECOMP Rig down tubing handling equipment and clean floor. 05:00 - 10:00 5.00 FISH P DECOMP Pickup Baker PRT miling assembly and RIH to 10,176' 10:00 - 11 :00 1.00 FISH P DECOMP Makeup topdrive blower hose, RIH picking up singles from 10,176' to 10,336'. 11 :00 - 12:00 1.00 FISH P DECOMP Wash from 10,336' took weight at 10,341', circulate bottoms up, 485 gpm @ 2,570 psi, up wt =205k, dn wt = 165k rt wt = 175k. Tar balls and a small amount of sand back at bottoms up. 12:00 - 14:00 2.00 FISH P DECOMP Mill Packer @ 10,353',250 gpm @ 750 psi, 70 - 120 rpm, torque 7k - 15k, wob 10k - 40k. 14:00 - 15:00 1.00 FISH N RREP DECOMP Tighten wash pipe packing. 15:00 - 00:00 9.00 FISH P DECOMP Mill Packer @ 10,353',250 gpm @ 750 psi, 70 - 120 rpm, torque 7k - 15k, wob 10k - 40k. 8/29/2004 00:00 - 07:30 7.50 FISH P DECOMP Mill Packer @ 10,353',250 gpm @ 750 psi, 70 - 120 rpm, torque 7k - 15k, wob 10k - 40k. Moved packer down hole 2' by jaring down, no progress since packer moved down hole. hole taking between 4-6 bph while milling. 07:30 - 11 :00 3.50 FISH P DECOMP Monitor well, pump dry job and POH with PRT milling assembly. 11 :00 - 13:00 2.00 FISH P DECOMP Change mill, cutting structure on mill was 90% gone, empty junk baskets, recovered 5 gal bucket off metal. Make up junk baskets. Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 8/29/2004 13:00 - 13:45 0.75 FISH P DECOMP Service and change oil in topdrive. 13:45 - 17:30 3.75 FISH P DECOMP RIH with PRT Milling assembly, pickup 21 jts of 4" HWDP for additional weight. Tag fish @ 10,349', up wt = 215k, dn wt = 163k, st wt = 185k. Lossing 4-6 bph while milling. 17:30 - 18:30 1.00 FISH P DECOMP Mill packer, 45-50k wOb, 100 rpm, 245 gpm @ 800 psi, packer dropped down hole 5' continued milling, dropped another 3', picked up on srting 300k intially, weight dropped of to 225k set back one stand. 18:30 - 19:45 1.25 FISH P DECOMP Circulate bottoms up, 535 gpm @ 3,400 psi, monitor well, pump dry job. 19:45 - 00:00 4.25 FISH P DECOMP POH with PRT milling assembly, no fish. Losses for last 12 hrs = 80 bbls. 8/30/2004 00:00 - 01 :00 1.00 FISH P DECOMP Lay down mill and junk baskets, Make up spear with 4.81" grapple, pickup accelerator jars. 01 :00 - 04:30 3.50 FISH P DECOMP RIH with spear, to 10,320' 04:30 - 06:00 1.50 FISH P DECOMP Make up topdrive break circulation, 60 spm @ 310 psi, wash down and engage fish at 10,350', pressure increased to 1,650 psi, Picked up drill string, 60' no indication of fish, when string weight was picked up pressure dropped back to 310 psi. up wt = 215K 06:00 - 11 :00 5.00 FISH P DECOMP POH with spear, monitor well at BHA. Losses for last 12 hrs = 35 bbls. 11 :00 - 14:00 3.00 FISH P DECOMP Stand back BHA, no fish, Lay down spear, make up new spear with 10' extension, 3.947" grapple, RIH to 960'. 14:00 - 15:00 1.00 FISH P DECOMP Slip and cut drilling line. 15:00 - 17:15 2.25 FISH P DECOMP RIH with spear tag fish @ 10,347', up wt = 217k, dn wt = 160k 17:15 - 21 :00 3.75 FISH P DECOMP Break circulation, engage fish, jar on fish with 275k to 400k, no indication of movment. release grapple, rack back one stand. 21 :00 - 21 :30 0.50 FISH P DECOMP Inspect derrick and topdrive after jarring operations. 21 :30 - 00:00 2.50 FISH P DECOMP Monitor well, pump dry job, POH to 4,431' Losses for last 12 hrs = 21 bbls. 8/31/2004 00:00 - 01 :00 1.00 DHB P DECOMP Make up and set 9 5/8" HES RTTS 20' below wellhead. POH with setting tool and test to 1,000 psi. 01 :00 - 06:00 5.00 WHSUR P DECOMP Nipple down riser, BOP and tubing spool, change out 9 5/8" slip seals packing. 06:00 - 08:30 2.50 WHSUR P DECOMP Install new 13 518" tubing spool with pre installed 9 5/8" secondary packing. 08:30 - 10:45 2.25 WHSUR P DECOMP Nipple up BOP on new 13 5/8" 5M tubing spool. 10:45 - 11 :30 0.75 DHB P DECOMP Retrieve 9 5/8" Storm valve and RTTS packer. Check and change out RTTS, slips sticking. 11 :30 - 13:00 1.50 DHB P DECOMP RIH with 9 5/8" RTTS. Set at3,115'. 13:00 - 14:00 1.00 DHB P DECOMP Test 9 5/8" casing from surface to 3,115', 13 5/8" 5M flange on tubing spool and lower pipe rams to 3500 psi for 30 minutes. 14:00 - 17:45 3.75 DHB P DECOMP POH. Lay down 9 5/8" RTTS. 17:45 - 18:30 0.75 DHB P DECOMP PJSM, RIU SWS E-Line. 18:30 - 21:15 2.75 DHB P DECOMP Make 8.51" gauge ring I junk basket run to 10,000'. POH- Nothing in junk basket 21 :15 - 00:00 2.75 DHB P DECOMP P/U firing head & 95/8" EZSV. RIH, correlate & set EZSV @ 9,930' ( 5' above casing collar @ 9,935'). POH . 9/1/2004 00:00 - 01 :00 1.00 DHB P DECOMP POH wI E-Line, Firing head looked good. 01 :00 - 02:30 1.50 STWHIP P WEXIT P/U Milling Assy. & MWD. Orient & discovered that Sperry had tool communication problems. 02:30 - 04:00 1.50 STWHIP N SFAL WEXIT Trouble shoot problem & establish communication w/ MWD, Printed: 9/20/2004 11:14:35 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: 8/24/2004 9/19/2004 Spud Date: 8/5/1985 End: 9/19/2004 9/1/2004 02:30 - 04:00 1.50 STWHIP N SFAL WEXIT then unable to read tool pulse. Determined that problem was in surface equipment (transducer) & repaired same. 04:00 - 05:45 1.75 STWHIP P WEXIT M/U Whipstock and RIH w/ same. 05:45 - 11 :30 5.75 STWHIP P WEXIT RIH with Whipstock to 8785'. Fill pipe while RIH. 11 :30 - 13:00 1.50 STWHIP P WEXIT Service top drive. Connect blower hose. 13:00 - 13:30 0.50 STWHIP P WEXIT RIH with Whipstock to 9646'. Fill pipe while RIH. Discovered small leak in flowline. 13:30 - 15:30 2.00 STWHIP N RREP WEXIT Replace flexible hose connection in flowline between sub base and pit module. 15:30 - 15:45 0.25 STWHIP P WEXIT RIH to 9870'. 15:45 - 16:00 0.25 STWHIP P WEXIT Break circulation. 420 GPM @ 1830 psi. Orient to High Side. RIH and tag EZSV at 9894' Drillers Depth. Set bottom trip anchor wI 25 K and shear mills off Whipstock w/ 45K. 16:00 - 17:30 1.50 STWHIP P WEXIT Displace with 11.2 ppg. LSND Mud @ 485 GPM - Final pressure 2750 psi. 17:30 - 18:15 0.75 STWHIP P WEXIT Monitor Well. Losing 9.4 BPH static and 10 BPH circulating @ 400 GPM. 18:15 - 23:45 5.50 STWHIP P WEXIT Mill window from 9,869' to 9,885'. Continue milling open hole to 9,899' 475 GPM @ 2710 psi. 110 RPM . WOB = 2 to 12 K milling window & 10 to 15 K in formation. Torque = 6 to 15K. 23:45 - 00:00 0.25 STWHIP P WEXIT Pump 50 Bbl. Hi-Vis Sweep. Work through window. Pump @ 500 GPM 12870 psi. Rotating @ 115 RPM w 7K TQ. 9/2/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Circulate out Hi-Vis Sweep. Mud clean and balanced @ 11.2 ppg. 01 :00 - 02:00 1.00 STWHIP P WEXIT R/U and perform FIT. Pressured up to 555 psi. @ 10 SPM. - Total 55 strokes - straight line build up. Shut in - Bled off immediately to 75 psi. then down to 25 psi in 3 minutes. Held 25 psi for 10 minutes. 555 psi with 11.2 ppg mud at 8,126' TVD = FIT of 12.51 ppg. EMW. 02:00 - 05:00 3.00 STWHIP P WEXIT Pump slug & POH to BHA. 05:00 - 07:00 2.00 STWHIP P WEXIT Stand back 4" HWDP & 61/2" DC's. Lay down milling assembly. All mills in gauge. 07:00 - 09:00 2.00 STWHIP P WEXIT Clear rig floor. Pull wear bushing. Wash BOP with jetting tool. Install wear bushing. 09:00 - 11 :30 2.50 DRILL P WEXIT Pick up new 8 1/2" PDC bit and drilling BHA with 1.5 deg bend motor housing. Surface test MWD. 11 :30 - 14:45 3.25 DRILL P WEXIT RIH to 9,730'. 14:45 - 16:15 1.50 DRILL P WEXIT Service Top Drive - Change Oil & Filter. 16:15 - 16:45 0.50 DRILL P WEXIT RIH to 9,825'. Orient to High Side. Run past window with no problems. Tag up @ 9,888'. 16:45 - 19:00 2.25 DRILL P INT1 Drill underguage Hole to 9,899'. Directional Drill 8.5" Hole from 9,899' to 9,958'. 500 GPM @ 3600 psi. on bottom, 3250 psi off bottom. Torque off bottom = 6.5K, on bottom = 8.5K. Rotating @ 60 RPM. Calculated ECD = 11.6 ppg. Actual ECD = 11.8 ppg. PU WI. = 190K, On. WI. = 148K. Rot WI. = 168K 19:00 - 20:30 1.50 DRILL N RREP INT1 Trouble shoot & Repair load share problem with generators. 20:30 - 23:30 3.00 DRILL P INT1 Directional Drill 8.5" Hole from 9,958' to 10,056'. 500 GPM @ 3600 psi. on bottom, 3250 psi off bottom. Torque off bottom = 6.5K, on bottom = 8.5K. Rotating @ 60 to 80 RPM. Calculated ECD = 11.6 ppg. Actual ECD = 11.8 ppg. PU WI. = 200K, On. WI. = 150K. Rot WI. = 170K Bit balling - Pump Sapp + Nut plug sweep - bit cleaned up. Printed: 9/20/2004 11:14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/2/2004 23:30 - 00:00 0.50 DRILL N RREP INT1 Flow line leaking - replaced damaged air boot. 9/3/2004 00:00 - 13:00 13.00 DRILL P INT1 Directional Drill 8.5" Hole from 10,056' to 10,810' 500 GPM @ 4050 psi. on bottom, 3800 psi off bottom. Torque off bottom = 7K, on bottom = 9K. Rotating @ 80 RPM. Calculated ECD = 11.6 ppg. Actual ECD = 11.86 ppg. PU Wt. = 190K, On. Wt. = 155K. Rot Wt. = 168K. No noticable fluid losses to formation. 13:00 - 14:00 1.00 DRILL P INT1 Pump 40 BBL Hi-Vis sweep. Circulate out samples for Geologist. Pumping @ 510 GPM & 3975 psi. 14:00-15:15 1.25 DRILL P INT1 Directional Drill from 10,810' to 10,817'. Circulate up sample- TO per Geologist. Same Drilling parameters. 15:15 -16:15 1.00 DRILL P INT1 POH to 9,825'. Dry wiped a couple spots - no problems. 16:15-17:00 0.75 DRILL P INT1 Change out air boots on Stack Riser. 17:00 - 17:30 0.50 DRILL P INT1 RIH to 10,781'. 17:30 - 19:15 1.75 DRILL P INT1 Wash down from 10,781' to 10,817'. Pump 40 Bbl Hi-Vis sweep. Circulate @ 510 GPM & 3875 psi. Rotating @ 115 RPM. ECD down to 11.56 ppg. Pump dry job & drop 2.30" rabbit w/ tail. 19:15 - 23:00 3.75 DRILL P INT1 POH standing back all DP & HWDP. 23:00 - 00:00 1.00 DRILL P INT1 UD BHA. 9/4/2004 00:00 - 01 :00 1.00 DRILL P INT1 UDBHA. 01 :00 - 02:00 1.00 CASE P INT1 Rig up to run 7" Drilling Liner. 02:00 - 02:15 0.25 CASE P INT1 PJSM with Crew, Casing hand & Baker Rep. 02:15 - 09:30 7.25 CASE P INT1 Run 26 Jts 7", 26#, L-80, BTC-M Liner as per program. M/U Baker HMC Hgr & ZXP Packer and RIH on 4" DP to 9,850'. 09:30 - 11:15 1.75 CASE P INT1 Circulate & Condition Mud @ 8 BPM 11472 psi. M/U Cementing Head to single & lay in Skate.Hold PJSM with Crew and Schlumberger Cement crew while circulating. 11 :15 - 12:30 1.25 CASE P INT1 Run in open hole with liner M/U single & Cement head & tag bottom @ 10,817. 12:30 - 13:30 1.00 CASE P INT1 Break circulation & stage up pumps to 6 BPM @ 1370 psi. 13:30 - 14:30 1.00 CEMT P INT1 Switch to Schlumberger & Cement as follows: Pump water to fill Lines & test same to 4500 psi. Pump 25 Bbls, 12.2 ppg MudPush @ 4 BPM, followed by 34 Bbls, (165 sX), 15.8 ppg, "G" Slurry wI yield of 1.16 cu ft I sk @ 4 BPM. Flush cement lines to floor with water and switch to rig pumps. Drop DP Dart and displace with 134 Bbls 11.3 ppg. Mud. Final pumping pressure - 1386 psi. Bump Plug & pressure up to 4100 psi. 14:30 - 15:00 0.50 CASE P INT1 Slack off 85 K to confirm HMC Hanger set. Bleed off pressure & check floats - OK. Rotate & release setting tool. Pressure up to 1000 psi. P/U until pressure bleeds then pump 30 bbls mud @ 5 BPM 11300 psi. Set 45 K down to set ZXP Packer. Check with wieght & rotation. 15:00 - 16:00 1.00 CASE P INT1 Circulate bottoms up at 9 BPM with 2100 psi. while reciprocating pipe. 16:00 - 16:30 0.50 CASE P INT1 Break out & Lay down cement head. 16:30 - 20:15 3.75 CASE P INT1 Attempt to POH - 20 to 25 K drag. Screw in wI Top Drive and break circulation. Pump Hi-Vis weighted sweep @ 14 BPM I 3300 psi, rotating @ 15 RPM and reciprocating. Fine solids unloaded across shakers with sweep then cleaned up. 20:15 - 00:00 3.75 CASE P INT1 POH with no problems - Lay down C-2 running tool. 9/5/2004 00:00 - 01 :00 1.00 CASE P INT1 Rig up to run 7" Tie Back Liner. 01 :00 - 12:00 11.00 CASE P INT1 Run 166 Jts, 7",26#, L-80, BTC-M Tie Back Liner as per program with 83 centralizers. Make up FlexLock Hanger, Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/5/2004 01 :00 - 12:00 11.00 CASE P INT1 SLZXP Liner Top Packer and running tool. RIH with 3 stands of 61/4" DC's, 7 stands of HWDP. 12:00 - 13:15 1.25 CASE P INT1 Circulate liner volume at 8 BPM 11200 psi. Pick up and make up Cement head on DP single and lay down on skate. 13:15 - 14:45 1.50 CASE P INT1 RIH 7" liner on 4" DP to 9,695'. Make up Cement head with single. 14:45 - 16:00 1.25 CASE P INT1 Rig up Circulating line to Cementing Head. Run seal assyembly into PBR at 9715'. Pick up to postion circulating ports above PBR. Circulate and condition mud a 7 BPM 11400 psi. Hold PJSM with all personnel while circulating. 16:00 - 17:30 1.50 CEMT P INT1 Switch to Schlumberger and cement as follows: Pump 5 Bbls water and pressure test lines to 4200 psi. Pump 30 bbl 12 ppg MudPush at 5 BPM. Pump 157 bbl (368 sX), 12.5 ppg, class "G" Lead slurry, followed by 28 bbl ( 136 sX), 15.8 ppg, Class "G" Tail slurry. Drop dart, flush cement lines with 5 bbl water then switch over to rig pumps. Displace with 290 Bbls 11.1 ppg. Mud. Bump plug with 1560 psi. 17:30 - 18:30 1.00 CASE P INT1 Lower seal assembly into PBR to No-Go. Set FlexLock Hanger and SLZXP Packer - good indication of set. Circulate bottoms up at 8 BPM 11150 psi. Approximately 6 bbl Cement to surface. 18:30 - 21 :00 2.50 CASE P INT1 POH. Lay down DC's and Liner running tool. 21 :00 - 22:00 1.00 CASE P INT1 Change out Saver Sub / TIW valve on top drive. Change out Top Drive gripper dies and servive gripper. 22:00 - 23:00 1.00 CASE P INT1 Pull wear bushing and set test plug. Fill stack and rig up to test BOPE. 23:00 - 00:00 1.00 CASE P INT1 Test BOPE as per Permit to Drill - 250 psi Low and 3500 psi High. 9/6/2004 00:00 - 02:30 2.50 CASE P INT1 Complete testing BOPE to 250 psi Low & 3500 psi High. All tests good. Witness of test waived by John Spaulding, AOGCC. 02:30 - 03:00 0.50 CASE P INT1 Pull test plug & run wear bushing. Blow down all lines. 03:00 - 04:00 1.00 CASE P INT1 Slip & Cut Drilling line 154 ft. Service Top Drive. 04:00 - 06:15 2.25 DRILL P PROD1 P/U, M/U, & RIH with 6 1/8" Directional Drilling BHA. 06:15 - 11 :00 4.75 DRILL P PROD1 P/U 4" DP from Shed & RIH. 11 :00 - 12:15 1.25 DRILL P PROD1 RIH from derrick to 9417' 12:15 - 13:00 0.75 CASE P PROD1 Test lower rams & Liner lap to 250 psi Low & 3500 psi high. 13:00 - 13:30 0.50 DRILL P PROD1 RIH to 9608'. Hook up Blower Hose. 13:30 - 15:30 2.00 DRILL P PROD1 Circulate down & Tag Landing Collar @ 9,644'. Drill out Landing Collar & Float. 15:30 - 17:00 1.50 DRILL P PROD1 Continue RIH, washing through cement stringers from 9715' to 9890' & from 10540' to 10565'. 17:00 - 18:00 1.00 CASE P PROD1 RIU & test liner to 3500 psi & chart for 30 minutes. 18:00 - 19:30 1.50 DRILL P PROD1 Wash down to landing collar @ 10730'. Drill landing collar & shoe track to top of float shoe @ 10,812'. 19:30 - 21 :30 2.00 DRILL P PROD1 Displace well bore with 8.5 ppg. FloPro mud. 21 :30 - 22:30 1.00 DRILL P PROD1 Drill out float shoe and 20 ft. of new hole to 10,837'. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate bottoms up in preparation for FIT. Also sweep with EMI - 920 Lube ( MI version of EP MudLube). Cut Torque from 9000 to 6000 ft Ibs. Noticed loss in returns at tail end of circulation. 9/7/2004 00:00 - 01 :30 1.50 DRILL N DPRB PROD1 Monitor well on trip Tank. Losing 24 Bbls I Hr. Call & discuss wI ODE. Mix LCM pill. Printed: 9/20/2004 11: 14:35 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/7/2004 01 :30 - 02:00 0.50 DRILL N DPRB PROD1 Drill 15' to 10,852' while pumping 15 ppb LCM pill. 71/2 ppb SafeCarb 250 + 7112 ppb SafeCarb 40. Loss rate circulating @ 260 GPM was initially 120 BPH - dropped to 54 BPH with LCM. Continue adding 100 Lb Safe Carb mix every 5 minutes. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 Pick up into shoe and circulate remeaining LCM out of DP @ 150 GPM with 100 to 200 BPH loses. 02:30 - 03:15 0.75 DRILL N DPRB PROD1 Circulate over top while mixing LCM Pill. Static loses = 60 BPH. 03:15 - 04:00 0.75 DRILL N DPRB PROD1 Pump 43 Bbl. - 20 ppbl LCM Pill. 10 ppb Mix II Med. + 10 ppb Mix II Coarse. Spot out of pipe. 04:00 - 04:45 0.75 DRILL N DPRB PROD1 POH 10 stands tp 9991'. 04:45 - 06:30 1.75 DRILL N DPRB PROD1 Monitor Well. losses down to 2 BBL I Hr. 06:30 - 08:00 1.50 DRILL P PROD1 Rig up & perform FIT. Pressure up to 920 psi with 8.5 ppg mud. - straight line rise, strokes to pressure corresponding to casing test. Shut in. Pressure bled to "0" psi. in 3 minutes. Injected into fault 11.5 bbls @ 435 psi. shut in & bled to "0" in 1 minute. 08:00 - 10:00 2.00 DRILL N DPRB PROD1 Mix 50 bbl, 30 ppb LCM pill (7 1/2 ppb ea. Safecarb 250 & 40 + 15 ppb mix II med, coarse + MI Seal fine) while TIH to 10,815'. Spot LCM pill @ Bit. Loss rate while pumping = 54 BBH. 10:00 - 00:00 14.00 DRILL P PROD1 Directional Drill 6 1/8" Hole from 10,852' to 11,220'. 282 GPM @ 2425 psi, WOB = 20 to 35K, Rotate @ 40 to 60 RPM, Torque off bottom = 4.5 to 5K, on bottom = 5 to 6.5K, P/U Wt. = 190K, DN Wt. = 155K, ROT Wt. = 175K. Adding LCM while drilling. Losses to 0 while sliding from 13:00 hrs to midnight. 