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Home My WebLink About207-095CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-217 (PTD #2070950) for tracking purposes Date:Monday, February 2, 2026 8:37:03 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, January 31, 2026 6:11 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-217 (PTD #2070950) for tracking purposes Mr. Wallace, Injector S-217 (PTD #2070950) injection has been delayed and it is unknown when injection will commence. It will be classified back to NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 16, 2026 12:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: OPERABLE: Injector S-217 (PTD #2070950) Requires online AOGCC MIT-IA Mr. Wallace, Injector S-217 (PTD # 2070950) is ready to be put on injection by operations. The well is now classified as OPERABLE and an AOGCC witnessed MIT-IA will be performed once the well is on stable injection. Please call with any questions or concerns, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 30, 2025 2:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-217 (PTD #2070950) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-217 (PTD # 2070950) is due for its AOGCC MIT-IA by the end of October 2025. It is currently shut-in and will not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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. 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: OPERABLE: Injector S-217 (PTD #2070950) Requires online AOGCC MIT-IA Date:Friday, January 16, 2026 1:21:00 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 16, 2026 12:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector S-217 (PTD #2070950) Requires online AOGCC MIT-IA Mr. Wallace, Injector S-217 (PTD # 2070950) is ready to be put on injection by operations. The well is now classified as OPERABLE and an AOGCC witnessed MIT-IA will be performed once the well is on stable injection. Please call with any questions or concerns, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 30, 2025 2:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-217 (PTD #2070950) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-217 (PTD # 2070950) is due for its AOGCC MIT-IA by the end of October 2025. It is currently shut-in and will not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-217 (PTD #2070950) will lapse on AOGCC MIT-IA Date:Thursday, October 30, 2025 4:19:38 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 30, 2025 2:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-217 (PTD #2070950) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-217 (PTD # 2070950) is due for its AOGCC MIT-IA by the end of October 2025. It is currently shut-in and will not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-217 Install Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-095 50-029-23362-00-00 ADL 0028257, 0028258, 0028261 7049 Conductor Surface Intermediate Production Liner 5490 80 4312 7013 6804 20" 9-5/8" 7" 5279 28 - 108 28 - 4340 26 - 7038 2750 28 - 108 28 - 3478 26 - 5480 None 3090 5410 6804 5750 7240 6513 - 6782 3-1/2" 9.2# L-80 23 - 68475027 - 5260 Structural 3-1/2" HES Dual Feedthru Packers (2) 3-1/2" HES Single Feedthru Packers (2) 6454,4976 / 6555,5063 6598,5100 / 6723,5208 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 9/30/2025 Current Pools: POLARIS OIL Proposed Pools: POLARIS OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov No SSSV Installed By Grace Christianson at 3:59 pm, Sep 15, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.15 15:27:16 - 08'00' Torin Roschinger (4662) 325-562 AOGCC witnessed MITIA once on stabilized injection. 10-404 SFD 9/16/2025JJL 9/22/25 X DSR-9/24/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.24 15:33:35 -08'00'09/24/25 RBDM JSB 092625 Reset Patch on Injector Well: S-217 PTD: 207-095 API: 50-029-23362-00 Well Name:S-217 Permit to Drill:207-095 Current Status:Not Operable API Number:50-029-23362-00 Estimated Start Date:9/30/2025 Estimated Duration:2day Regulatory Contact:Abbie Barker Service Lines:SL/EL/FB First Call Engineer:Hunter Gates (215) 498-7274 (M)(907) 777-8326 (O) Second Call Engineer:Tyson Shriver (406) 690-6385 (M) Brief Well Summary: S-217 is a WAG injector that supports S-213. We have dummied off the OA and OBa sands in S-213 and therefore have no need to injector through these sleeves. The patch isolating a tubing leak, however, was preventing us from dummying off these stations. The old patch was pulled and all the stations were dummied. A new patch will be reset that has an ID that we can swap out gas lift valves through. We will pressure test against the patch once set and then install live gas lift valves in Stations #1 and #2. Current Status: Shut-In – Operable, WAG injector Pressure/Integrity History 10/28/2021 – MIT-IA passed to 3356 psi 10/22/2023 – MIT-IA passed to 3300 psi 10/23/2021 – PPPOT-T & IC both passed Procedure E-line/Fullbore 1. MIRU EL. 2. MU logging tools and RIH w/ Temp/CCL and pull baseline pass from 6,600’ MD to 6,300’ MD. Then pump down IA and pull secondary pass across same interval to verify leak point. 3. POOH and MU single trip straddle patch and correlate to leak. Anticipated leak point to be about 6,457’ MD. Set patch to straddle leak point once depth is confirmed. 4. Utilize pump truck to pressure up against packer and plug to verify good set. Conduct MIT-T to 2500 psi. 5. RDMO EL. Slickline/Fullbore 1. MIRU SL. RIH and drift through patch to 6,804’ MD. POOH. 2. Pull dummy valve from Station #2 and set WFRV sized for 500 BPD of injection. 3. Pull dummy valve from Station #1 and set WFRV sized for 500 BPD of injection. 4