24 Hr losses = 417 Bbls. 9/8/2004 00:00 - 13:00 13.00 DRILL P PROD1 Directional Drill 6 1/8" Hole from 11,220' to 11,871', 282 GPM @ 2570 psi, WOB = 20 to 30K, Rotate @ 80 RPM, Torque off bottom = 4.5 to 5K, on bottom = 6K, P/U Wt. = 190K, ON Wt. = 153K, ROT Wt. = 175K. Adding LCM while drilling. Losses averaging 50 BPH. Swept hole wI Hi-Vis & LCM every 300 ft. ART = 6.34 Hrs. AST = 2.03 Hrs. ROP down - unable to slide. 13:00 - 14:15 1.25 DRILL P PROD1 Circulate bottoms up @ 282 GPM 12260 psi. Rotate @ 80 RPM w/4 to 5K Torque while recprocating. 14:15 - 15:00 0.75 DRILL P PROD1 POH to 10,756' with no problems. 15:00 - 15:45 0.75 DRILL P PROD1 Spot 60 Bbl., 12 PPB, LCM pill around bit. 15:45 - 19:45 4.00 DRILL P PROD1 POH, Stand back HWDP, UD Jars - badly belled (mushroomed) service break on Jars. 19:45 - 20:00 0.25 DRILL P PROD1 Stand back flex DC's & B/O Bit. Bit missing one cone, other two badly worn & show junk damage as does post for missing cone. 20:00 - 20:30 0.50 DRILL P PROD1 Down load MWD and pull pulsar. 20:30 - 21 :15 0.75 DRILL P PROD1 UD MWD & Motor. Box connection of sub on top of Motor slightly belled. 21:15 - 00:00 2.75 DRILL P PROD1 Remove Top Drive Washpipe packing and replace upper Quill shaft seals under direction of Canrig representative. Canrig Rep also checked bearing wear & rig mechanic changed oil & filter. 9/9/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Complete re-installing wash pipe & changing out oil in Top Drive. Test wash pipe to 3000 psi. 01 :30 - 03:30 2.00 DRILL P PROD1 P/U and M/U BHA #4, Running XR10 insert bit, New Motor & Printed: 9/20/2004 11: 14:35 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/912004 01 :30 - 03:30 2.00 DRILL P PROD1 New set of jars. Up-loaded MWD in Shed prior to P/U. 03:30 - 04:15 0.75 DRILL P PROD1 Shallow test MWD - Ok. Check Top Drive torque against rig tongs & EZ - Torque = Same reading. Check Top Drive torque against Iron roughneck. 04:15 - 08:30 4.25 DRILL P PROD1 RIH, filling pipe every 35 stands to 10,757'. Break circulation & circulate 240 GPM 11534 psi. Losses still 50 Bbll Hr. while circulating 08:30 - 09:45 1.25 DRILL P PROD1 RIH to 11,809. Had to wash down from 11,015' to 11,139'. Trip losses = 190 Bbls. 09:45 - 13:15 3.50 DRILL N DPRB PROD1 RIH to app. 11,800 Orient High side and wash down to lost cone at 11,871 Stall motor at 11 ,871. Stop pumps and PIU with 20K drag. Shake off cone at 11,851. Tag and chase cone to bottom while stacking wt. several times. Leave cone on bottom and orient low side of hole. Wash to within 1 ft. of lost cone. Bring pump rate up to 280 and wash hole below cone for app. 1 hour while working down hole app. 1 ft. Pull off bottom and orient HS. Wash to within 1 ft. of cone and circulate app. 30 minutes at HS. Slow pumps to 200 GPM. Tag cone and stall motor. Drop pumps and P/U off bottom. Orient HS and wash down to lost cone. Control drill by cone observing a partial stall as bit passed over junk and push to low side of hole. Rotate and slide from 11,871 to 11,889 while stalling motor and hanging up. Backream and put cone back into wash. Rotate string back and forth over lost cone with drill string, attempting to drive into low side wash. 13:15 - 00:00 10.75 DRILL P PROD1 Directional Drill 6 118" Hole from 11,898' to 12,512', 282 GPM @ 2320 psi, WOB = 15 to 20K, Rotate @ 60 RPM, Torque off bottom = 4.5 to 5K, on bottom =5 to 6K, P/U Wt. = 195K, ON Wt. = 150K, ROT Wt. = 175K. Adding LCM while drilling. Losses averaging 50 BPH. Swept hole wI Hi-Vis & LCM every 300 ft. ART = 3.77 Hrs. AST = 2.21 Hrs. Drilled through fault @ 12,200' - No change in losses - still 50 Bbls/Hr. 9/10/2004 00:00 - 00:30 0.50 DRILL P PROD1 Rotate from 12,512' to 12,530'. Seeing Chert in cuttings. ROP down to 28' I Hr. Motor stalling and torque spiked to 8500 ftllbs. Total drilling time = 6.59 Hrs. 00:30 - 02: 15 1.75 DRILL P PROD1 Circulate Hi-Vis Sweep @ 282 GPM, 2220 psi. Rotating @ 80 RPM. 02:15 - 03:30 1.25 DRILL P PROD1 POH wet to shoe @ 10,815'. No excess drag - Hole slick. 03:30 - 04:30 1.00 DRILL P PROD1 Monitor well - taking 20 BbllHr static. Spot 50 BBI. LCM pil ( 15 PPB Mix II Med & Coarse). Pump dry job. 04:30 - 08:30 4.00 DRILL P PROD1 POH to 2,053'. 08:30 - 11 :00 2.50 DRILL P PROD1 Stand back BHA, Break off bit - missing two cones, Down load MWD. 11 :00 - 13:00 2.00 DRILL P PROD1 Service Rig & Top Drive. 13:00 - 14:00 1.00 DRILL N DPRB PROD1 Up load MWD, MI Bit & orient, M/U DC's, circ sub & one stand DP. Shallow test MWD. 14:00 - 18:30 4.50 DRILL N DPRB PROD1 RIH to 10,057' 18:30 - 20:00 1.50 DRILL P PROD1 Slip & cut 114 ft of Drilling line. Change oil in Top Drive & Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/10/2004 18:30 - 20:00 1.50 DRILL P PROD1 service grabber. 20:00 - 21 :30 1.50 DRILL N DPRB PROD1 RIH to 11,109' - took weight. Wash down to 11,162'. High side Motor & RIH to 12,530'. 21 :30 - 23:00 1.50 DRILL N DPRB PROD1 Work past junk @ 12,530' sliding to 12,532'. Motor stalled. P/U and drag junk to 12,528'. RIH to 12,532' and attempt to rotate- torqued up to 8500 ftllbs. Slide from 12532' to 12,534'. Initiate rotation & kicked junk into wall with NB Stabilizer. Able to rotate ahead @ 40 RPM wI 5000 ft Ilbs. of torque. 23:00 - 00:00 1.00 DRILL P PROD1 Increase rotary to 60 RPM & Drill ahead from 12,534' to 12,560'. wI 282 GPM & 2220 psi. WOB = 20 K, Torque off bottom = 5000 ft Ilbs. Torque on bottom + 5500 ft Ilbs. Started out wI ROP of 65 ftlhr. Came down to 10 ftIhr with no change in Torque. 9/11/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drill from 12,560' to 12,565'. Same parameters. ROP @ 10ft I Hr. Torque on bottom steady @ 5500 ft Ilbs. 2 % chert in cuttings and a coarser sand. 00:30 - 02:15 1.75 DRILL P PROD1 Circulate Hi-Vis sweep whle reciprocating pipe & Rotating @ 80 RPM. No changes in torque. 02: 15 - 04:00 1.75 DRILL P PROD1 POH wet to shoe - no problems. Did not see any junk. 04:00 - 04:30 0.50 DRILL P PROD1 Spot 50 Bbl, 15 PPB LCM pill around bit. Pump dry job. 04:30 - 07:45 3.25 DRILL P PROD1 Continue POH to BHA. 07:45 -11:15 3.50 DRILL P PROD1 Stand back all BHA. Break out bit & M/U new PDC Bit. Down load & Up Load MWD. RIH wI BHA # 6. Shallow test MWD - OK. 11 :15 - 15:30 4.25 DRILL P PROD1 RIH to 10,760'. 15:30 - 16:30 1.00 DRILL P PROD1 Service Top Drive, Brakes & Crown. 16:30 - 17:30 1.00 DRILL P PROD1 High Side Motor and RIH to 12,565'. - No Problems. 17:30 - 00:00 6.50 DRILL P PROD1 Directional Drill 6 1/8" Hole from 12,565' to 12,775', 282 GPM @ 2270 psi, WOB = 15 to 20K, Rotate @ 60 RPM, Torque off bottom = 4.5 to 5K, on bottom =5.5 to 6K, P/U Wt. = 195K, ON Wt. = 150K, ROT Wt. = 175K. Adding LCM while drilling. Losses averaging 30 BPH. Swept hole wI Hi-Vis & LCM every 300 ft. ART = 0.55 Hrs. AST = 2.66 Hrs. Adding beads to assist in sliding. 9/12/2004 00:00 - 00:00 24.00 DRILL P PROD1 Directional Drill 6 1/8" Hole from 12,775' to 14,220', 282 GPM @ 2620 psi, WOB = 8 to 20K, Rotate @ 60 RPM, Torque off bottom = 5K, on bottom =6.5 to 7K, P/U Wt. = 200K, ON Wt. = 145K, ROT Wt. = 168K. Adding LCM while drilling to control losses averaging 35 BPH. Sweeping hole wI Hi-Vis & LCM every 300 ft. Adding beads to assist in sliding. Crossed predicted fault @ 13,625' with appox. 190' throw - experienced no additional losses. AST = 7.77 Hrs, ART = 5.01 Hrs. 9/13/2004 00:00 - 04:00 4.00 DRILL P PROD1 Directional Drill 6 1/8" Hole from 14,220' to 14,600', 280 GPM @ 2700 psi, WOB = 8 to 22K, Rotate @ 60 RPM, Torque off bottom = 5.5K, on bottom = 7.5K, P/U Wt. = 185K, ON Wt. = 130K, ROT Wt. = 165K. Adding LCM while drilling to control losses averaging 35 BPH. Sweeping hole wI Hi-Vis & LCM every 300 ft. Drilled 100' past target polygon at Geologists request in an attempt to intersect Shublik. AST = 0.74 Hrs, ART = 2.64 Hrs. 04:00 - 04:30 0.50 DRILL P PROD1 Circulate Hi-Vis sweep. Pumping @ 285 GPM 12350 psi. Rotating @ 90 RPM & reciprocating 80 ft. Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/13/2004 04:30 - 11 :30 7.00 DRILL P PROD1 Pump out of hole from 14,600' to 13,940'. Tight and trying to pack off. Backream from 13,940' to 12,669'. Pump out from 12,669' to 10,757'. 11 :30 - 12:00 0.50 DRILL P PROD1 Service top Drive & Crown. 12:00 - 14:00 2.00 DRILL P PROD1 RIH - Taking weight @ 10,900' - work through, continue RIH to 14,580. Wash to 14,600'. 14:00 - 19:00 5.00 DRILL P PROD1 Circulate Hi-Vis Sweep. Heavy returns with sweep over shakers. Pump 2nd, Hi-Vis, weighted sweep. No increase in returns. Spot 200 Bbl. Lube pill in DP. 19:00 - 22:30 3.50 DRILL P PROD1 Pump out of hole to 10,757', spotting lube pill in open hole. Pulled 20K over @ 10,887' worked through once - OK. 22:30 - 00:00 1.50 DRILL P PROD1 Drop rod/ball and open Circ. Sub. Circulate bottoms up @ 350 GPM 11200 psi. - then spot 50 Bbl. LCM pill around bit. 9/14/2004 00:00 - 00:30 0.50 DRILL P PROD1 POH through LCM pil to 9,609'. 00:30 - 01 :00 0.50 DRILL P PROD1 Monitor well, Pump Dry job, Blow down Top Drive. 01 :00 - 03:15 2.25 DRILL P PROD1 POH to 3,297'. 03:15 - 03:45 0.50 DRILL P PROD1 UD HWDP to position Circ. Sub @ 2,823'. 03:45 - 04:30 0.75 DRILL P PROD1 Circulate Top of 7" Liner clean through Circ Sub wI 525 GPM @ 640 psi. Large quantity of fine sand over shakers. 04:30 - 05:30 1.00 DRILL P PROD1 UD HWDP & Jars. 05:30 - 06:00 0.50 DRILL P PROD1 POH & Stand back 4" DP. 06:00 - 07:30 1.50 DRILL P PROD1 Flush and lay down BHA. 07:30 - 08:15 0.75 CASE P RUNPRD R/U to run 4.5" Liner, held PJSM. 08:15 - 14:00 5.75 CASE P RUNPRD Ran 94 joints 4.5" L-80 IBT-M Liner, up wt = 80k, dn wt = 75k Losses for last 12 hrs = 109 bbls. 14:00 - 14:30 0.50 CASE P RUN PRO Rig down casing equipment, make up Baker ZXP liner top packer. 14:30 - 15:00 0.50 CASE P RUN PRO Circulate liner volume 65 bbls @ 170 gpm, 205 psi. 15:00 - 19:30 4.50 CASE P RUN PRO RIH with liner on 4" DP to 10,783, losing pipe displacment. 19:30 - 20:30 1.00 CASE P RUNPRD Make up Baker cement head & Lay on skate, Circulate bottoms up, staging up pumps to 6 bpm, 780 psi, loss rate 25 - 50 bph. 20:30 - 23:30 3.00 CASE P RUNPRD Continue running 4.5" liner from 10,783' to 14,580' make up cement head and wash from 14,580' to 14,600', string took 40k @ 11,090' worked through, no other hole problems. 23:30 - 00:00 0.50 CEMT P RUNPRD Make up Baker cement head and break circulation, stage up pumps to 6 bpm, 1230 psi, reciprocate pipe. With pump rate at 6 bpm string started hanging up and packing off, reduce flow rate to 4 bpm. Total losses for last 12 hrs = 114 bbls. 9/15/2004 00:00 - 02:00 2.00 CEMT P RUN PRO Held PJSM with Rig personel Co. Rep and Toolpusher while circulating, Liner packed off, with liner 15' off bottom worked packoff and regained circulation, and pipe movement, by slowly staging pumps back up to 3 bpm @ 880 psi. Continued circulating and reciprocating while batch mixing cement. 02:00 - 03:30 1.50 CEMT P RUNPRD Pumped 5 bbls water and tested lines to 4,000 psi, pump 20 bbls CW-100 followed by 30 bbls 9.6 ppg mud push @ 5 bpm 1305 psi, pumped 99 bbls 15.8 ppg Class G cement, Final rate and pressure 5 bpm @ 730 psi, hole becoming sticky, displace with 90 bbls perf pill followed by seawater with rig pumps @ 7 bpm at 150 psi, caught up with cement 58 bbls into displacement, 121 bbls into displacement set liner on bottom. Bumped plug with calculated strokes, pressure up to 3,500 psi Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/15/2004 02:00 - 03:30 1.50 CEMT P RUNPRD and held for 5 min, to set liner hanger bled off pressure and checked floats, rotated string 15 turns to the right, applied 1,000 psi picked up to expose rotating dog sub, circulate 20 bbls, set down 50k to set ZXP packer repeat twice, continue circulating at 1 bpm.while setting packer, rotate string at 20 rpm while applying 50k on packer to confirm set. CIP @ 03: 15 03:30 - 05:00 1.50 CEMT P RUN PRO Circulate bottoms up @ 500 gpm, 3,030 psi, 28 bbls cement to surface. Lay down Baker cement head. 05:00 - 09:30 4.50 CEMT P RUN PRO POH with liner running tool. 09:30 - 10:00 0.50 CEMT P RUN PRO Clean rig floor 10:00 - 12:00 2.00 PERFO P LOWER1 Load pipe shed with perforating tools, bring perf handling equipment to rig floor. Total losses for last 12 hrs = 81.5 bbls 12:00 - 12:30 0.50 PERFO P LOWER1 Service topdrive, change gear oil. 12:30 - 13:00 0.50 PERFO P LOWER1 Test casing to 3,500 psi for 30 min. record on chart. 13:00 - 21 :30 8.50 PERFO P LOWER1 Held PJSM with Schlumberger, Co Rep, and rig crew, picking up perforating assembly. P/U perf guns as per Schlumberger running order. 21 :30 - 22:00 0.50 PERFO P LOWER1 Rig down Schlumberger handling equipment. 22:00 - 00:00 2.00 PERFO P LOWER1 RIH with perforating guns to 8,728. 9/16/2004 00:00 - 03:00 3.00 PERFO P LOWER1 Continue RIH with perforating guns from 8,728' tagged landing collar @ 14,509' space out place bottom shot @ 14,505' 03:00 - 03:30 0.50 PERFO P LOWER1 Held PJSM with CO Rep, Toolpusher, Schlumberger and rig crew, firing guns, break circulation. 03:30 - 04:30 1.00 PERFO P LOWER1 Close Annular, pressure up to 3,000 psi and held for 2 min. bled pressure to zero, shot indicator showed 4 out of 5 shots fired, wait an additional 15 min. check for flow back, open annular and monitor well, hole static. 04:30 - 06:00 1.50 PERFO N DFAL LOWER1 POH to 11,215' 06:00 - 07:00 1.00 PERFO N DFAL LOWER1 Circulate hole volume staging pumps up to 400 gpm, 2,560 psi, no losses. 07:00 - 08:00 1.00 PERFO N DFAL LOWER1 Slip and cut drilling line. 08:00 - 08:30 0.50 PERFO N DFAL LOWER1 Service rig and crown. 08:30 - 11 :00 2.50 PERFO N DFAL LOWER1 POH rack back 4" DP. 11 :00 - 12:00 1.00 PERFO N DFAL LOWER1 RIU 2 7/8" handling equipment. 12:00 - 13:30 1.50 PERFO N DFAL LOWER1 UD 2 7/8" DP. 13:30 - 22:00 8.50 PERFO N DFAL LOWER1 Held PJSM wI Schlumberger, UD Perforating assembly, clean floor. Firing head on station #3 failed causing guns not to fire in the interval from 13,050 to 13,150 and 12,850 to 12,900. Lay down guns and blanks. Prepare new firing head at Schlumberger shop while laying down remainder of 2 1/16 tubing and guns. Intervals successfully perforated: 14,440 to 14,505 14,010 to 14,025 13,830 to 13,990 11,970 to 12,125 11,575 to 11,675 11 ,350 to 11 ,540 22:00 - 00:00 2.00 PERFO N DFAL LOWER1 Held PJSM wI Schlumberger,Co Rep and Toolpusher, P/U perf assembly #2. 9/17/2004 00:00 - 03:00 3.00 PERFO N DFAL LOWER1 Continue picking up perforating assembly, 60 jts 21/16" DP, 13 jts 2 7/8" PAC DP. Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 RIH with perf guns on 4" DP, to 13,185', drop ball and make up topdrive, position bottom shot @ 13,150' top shot @ 12,850' 08:00 - 09:00 1.00 DFAL LOWER1 Pressure up to 2,300 psi, fire guns, shot indicator showed guns fired. Perforated interval 13,05' -13,150' 12,850" -12,900', monitor well. 09:00 - 09:30 0.50 LOWER1 Attempt to pump out, drill string pressuring up. POH to 12,803' unable to circulate. 09:30 - 11 :30 2.00 LOWER1 POH wet to 12,037', UD DP from 12,037' to 11,464' 11:30 -13:00 1.50 LOWER1 RIU and reverse circulate @ 146 gpm, 1,060 psi, install inverted DP screen in DP to prevent pumping 5/8" firing head ball out drill string. Monitor well and pump dry job. 13:00 - 20:00 7.00 LOWER1 POH lay down 4" DP. 20:00 - 00:00 4.00 LOWER1 Held PJSM, R/U and lay down Firing head, 13 jts 2 7/8" PAC DP, 60 jts 2 1/16' DP. 5/8" ball recovered from firing head. 9/18/2004 00:00 - 01 :00 1.00 PERFO LOWER1 Held PTSM, UD perforating guns. 01 :00 - 02:00 1.00 PERFO LOWER1 Clear floor of perforating tools & equipment, clean floor. 02:00 - 03:00 1.00 CLEAN CLEAN RIH w/47 stds. from derrick. 03:00 - 06:30 3.50 CLEAN CLEAN POH, LID 141 jts 4" DP. 06:30 - 07:30 1.00 WHSUB RUNCMP R/U & pull wear ring, P/U landing joint & tubing hanger,make dummy run, UD hanger & landing joint. 07:30 - 09:00 1.50 RUNCMP R/U to run 3.5" 13CR-80 Completion. 09:00 - 00:00 15.00 RUNCMP M/U & run 3.5 13CR Vam Ace Completion 4.5" WLEG 'XN' Nipple Assy, 'X' Nipple Assy & Baker S-3 Permanent Packer Assy. Run 3.5" 9.2# 13CR-80 Tubing as per running order. Makeup Torque 2,820 ftllbs. Ran 277 Jts. + jewelry to 8,908'. Losses for last 24 hrs = 73.5 9/19/2004 00:00 - 03:00 3.00 RUNCMP Continue running 3.5" 13CR-80 9.2# Completion, ran a total of 330 jts. 03:00 - 05:00 2.00 TUBHGR Space out tubing, P/U joint #331 & #332 tagged up @ 10,629', Picked up 20' and rotated string 1/2 turn worked torque down, & tagged @ 10,619' Picked up and rotated string 1/4 turn worked torque down got past 10,618' & took weight at 10,629' repeated several times. UD joints 332 - 330, Picked up 3 pup joints totaling 23.51' P/U joint # 330, tubing hanger & landing joint, sat down @ 10,619' picked up & rotated string, worked down, land tubing, RILDS. bottom of WLEG is inserted 6' in tie back extension. 05:00 - 08:00 3.00 RUNCO RUNCMP R/U to reverse circulate, reverse 95 bbls clean seawater followed by 195 bbls treated with 1 drum of corrosion inhibitor, followed by 183 bbls untreated seawater. @ 3 bpm, 300 psi. 08:00 - 10:00 2.00 RUNCO RUNCMP Drop 1 5/16" BallI Rod to RHC Plug. Pressure up to 2,800 psi to set packer, pressure up to 3,500 psi, to test tubing, hold for 30 min record on chart. Bleed tubing to 1800 psi. Pressure Annulus to 3500 psi. Hold & chart for 30 minutes. Bleed Annulus then tubing to zero. Pressure Annulus to shear DCK valve in GLM located @ 3189'. Valve sheared at 2,750 psi. Pump 3 Bbls each way - OK - Full shear. 10:00 - 11 :00 1.00 BOPSU P WHDTRE Install TWC and test from below to 1,000 psi, Blow down all lines. 11 :00 - 12:00 1.00 BOPSU P WHDTRE NID BOP 12:00 - 14:30 2.50 WHSUR P WHDTRE Nipple up adapter flange & tree and test to 5,000 psi. 14:30 - 15:00 0.50 WHSUR P WHDTRE R/U DSM lubricator and pull TWC 15:00 - 18:00 3.00 WHSUR P WHDTRE R/U Little Reds high pressure lines and test. Freeze protect Printed: 9/20/2004 11: 14:35 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-12 U-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/24/2004 Rig Release: 9/19/2004 Rig Number: Spud Date: 8/5/1985 End: 9/19/2004 9/19/2004 15:00 - 18:00 3.00 WHSUR P WHDTRE 3.5" tubing & 3.5" X 9 5/8" annulus to 2,200' with 155 bbls diesel @ 2.5 bpm, 900 psi. U-tube diesel. POST R/U Lubricator & install BPV, test from below to 1,000 psi. RID lubricator, RID Little Reds, Secure well, install VR plugs in both IA valves. 18:00 - 20:00 2.00 WHSUR P Release Rig @ 20:00 hrs. 9/19/2004 Printed: 9/20/2004 11: 14:35 AM Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA U Pad U-12A Job No. AKZZ3254802, Surveyed: 13 September, 1998 Survey Report 29 September, 2004 Your Ref: API 500292140901 Surface Coordinates: 5961039.00 N, 631718.00 E (70018' 05.8715" N, 148055'59.1663" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 961039.00 N, 131718.00 E (Grid) Surface Coordinates relative to Structure Reference: 477.52 N, 1550.86 E (True) Kelly Bushing Elevation: 76.53ft above Mean Sea Level Kelly Bushing Elevation: 76.53ft above Project V Reference Kelly Bushing Elevation: 76.53ft above Structure Reference sper"r"Y-sul"1 DRtL.LtN.G seRVices A Halliburton Company D EFIN ITI E . . Survey Ref: svy2454 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A Your Ref: API 500292140901 Job No. AKZZ3254802, Surveyed: 13 September, 1998 BPXA BPXA North Slope Alaska 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) 9799.11 42.830 326.900 7998.01 8074.54 3485.09 N 2615.15 W 5964477.71 N 629042.16 E 4341.34 Tie On Point MWD+IIFR+MS 9869.00 42.100 327.800 8049.57 8126.10 3524.82 N 2640.61 W 5964516.98 N 629016.01 E 1.359 4388.52 Window Point 9944.94 46.670 326.550 8103.83 8180.36 3569.43 N 2669.41 W 5964561.08 N 628986.42 E 6.127 4441.62 10042.22 48.860 324.940 8169.21 8245.74 3628.94 N 2709.96 W 5964619.88 N 628944.83 E 2.563 4513.58 . 10137.99 50.300 329.160 8231.32 8307.85 3690.11 N 2749.58 W 5964680.34 N 628904.15 E 3.676 4586.45 10232.77 49.910 330.350 8292.11 8368.64 3752.93 N 2786.21 W 5964742.51 N 628866.43 E 1.047 4659.13 10329.81 50.330 327.780 8354.34 8430.87 3816.79 N 2824.49 W 5964805.69 N 628827.04 E 2.078 4733.57 10424.75 50.220 330.170 8415.02 8491.55 3879.36 N 2862.12 W 5964867.58 N 628788.31 E 1.940 4806.57 10519.77 51.040 329.900 8475.30 8551.83 3942.99 N 2898.81 W 5964930.57 N 628750.51 E 0.890 4879.98 10616.05 50.070 330.450 8536.47 8613.00 4007.49 N 2935.79 W 5964994.41 N 628712.41 E 1.100 4954.28 10711.55 49.930 331.130 8597.85 8674.38 4071.35 N 2971.49 W 5965057.63 N 628675.59 E 0.565 5027.35 10749.51 49.910 330.950 8622.29 8698.82 4096.76 N 2985.55 W 5965082.79 N 628661.09 E 0.367 5056.35 10846.05 51.200 329.610 8683.63 8760.16 4161.50N 3022.52 W 5965146.87 N 628622.99 E 1.713 5130.84 10875.63 51.030 328.920 8702.20 8778.73 4181.29N 3034.29 W 5965166.45 N 628610.88 E 1,905 5153.86 10907.72 50.970 328.230 8722.39 8798.92 4202.57 N 3047.29 W 5965187.50 N 628597.51 E 1.681 5178.80 10939.56 53.840 327.880 8741.82 8818.35 4223.97 N 3060.64 W 5965208.67 N 628583.79 E 9.056 5204.02 10971.35 57.540 327.940 8759.73 8836.26 4246.22 N 3074.58 W 5965230.66 N 628569.45 E 11.640 5230.28 11002.90 60.770 327.420 8775.91 8852.44 4269.10 N 3089.07 W 5965253.29 N 628554.57 E 10.335 5257.36 11035.15 64.250 327.010 8790.79 8867.32 4293.15 N 3104.56 W 5965277.06 N 628538.66 E 10.849 5285.96 11067.23 68.560 326.930 8803.63 8880.16 4317.79 N 3120.58 W 5965301.42 N 628522.21 E 13.437 5315.35 11100.46 73.350 327.200 8814.47 8891.00 4344.15 N 3137.65 W 5965327.47 N 628504.68 E 14.435 5346.75 . 11132.55 76.490 328.310 8822.82 8899.35 4370.35 N 3154.18 W 5965353.38 N 628487.69 E 10.339 5377.73 11162.90 80.580 328.800 8828.85 8905.38 4395.72 N 3169.69 W 5965378.48 N 628471.74 E 13.569 5407.46 11258.44 85.800 329.530 8840.17 8916.70 4477.15 N 3218.29 W 5965459.04 N 628421.71 E 5.516 5502.28 11354.16 85.310 325.590 8847.59 8924.12 4557.68 N 3269.47 W 5965538.66 N 628369.13 E 4.136 5597.69 11450.34 84.130 321.110 8856.45 8932.98 4634.49 N 3326.62 W 5965614.46 N 628310.64 E 4.798 5693.12 11545.61 84.130 321.200 8866.19 8942.72 4708.31 N 3386.07 W 5965687.22 N 628249.92 E 0.094 5787.21 11641.05 85.500 322.030 8874.82 8951.35 4782.81 N 3445.08 W 5965760.68 N 628189.60 E 1.676 5881.67 11736.73 85.310 322.430 8882.48 8959.01 4858.20 N 3503.50 W 5965835.03 N 628129.87 E 0.462 5976.56 11832.15 84.940 323.440 8890.59 8967.12 4934.06 N 3560.80 W 5965909.88 N 628071.25 E 1.124 6071.26 29 September, 2004 - 17:00 Page 2 of 5 DríllQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A Your Ref: API 500292140901 Job No. AKZZ3254802, Surveyed: 13 September, 1998 BPXA BPXA North Slope Alaska 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) (·/100ft) 11864.52 82.890 322.910 8894.02 8970.55 4959.83 N 3580.09 W 5965935.30 N 628051.51 E 6.539 6103.33 11896.43 83.450 322.160 8897.82 8974.35 4984.97 N 3599.36 W 5965960.11 N 628031.80 E 2.920 6134.87 11927.66 84.930 320.960 8900.98 8977.51 5009.31 N 3618.68 W 5965984.10 N 628012.06 E 6.089 6165.74 11960.92 85.180 318.610 8903.85 8980.38 5034.61 N 3640.07 W 5966009.02 N 627990.23 E 7.079 6198.54 11993.08 85.310 315.690 8906.51 8983.04 5058.10 N 3661.87 W 5966032.13 N 627968.02 E 9.057 6230.01 . 12023.88 85.310 312.980 8909.03 8985.56 5079.55 N 3683.82 W 5966053.19 N 627945.70 E 8.769 6259.83 12055.80 85.680 310.900 8911.54 8988.07 5100.82 N 3707.49 W 5966074.04 N 627921.66 E 6.599 6290.41 12087.69 87.100 310.910 8913.55 8990.08 5121.66N 3731.54 W 5966094.46 N 627897.24 E 4.453 6320.83 12119.59 86.980 311.120 8915.19 8991.72 5142.57 N 3755.58 W 5966114.94 N 627872.84 E 0.757 6351.30 12215.32 87.590 309.600 8919.73 8996.26 5204.49 N 3828.44 W 5966175.57 N 627798.91 E 1.709 6442.42 12310.42 87.100 310.820 8924.13 9000.66 5265.82 N 3900.99 W 5966235.62 N 627725.30 E 1.381 6532,88 12406.67 87.410 309.950 8928.74 9005.27 5328.11 N 3974.22 W 5966296.62 N 627650.99 E 0.959 6624.51 12456.25 87.780 309.720 8930.82 9007.35 5359.84 N 4012.26 W 5966327.68 N 627612.40 E 0.878 6671.57 12501.77 87.650 311.460 8932.64 9009.17 5389.43 N 4046.80 W 5966356.66 N 627577.35 E 3.830 6714.97 12535.83 88.270 311.510 8933.85 9010.38 5411.98 N 4072.29 W 5966378.76 N 627551.46 E 1.826 6747.61 12565.28 87.840 311.480 8934.85 9011.38 5431.48 N 4094.34 W 5966397.87 N 627529.07 E 1 .464 6775.83 12597.85 89.810 315.130 8935.52 9012.05 5453.81 N 4118.03W 5966419.78 N 627504.99 E 12.732 6807.32 12629.49 90.000 316.650 8935.57 9012.10 5476.53 N 4140.05 W 5966442.11 N 627482.58 E 4.841 6838.25 12661.00 89.260 317.270 8935.78 9012.31 5499.56 N 4161.56W 5966464.75 N 627460.67 E 3.064 6869.18 12685.63 88.090 317.310 8936.35 9012.88 5517.65 N 4178.26 W 5966482.55 N 627443.65 E 4.753 6893.37 12724.42 87.350 318.880 8937.89 9014.42 5546.49 N 4204.15 W 5966510.94 N 627417.27 E 4.472 6931.55 12756.29 86.730 320.750 8939.53 9016.06 5570.81 N 4224.68 W 5966534.89 N 627396.31 E 6.174 6963.05 . 12788.99 86.730 322.670 8941 .40 9017.93 5596.43 N 4244.91 W 5966560.15 N 627375.63 E 5.862 6995.50 12820.29 86.730 324.330 8943.19 9019.72 5621.55 N 4263.50 W 5966584.94 N 627356.61 E 5.295 7026.65 12852.46 87.780 327.540 8944.73 9021.26 5648.17 N 4281.49 W 5966611.24 N 627338.15 E 1 0.487 7058.76 12884.72 88.640 330.380 8945.73 9022.26 5675.79 N 4298.12 W 5966638.57 N 627321.04 E 9.194 7091.00 12915.36 88.090 335.040 8946.61 9023.14 5703.00 N 4312.16 W 5966665.53 N 627306.53 E 15.308 7121.51 12947.99 87.530 337.910 8947.86 9024.39 5732.89 N 4325.17 W 5966695.19 N 627292.99 E 8.955 7153.76 12980.73 87.780 339.310 8949.20 9025.73 5763.35 N 4337.10W 5966725.43 N 627280.53 E 4.340 7185.91 13012.06 90.120 340.660 8949.77 9026.30 5792.78 N 4347.82 W 5966754.67 N 627269.30 E 8.622 7216.55 13043.98 91.980 343.330 8949.18 9025.71 5823,13 N 4357.68 W 5966784.84 N 627258.90 E 10.193 7247.52 13076.23 92.590 345.250 8947.90 9024.43 5854.15 N 4366.41 W 5966815.70 N 627249.63 E 6.242 7278.44 13107,16 92.900 347.200 8946.42 9022.95 5884.15 N 4373.77 W 5966845.57 N 627241.75 E 6.377 7307.79 13139.40 92.780 348.250 8944.82 9021.35 5915.62 N 4380.61 W 5966876.91 N 627234.36 E 3.274 7338.10 13170.79 92.220 350.410 8943.45 9019.98 5946.43 N 4386.42 W 5966907.62 N 627228.01 E 7.102 7367.31 29 September, 2004 - 17:00 Page 3 of5 Dri//Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A Your Ref: API 500292140901 Job No. AKZZ3254802, Surveyed: 13 September, 1998 BPXA BPXA North Slope Alaska 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) 13203.43 91.910 351.500 8942.27 9018.80 5978.65 N 4391.55 W 5966939.74 N 627222.32 E 3.470 7397,34 13234.29 90.860 352.700 8941.53 9018.06 6009.20 N 4395.79 W 5966970.22 N 627217.55 E 5.166 7425.50 13266.46 90.370 354.290 8941.18 9017.71 6041.16 N 4399.43 W 5967002.11 N 627213.34 E 5.172 7454.54 13299.23 89.880 356.160 8941.11 9017.64 6073.82 N 4402.16 W 5967034.71 N 627210.04 E 5.899 7483.68 13330.70 90.370 357.370 8941.04 9017.57 6105.24 N 4403.93 W 5967066.09 N 627207.72 E 4.148 7511.26 . 13363.62 92.160 358.580 8940.32 9016.85 6138.13N 4405.10 W 5967098.96 N 627205.98 E 6.563 7539.77 13395.24 94.070 0.350 8938.60 9015.13 6169.70 N 4405.39 W 5967130.52 N 627205.13 E 8.230 7566.70 13426.00 95.500 1.570 8936.03 9012.56 6200.34 N 4404.88 W 5967161.17 N 627205.10 E 6.102 7592.42 13457.81 97.360 2.320 8932.47 9009.00 6231.93 N 4403.81 W 5967192.77 N 627205.62 E 6.299 7618.64 13554.21 99.110 3.240 8918.66 8995.19 6327.22 N 4399.18 W 5967288.13 N 627208.58 E 2.046 7697.00 13652.76 99.920 3.080 8902.37 8978.90 6424.27 N 4393.82 W 5967385.25 N 627212.23 E 0.837 7776.46 13745.15 101.070 2.920 8885.54 8962.07 6514.99 N 4389.07 W 5967476.04 N 627215.40 E 1.256 7850.87 13840.09 101.560 3.300 8866.92 8943.45 6607.94 N 4384.02 W 5967569.07 N 627218.82 E 0.648 7927.03 13935.86 101.060 3.570 8848.13 8924.66 6701.68 N 4378.39 W 5967662.90 N 627222.80 E 0.591 8003.54 14031.86 101.500 3.640 8829.36 8905.89 6795.64 N 4372.47 W 5967756.94 N 627227.07 E 0.464 8080.09 14127.04 101.940 4.190 8810.02 8886.55 6888.62 N 4366.11 W 5967850.02 N 627231.80 E 0.731 8155.57 14223.11 101.930 3.360 8790.15 8866.68 6982.41 N 4359.92 W 5967943.90 N 627236.34 E 0.845 8231.82 14318.54 101.760 3.180 8770.57 8847.10 7075.65 N 4354.59 W 5968037.23 N 627240.04 E 0.257 8308.08 14414.39 102.060 3.530 8750.78 8827.31 7169.28 N 4349.10 W 5968130.93 N 627243.88 E 0.475 8384.57 14509.50 103.140 3.360 8730.04 8806.57 7261.93 N 4343.53 W 5968223.67 N 627247.84 E 1.149 8460.18 14600.00 103.140 3.360 8709.46 8785.99 7349.91 N 4338.36 W 5968311. 72 N 627251.46 E 0.000 8532.06 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 328.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14600.00ft., The Bottom Hole Displacement is 8534.78ft., in the Direction of 329.448° (True). 29 September, 2004·17:00 Page 4 of 5 Dril/Quest 3.03.06.006 Halliburlon Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A Your Ref: API 500292140901 Job No. AKZZ3254802, Surveyed: 13 September, 1998 BPXA North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9799.11 9869.00 14600.00 8074.54 8126.10 8785.99 3485.09 N 3524.82 N 7349.91 N 2615.15 W 2640.61 W 4338.36 W Tie On Point Window Point Projected Survey . Survey tool program for U-12A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9799.11 0.00 9799.11 8074.54 14600.00 8074.54 BP High Accuracy Gyro - Boss Gyro.(U-12) 8785.99 MWD+IIFR+MS (U-12A) . 29 September, 2004 . 17:00 Page 5 of 5 DrillQuest 3.03.06.006 . AOGCC Robin Deason 333 W.7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well U-12A MWD 04-0ct-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,799.11' MD 9,869.11' MD 14,600.00' 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 Date 7 /) !'j-~ Signed µ diU Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ).JJvt -1·'-17 Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA U Pad U-12A (mwd) . Job No. AKMW3254802, Surveyed: 13 September, 2004 Survey Report 29 September, 2004 Your Ref: API 500292140901 Surface Coordinates: 5961039.00 N, 631718.00 E (70018' 05.8715" N, 148055' 59.1663" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 961039.00 N, 131718.00 E (Grid) Surface Coordinates relative to Structure Reference: 477.52 N, 1550.86 E (True) Kelly Bushing Elevation: 76.53ft above Mean Sea Level Kelly Bushing Elevation: 76.53ft above Project V Reference Kelly Bushing Elevation: 76.53ft above Structure Reference SI:Jf!!r"'r"'):I-SUI! DFUL-LING $IæAVICIæ$ A Halliburton Company Survey Ref: svy4393 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad· U-12A (mwd) Your Ref: API 500292140901 Job No. AKMW3254802, Surveyed: 13 September, 2004 BPXA BPXA North Slope Alaska 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) 9799.11 42.830 326.900 7998.01 8074.54 3485.09 N 2615.15 W 5964477.71 N 629042.16 E 4341.34 Tie On Point MWD Magnetic 9869.00 42.100 327.800 8049.57 8126.10 3524.82 N 2640.61 W 5964516.98 N 629016.01 E 1.359 4388.52 9869.11 42.107 327.798 8049.65 8126.18 3524.88 N 2640.65 W 5964517.04 N 629015.97 E 6.127 4388.60 Window Point 9944.94 46.670 326.550 8103.83 8180.36 3569.43 N 2669.41 W 5964561.08 N 628986.42 E 6.127 4441.62 . 10042.22 48.860 325.590 8169.21 8245.74 3629.18 N 2709.62 W 5964620.12 N 628945.17 E 2.367 4513.60 10137.99 50.300 329.790 8231.32 8307.85 3690.79 N 2748.55 W 5964681.04 N 628905.17 E 3.661 4586.48 10232.77 49.910 330.930 8292.11 8368.64 3753.99 N 2784.51 W 5964743.59 N 628868.1 0 E 1.010 4659.13 10329.81 50.330 328.350 8354.34 8430.87 3818.23 N 2822.15 W 5964807.17 N 628829.35 E 2.086 4733.56 10424.75 50.220 330.590 8415.02 8491.55 3881.12 N 2859.24 W 5964869.40 N 628791.16 E 1.818 4806.54 10519.77 51.040 330.420 8475.29 8551.82 3945.06 N 2895.41 W 5964932.69 N 628753.88 E 0.874 4879.93 10616.05 50.070 331.040 8536.46 8612.99 4009.91 N 2931.76 W 5964996.90 N 628716.39 E 1.124 4954.19 10711.55 49.930 331.620 8597.85 8674.38 4074.10 N 2966.86 W 5965060.46 N 628680.17 E 0.488 5027.23 10749.51 49.910 331.580 8622.29 8698.82 4099.65 N 2980.67 W 5965085.76 N 628665.91 E 0.096 5056.22 10846.05 51.200 330.440 8683.63 8760.16 4164.85 N 3016.81 W 5965150.32 N 628628.64 E 1.618 5130.66 10875.63 51.030 329.720 8702.19 8778.72 4184.81 N 3028.30 W 5965170.07 N 628616.81 E 1.980 5153.67 10907.72 50.970 328.570 8722.39 8798.92 4206.22 N 3041.08 W 5965191.26 N 628603.65 E 2.791 5178.60 10939.56 53.840 328.360 8741.81 8818.34 4227.72 N 3054.28 W 5965212.52 N 628590.08 E 9.029 5203.83 10971.35 57.540 328.250 8759.73 8836.26 4250.05 N 3068.07 W 5965234.61 N 628575.89 E 11.642 5230.08 11002.90 60.770 328.550 8775.90 8852.43 4273.12 N 3082.26 W 5965257.43 N 628561.30 E 10.270 5257.16 11035.15 64.250 328.190 8790.79 8867.32 4297.48 N 3097.27 W 5965281.52 N 628545.87 E 10.836 5285.77 11067.23 68.560 328.180 8803.62 8880.15 4322.45 N 3112.76W 5965306.22 N 628529.94 E 13.435 5315.16 . 11100.46 73.350 330.120 8814.47 8891.00 4349.41 N 3128.86 W 5965332.89 N 628513.38 E 15.434 5346.55 11132.55 76.490 329.870 8822.81 8899.34 4376.24 N 3144.35 W 5965359.45 N 628497.42 E 9.814 5377.52 11162.90 80.580 331.600 8828.85 8905.38 4402.19 N 3158.88 W 5965385.13 N 628482.43 E 14.588 5407.22 11258.44 85.800 329.940 8840.17 8916.70 4484.94 N 3205.20 W 5965467.06 N 628434.67 E 5.729 5501.94 11354.16 85.310 328.450 8847.59 8924.12 4566.90 N 3254.07 W 5965548.15 N 628384.37 E 1.634 5597.35 11450.34 84.130 323.340 8856.45 8932.98 4646.18 N 3307.74 W 5965626.47 N 628329.31 E 5.431 5693.02 11545.61 84.130 322.440 8866.19 8942.72 4721.75 N 3364.92 W 5965701.04 N 628270.82 E 0.940 5787.41 11641.05 85.500 322.490 8874.82 8951.35 4797.12 N 3422.83 W 5965775.38 N 628211.60 E 1.436 5882.02 11736.73 85.310 322.730 8882.48 8959.01 4872.90 N 3480.74 W 5965850.13 N 628152.37 E 0.319 5976.97 29 September, 2004 - 17:05 Page 2 of5 Dri/lQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A (mwd) Your Ref: API 500292140901 Job No. AKMW3254802, Surveyed: 13 September, 2004 BPXA BPXA North Slope Alaska 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) 11832.15 84.940 323.690 8890.59 8967.12 4949.04 N 3537.68 W 5965925.26 N 628094.10 E 1.075 6071.71 11864.52 82.890 322.920 8894.02 8970.55 4974.85 N 3556.91 W 5965950.72 N 628074.42 E 6.760 6103.79 11896.43 83.450 322.400 8897.82 8974.35 5000.03 N 3576.13 W 5965975.57 N 628054.76 E 2.387 6135.33 11927.66 84.930 321.180 8900.98 8977.51 5024.45 N 3595.35 W 5965999.64 N 628035.12 E 6.129 6166.22 11960.92 85.180 318.850 8903.84 8980.37 5049.83 N 3616.64 W 5966024.65 N 628013.39 E 7.020 6199.03 . 11993.08 85.310 315.950 8906.51 8983.04 5073.42 N 3638.33 W 5966047.86 N 627991.29 E 8.995 6230.53 12023.88 85.310 313.220 8909.03 8985.56 5094.97 N 3660.19 W 5966069.02 N 627969.05 E 8.834 6260.39 12055.80 85.680 311.200 8911.54 8988.07 5116.35N 3683.76 W 5966089.98 N 627945.11 E 6.414 6291.00 12087.69 87.100 311.160 8913.54 8990.07 5137.30 N 3707.71 W 5966110.51 N 627920.80 E 4.455 6321.47 12119.59 86.980 311.390 8915.19 8991.72 5158.32 N 3731.66 W 5966131.10 N 627896.49 E 0.812 6351.98 12215.32 87.590 311.510 8919.73 8996.26 5221.62 N 3803.33 W 5966193.14 N 627823.72 E 0.649 6443.64 12310.42 87.100 312.610 8924.13 9000.66 5285.25 N 3873.86 W 5966255.53 N 627752.08 E 1.265 6534.98 12406.67 87.410 311.900 8928.74 9005.27 5349.90 N 3945.02 W 5966318.92 N 627679.80 E 0.804 6627.51 12456.25 87.780 311.670 8930.82 9007.35 5382.91 N 3981.95 W 5966351.27 N 627642.29 E 0.878 6675.08 12501.77 87.650 311.730 8932.64 9009.17 5413.17 N 4015.91 W 5966380.93 N 627607.81 E 0.314 6718.74 12535.83 88.270 311.740 8933.85 9010.38 5435.82 N 4041.31 W 5966403.14 N 627582.01 E 1.821 6751.41 12565.28 87.840 311.750 8934.85 9011.38 5455.42 N 4063.27 W 5966422.35 N 627559.71 E 1 .460 6779.67 12597.85 89.810 315.300 8935.52 9012.05 5477.84 N 4086.88 W 5966444.35 N 627535.72 E 12.463 6811.19 12629.49 90.000 316.850 8935.57 9012.10 5500.63 N 4108.83 W 5966466.75 N 627513.37 E 4.936 6842.15 12661.00 89.260 317 .480 8935.77 9012.30 5523.74 N 4130.25 W 5966489.48 N 627491.55 E 3.084 6873.09 12685.63 88.090 317.510 8936.34 9012.87 5541.89 N 4146.89 W 5966507.34 N 627474.60 E 4.752 6897.30 12724.42 87.350 319.110 8937.89 9014.42 5570.83 N 4172.67 W 5966535.82 N 627448.32 E 4.542 6935.51 . 12756.29 86.730 320.960 8939.53 9016.06 5595.22 N 4193.11 W 5966559.85 N 627427.45 E 6.115 6967.03 12788.99 86.730 322.900 8941 .40 9017.93 5620.92 N 4213.24 W 5966585.20 N 627406.87 E 5.923 6999.49 12820.29 86.730 324.610 8943.18 9019.71 5646.13 N 4231.71 W 5966610.07 N 627387.96 E 5.454 7030.65 12852.46 87.780 327.750 8944.72 9021.25 5672.82 N 4249.59 W 5966636.45 N 627369.61 E 10.281 7062.76 12884.72 88.640 330.600 8945.73 9022.26 5700.50 N 4266.12 W 5966663.84 N 627352.61 E 9.224 7095.00 12915.36 88.090 335.230 8946.61 9023.14 5727.77 N 4280.06 W 5966690.85 N 627338.19 E 15.211 7125.50 12947.99 87.530 338.060 8947.85 9024.38 5757.70 N 4292.98 W 5966720.55 N 627324.74 E 8.835 7157.74 12980.73 87.780 339.460 8949.19 9025.72 5788.19 N 4304.83 W 5966750.83 N 627312.36 E 4.340 7189.87 13012.06 90.120 340.790 8949.77 9026.30 5817.64 N 4315.48 W 5966780.09 N 627301.20 E 8.591 7220.50 13043.98 91.980 343.460 8949.18 9025.71 5848.01 N 4325.28 W 5966810.29 N 627290.87 E 10.193 7251.44 13076.23 92.590 345.390 8947.90 9024.43 5879.05 N 4333.93 W 5966841.17 N 627281.68 E 6.272 7282.35 13107.16 92.900 347.330 8946.41 9022.94 5909.07 N 4341.21 W 5966871.06 N 627273.87 E 6.345 7311.67 13139.40 92.780 348.330 8944.82 9021.35 5940.55 N 4348.00 W 5966902.41 N 627266.53 E 3.120 7341.96 29 September, 2004 - 17:05 Page 3 of 5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A (mwd) Your Ref: API 500292140901 Job No. AKMW3254802, Surveyed: 13 September, 2004 BPXA BPXA North Slope Alaska 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) 13170.79 92.220 350.530 8943.45 9019.98 5971.38 N 4353.75 W 5966933.13 N 627260.24 E 7.226 7371.15 13203.43 91.910 351.660 8942.27 9018.80 6003.60 N 4358.80 W 5966965.26 N 627254.62 E 3.588 7401.16 13234.29 90.860 352.850 8941.53 9018.06 6034.17 N 4362.96 W 5966995.76 N 627249.93 E 5.142 7429.28 13266.46 90.370 354.400 8941.18 9017.71 6066.14 N 4366.53 W 5967027.66 N 627245.80 E 5.053 7458.29 13299.23 89.880 356.350 8941.11 9017.64 6098.80 N 4369.17 W 5967060.27 N 627242.58 E 6.136 7487.38 . 13330.70 90.370 357.530 8941.04 9017.57 6130.22 N 4370.85 W 5967091.66 N 627240.35 E 4.060 7514.92 13363.62 92.160 358.770 8940.31 9016.84 6163.12N 4371.92 W 5967124.53 N 627238.71 E 6.614 7543.38 13395.24 94.070 0.560 8938.60 9015.13 6194.69 N 4372.10 W 5967156.09 N 627237.98 E 8.273 7570.25 13426.00 95.500 1.770 8936.03 9012.56 6225.33 N 4371.48 W 5967186.74 N 627238.06 E 6.081 7595.91 13457.81 97.360 2.530 8932.47 9009.00 6256.92 N 4370.29 W 5967218.34 N 627238.69 E 6.311 7622.07 13554.21 99.110 3.470 8918,66 8995.19 6352.19 N 4365.30 W 5967313.68 N 627242.01 E 2.056 7700.22 13652.76 99.920 3.330 8902.37 8978.90 6449.21 N 4359.54 W 5967410.79 N 627246.08 E 0.834 7779.44 13745.15 101.070 3.170 8885.54 8962.07 6539.91 N 4354.39 W 5967501.57 N 627249.63 E 1.256 7853.63 13840,09 101.560 3.580 8866.91 8943.44 6632.84 N 4348.91 W 5967594.58 N 627253.48 E 0.668 7929.54 13935.86 101.060 3.820 8848.13 8924.66 6726.55 N 4342,85 W 5967688.39 N 627257.90 E 0.577 8005.80 14031.86 101.500 3.860 8829.35 8905.88 6820.49 N 4336.54 W 5967782.42 N 627262.56 E 0.460 8082.12 14127.04 101.940 4.390 8810.02 8886.55 6913.44 N 4329.84 W 5967875.47 N 627267.63 E 0.715 8157.40 14223.11 101.930 3.560 8790.15 8866.68 7007.21 N 4323.32 W 5967969.34 N 627272.50 E 0.845 8233.46 14318.54 101.760 3.410 8770.56 8847.09 7100.43 N 4317.64 W 5968062.65 N 627276.54 E 0.235 8309.51 14414.39 102.060 3.730 8750.78 8827.31 7194.04 N 4311.80 W 5968156.34 N 627280.74 E 0.452 8385.80 14509.50 103.140 3.590 8730.03 8806.56 7286.67 N 4305.88 W 5968249.06 N 627285.04 E 1.145 8461.21 14600.00 103.140 3.590 8709.46 8785.99 7374.62 N 4300.36 W 5968337.10 N 627289.02 E 0.000 8532.88 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 328.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14600.00ft., The Bottom Hole Displacement is 8536.87ft., in the Direction of 329,752° (True). 29 September, 2004 - 17:05 Page 40f5 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA U Pad - U-12A (mwd) Your Ref: API 500292140901 Job No. AKMW3254802, Surveyed: 13 September, 2004 BPXA North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~) Comment 9799.11 9869.11 14600.00 8074.54 8126.18 8785.99 3485.09 N 3524.88 N 7374.62 N 2615.15 W 2640.65 W 4300.36 W Tie On Point Window Point Projected Survey . Survey too/ørof/ram for U-12A (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9799.11 0.00 9799.11 8074.54 14600.00 8074.54 BP High Accuracy Gyro - Boss Gyro (U-12) 8785.99 MWD Magnetic (U-12A (mwd)) . 29 September, 2004 - 17:05 Page 5 of 5 DrillQuest 3.03.06.006 13-3/8" CSG, 72#, 1 L-80, ID = 12.347" 2,700' I 7",26#, L-80, BTC-M scab liner 9 5/8" w hip stock set on bridge plug. 1 -9,930' I I TOP OF 7" LNR H 10415' I I Top of Cement H 10,503' 95/8",47#, L-80, -1 I Csg ID = 8.681" I 10680' 7",26#, U4S, Lnr --f 11280' I 10 = 6.276" I DATE 08/30/85 02/05/01 03/08/01 11/02/01 11/05/02 08/30/04 U-.A DATE 09/19/04 REV BY COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-MD FINAL RNlTP CORRECTIONS PP/TP SOZ ÆRF CHANGE, TOC dew lJ-12A Contingency Wp17 . TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= CAMERON 4" AXELSON 77.07' 48.57' 3100' 103 @ 14600' 2198' 1-13 1/2" 'X' landing nipple, ID = 2.813" I 2,823' 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr with TBS ST MD TVD DEV TYÆ VALVE LA TCH 4 10482 8528 14° 3 1/2" X 1 1/2" MMG Dummy RK 3 8541 7207 45° 31/2" X 1 1/2" MMG OCR RKP 2 6100 5496 45° 3 1/2" X 1 1/2" MMG Dummy RK 1 3190 3185 52° 3 1/2" X 1 1/2" MMG Dummy RK 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr with TBS Window in 9 5/8 11 9865-9885\ Discription of equipment 31/2" X landing nipple with 2.8131D Baker S-3 HYDRO-Set 7" x 3 .5" 9CR Packer 31/2" X landin9 nipple with 2.813 ID 3 1/2 XN landing nipple with 2.75 ID 31/29.2# 13 CR-80 VamAce with 2.9921D 7" x 5" ZXP Packer with HMC liner hanger 3 1/2 x 4 1/2 9Cr. WLEG 4.950D 7" 26# L-80 BTC-M Drlg liner 14600' I 4 1/2" 12.6 L-80 1ST solid liner with 3.958 ID SIZE 21/2" 2 1/2" 2 1/2" 2 1/2" 2 1/2" 2 1/2" 2 1/2" 2 1/2" ÆRFORA TION SUMMARY ANGLEATTOPÆRF: 85 @ 11350' SPF INTERVAL Opn/Sqz 4 11350-11540 0 4 11575-11675 0 4 11970-12125 0 4 12850-12900 0 4 13050-13150 0 4 13830-13990 0 4 14010-14025 0 4 14440-14505 0 DATE 09/16/04 09/16/04 09/16/04 09/17/04 09/17/04 09/16/04 09/16/04 09/16/04 REV BY AM PRUDHOE BAY UNIT WELL: U-12A PERMIT No: 1851820 API No: 50-029-21409-01-00 SEe 18, T11N, R13E COMMENTS Actual depths per drilling BP Exploration (Alaska) U - I LA- 2A? 4 - l4-1 . . Phase 3: Run Whip Stock (Revised) Planned Phase Time 30 hours Planned Phase Cost $187,322 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards >- A 9 5/8" whip stock will be run and set in the existing intermediate casing. >- According to the initial cementing report, it is likely there will be 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%" Intermediate Hole Interval (Revised) Planned Phase Time 70 hours Planned Phase Cost $436,906 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards >- This well bore will exit the original well in the mid Kingak shale, and drill to the top of the Sag River formation. Previous U-pad wells drilled the Kingak with 9.7 to 10.0ppg mud weights. For this well, the Kingak will require a mud weight of 11.2ppg, according to the Kingak Polar plot. Maintain mud weight at 11.2 from the window to 7" liner point. Follow all shale drilling practices to minimize potential problems. >- The 9 5/8" casing has a leak at -5,300'md. The 8 W' intermediate section will be drilled with this leak exposed. Minimize swab, surge, and excessive ECD while drilling this interval. >- KICK TOLERANCE: In the worst-case scenario of 9.5ppg pore pressure at the Sag River depth, a fracture gradient of 11.45ppg at the 9 5/8" casing window, and 11.2ppg mud in the hole, the kick tolerance is infinite. RECEIVED SEP - 1 2004 Alaska Oil & Gas Cons. Commission Anchorage U-12A Sidetrack Version 1.2 Page 1 . . Phase 6: Run and Cement 7" Intermediate Liner (Revised) Planned Phase Time 48 hou rs Planned Phase Cost $434,351 Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab I surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Slurry Design Basis: Fluids Sequence I Volume: ; 1.16 cf/sk. Run and Cement 7" Scab liner 7", 26#, L-80, BTC-M scab liner Lead slurry: -5,925' of 7" X 95/8" annulus, plus 1 00' of 9 5/8" X 4" drill pipe Slurry Design Basis: annulus. Tail slur : 1,000' of 7" X 9 5/8" annulus, Ius 60' of 7", 26.0#, shoe track. Pre-Flush None re uired S acer 15bbls MudPUSH at 12.2 Fluids Sequence I Volume: Lead Slur 157.5bbl I 884 cf I 372 sx Class 'G', 12.0 ; 2.38 cf/sk. Tail Slur 28.0bbl 1157 cf 1136 sx Class 'G', 15.8 ; 1.16 cf/sk. U-12A Sidetrack Version 1.2 Page 2 . . Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 216 hours Planned Phase Cost $1,208,996 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ Near well, N-11 experienced losses during drilling operations. N-11 lost 500bbls in the Sag River. 60bbls while drilling Zone 4, and 440bbls while drilling Zone 2. These losses were associated with penetration of a fault. The trajectory of the U-12A will not penetrate this fault, and will remain in Zone 4. ~ The parent well, U-12, experienced no lost circulation events during drilling operations. ~ The planned well, U-12A, will cross a Graben fault in Zone 4. As outlined earlier, the expected throw is -130' at the first encounter, and -180' at the second encounter. Be prepared with adequate Lost Circulation Material. Phase 9: Run 4%" Production Liner Planned Phase Time 37 hours Planned Phase Cost $275,386 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a 4 W', 12.6#, L-80 solid liner throughout the production 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 Y2" liner will be run to extend 150' back up into the 7" drilling liner. ~ Ensure the 4 W' liner top packer is set prior to POOH. 41/2", 12.6#, L-80, IBT-M solid roduction liner Lead slurry: none planned Tail slurry: 3,625' of 41/2" X 61/8" annulus with 40% excess, plus 85' of 4 1/2",12.6# shoe track, plus 150' of 7" X 4 W' liner lap, plus 200' of 7" X 4" drill i e annulus. Pre-Flush 25bbls CW100 S acer 35bbls MudPUSH at 9.6 Lead Slur None lanned Tail Slur 94.0bbl I 528 cf I 440 sx Class 'G', 15.8 ; 1.20 cf/sk. Slurry Design Basis: Fluids Sequence I Volume: U-12A Sidetrack Version 1.2 Page 3 . . Proposal Ref: pr04363 Halliburton Sperry-Sun <,;j}Ù,. North Slope Alasli., ':>E+{ BPKA ,"J \\\j~¡¡~:.L _," ..._pi'<\''''.f'':?'''';j!¡ ; .- :1î'. /%;>'1:~¡+«; d 'ft,,-, t. ,\'t Yc Yt;/ U 1""~p:; :,. .1';' .-.- ,". ?ikt,*ii{ ,<- .-.- '\. -.:: -::)iX .... <.:"f ~itiíiitn~~ Ž'~i;" Report 30 August, 2004 Surface Coordinates: 5961039.00 N, 631718.00 E (70"18' 05.8715" N, 211" 04' 00.8337" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 77.07ft above Mean Sea Level sp.......,..,V-!IUI! ".~VB:;IUI A Halliburton Company BPXA North Slope Alaska Well: Current Well Properties U-12A WPi7J) RKa 8evation : 5001039.00 N. 631718.00 E 477.52 N.. 155Ma E 70~ 18"05.8715~ N, 211" 04· 00.8337'" E nons"""" Mean Sea Level 77J)1ft above Struc:ture Refarenœ The "Directional Difficulty profile is 6.1 ¡¡"gIn Dlr@4.000"I100ft 1$26.561'1 !liD, 8981.0111 TVO 4000 PBU_W U U·12A Wp 17.0 Contingency End 6500 4500 KOP : 2 L!l1! TF, it¡¡rt Olr@ 12.000'110011 9924.00IIM0,I!1!!7.1!!ftTVD -4500 Sea¡.., UncI! = 1000ft -wOO Eastings Halliburton Sperry-Sun Proposal Report for U-12A Recca - U-12A Wp 17 BP BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (0/1oaft) 9924.00 41.894 328.055 8090.09 8167.16 3555.68 N 2659.82 W 62 4424.88 Assume 12.0°/1000 DLS across Whipstock in 9-5/8" Csg : 9924.000 MD, 8167.16ft TVD ,+yð?b 9 5/8in Casing 9944.00 44.293 327.935 8104.69 8181.76 3567.27 N 2667.06 W 628988.81 E 12.000 4438.54 PU Dir tools and Begin Dir @ 4.0°/1000 in 8-112" Hole: . 9944.000 MD, 8181.76ft TV 10000.00 46.530 327.767 8144.00 8221.07 3601.03 N 628967.00 E 4.000 4478.42 10100.00 50.524 327.496 8210.22 8287.29 3664.30 N 628925.79 E 4.000 4553.33 10107.55 50.826 327.477 8215.00 8292.07 3669.22 628922.57 E 4.000 4559.17 End Dir, Start Sail @ 50.83° : 10107.55ft MD, 8292.07ft TVD 10200.00 50.826 327.477 0.06W 5964719.52 N 628882.98 E 0.000 4630.84 10300.00 50.826 327.477 2811.74 W 5964784.14 N 628840.16 E 0.000 4708.36 10392.50 50.826 327.477 2850.30 W 5964843.92 N 628800.55 E 0.000 4780.06 TJC 10400.00 50.826 327.477 2853.42 W 5964848.77 N 628797.34 E 0.000 4785.88 10500.00 50.826 327.477 2895.10 W 5964913.39 N 628754.52 E 0.000 4863.39 10598.30 50.826 327.477 3990.01 N 2936.07 W 5964976.92 N 628712.43 E 0.000 4939.60 TJB 10600.00 50.826 327.47 3991.12 N 2936.78 W 5964978.02 N 628711.70 E 0.000 4940.91 10700.00 50.826 327.47 4056.48 N 2978.46 W 5965042.64 N 628668.89 E 0.000 5018.43 10701.21 50.826 327.477 4057.27 N 2978.96 W 5965043.42 N 628668.37 E 0.000 5019.37 TJA 10800.00 50.826 327.477 4121.85 N 3020.14 W 5965107.27 N 628626.07 E 0.000 5095.95 10819.94 50.826 327.477 8665.00 8742.07 4134.88 N 3028.45 W 5965120.15 N 628617.53 E 0.000 5111.41 TSGR 10820.00 50.826 327.477 8665.04 8742.11 4134.92 N 3028.48 W 5965120.19 N 628617.50 E 0.000 5111.46 7" Csg Pt @ 10820.0' MD, 8742.11' TVD... Begin 6-1/8" Ho 7in Liner . 10883.26 50.826 327.477 8705.00 8782.07 4176.27 N 3054.84 W 5965161.08 N 628590.42 E 0.000 5160.50 TSHU 10900.00 50.826 327.477 8715.57 8792.64 4187.21 N 3061.82 W 5965171.89 N 628583.25 E 0.000 5173.47 10919.57 50.826 327.477 8727.93 8805.00 4200.00 N 3069.97 W 5965184.54 N 628574.87 E 0.000 5188.64 Begin Dir @ 12.0°/1000: 10919.57ft MD, 8805.01ft TVD 11000.00 60.436 326.380 8773.29 8850.36 4255.55 N 3106.19 W 5965239.44 N 628537.69 E 12.000 5254.94 11036.33 64.779 325.953 8790.00 8867.07 4282.34 N 3124.15 W 5965265.91 N 628519.26 E 12.000 5287.18 TSAD 11100.00 72.393 325.273 8813.23 8890.30 4331.21 N 3157.61 W 5965314.19 N 628484.95 E 12.000 5346.35 11200.00 84.356 324.306 8833.34 8910.41 4411.08N 3213.99 W 5965393.06 N 628427.17 E 12.000 5443.97 11201.65 84.553 324.290 8833.50 8910.57 4412.41 N 3214.95 W 5965394.38 N 628426.19 E 12.000 5445.60 End Dir, Start Sail @ 84.55° : 11201.65ft MD,8910.57ftTVD 30 August, 2004 - 21:36 Page 2 of 10 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Proposal Report for U-12A Recca - U-12A Wp 17 BP BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11300.00 84.553 324.290 8842.84 8919.91 4491.91 N 3272.10 W 5965472.86 N 0.000 5543.31 11400.00 84.553 324.290 8852.33 8929.40 4572.75 N 3330.20 W 5965552. 0.000 5642.65 11500.00 84.553 324.290 8861.82 8938.89 4653.58 N 3388.31 W 596~p3 0.000 5741.99 11600.00 84.553 324.290 8871.32 8948.39 4734.41 N 3446.41 W 59 0.000 5841.33 11700.00 84.553 324.290 8880.81 8957.88 4815.24 N 3504.51 W 5 0.000 5940.67 11799.22 84.553 324.290 8890.23 8967.30 4895.45 N 628070.56 E 0.000 6039.23 Begin Dir@ 6.00/10Oft: . 11799.22ft MD, 8967.3Oft TV 11800.00 84.598 324.280 8890.30 8967.37 4896.07 N 628070.10 E 6.000 6040.01 11820.24 85.780 324.000 8892.00 8969.07 4912.42 628058.00 E 6.000 6060.13 Target - U-12A T2B, Current Target 11900.00 86.360 319.238 8897.47 628007.52 E 6.000 6139.19 12000.00 87.121 313.277 8903.16 627937.27 E 6.000 6236.89 12022.86 87.300 311.915 8904.27 3709.63 W 5966035.52 N 627920.19 E 6.000 6258.90 End Dir, Start Sail @ 87.3° : 12022.86ft MD,8981.34ft TVD 12100.00 87.300 311.915 3766.97 W 5966085.98 N 627861.96 E 0.000 6332.94 12200.00 87.300 311.915 3841.30 W 5966151.39 N 627786.47 E 0.000 6428.92 12300.00 87.300 311.915 3915.63 W 5966216.81 N 627710.98 E 0.000 6524.90 12400.00 87.300 311.91 3989.96 W 5966282.22 N 627635.49 E 0.000 6620.88 12500.00 87.300 9003.82 5380.72 N 4064.29 W 5966347.64 N 627560.00 E 0.000 6716.85 12573.44 87.300 9007.28 5429.72 N 4118.88W 5966395.68 N 627504.57 E 0.000 6787.34 Begin Dir @ 6.00/10Oft: 12573.44ft MD, 9007.28ft TVD 12600.00 87.381 313.509 8931.44 9008.51 5447.72 N 4138.38 W 5966413.33 N 627484.76 E 6.000 6812.93 12700.00 87.704 319.506 8935.73 9012.80 5520.16 N 4207.11 W 5966484.56 N 627414.77 E 6.000 6910.79 12800.00 88.053 325.500 8939.44 9016.51 5599.41 N 4267.91 W 5966562.73 N 627352.59 E 6.000 7010.22 12900.00 88.422 331.491 8942.52 9019.59 5684.59 N 4320.12 W 5966646.99 N 627298.89 E 6.000 7110.12 . 13000.00 88.809 337.480 8944.94 9022.01 5774.77 N 4363.16 W 5966736.40 N 627254.28 E 6.000 7209.41 13100.00 89.209 343.468 8946.67 9023.74 5868.97 N 4396.56 W 5966829.99 N 627219.23 E 6.000 7306.99 13200.00 89.618 349.454 8947.69 9024.76 5966.14 N 4419.96 W 5966926.74 N 627194.13 E 6.000 7401.79 13292.64 90.000 355.000 8948.00 9025.07 6057.89 N 4432.48 W 5967018.26 N 627180.00 E 6.000 7486.24 Target - U-12A T4D, Current Target 13300.00 90.326 355.297 8947.98 9025.05 6065.22 N 4433.11 W 5967025.58 N 627179.25 E 6.000 7492.79 13400.00 94.758 359.346 8943.54 9020.61 6164.97 N 4437.78 W 5967125.23 N 627172.83 E 6.000 7579.85 13500.00 99.166 3.448 8931.42 9008.49 6264.16 N 4435.37 W 5967224.44 N 627173.49 E 6.000 7662.70 13513.93 99.777 4.027 8929.13 9006.20 6277.87 N 4434.48 W 5967238.17 N 627174.15 E 6.000 7673.85 End Dir, Start Sail @ 99.78° : 13513.93ft MD, 9006.20ft TVD 13600.00 99.777 4.027 8914.51 8991.58 6362.48 N 4428.52 W 5967322.87 N 627178.62 E 0.000 7742.45 30 August, 2004 - 21 :36 Page 3 of 10 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Proposal Report for U-12A Recca - U-12A Wp 17 BP North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azlm. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 13626.56 99.777 4.027 8910.00 8987.07 6388.58 N 4426.69 W 13689.73 101.711 2.370 8898.22 8975.29 13700.00 101.711 2.370 8896.14 8973.21 13800.00 101.711 2.370 8875.84 8952.91 13900.00 101.711 2.370 8855.54 8932.61 14000.00 101.711 2.370 8835.25 14100.00 101.711 2.370 8814.95 14200.00 101.711 2.370 8794.65 14300.00 101.711 2.370 8774.36 14400.00 101.711 2.370 8754.06 14444.60 101.711 2.370 14444.64 101.711 6450.54 N 4423.22 W 6460.60 N 6558.43 N 6656.27 N 4392.65 W 7189.11 N 4392.65 W All data is in Feet (US Survey) unless ted. Directions and coordinates are relative to True North. Vertical depths are relative to Well. N Eastings are relative to Well. 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 and calculated along an Azimuth of 328.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14444.64ft., The Bottom Hole Displacement is 8424.88ft., in the Direction of 328.574° (True). BPXA Global Coordinates Dogleg Vertical Northings Eastings Rate Section Comment (ft) (O/10Oft) 62 0.000 7763.61 Begin Dir@4.0000/100fl: 13626.56ft MD, 8987.07ft TVD Target- U-12A T5A, Current 'i'$79' Target 627182.38 E 4.000 7814.32 End Dir, Start Sail @ 101.71°: 627182.62 E 0.000 7822.62 13689.73ft MD, 8975.200 TV. 627184.95 E 0.000 7903.45 627187.29 E 0.000 7984.27 967714.74 N 627189.62 E 0.000 8065.09 5967812.63 N 627191.96 E 0.000 8145.91 5967910.52 N 627194.29 E 0.000 8226.74 5968008.41 N 627196.62 E 0.000 8307.56 5968106.30 N 627198.96 E 0.000 8388.38 5968149.96 N 627200.00 E 0.000 8424.43 Total Depth: 14444.600 MD, 8822.08ft TVD 5968150.00 N 627200.00 E 0.000 8424.46 4 1/2in Liner Target - U-12A T6, Current TargE . 30 August, 2004 - 21:36 Page 4 of 10 DrillQuest 3.03.06.006 BP North Slope Alaska Comments Measured Depth (ft) 9924.00 9944.00 10107.55 10820.00 10919.57 11201.65 11799.22 12022.86 12573.44 13513.93 13626.56 13689.73 14444.60 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8167.16 8181.76 8292.07 8742.11 8805.01 8910.57 8967.30 8981.34 9007.28 9006.20 8987.07 8975.29 8822.08 3555.68 N 3567.27 N 3669.22 N 4134.92 N 4200.00 N 2659.82 W 2667.06 W 2731.53 W 3028.48 W 3069.98 W Halliburton Sperry-Sun Proposal Report for U-12A Reeca - U-12A Wp 17 Comment Assume 12.0°/1000 DLS across PU Dir tools and Be' O' End Dir, Start Sail O. 7" Csg Pt @ Begin . Csg : 9924.000 MD, 8167.16ft TVD : 9944.000 MD, 8181.76ft TVD , 8292.07ft TVD TVD ... Begin 6-1/8" Hole ft MD, 8805.01ft TVD 4412.42 N 4895.44 N 5062.32 N 5429.72 N 6277.87 N End Dir, S 01.65ft MD,8910.57ftTVD n Dir@ 000 : 11799.22ft MD, 8967.300 TVD ir, Start @ 87.3° : 12022.86ft MO,8981.34ft TVD 'r@ 6.0°/1000: 12573.44ft MD, 9007.28ft TVD ,Start Sail @99.78° : 13513.93ft MD, 9006.2OOTVO Begin Dir@4.0000/10OO: 13626.56ft MD, 8987.07ft TVD End Dir, Start Sail@ 101.71° : 13689.73ft MD, 8975.200 TVD Total Depth: 14444.600 MD, 8822.0Bft TVD Formation Toos Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Dip Up-Dip Formation Name (ft) (ft) (ft) (ft) (ft) Angle Dirn. 8428.67 7127.07 7050.00 2681.96 N 2037.27 W 0.000 0.000 BHRZ 9382.29 7777.07 7700.00 3244.67 N 2449.17 W 0.000 0.000 TJF 9636.93 7957.07 7880.00 3392.15 N 2552.56 W 0.000 0.000 TJE 9923.88 8167.07 8090.00 3555.61 N 2659.78 W 0.000 0.000 TJD 10392.50 8472.07 8395.00 3855.48 N 2850.30 W 0.000 0.000 TJC 10598.30 8602.07 8525.00 3990.01 N 2936.07 W 0.000 0.000 TJB 10701.21 8667.07 8590.00 4057.27 N 2978.96 W 0.000 0.000 TJA 10819.94 8742.07 8665.00 4134.88 N 3028.45 W 0.000 0.000 TSGR 10883.26 8782.07 8705.00 4176.27 N 3054.84 W 0.000 0.000 TSHU 11036.33 8867.07 8790.00 4282.34 N 3124.15W 0.000 0.000 TSAD BPXA . . 30 August, 2004 - 21 :36 DrillQuest 3.03.06.006 Page 5 of 10 U-12A Cont.gency ComplEØon 13-318" CSG, 72#, 1 I L-80, D= 12.347" , 2,700' 7",26#, L-80, BTC-M scab liner 95/8" w hip stock set on bridge plug. I TOP OF 7" LNR H 10415' I I Top of Cement H 10,503' 95/8",47#, L-80, Csg D = 8.681" Î 10680' I 7",26#, U4S. Lnr D = 6.276" 111280' I DATE 08/30/85 02105101 03/08/01 11/02101 11/05/02 08/30/04 REV BY COflMÆNTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS PPITP SQZ PERF CHANGE, TOC dew lJ-12A Contingency Wp17 DATE 2,200' H 3 1/2" 'X' landing nipple, D = 2.813" I I 2,850' I 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr w ith TBS ST MD 4 TBD 3 TBD 2 TBD 1 TBD GAS LFT MANDRELS DEV TYÆ 3 1/2" X 1 1/2" MMG 31/2" X 1 1/2" MMG 31/2" X 1 1/2" MMG 31/2" X 1 1/2" MMG VALVE [)my DCR [)my [)my ND TBD TBD TBD TBD ~ 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr w ith TBS TREE = WB..LHEAD = ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD - Datum ND = CAfÆRON 4" AXB..SON 77.42' 48.57' 3100' 49 @ 7000' 10904' 8800' SS LATCH RK RK RK RK 10,600' H3 1/2" 'X'landing nipple, D = 2.813" I 10,620' Hr X 41/2" Baker 5-3 packer I 10,640' H31/2" 'X'landing nipple, D= 2,813" I 10,660' H31/2" 'XN' Iandin9 nipple. D = 2.75" I 10,665' H31/2", 9.2#, 13Cr-80, VAMACE 7" X 5" Baker HMC Lnr hngr and ZXP pkr w ith TBS I 10,820' Hr. 26#. L-80 BTC-M Drlg liner I I 14,445' H4 1/2", 12.6#, L-80. IBT-M solid liner I REV BY COMMENTS PRUDHOE BA Y UNff WB..L: lJ-12A PERMIT No: 1851820 API No: 50-029-21409-01 SEC 18, T11N, R13E BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 J\nchorage,AJ( 99519 Re: Prudhoe Bay Unit U12A BP Exploration (Alaska), Inc. Pennit No: 204-147 Surface Location: 463' NSL, 2276' WEL, Sec. 18, TIIN, R13E, UM Bottomhole Location: 2371' NSL, 1724' WEL, Sec. 12, TIIN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). BY ORDER q~. THE COMMISSION DATED this-7 day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. VJ6Æ- 8(9{¿L104- STATE OF ALASKA ALASKA_AND GAS CONSERVATION CO_ISSION PERMIT TO DRILL 20 MC 25.005 / 1 a. Type of work o Drill II Redrill 1b. Current Well Class o Exploratory III Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: ØI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU U-12A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14299 TVD 8822 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028260 463' NSL, 2276' WEL, SEC. 18, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 95' NSL, 905' WEL, SEC. 12, T11N, R12E, UM August25,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2371' NSL, 1724' WEL, SEC. 12, T11N, R12E, UM 2560 21,345' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: X-631718 y- 5961039 Zone- ASP4 (Height above GL): 77.07' feet N-11 is 632' away at 12703' MD 16. Deviated Wells: Kickoff Depth: 10725 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 101 ~ Downhole: 3200 Surface: 2320 1~J~aSing -~.~.,.. ,,; i, ~~ Size .",,p ,;,.". ··R.nt,.......,,",", Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD, TVD~ ".f ina staae dat~) , NIA 7" 26# L-80 BTC-M 7565' 2850' 2850' 10415 8520 " "", ' tP2 cu ft G 6-1/8" 4-112" 12.6# L-80 IBT-M 4099' 10200' 8370' 14299' 8822' 561 cu ft Class 'G [j i ¡.'. l) ,.. ~ ". '.' . "þ:ff .. ,- .19. ARESENTWELL' COND'ælø""'~I.)MMAR¥(æ!?l:)ecOrrip'eted"forR~a"Q'~""'PR~è_·"'I..OIn.>-';', -, Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 11280 9142 10503 10503 8589 11090 ; i;; ;; is· ;: ;'i';-;;';; ,; :';;' ii'i'J\4U'ii' ¡.' ;;,;;";: ~ ConnlJctor 110' 20" x 30" 8 cu vds Concrete 110' 110' Surface 2674' 13-3/8" 3719 cu ft CS III & II 2674' 2674' IntArmAni~tA 10680' 9-5/8" 2056 cu ft Class 'G', 230 cu ft Class 'G' 10680' 8717' Production LinAr 865' 7" 290 cu ft Class 'G' 10415' - 11280' 8525' - 9142' Perforation Depth MD (ft): None - Below Cement Plug perfOration Depth TVD (ft): NIA 20. Attachments 1&1 Filing Fee, $100 o BOP Sketch Ia Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IS Drilling Fluid Program a 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 pill Isaacson Title Senior Drilling Engineer r I~. A ejSjOi Prepared By Name/Number: Signature Ncioo Phone 564-5521 Date Terrie Hubble, 564-4628 ¡;;;;i;; :·,ii"':·..·..;i ii;S i..;i;';;;:;;, ;.;; '.": i',,;;;,';:;: ;i,.;; /';; ; ;W;:i;',:;;,/,.; PermitTo Drill¡ÿ:. I API Number: Permit Approval See cover letter for Number: <t:J . -- /4 ? 50- 029-21409-01-00 Date: other requirements Conditions of Approval: Samples Required DYes %No Mud Log Required 0 Yes ~ No ~Measu'es ?;es DNo Directi~nal Su~ey .ReqUire:d. )8Yes D.NO~, J Other: T£st ßrP, F ,"5 0 ?~t' J pil.l" ,0. 'S j Ie. C'CO ~v t I't '"1 V'fH' ~l <"...fi ~I.£. (\..( f YL Ve L,,",A ~ 0 40. . Pev Z-o Z.S~ (I)) tllt-~-v'Vl",-te BePG is CV{) p tv ved ' Date 'Øj' 9 ktf ADDroved iv:T ~¢ U APPROVED BY " ,-" f"' t 1\ I ^ , THE COMMISSION Form 10-401 R~ 06:ztrð~ \.---- l} 1'\ ~ Q t 1 \\ t"\ J.... ßuôr¢"t In Duplicate It e I Well Name: I Well U-12A U-12A Planned Well Summary I Target Objective Horizontal Sidetrack Zone 48 I AFE Number: I PSD 4P2263 I I API Number: 50-029-21409-01 Suñace Location Offsets TRS 463' FSL / 2,276' FEL 11N,13E,18 /' Offsets TRS 95' FSL / 905' FEL 11 N, 12 E, 12 ~ Offsets TRS 2,371' FSL /1,724' FEL 11 N, 12 E, 12 / 1 Planned TD: 114,299' md Target Location Bottom Location I Planned KOP: 110,725' md I Rig: I Nabors 7ES I / Maximum Hole Inclination: Proximity Issues: U-12A Sidetrack I BFE: I 48.57' I RTE: I 77.07' Directional Proaram W 12 Exit oint: 10,725' md /8,672' sstvd -50.0° at 7,000' in the original well bore, -101.0° in the planned 6 1/8" roduction section from 13,550' md to TD at 14,299' md. There are four close approach issues in drilling U-12A. Well N-11 has a center-to-center distance of 632 feet at 12,703'md, Well U-01 has a center-to-center distance of 1,212 feet at 10,730'md, Well U-02A PB1 has a center-to-center distance of 419 feet at 10,993'md, Well U-02A has a center-to-center distance of 852 feet at 10,758'md. These four wells require 1 :200 Minor Risk based criteria. All other surrounding wells pass ma'or risk criteria. Standard MWD with IIFR / Cassandra. Well N-11, with center-to-center distance of -632' at 12,703' md. 21,345' to the nearest PBU ro e line. Page 1 e e LOQQinq Proqram Hole Section: Required Sensors I Service 6 1/8" production: Real time MWD Dir/GR/Res throuqhout the interval. Two sample catchers Cased Hole: None planned Open Hole: None planned Mud Proqram Set Whi PV YP 10-15 40+ PV 8-12 Casinq I Tubinq Proqram Hole CasinglTubing Wt. Gra~ Connectioy Length Top Bottom Size Size md I tvd md 1 tvd 8.681" 7" scab 26.0# L-80 BTC-M 7,565 2,850' I 2,850' 10,415 I 8,520' 61/8" 4 Y2" 12.6# L-80 IBT-M 4,099' 10,200 I 8,370' 14,299 I 8,822' Tubina 3 Y2" 9.2# 13Cr-80 V AM ACE 10,200' Su rface 10,200 I 8,370' Cementinq PrOqram 7",26#, L-80, BTC-M scab liner Lead slurry: -6,565' of 7" X 9 5/8" annulus, plus 100' of 9 5/8" X 4" drill pipe Slurry Design Basis: annulus. Tail slur : 1,000' of 7" X 9 5/8" annulus, Ius 42' of 7", 26.0#, shoe track. Pre-Flush -100bbls fresh water s acer S acer 25bbls MudPUSH Fluids Sequence I Volume: Lead Slur 174.0bbl I 977 cf Tail Slur 27.0bbl 1152 cf!. Slurry Design Basis: Fluids Sequence 1 Volume: U-12A Sidetrack Page 2 Test 9 5/8" casin 9 5/8" casin I 7" liner 7" liner window 4 Y2" roduction liner e e Casina I Formation Intearity Testina Test Point Test Type 30 min recorded 30 min recorded FIT 30 min recorded Test pressure 3,500 si surface 3,500 si surface 10.5 EMW 3,500 si surface Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blindlshear 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. Well Interval: Maximum antici ated BHP: Maximum suñace ressure: Calculated kick tolerance: Planned BOPE test ressure: BOPE configuration for 7" drilling liner" s~ p. S- V..JCr,t- Disposal No annular in'ection 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. Annular In"ection: Cuttings Handling: Fluid Handling: U-12A Sidetrack Page 3 e e Geoloaic Proanosis Formation MD TVDbkb TVDss Comments SV1 Above Kick off point UG4 Above Kick off point UG4A Above Kick off point UG3 Above Kick off point UG1 Above Kick off point WS2 Above Kick off point WS1 Above Kick off point CM3 Above Kick off point CM2 Above Kick off point CM1 Above Kick off point THRZ Above Kick off point BHRZ 7,050 Above Kick off point LCU TKNG TJG TJF 7,700 TJE 7,880 TJD 8,090 TJC 8,395 TJB 8,525 TJA 8,590 TSGR 8,665 TSHU 8,705 TSAD/TZ4B 8,790 -3,200psi (7.0ooo EMW) ,/ TSAD in Graben 8,910 TSAD at toe 8,735 THaT 8,965 TCGL/TZ3 Below olanned well oath TD Criteria TD Criteria: In North fault block, cut enough section to determine LaC. If oil saturation is high, flatten the tra'ecto and extend u to 500', toein u to to of Z4. Fault Proanosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 Z4B 11,965' -8,900' -130' U/D North +/- 220' Fault #2 Z4B 13,145' -8,949' -180' DIU South +1- 220' U-12A Sidetrack Page 4 e e Qperations Summary Pre-Ria ODerations: 1. Tubing has failed an MIT-T and Tubing X IA failed a CMIT in 7/2003. 2. Drift the 4 %" tubing to the top of the 2 7/8" liner patch at -10, 114'md to confirm clear for upcoming chemical cut. 3. RIU E-line. RIH with the appropriate chemical cutter and cut the 4 W' tubing at -10,1 OO'md. 4. Displace the well to weighted brine, as necessary to balance, by circulating down the tubing through the tubing cut. Continue to circulate until clean brine returns to surface. Freeze protect to -2,200' MD with diesel. 5. Function all 9 5/8" casing and tubing Lock Down Screws; repair or replace as needed. Both the 9 5/8" pack-off and the tubing spool will be changed out during the work-over. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV. Secure the well. Level the pad as necessary. Ria ODerations: 1. Mil RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to weighted brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 4. RIU. Pull the 4%" tubing from the cut at -10,100' MD and above. 5. M/U an overshot I grapple fishing assembly. RIH and OIS the 4 %" tubing stub. Jar the tubing OIS seal assembly free. POOH and UD the 4 %" tubing fish and the internal 2 7/8" tubing patch. Alternatively, may elect to attempt to rotate the entire tubing stub and latchlanchor free, if the seal assembly will not straight pull free. 6. If necessary, M/U an OIS I grapple fishing assembly. RIH to the latch/anchor. Overshot the anchor and rotate it free. POOH. 7. M/U a Baker 9 5/8" PRT I milling assembly. RIH to the TIW HBBP packer. Mill the packer free and recover the packer and tubing tail pipe. 8. M/U a 7" liner top polishing mill assembly. RIH to the existing 7" drilling liner top and polish I clean the liner top in preparation for running the 7" scab liner seal assembly. 9. POOH to approximately 4,OOO'md. M/U a HES 9 5/8" RTTS. Set the RTTS -15' below the wellhead. 10. N/D the BOPE and the tubing spool. Change out the 9 5/8" casing slips seal. 11. N/U a new tubing spool with the new YB pack-off installed. 12. N/U and test the BOPE. 13. Run back in the hole with the RTTS. Set the RTTS at -3,OOO'md. The scab liner will be run to approximately 2,850'md. 14. Confirm 95/8" casing integrity above this point by pressure-testing the casing to surface to 3,500psi for 30 minutes. Record test. POOH with RTTS. UD polishing mill assembly. 15. RIU to run and cement -7,560' of 7" scab liner, sufficient to extend from the top of the 7" drilling liner to -2,850'md. POOH and UD the liner running tool. 16. M/U a 6 1/8" clean out assembly. RIH to the float equipment. Test the 9 5/8" X 7" scab liner to 3,500psi for 30 minutes. Record the test. 17. Drill out the float equipment. RIH to tag at the P&A cement plug in the 7" drilling liner. 18. Clean out cement down to 10,750'md. Circulate well clean. 19. Displace the well to 8.5ppg Flo-Pro based milling fluid. POOH and UD CIO assembly. 20. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on the cement lu . Shear off of whi stock. TM S (0 - 4-0 ( ,!-..ppro(/~ L 21. Mill window in 7" liner at ± 10,730'md, plus approximately 20' beyond middle of window. Circulate the well bore clean. 22. Pull up into 7" liner and attempt an FIT to 10.0ppg EMW. POOH. / 23. M/U a 6 1/8" Dir/GRlRes/ABI drilling assembly. RIH to the window. 24. Directionally drill section per directional proposal. Circulate well bore clean, short trip to the 7" window. Circulate. POOH. U-12A Sidetrack Page 5 e e 25. Run and cement a 4 %,', 12.6#, L-80 solid production liner, extending the liner lap to -10,200'md. / POOH. 26. After sufficient WOC time, pressure test the 4 %" liner to 3,500psi for 30 minutes. Record the test. 27. P/U and RIH with Schlumberger 2 %" tcp perforating guns. Perforate approximately 1,400' of 24 // interval, per subsurface team. POOH. 28. RIU and run a 3 1/2", 9.2#, 13Cr-80, VAM ACE completion, stinging into the 4 1/2" liner tie back /~ sleeve. 29. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 30. Install a TWC. / 31. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 32. Freeze protect the well to -2,200'. Install BPV. Secure the well. 33. Rig down and move off. Post-Ria Operations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 08/10/04 Estimated Spud Date: 08/25/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 U-12A Sidetrack Page 6 e e Phase 1: Move In I Ria UP I Test BOPE Planned Phase Time 21 hours Planned Phase Cost $54,811 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 U-12. However, U-05 is 55.0' to the North, and U-04 is 55.0' 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 U-12 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, brine, and a BPV. o IA: the P&A cement plug, Annulus valves and brine. o OA: Annulus valve and kill weight fluid. OA tested to 2,400psi on 10/21/2003. ~ Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. ~ The 9 518" casing probably has a leak at -5,300'md. The liquid leak rate, with crude, is - 3.0bpm at -2,850psi. ~ During ND/NU BOPE operations, the U-12 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, brine, and a TWC. o IA: the P&A cement plug, Annulus valves and brine. o OA: Annulus valve and kill weight fluid. OA tested to 2,400psi on 10/21/2003. ~ U-Pad is designated as an H2S site. Standard Operating Procedures for H2S precautions should be follõWêëi 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 U-04A Injector U-02A 50ppm U-05 Injector U-04A Injector The maximum level recorded of H2S on the pad was 120ppm, in 07/2003. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud U-12A Sidetrack Page 7 e e Phase 2: De-comDlete Well Planned Phase Time 137 hours Planned Phase Cost $429,182 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 a McEvoy Split Speed Head (SSH). The tubing hanger is a 12" X 4 1/2 McEvoy (5) seal hanger, with 41/2" Buttress lifting thread. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. > There is a 4Y2" Ball Valve landing nipple with dual control lines. No records were found regarding the type and quantity of securing bands used in running the control lines. > The 9 5/8" TIW HBBP packer will be milled free and recovered. Be prepared for any trapped gas, from below the packer, as it migrates to surface. > During ND/NU operations to change the 9 518" pack-off, the U-12 well bore will be secured with the following barriers: o IC: the P&A cement plug, and an RTTS. o OA: Kill weight fluid. OA (9 5/8" X 133/8") down squeezed with 300 sks Cold-Set cement on 8/27/1985. Tested to 2,400psi on 10/21/2003. > After de-completing the well, a 7" scab liner will be run and cemented from the existing 7" liner top at 10,415'md to -2,850'md. Phase 3: Run WhiD Stock Planned Phase Time 35 hours Planned Phase Cost $240,112 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards > After running and cementing the 7" scab, a 7" whip stock will be run and set in the existing production liner. > According to the initial cementing report, there should be cement behind the 7" 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. U-12A Sidetrack Page 8 e e Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 216 hours Planned Phase Cost $1,208,996 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ Near well, N-11 experienced losses during drilling operations. N-11 lost SOObbls in the Sag River. 60bbls while drilling Zone 4, and 440bbls while drilling Zone 2. These losses were associated with penetration of a fault. The trajectory of the U-12A will not penetrate this fault, and will remain in Zone 4. ~ The parent well, U-12, experienced no lost circulation events during drilling operations. ~ The planned well, U-12A, will cross a Graben fault in Zone 4. As outlined earlier, the expected throw is -130' at the first encounter, and -180' at the second encounter. Be prepared with adequate Lost Circulation Material. Phase 9: Run 4%" Production Liner Planned Phase Time 37 hours Planned Phase Cost $27S,386 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a4 %", 12.6#, L-80 solid liner throughout the production 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 %" liner will be run to extend -S2S' back up into the 7" liner, above the original 7" liner top. ~ Ensure the 4 %" liner top packer is set prior to POOH. Phase 1 0: DPC Perforate Planned Phase Time 39 hours Planned Phase Cost $381 ,60S U-12A Sidetrack Page 9 e e Reference RP .:. "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards ~ The well will be DPC perforated, -600psi overbalanced, after running the 4 W' liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities 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 3 %" 13Cr-80 Completion Planned Phase Time 30 hours Planned Phase Cost $497,112 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" 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 3Yz", 9.2#, 13Cr-80, VAM ACE production tubing string, stinging into the 4 Yz" liner tieback sleeve. ~ Cross over to a 4 Yz" WLEG to ensure the tubing tail is properly spaced and landed in the liner top tie back sleeve. Phase 13: ND/NU/Release Ria Planned Phase Time 15 hours Planned Phase Cost $50,651 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto U-12. However, U-05 is 55.0' to the North, and U-04 is 55.0' 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. U-12A Sidetrack Page 10 aOST THIS NOTICE IN THE DOGHOUa U-12A 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 120 ppm, measured in July 2003. ./' NORM test all retrieved well head and completion equipment. ./' Three wells, N-11, U-01, and U-02, fail to pass major risk criteria. These wells encroach the area of allowable separation within the reservoir. Each of these wells is currently shut in. ./' The closest neighboring wells, at surface, are U-04 and U-05. Well U-05 is approximately 55' to the North. Well U-04 is approximately 55' to the South. No shut-in should be required, but care should be taken during rig MIRU and ROMO. Use spotters as necessary. ./' The well will cross a Graben, faulted area, during the drilling of the production interval of U-12A. Significant losses are possible, so due preparation is prudent. ./' The only fault related losses, in the surrounding area, occurred during the drilling of N-11. The planned well trajectory of U-12A does not encounter this particular event, but again, due diligence is warranted. The lost circulation decision tree should be followed if lost fluid returns are encountered. ./' 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 U-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. U-12A U-12 ~ Rig / 13-3f8" CSG, 72#, 1 I L-80, 10= 12.347" . 2,700' e . 2129' H 4-1 f2" OTIS X SSSV NIP, ID = 3.813" I TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = GAS LIFT MANDRELS ST MD TVO DEV TYÆ VLV LATCH PORT DATE 5 3605 3506 21 OTIS DOME RA 16 07/96 Potential 9 5f8" 1 -5,300' I 4 6293 5556 45 OTIS DOME RA 16 07/96 casing leak 3 8493 7096 45 OTIS DOME RA 16 07/96 2 9876 8054 43 OTIS SO RA 16 07/96 1 10173 8273 44 OTIS PATCH RA Potential 9 5f8" casing leak Top of 2 7/8" Tubing HES RCP Packer, 1.0. = 2.390" 1 -8,980' I 10114' 10114' Min.ID = 2.313 @ 10297' 2-7/8" X NIPPLE I TOP OF 7" LNR H 10415' I I Top of Cement H 10,503' 95/8",47#, L-80, 110680' Csg 10 = 8.681" . 7",26#, U4S, Lnr ID = 6.276" DATE 08/30/85 02l05fO 1 03/08/01 11/02101 11 f05f02 07/26/04 111280' I -I -10,100' HPre rig tubing cut REV BY COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS PPfTP SQZ ÆRF CHANGE, TOC dew lJ-12 Pre rig condition DATE I 10277' HoTlS SLIDING SLEEVE, ID = 3.813" 10297' H2-7/8" OTIS X NIP, ID = 2.313" I 10309' H2-7/8" WLEG, 10 = 2.441" I 10397' H4-1/2" OTIS X NIP, 10 = 3.813" I 10429' H4-1/2" OTIS XN NIP, 10 = 3.725" I 10429' H2-7f8" REDUCING X NIP, ID = 2.313" I 10466' H4-1/2" TBG TAIL (BOT SOS), ID = 3.958" I 10443' HELMDlTLOGGED07/26/92 ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/24/85 ANGLE AT TOP ÆRF: 45 @10716' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10716 - 10720 S 01/17/99 3-3/8" 6 10720 - 10750 S 01f17/99 3-3/8" 6 10750 - 10758 S 01/17/99 3-3/8" 6 10883 - 10884 S 01/17/99 3-318" 6 10884 - 10924 S 01/17/99 3-3/8" 6 11002 - 11102 S 01f17/99 REV BY COMMENTS PRUDHOE BA Y UNIT WELL: lJ-12 ÆRMIT No: 1851820 API No: 50-029-21409-00 SEC 18, T11N, R13E BP Exploration (Alaska) CAMERON 4" AXELSON 77.42' 48.57' 3100' 49 @ 7000' 10904' 8800' SS U-12A Prope>eed Completio'- 13-3/8" CSG, 72#, 1 I L-80. ID= 12.347" , 2,700' / 7",26#, L-80, 1 -10,412' I BTG-M scab liner TOP OF 7" LNR H 10415' I 95/8",47#, L-80, Î Csg ID = 8.681" , 1 H 10680' 7" w hip stock set on cement plug. Top of Cement -10,730' 10,750' 7",26#, U4S, Lnr 1 11280' I ID = 6.276" , , DATE 08/30/85 02/05/01 03/08/01 11/02101 11/05/02 07/26/04 2,200' H3 1/2" 'X' landing nipple, ID = 2.813" I ~ 9 5/8" X 7" Baker HMC Lnr hngr and ZXP pkr with TBS VALVE Dmy OCR Dmy Dmy TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = LA TCH RK RK RK RK CAMERON 4" AXELSON 77.42' 48.57' 3100' 49 @ 7000' 10904' 8800' SS REV BY COMMENTS ORIGINAL COMA...El1ON SIS-QAA CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS PPfTP SOl ÆRF CHANGE, TOC dew U-12A Wp12 A"oposed c0lT1>. DATE ST MD 4 TBD 3 TBD 2 TBD 1 TBD GAS LIFT MANDR8...S DEV TY Æ 31/2" X 1 1/2" MMG 31/2" X 1 1/2" MMG 3 1/2" X 1 1/2" MMG 31/2" X 1 1/2" MMG lVD TBD TBD TBD TBD 10,130' H3 1/2" 'X' landing nipple, ID = 2.813" 10,150' H 7" X 4 1/2" Baker S-3 packer 10,170' H3 1/2" 'X' landing nipple, ID = 2.813" 10,190' H 3 1/2" 'XN' landing nipple, ID = 2.725" 10,195' I-P 1/2", 9.2#, 13Cr-80, VAMACE ~ 7" X 5" Baker HMC Lnr hngr and L.:::=-.J ZXP pkr with TBS o 0 0 0 o 0 0 0 14,300' H4 1/2", 12.6#, L-80, IBT-M solid liner r REV BY COMMENTS PRUDHOE BA Y UNIT WELL: U-12A ÆRMIT No: 1851820 API No: 50-029-21409-01 SEC 18, T11N, R13E BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMA nON SURVEY PROGR:\M Plan: U+12A ""'p!2 (U+!2/PJan U~!2A) BP Amoco Depth Fm Depth To Survey/PIa.n Tool Created By: Digital BusÎnes¡¡ CHen! User Date: 8/2/2004 M_. 10125.00 14298Æ¡ Planned: U-I2A ",,-pJ2 V79 MWD+!FR-MS IE~;E ISeWSA , 48.57+28.5 77.fJ7 Checked: Date:~ Reviewed; Date: "'. ",I",e,,,,,, WELL DETAILS FORMA nON TOP DETAILS N~ -WI...'; I-g/·W Northing Eaiiting Latitude Longitude Slot U-12 478.16 154857 5961039.00 63J11ß.00 70"18'05.872N !48º55'59.I66W 12 No. TVDPath MDPath Fonnation No formation top details fall on the wellpath. TARGET DETAILS NIU1J< TVD +N/-S +E/-W Northîng Easting Shape 7189.69 m~:~~ :~: ~~ 4190.00 ¡ Ii Ii j Ii : 4190.00 ¡~~f~~ ::: . . 4912.81 .. , 6382.65 ill~~? :~: 650 :~ 6050.01 Õ I i : J i . ' i . : ¡ 5708.89 ¡~¡ SECTION DETAILS Sec MD Ine Azi TVD +N/-S +FJ-W DLeg TF ace VSe~ Target I , i ¡g;: 1 : :)' ! : I · ~ ¡g~ .; ¡ ì i U-12AT! 700 I ! . ¿ I iil { -I, ; ¡ ¡; U-12A T2 B , 9 : ci 10 4 -~~ U-12A T3 B II ci 12 -3~ 13 g 4 !:~, U-I2A T4 C 14 ó: -ó. I i . . . 15 IÒ U-12A T5 16 :: ó: -5Ö: U: 750 I J I . l 17 ¡Õ ¡.07 8 U-12A T6 " !J 17 ~ . T ; ii! ] , I j ¡ CASING DETAILS <::> AI ~ '¡ iI indD No. TVD MD Name Size fJ I '" 1 8822.19 14298.00 4-1/2" 4.500 " / '/ E Id Oi, , 0 ¡ . 1/'1· / I -¡¡¡ " \i . ' V 7 12 " 800 L i II 7 , ! . , .J ....... , > ..... " . 1/ V T· ;:: I VD I, . f-< / Iii, ..., , ! " il! i ..... ....T..! , :; ¡ ·v : .+ . . + J 'f ' ; ! T I + ¡'\ , ; ill t r iT IT I it ¡. Ai " , .....;........ T , r ,,; ./ i! .... ........ ., '.' , , I 'I Ii 1 I ! , 850" " L I ..i T r IIi I 1 Ii . . . I . 1+· . , f! il II II .. " ~. if' iI 1-- , p+ I..... " i . ....,. , !12" 900 , --;' , >I> , I '\\ ¡ ; I 1 i . ; ¡ 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 Vertical Section at 328.57° [500ft/in] COMPANY DETAILS REFERENCE INFORMA TJON SURVEY PRiXiRAM Plan: U·12A wp!2 (U-I2íPJan U-12M BP Amoco ,I"'''"",, Depfh Pm Depth To Survey/Plan Tool Create{. By: Digital Business CJient User Date: 8/2/2004 10125.00 14298.61 Planaoo: U-!2A. wpl2 V79 MWDo-IFR-+MS Checked: Date: Eom Sy~""" ¡SCWSA '~'57c285 n07 \VELL DETAILS Name +N/-S ->-EÎ-W Northing &sting Lati1ude Longil:1Jde Slot U·!2 418.16 1548.57 5%1039JJO 631718.00 7(f'18'05.872N 14&<'55'59.!66W 12 ! TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape if ìA' 1T~'1 :ATI I U-I2A T6 8822.07 718969 -4 '~.' 5968150.01 627200,00 Point ''\ / th De ~*J7'T{I , , U-12A Tl 8867.07 419000 -3 '5.1 5965174.48 628590.27 Point ..." 1\ \~ , : U-12A TIll 8867.07 4190.00 -35.1 5965174.48 628590.27 Point i4- U-12A T2 II 8969.07 4912.81 -34'- 5965888.01 628058.00 Point \ U-12A T5 8987.07 638265 :j '9.1 5967349.01 627548.00 Point U-12A T4 C 9025.07 6050015.1 5967018.27 627657.88 Point \ U-12A T3 II 9029.07 5708.89 -3 3.1 5966679.01 627765.00 Point J SECTION DETAILS !\!j E1id JII Sec MD Ine AzI TVD +N/-S +EI-W DLeg TFace VSee Target Ov K ; i ¡g ~ :f· ¿~ j I¡:ã :~~~~: 0.00 12.00 :r V 3 ¡~: !6 13.00 1 i1 : ~:gg -I, U-12A TI -'k ~ Fic!DI' : ~ ¡ 0.00 4.00 U-12A T2 II IU~ ~ ¡ 4.00 S ; 0.00 . , . ! lOi 4.00 -< U-12A T3 II II ¡ 4.00 ~ ow \ , ! ~:gg -3 L... E,id ~¡, . ¡~ i ¡:Ú fj~r U-12A T4C ; 14 ¡ : :~: ç ~: :!~ ).ù 4,00 / 15 I~ , 0.00 U-12A T5 ~ /S :~ m :~: ~:; n~ :13 1.9 4.00 -5Õ:; mL II 10 , 0.00 U-12A T6 . K . :J FORMATION TOP DETAILS . T ; ....... ; H No. TVDPaih MDPath Formation .w .. \ . ,I i1ii No fonnation top details fall on the wellpath. ,. " ...... V . ....... .; i ...... l , P{)~ ;. ; , . , , ~L· i/ l , ..... ...... I F!\ ¡ ; L ; 7 ..... ... , ow . ; ...... ....... 1: + \ ..' i , ; '\ ; ; \; ¡ . , . ¡., J \. i.E .... CASING DETAILS ~vv ~ ; , ; No. TVD MD Name Size . I 8822, 19 14298.00 4-112" 4.500 ¡5~ð 0 '\ , + , -4800 -4200 -3600 -3000 -2400 -1800 West(-)/East(+) [600ft!in 72 66 60· 54 48 42 36 '" â "" ~ ¿ "" 10 ~ "" S o '" e BP-GDB BP Planning Report e Company: Field: Site: Wen: Wenpath: BP Amoco. Prudhoe Bay PB U Pad U-12 Plan U-12A Date: 8/2/2004 Time: 17:28:45 Co-onlinate(NE) Reference: Well: U-12, True North Verdeal (TVD) Reference: 48.57+28.5 77.1 Seetion (VS) Reference: Well (0.00N,O.OOE,328.57A%i) Snrvey Caleulation Method: Minimum Curvature Db: Oracle Plan: U-12A wp12 Date Composed: Version: Tied-to: 6/8/2004 79 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 U Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5960534.13 ft 630178.07 ft Latitnde: 70 18 Longitude: 148 56 North Reference: Grid Convergence: 1.170 N 44.315 W True 0.99 deg Well: U-12 Slot Name: 12 U-12 Well Position: +N/-S 478.16 ft Northing: 5961039.00 ft Latitnde: 70 18 5.872 N +E/-W 1548.57 ft Easting : 631718.00 ft Longitude: 148 55 59.166 W Position Uncertainty: 0.00 ft Casing Points MD TV» Diameter Hole Size Name ft ft in in 14298.00 8822.19 4.500 6.000 4-1/2" Formations MD TV» Formations Lithology Dip Angle ft ft deg 0.00 TSGR 0.00 Targets Map Map <- Latitude --> <- Longitude -> Name Description TV» +N/-S +EI-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft U-12A T6 8822.07 7189.69 -4392.99 5968150.01 627200.00 70 19 16.569 N 148 58 7.368 W U-12A T1 8867.07 4190.00 -3055.00 5965174.48 628590.27 70 18 47.074 N 148 5728.285 W U-12A T1B 8867.07 4190.00 -3055.00 5965174.48 628590.27 70 18 47.074 N 148 5728.285 W U-12A T2 B 8969.07 4912.81 -3574.72 5965888.01 628058.00 70 18 54.180 N 148 5743.456 W U-12A T5 8987.07 6382.65 -4059.06 5967349.01 627548.00 70 19 8.634 N 148 57 57.610 W U-12A T4 C 9025.07 6050.01 -3955.00 5967018.27 627657.88 70 19 5.363 N 148 57 54.568 W U-12A T3 B 9029.07 5708.89 -3853.83 5966679.01 627765.00 70 19 2.008 N 148 5751.611 W Plan Section Information MD Incl Azim TV» +N/-S +EI-W DLS BnDd Tnrn TFO Target ft deg deg ft ft ft deg/10Oft degl100ft deg/100ft deg 10725.00 44.43 332.42 8748.98 4021.19 -2953.09 0.00 0.00 0.00 0.00 10745.00 46.79 331.85 8762.97 4033.83 -2959.77 12.00 11.83 -2.86 -10.00 10952.80 73.39 326.28 8865.72 4186.25 -3052.49 13.00 12.80 -2.68 -11.82 10957.51 73.39 326.28 8867.07 4190.00 -3055.00 0.00 0.00 0.00 0.00 U-12A T1 11149.48 84.54 323.35 8903.77 4343.69 -3163.46 6.00 5.81 -1.52 -14.74 11686.56 84.54 323.35 8954.85 4772.65 -3482.57 0.00 0.00 0.00 0.00 11855.00 85.78 330,00 8969.07 4912.81 -3574.72 4.00 0.73 3.95 79.71 U-12A T2 B e BP-GDB e BP Planning Report çOJupany: BP>A(J'Iopo Field: Pl'\.ld~QªY Site: PB UPâd WêJl; U,;12 ~"JIp!ltb: Plan .U-1 '1A Plan Section Information TV"D dê9 ft 12188.49 85.78 343.38 8993.71 5217.55 -3706.03 4.00 0.00 4.01 90.48 12615.42 85.78 343.38 9025.09 5625.53 -3827.84 0.00 0.00 0.00 0.00 12702.84 89.00 342.00 9029.07 5708.89 -3853.83 4.00 3.68 -1.57 -23.18 U-12A T3 B 12762.90 90.75 343.65 9029.20 5766.27 -3871.56 4.00 2.91 2.74 43.25 13028.92 90.75 343.65 9025.72 6021.50 -3946.46 0.00 0.00 0.00 0.00 13058.68 91.75 343.00 9025.07 6050.01 -3955.00 4.00 3.36 -2.17 -32.84 U-12A T4 C 13198.88 97.34 342.53 9013.97 6183.44 -3996.38 4.00 3.99 -0.33 -4.73 13409.45 97.34 342.53 8987.07 6382.65 -4059.06 0.00 0.00 0.00 0.00 U-12A T5 13574.27 101.04 337.00 8960.74 6535.24 -4115.25 4.00 2.24 -3.36 -55.47 14298.61 101.04 337.00 8822.07 7189.69 -4392.99 0.00 0.00 0.00 0.00 U-12A T6 Survey MD Ind Adm TV» Sys TYD !\itS ft deg deg ft ft ft 10725.00 44.43 332.42 8748.98 8671.91 4021.19 -2953.09 0.00 5965007.49 628695.11 Start Dir 12/10 10745.00 46.79 331.85 8762.97 8685.90 4033.83 -2959.77 12.00 5965020.00 628688.21 Start Dir 13/10 10750.00 47.43 331.67 8766.38 8689.31 4037.05 -2961.50 13.00 5965023.20 628686.42 MWD+IFR+MS 10775.00 50.61 330.82 8782.77 8705.70 4053.60 -2970.58 13.00 5965039.58 628677.05 MWD+IFR+MS 10800.00 53.81 330.04 8798.09 8721.02 4070.78 -2980.33 13.00 5965056.58 628667.00 MWD+IFR+MS 10825.00 57.00 329.33 8812.28 8735.21 4088.54 -2990.72 13.00 5965074.16 628656.31 MWD+IFR+MS 10850.00 60.20 328.66 8825.30 8748.23 4106.82 -3001.72 13.00 5965092.25 628644.99 MWD+IFR+MS 10875.00 63.41 328.03 8837.11 8760.04 4125.58 -3013.28 13.00 5965110.79 628633.11 MWD+IFR+MS 10900.00 66.61 327.44 8847.67 8770.60 4144.73 -3025.37 13.00 5965129.73 628620.68 MWD+IFR+MS 10925.00 69.82 326.88 8856.95 8779.88 4164.24 -3037.96 13.00 5965149.01 628607.75 MWD+IFR+MS 10950.00 73.03 326.34 8864.91 8787.84 4184.02 -3051.00 13.00 5965168.56 628594.37 MWD+IFR+MS 10952.80 73.39 326.28 8865.72 8788.65 4186.25 -3052.49 13.00 5965170.76 628592.84 End Dir : 1095 10957.51 73.39 326.28 8867.07 8790.00 4190.00 -3055.00 0.00 5965174.48 628590.27 U-12A T1 10975.00 74.40 326.00 8871.92 8794.85 4203.96 -3064.36 6.00 5965188.26 628580.67 MWD+IFR+MS 11000.00 75.85 325.61 8878.34 8801.27 4223.94 -3077.94 6.00 5965208.00 628566.74 MWD+IFR+MS 11025.00 77.31 325.22 8884.14 8807.07 4243.96 -3091.74 6.00 5965227.78 628552.59 MWD+IFR+MS 11050.00 78.76 324.84 8889.32 8812.25 4264.00 -3105.76 6.00 5965247.57 628538.23 MWD+IFR+MS 11075.00 80.21 324.46 8893.89 8816.82 4284.05 -3119.98 6.00 5965267.36 628523.66 MWD+IFR+MS 11100.00 81.66 324.09 8897.82 8820.75 4304.09 -3134.39 6.00 5965287.14 628508.89 MWD+IFR+MS 11125.00 83.12 323.72 8901.13 8824.06 4324.11 -3148.99 6.00 5965306.91 628493.95 MWD+IFR+MS 11149.48 84.54 323.35 8903.77 8826.70 4343.69 -3163.45 6.00 5965326.22 628479,14 End Dir : 1114 11150.00 84.54 323.35 8903.81 8826.74 4344.10 -3163.76 0.02 5965326.63 628478.83 MWD+IFR+MS 11175.00 84.54 323.35 8906.19 8829.12 4364.07 -3178.62 0.00 5965346.33 628463.63 MWD+IFR+MS 11200.00 84.54 323.35 8908.57 8831.50 4384.04 -3193.47 0.00 5965366.03 628448.43 MWD+IFR+MS 11225.00 84.54 323.35 8910.95 8833.88 4404.00 -3208.33 0.00 5965385.74 628433.22 MWD+IFR+MS 11250.00 84.54 323.35 8913.33 8836.26 4423.97 -3223.18 0.00 5965405.44 628418.02 MWD+IFR+MS 11275.00 84.54 323.35 8915.70 8838.63 4443.94 -3238.03 0.00 5965425.14 628402.82 MWD+IFR+MS 11300.00 84.54 323.35 8918.08 8841.01 4463.91 -3252.89 0.00 5965444.84 628387.62 MWD+IFR+MS 11325.00 84.54 323.35 8920.46 8843.39 4483.87 -3267.74 0.00 5965464.55 628372.42 MWD+IFR+MS 11350.00 84.54 323.35 8922.84 8845.77 4503.84 -3282.60 0.00 5965484.25 628357.22 MWD+IFR+MS 11375.00 84.54 323.35 8925.21 8848.14 4523.81 -3297.45 0.00 5965503.95 628342.02 MWD+IFR+MS 11400.00 84.54 323.35 8927.59 8850.52 4543.78 -3312.31 0.00 5965523.65 628326.82 MWD+IFR+MS 11425.00 84.54 323.35 8929.97 8852.90 4563.74 -3327.16 0.00 5965543.36 628311.62 MWD+IFR+MS 11450.00 84.54 323.35 8932.35 8855.28 4583.71 -3342.02 0.00 5965563.06 628296.42 MWD+IFR+MS 11475.00 84.54 323.35 8934.73 8857.66 4603.68 -3356.87 0.00 5965582.76 628281.22 MWD+IFR+MS 11500.00 84.54 323.35 8937.10 8860.03 4623.64 -3371.72 0.00 5965602.46 628266.02 MWD+IFR+MS 11525.00 84.54 323.35 8939.48 8862.41 4643.61 -3386.58 0.00 5965622.16 628250.81 MWD+IFR+MS 11550.00 84.54 323.35 8941.86 8864.79 4663.58 -3401.43 0.00 5965641.87 628235.61 MWD+IFR+MS 11575.00 84.54 323.35 8944.24 8867.17 4683.55 -3416.29 0.00 5965661.57 628220.41 MWD+IFR+MS 11600.00 84.54 323.35 8946.61 8869.54 4703.51 -3431.14 0.00 5965681.27 628205.21 MWD+IFR+MS e BP-GDB BP Planning Report e Company: Field: Site: Wen: WeIlpatb: BPAmoco Prudhoe Bay PB U Pad U-12 Plan U-12A 11625.00 84.54 323.35 8948.99 8871.92 4723.48 -3446.00 0.00 5965700.97 628190.01 MWD+IFR+MS 11650,00 84.54 323.35 8951.37 8874.30 4743.45 -3460.85 0.00 5965720.68 628174.81 MWD+IFR+MS 11675.00 84.54 323.35 8953.75 8876.68 4763.42 -3475.70 0.00 5965740.38 628159.61 MWD+IFR+MS 11686.56 84.54 323.35 8954.85 8877.78 4772.65 -3482.57 0.00 5965749.49 628152.58 Start Dir 4/100 11700.00 84.64 323.88 8956.11 8879.04 4783.42 -3490.51 4.00 5965760.12 628144.46 MWD+IFR+MS 11725.00 84.82 324.87 8958.41 8881.34 4803.66 -3505.01 4.00 5965780.10 628129.61 MWD+IFR+MS 11750.00 85.00 325.86 8960.63 8883.56 4824.15 -3519.16 4.00 5965800.33 628115.10 MWD+IFR+MS 11775.00 85.18 326.85 8962.77 8885.70 4844.88 -3532.96 4.00 5965820.82 628100.94 MWD+IFR+MS 11800.00 85.37 327.83 8964.83 8887.76 4865.86 -3546.41 4.00 5965841.55 628087.13 MWD+IFR+MS 11825.00 85.55 328.82 8966.80 8889.73 4887.06 -3559.49 4.00 5965862.53 628073.67 MWD+IFR+MS 11850.00 85.74 329.80 8968.70 8891.63 4908.50 -3572.22 4.00 5965883.74 628060.58 MWD+IFR+MS 11855.00 85.78 330.00 8969.07 8892.00 4912.81 -3574.72 4.00 5965888.01 628058.00 U-12A T2 B 11875.00 85.77 330.80 8970.54 8893.47 4930.16 -3584.57 4.00 5965905.17 628047.85 MWD+IFR+MS 11900.00 85.77 331.80 8972.39 8895.32 4952.03 -3596.54 4.00 5965926.83 628035.50 MWD+IFR+MS 11925.00 85.76 332.81 8974.23 8897.16 4974.10 -3608.13 4.00 5965948.69 628023.53 MWD+IFR+MS 11950.00 85.76 333.81 8976.08 8899.01 4996.38 -3619.32 4.00 5965970.77 628011.94 MWD+IFR+MS 11975.00 85.76 334.81 8977.93 8900.86 5018.84 -3630.13 4.00 5965993.04 628000.74 MWD+IFR+MS 12000.00 85.75 335.82 8979.78 8902.71 5041.50 -3640.54 4.00 5966015.50 627989.93 MWD+IFR+MS 12025.00 85.75 336.82 8981.63 8904.56 5064.33 -3650.56 4.00 5966038.16 627979.52 MWD+IFR+MS 12050.00 85.75 337.82 8983.48 8906.41 5087.33 -3660.17 4.00 5966060.98 627969.51 MWD+IFR+MS 12075.00 85.76 338.82 8985.34 8908.27 5110.50 -3669.38 4.00 5966083.99 627959.89 MWD+IFR+MS 12100.00 85.76 339.83 8987.18 8910.11 5133.83 -3678.18 4.00 5966107.15 627950.69 MWD+IFR+MS 12125.00 85.77 340.83 8989.03 8911.96 5157.30 -3686.57 4.00 5966130.48 627941.88 MWD+IFR+MS 12150.00 85.77 341.83 8990.88 8913.81 5180.92 -3694.56 4.00 5966153.95 627933.49 MWD+IFR+MS 12175.00 85.78 342.84 8992.72 8915.65 5204.68 -3702.12 4.00 5966177.57 627925.51 MWD+IFR+MS 12188.49 85.78 343.38 8993.71 8916.64 5217.55 -3706.03 4.00 5966190.37 627921.37 End Dir : 1218 12200.00 85.78 343.38 8994.56 8917.49 5228.55 -3709.31 0.00 5966201.31 627917.90 MWD+IFR+MS 12225.00 85.78 343.38 8996.39 8919.32 5252.44 -3716.45 0.00 5966225.07 627910.35 MWD+IFR+MS 12250.00 85.78 343.38 8998.23 8921.16 5276.33 -3723.58 0.00 5966248.83 627902.80 MWD+IFR+MS 12275.00 85.78 343.38 9000.07 8923.00 5300.22 -3730.71 0.00 5966272.59 627895.25 MWD+IFR+MS 12300.00 85.78 343.38 9001.91 8924.84 5324.11 -3737.85 0.00 5966296.35 627887.70 MWD+IFR+MS 12325.00 85.78 343.38 9003.74 8926.67 5348.00 -3744.98 0.00 5966320.11 627880.15 MWD+IFR+MS 12350.00 85.78 343.38 9005.58 8928.51 5371.89 -3752.11 0.00 5966343.87 627872.60 MWD+IFR+MS 12375.00 85.78 343.38 9007.42 8930.35 5395.78 -3759.24 0.00 5966367.63 627865.05 MWD+IFR+MS 12400.00 85.78 343.38 9009.26 8932.19 5419.67 -3766.38 0.00 5966391.38 627857.50 MWD+IFR+MS 12425.00 85.78 343.38 9011.09 8934.02 5443.56 -3773.51 0.00 5966415.14 627849.95 MWD+IFR+MS 12450.00 85.78 343.38 9012.93 8935.86 5467.45 -3780.64 0.00 5966438.90 627842.40 MWD+IFR+MS 12475.00 85.78 343.38 9014.77 8937.70 5491.34 -3787.78 0.00 5966462.66 627834.85 MWD+IFR+MS 12500.00 85.78 343.38 9016.61 8939.54 5515.23 -3794.91 0.00 5966486.42 627827.30 MWD+IFR+MS 12525.00 85.78 343.38 9018.45 8941.38 5539.12 -3802.04 0.00 5966510.18 627819.75 MWD+IFR+MS 12550.00 85.78 343.38 9020.28 8943.21 5563.01 -3809.17 0.00 5966533.94 627812.20 MWD+IFR+MS 12575.00 85.78 343.38 9022.12 8945.05 5586.90 -3816.31 0.00 5966557.70 627804.65 MWD+IFR+MS 12600.00 85.78 343.38 9023.96 8946.89 5610.79 -3823.44 0.00 5966581.46 627797.10 MWD+IFR+MS 12615.42 85.78 343.38 9025.09 8948.02 5625.53 -3827.84 0.00 5966596.11 627792.44 Start Dir 4/100 12625.00 86.14 343.22 9025.77 8948.70 5634.68 -3830.59 4.00 5966605.22 627789.54 MWD+IFR+MS 12650.00 87.06 342.83 9027.25 8950.18 5658.55 -3837,87 4.00 5966628.96 627781.84 MWD+IFR+MS 12675.00 87.98 342.44 9028.34 8951.27 5682.39 -3845.33 4.00 5966652.66 627773.97 MWD+IFR+MS 12700.00 88.90 342.04 9029.02 8951.95 5706.19 -3852.95 4.00 5966676.32 627765.93 MWD+IFR+MS 12702.84 89.00 342.00 9029.07 8952.00 5708.89 -3853.83 4.00 5966679.01 627765.00 U-12A T3 B 12725.00 89.65 342.61 9029.33 8952.26 5730.00 -3860.56 4.00 5966699.99 627757.90 MWD+IFR.¡.MS 12750.00 90.37 343.29 9029.33 8952.26 5753.90 -3867.89 4.00 5966723.76 627750.15 MWD+IFR.¡.MS 12762.90 90.75 343.65 9029.20 8952.13 5766.27 -3871.56 4.00 5966736.06 627746.27 End Dir : 1276 12775.00 90.75 343.65 9029.04 8951.97 5777.88 -3874.97 0.00 5966747.60 627742.66 MWD+IFR+MS e BP-GDB BP Planning Report e Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB U Pad U-12 Plan U-12A 90.75 343.65 9028.72 8951.65 5801.86 -3882.01 0.00 5966771.46 627735.20 MWD+IFR+MS 90.75 343.65 9028.39 8951.32 5825.85 -3889.04 0.00 5966795.32 627727.74 MWD+IFR+MS 12850.00 90.75 343.65 9028.06 8950.99 5849.83 -3896.08 0.00 5966819.17 627720.28 MWD+IFR+MS 12875.00 90.75 343.65 9027.73 8950.66 5873.82 -3903.12 0.00 5966843.03 627712.83 MWD+IFR+MS 12900.00 90.75 343.65 9027.41 8950.34 5897.81 -3910.16 0.00 5966866.89 627705.37 MWD+IFR+MS 12925.00 90.75 343.65 9027.08 8950.01 5921.79 -3917.20 0.00 5966890.75 627697.91 MWD+IFR+MS 12950.00 90.75 343.65 9026.75 8949.68 5945.78 -3924.24 0.00 5966914.60 627690.45 MWD+IFR+MS 12975.00 90.75 343.65 9026.42 8949.35 5969.77 -3931.28 0.00 5966938.46 627683.00 MWD+IFR+MS 13000.00 90.75 343.65 9026.10 8949.03 5993.75 -3938.32 0.00 5966962.32 627675.54 MWD+IFR+MS 13025.00 90.75 343.65 9025,77 8948.70 6017.74 -3945.35 0.00 5966986.18 627668.08 MWD+IFR+MS 13028.92 90.75 343.65 9025.72 8948.65 6021.50 -3946.46 0.00 5966989.92 627666.91 Start Dir 4/100 13050.00 91.46 343.19 9025.31 8948.24 6041.70 -3952.47 4.00 5967010.01 627660.54 MWD+IFR+MS 13058.68 91.75 343.00 9025.07 8948.00 6050.01 -3955.00 4.00 5967018.27 627657.88 U-12A T4 C 13075.00 92.40 342.95 9024.48 8947.41 6065.60 -3959.77 4.00 5967033.77 627652.83 MWD+IFR+MS 13100.00 93.40 342.86 9023.21 8946.14 6089.46 -3967.11 4.00 5967057.50 627645.07 MWD+IFR+MS 13125,00 94.39 342.78 9021.52 8944.45 6113.29 -3974.48 4.00 5967081.19 627637.29 MWD+IFR+MS 13150.00 95.39 342.70 9019.38 8942.31 6137.08 -3981.87 4.00 5967104.85 627629.48 MWD+IFR+MS 13175.00 96.39 342.61 9016.82 8939.75 6160.81 -3989.28 4.00 5967128.45 627621.66 MWD+IFR+MS 13198.88 97.34 342.53 9013.97 8936.90 6183.44 -3996.38 4.00 5967150.94 627614.16 End Dir : 1319 13200.00 97.34 342.53 9013.82 8936.75 6184.49 -3996.71 0.00 5967151.99 627613.81 MWD+IFR+MS 13225.00 97.34 342.53 9010.63 8933.56 6208.15 -4004.16 0.00 5967175.51 627605.95 MWD+IFR+MS 13250.00 97.34 342.53 9007.44 8930.37 6231.80 -4011.60 0.00 5967199.02 627598.10 MWD+IFR+MS 13275.00 97.34 342.53 9004.24 8927.17 6255.45 -4019.04 0.00 5967222.54 627590.25 MWD+IFR+MS 13300.00 97.34 342.53 9001.05 8923.98 6279.10 -4026.48 0.00 5967246.06 627582.39 MWD+IFR+MS 13325.00 97.34 342.53 8997.86 8920.79 6302.75 -4033.92 0.00 5967269.57 627574.54 MWD+IFR+MS 13350.00 97.34 342.53 8994.66 8917.59 6326.41 -4041.37 0.00 5967293.09 627566.68 MWD+IFR+MS 13375.00 97.34 342.53 8991.47 8914.40 6350.06 -4048.81 0.00 5967316.60 627558.83 MWD+IFR+MS 13400.00 97.34 342.53 8988.28 8911.21 6373.71 -4056.25 0.00 5967340.12 627550.97 MWD+IFR+MS 13409.45 97.34 342.53 8987.07 8910.00 6382.65 -4059.06 0.00 5967349.01 627548.00 U-12A T5 13425.00 97.69 342.02 8985.04 8907.97 6397.34 -4063.76 4.00 5967363.61 627543.05 MWD+IFR+MS 13450.00 98.26 341.18 8981.57 8904.50 6420.83 -4071.57 4.00 5967386.96 627534.83 MWD+IFR+MS 13475.00 98.82 340.35 8977.86 8900.79 6444.17 -4079.71 4.00 5967410.15 627526.28 MWD+IFR+MS 13500.00 99.38 339.51 8973.90 8896.83 6467.36 -4088.19 4.00 5967433.18 627517.40 MWD+IFR+MS 13525.00 99.94 338.67 8969.71 8892,64 6490.38 -4096.98 4.00 5967456.05 627508.20 MWD+IFR+MS 13550.00 100.50 337.83 8965.27 8888.20 6513.23 -4106.10 4.00 5967478.73 627498.69 MWD+IFR+MS 13574.27 101.04 337.00 8960.74 8883.67 6535.24 -4115.26 4.00 5967500.58 627489.15 End Dir : 1357 13575.00 101.04 337.00 8960.60 8883.53 6535.90 -4115.54 0.00 5967501.24 627488.86 MWD+IFR+MS 13600.00 101.04 337.00 8955.81 8878.74 6558.49 -4125.12 0.00 5967523.65 627478.88 MWD+IFR+MS 13625.00 101.04 337.00 8951.03 8873.96 6581.08 -4134.71 0.00 5967546.06 627468.90 MWD+IFR+MS 13650.00 101.04 337.00 8946.24 8869.17 6603.67 -4144.29 0.00 5967568.48 627458.92 MWD+IFR+MS 13675,00 101.04 337.00 8941.45 8864.38 6626.26 -4153.88 0.00 5967590.89 627448.94 MWD+IFR+MS 13700.00 101.04 337.00 8936.67 8859.60 6648.84 -4163.46 0.00 5967613.31 627438.96 MWD+IFR+MS 13725.00 101.04 337.00 8931.88 8854.81 6671.43 -4173.05 0.00 5967635.72 627428.98 MWD+IFR+MS 13750.00 101.04 337.00 8927.10 8850.03 6694.02 -4182.64 0.00 5967658.14 627419.00 MWD+IFR+MS 13775.00 101.04 337.00 8922.31 8845.24 6716.61 -4192.22 0.00 5967680.55 627409.02 MWD+IFR+MS 13800.00 101.04 337.00 8917 .52 8840.45 6739.19 -4201.81 0.00 5967702.97 627399.04 MWD+IFR+MS 13825.00 101.04 337.00 8912.74 8835.67 6761.78 -4211.39 0.00 5967725.38 627389.06 MWD+IFR+MS 13850.00 101.04 337.00 8907.95 8830.88 6784.37 -4220.98 0.00 5967747.79 627379.08 MWD+IFR+MS 13875.00 101.04 337.00 8903.17 8826.10 6806.96 -4230.57 0.00 5967770.21 627369.10 MWD+IFR+MS 13900.00 101.04 337.00 8898.38 8821.31 6829.54 -4240.15 0.00 5967792.62 627359.12 MWD+IFR+MS 13925.00 101.04 337.00 8893.59 8816.52 6852.13 -4249.74 0.00 5967815.04 627349.14 MWD+IFR+MS 13950.00 101.04 337.00 8888.81 8811.74 6874.72 -4259.32 0.00 5967837.45 627339.16 MWD+IFR+MS e BP-GDB BP Planning Report e 337.00 8884.02 8806.95 6897.31 -4268.91 0.00 5967859.87 627329.18 MWD+IFR+MS 337.00 8879.24 8802.17 6919.90 -4278.50 0.00 5967882.28 627319.20 MWD+IFR+MS 337.00 8874.45 8797.38 6942.48 -4288,08 0.00 5967904.69 627309.22 MWD+IFR+MS 337.00 8869.66 8792.59 6965.07 -4297.67 0.00 5967927.11 627299.24 MWD+IFR+MS 337.00 8864.88 8787.81 6987.66 -4307.25 0.00 5967949.52 627289.27 MWD+IFR+MS 14100.00 101.04 337.00 8860.09 8783.02 7010.25 -4316.84 0.00 5967971.94 627279.29 MWD+IFR+MS 14125.00 101.04 337.00 8855.31 8778.24 7032.83 -4326.42 0.00 5967994.35 627269.31 MWD+IFR+MS 14150.00 101.04 337.00 8850.52 8773.45 7055.42 -4336.01 0.00 5968016.77 627259.33 MWD+IFR+MS 14175.00 101.04 337.00 8845.73 8768.66 7078.01 -4345.60 0.00 5968039.18 627249.35 MWD+IFR+MS 14200.00 101.04 337.00 8840.95 8763.88 7100.60 -4355.18 0.00 5968061.60 627239.37 MWD+IFR+MS 14225.00 101.04 337.00 8836.16 8759.09 7123.19 -4364.77 0.00 5968084.01 627229.39 MWD+IFR+MS 14250.00 101.04 337.00 8831.38 8754.31 7145.77 -4374.35 0.00 5968106.42 627219.41 MWD+IFR+MS 14275.00 101.04 337.00 8826.59 8749.52 7168.36 -4383.94 0.00 5968128.84 627209.43 MWD+IFR+MS 14298.00 /101.04 337.00 8822.19 8745.12 7189.14 -4392.76 0.00 5968149.46 627200.25 4-1/2" 14298.61 101.04 337.00 8822.07 8745.00 7189.69 -4392.99 0.00 5968150.01 627200.00 U-12A T6 e e TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 132 "Mastercard Check" ("9 _/';5"-/1 II DATE ''-..../ (" L../: v'-{ $ iW. îJOt~~~ First National Bank Alas a Anchorage. AK 99501 LX ¡a/\ MEMO . \, ;1 /, ¡ --r/. - , ! /) ~! fÆ:.' /1" ,~!t"' ~UìL~,/~," " . ':.25 2000bO.:Qq ......Ib 2 27111. 55bU- O.:l 2 e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAMEß0 &(-)2A PTD# 200/ J /Lf 7 X Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new weUboresegment of LA TERAL existing well . Permit No, API No. . (If API number Production should continue to be reponed as Jast two (2) digits a function ·of the original API number. stated are between 60-69) above. PILOT HOLE ]n accordance with 20 AAC 25.005(f), aU (PH) records, data and Jogs acquired for the pilot hoJe must be dearly differentiated "in both name (name on permit plus PH) .. and API num ber (SO - 70/80) from records, data and Jogs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fuD EX CEPT] ON ." compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:Jcep1Íon tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tbaD 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample intervals tbrougb target zones. PTD#: 2041470 Administration D D Appr Date RPC 8/5/2004 Engineering Appr Date WGA 8/9/2004 Geology Appr RPC Geologic Commissioner: DTs Date 8/5/2004 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT U-12A Program DEV Well bore seg Company BP EXPLORATION (ALASKA) INC Initial Classrrype DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 1 P~rmitfee attacheJ:l . . . . . . . . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Y~s _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . 2 Leas~nllmber _appropriate_ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_niqlle weltn_am~_arl(:! ol!.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WelllQcat~d in a d_efil1eJ:l_ppol _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJIJQcat~d proper _distance_ from driJling ul1itb.oUl1d_ary _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJQcat~d pr.oper _distance.from Qtber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_ufficiel1tacreageaYailable in_drilliog unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ Yes _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 If.d~viated, is_ weJlbQre platil1cJuded _. _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 9 Operator onl}! affected party _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ 10 _Oper_atof bas_apprppriateJ~ond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P~rmit c_atl be iSSl!.ed witbQut co_nservaiion order _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 P~rmitc_atl be iSSl!.ed wjtbQut ad_mil1istratilleapprpval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15-day wait Yes 14 WeIIJQcat~dwithil1areaandstrata_authorizedbY.ltljectipoOrd~r#(pllllO#in_c_omm~tlts)(For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 15 .AJlwells_withillJl4_n:Jite_afea_ofreYiewid~tllified(FprseNi~we[lOl1ly)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 116 Pre-produçed itljector; _duratiQnof pre-proJ:luGtioo I~Ss. than_:3 montbs_ (For_service well QnJy) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMP_finding_ofCQnsistetlcyh_as bee_nJs.slledfor.tbis pr_ojeçt _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 _C.otlductor string_prQvided _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_udac~cas.il1g_ pJQtec.ts. alLkllown USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 20 _CMTvoladequ_ate.tocircutate_oll_cOl1d_uctpr&suJf.csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 21 _CMT vol adequate.to tie-inlQngstring to_slid csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22CMTwill coyer_aJl koowllprodllctiye bQri~on_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _Casitlg desi.Qtls ad_eCluaie fpr C,T, B8opermafr.ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _AJ:lequatetankage_oJ re_Serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ Nab.orsJES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Ifare-ßrilL has_a 10-403 fQr abandonment be~tl apPJQved _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ Z/30/20_04._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 .AJ:lequSlte.we[lbofe separatiOll_PfOppseJ:l_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 If.div~rter Jeq_uired, dQes it meet regulatipl1s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ SidetraCk. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 _DJilliog fluidprQgram sc.hematic& eq.uiplistaJ:lequatß_ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ Max MW8Jì ppg, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 29 _BOPEs,_dp ihey meet regulaiiOI1 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPE_press ratitlg appropriate;testlo(pui psig incommel1ts)_ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ Testlo _3500 psLM5F> 23_20 psi. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _C_hOke_manifold cQmplies_ w/APt RF>-5:3 (May 64) _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 WQrk will pccur withputoperatiollshutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 33 Is. pres.ence_Qf H2S gas_prob_able _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _1:125 pad; 120_ppm, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mechanical_q)IJdJliotl p{ wells withil1 ,4.0R verified (For_s_ervi~ welJ only) _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - e e 35 P~rmit c_atl be iSSl!.ed w/Q hydrogen s_ulfide meas_ures _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ 36D_atapJeseoted Qn_ pote_ntial pyeJpres.sllreZOl1ej> _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 37 _S~ismic_allalysJs Qf sballow gaszpoes_ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ 38S~abeJ:lc0l1ditipo survey (if off-shpre) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ 39 _ CQnta_ct l1am_elphoneJor_weekly prpgressreports [e~ploratpryonly] _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Date g\ 9li e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting 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. . . c:(tJ'I-1'f7 Sperry-Sun Drilling Services LIS Scan Utility $Revi.sion: 3 $ LisLib $Revision: 4 $ Mon Nov 01 14:17:25 2004 #- ) J-~ J--~ Reel Header Service name.... .........LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/11 / 01 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 Da t e. . . . . . . . . . . . . . . . . . . . . 04/11 / 01 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 Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA U-12A 500292140901 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 0l-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003254802 P. SMITH D. FERGUSON MWD RUN 2 MW0003254802 B. HENNINGSE D. FERGUSON MWD RUN 3 MW0003254802 B. HENNINGSE D. FERGUSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003254802 B. HENNINGSE A. MADSEN MWD RUN 5 MW0003254802 B. HENNINGSE A. MADSEN MWD RUN 6 MW0003254802 B. HENNINGSE A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 11 13 463 2276 76.53 48.57 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9869.0 10815.0 # 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. U-12A WAS DRILLED FROM A WHIPSTOCK POSITIONED AT 9869'MD IN THE U-12 WELLBORE. THE BOTTOM OF THE WHIPSTOCK WAS AT 9885'MD. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW WAS MILLED DURING RUN 1. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) . 5. MWD RUNS 3 - 6 COMPRISED DIRECTIONAL DGR); ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 19' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 8 OCTOBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 6 REPRESENT WELL U-12A WITH API#: 50-029-21409-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14600'MD/8786'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS 1 clipped curves; all bit runs merged. .5000 START DEPTH 9800.5 9850.0 10748.5 10748.5 10748.5 10748.5 STOP DEPTH 14523.0 14581.0 14530.0 14530.0 14530.0 14530.0 . . RPX $ 10748.5 14530.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9800.5 9819.5 14581. 0 14600.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9819.5 9898.5 MWD 2 9898.5 10817.0 MWD 3 10817.0 11871.0 MWD 4 11871.0 12530.0 MWD 5 12530.0 12565.0 MWD 6 12565.0 14600.0 $ # REMARKS: MERGED MAIN PASS. $ # 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9800.5 14581 12190.8 9562 9800.5 14581 ROP MWD FT/H 0.07 407.68 110.34 9463 9850 14581 GR MWD API 13.94 585.9 72.612 9446 9800.5 14523 RPX MWD OHMM 0.58 2000 18.9829 7564 10748.5 14530 RPS MWD OHMM 0.85 2000 21.1199 7564 10748.5 14530 RPM MWD OHMM 0.53 2000 32.8532 7564 10748.5 14530 RPD MWD OHMM 0.21 2000 35.475 7564 10748.5 14530 FET MWD HOUR 0.21 93.01 3.08641 7564 10748.5 14530 First Reading For Entire Fi1e..........9800.5 Last Reading For Entire File...........14581 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 Fi 1 e 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..... ..04/11/01 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 GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9819.5 9869.0 STOP DEPTH 9849.0 9898.5 # 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): Ii REMARKS: $ Ii Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O 01-SEP-04 Insite 66.37 Memory 9898.0 9869.0 9898.0 .0 .0 TOOL NUMBER 120558 8.500 9869.0 LSND 11.20 68.0 9.0 9000 5.2 .000 .000 .000 .000 .0 182.3 .0 .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 Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWDOI0 MWDOI0 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9819.5 9898.5 9859 159 9819.5 9898.5 ROP MWDOI0 FT/H 0.07 29.77 10.6107 60 9869 9898.5 GR MWDOI0 API 90.71 101. 71 98.1042 60 9819.5 9849 First Reading For Entire File..........9819.5 Last Reading For Entire File...........9898.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/11/01 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 ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9849.5 9899.0 STOP DEPTH 10779.5 10817.0 # 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: 03-SEP-04 Insite 66.37 Memory 10817.0 9898.0 10817 . 0 46.7 . 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..................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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Units FT FT/H API Rep 68 68 68 Code Size 4 4 4 Nsam 1 1 1 MWD020 MWD020 51.0 TOOL NUMBER 120558 8.500 9869.0 LSND 11.20 52.0 9.0 7500 4.6 .000 .000 .000 .000 .0 172.4 .0 .0 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9849.5 10817 10333.3 1936 9849.5 10817 ROP MWD020 FT/H 0.59 282.26 79.8214 1837 9899 10817 GR MWD020 API 66.42 215.64 151.798 1861 9849.5 10779.5 First Reading For Entire File..........9849.5 Last Reading For Entire File...........10817 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation..... ..04/11/01 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.004 Offset o 4 8 Channel 1 2 3 . Physical EOF File Header Service name........... ..STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 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 10767.5 10767.5 10767.5 10767.5 10767.5 10780.0 10817.5 STOP DEPTH 1182l.5 11821. 5 11821.5 11821.5 11821. 5 11814.5 11871.0 # 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: 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): 08-SEP-04 Insite 66.37 Memory 11871.0 10817.0 11871.0 51. 0 85.8 TOOL NUMBER 151107 148579 6.125 10815.0 FLO PRO 8.50 43.0 9.0 2800 8.8 1.200 .460 1.000 1. 500 70.0 194.0 70.0 70.0 . . # 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 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 10767.5 11871 11319.3 2208 10767.5 11871 ROP MWD030 FT/H 1.23 363.12 71. 4691 2108 10817.5 11871 GR MWD030 API 15.71 574.61 60.5771 2070 10780 11814.5 RPX MWD030 OHMM 0.58 2000 23.3245 2109 10767.5 11821.5 RPS MWD030 OHMM 0.85 2000 26.1834 2109 10767.5 11821.5 RPM MWD030 OHMM 0.53 2000 78.7109 2109 10767.5 11821. 5 RPD MWD030 OHMM 0.21 2000 78.3604 2109 10767.5 11821. 5 FET MWD030 HOUR 0.46 93.01 5.68461 2109 10767.5 11821.5 First Reading For Entire File..........10767.5 Last Reading For Entire File...........11871 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 Fi I e 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.......04/ll/0l 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 5 header data for each bit run in separate files. 4 .5000 . VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ START DEPTH 11815.0 11822.0 11822.0 11822.0 11822.0 11822.0 11871.5 STOP DEPTH 12472.5 12479.5 12479.5 12479.5 12479.5 12479.5 12530.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 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 . 10-SEP-04 Insite 66.37 Memory 12530.0 11871.0 12530.0 82.9 87.8 TOOL NUMBER 151107 148579 6.125 10815.0 FLO PRO 8.50 46.0 8.7 1500 6.8 1.250 .460 1. 000 1. 550 68.0 199.7 68.0 68.0 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 RPM RPD FET MWD040 MWD040 MWD040 MWD040 OHMM OHMM OHMM HOUR 4 4 4 4 . 1 1 1 1 16 20 :24 28 5 6 7 8 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11815 12530 12172.5 1431 11815 12530 ROP MWD040 FT/H 0.59 323.83 126.236 1318 11871.5 12530 GR MWD040 API 16.06 94.81 29.4249 1316 11815 12472.5 RPX MWD040 OHMM 3.76 11. 05 7.69514 1316 11822 12479.5 RPS MWDO 4 0 OHMM 3.64 11 7.63891 1316 11822 12479.5 RPM MWD040 OHMM 3.64 11. 34 7.75716 1316 11822 12479.5 RPD MWD040 OHMM 3.88 12.04 8.09957 1316 11822 12479.5 FET MWD040 HOUR 0.3 27.16 2.76864 1316 11822 12479.5 First Reading For Entire File..........11815 Last Reading For Entire File...........12530 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX RPM FET RPS ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 12473.0 12480.0 12480.0 12480.0 12480.0 12480.0 12530.5 # 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 STOP DEPTH 12507.5 12514.5 12514.5 12514.5 12514.5 12514.5 12565.0 11-SEP-04 Insite 66.37 Memory 12565.0 12530.0 12565.0 . MINIMUM ANGLE: MAXIMUM .I\NGLE: # 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..................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 Abs ent val ue. . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O .0 .0 TOOL NUHBER 151107 148579 6.125 10815.0 Flo Pro 8.50 48.0 8.0 1600 8.2 1. 250 .430 1.000 1. 550 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD050 FT/H MWD050 API MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 OHMM MWD050 HOUR Min 12473 1.3 20.31 7.21 6.66 6.04 6.43 22.57 Max 12565 113.88 32.79 11.68 10.02 9.42 9.4 25.03 First Reading For Entire File..........12473 Last Reading For Entire File...........12565 Mean 12519 35.671 7 27.1241 9.78514 8.40886 7.54157 7.60214 23.8439 Nsam 185 70 70 70 70 70 70 70 . 68.0 208.9 68.0 68.0 First Reading 12473 12530.5 12473 12480 12480 12480 12480 12480 Last Reading 12565 12565 12507.5 12514.5 12514.5 12514.5 12514.5 12514.5 . . File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/l1/01 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/11/01 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.006 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 $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 12508.0 12515.0 12515.0 12515.0 12515.0 12515.0 12565.5 STOP DEPTH 14542.0 14549.0 14549.0 14549.0 14549.0 14549.0 14600.0 # 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: MAXIMUM ANGLE: 13-SEP-04 Insite 66.37 Memory 14600.0 12565.0 14600.0 86.7 103.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 151107 148579 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10815.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) FLO PRO 8.50 43.0 9.7 1900 7.8 . . MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1.500 .520 1.300 2.000 68.0 208.9 68.0 68.0 # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12508 14600 13554 4185 12508 14600 ROP MWD060 FT/H 0.16 407.68 141. 853 4070 12565.5 14600 GR MWD060 API 13.94 585.9 56.892 4069 12508 14542 RPX MWD060 OHMM 1.91 2000 20.5416 4069 12515 14549 RPS MWD060 OHMM 1. 54 2000 23.0742 4069 12515 14549 RPM MWD060 OHMM 0.55 2000 17.6368 4069 12515 14549 RPD MWD060 OHMM 0.23 2000 22.5804 4069 12515 14549 FET MWD060 HOUR 0.21 42.04 1.48542 4069 12515 14549 First Reading For Entire File..........12508 Last Reading For Entire File...........14600 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/l1/01 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name.............LISTPE Date......... ........ ....04/11/01 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.....................04/11/01 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File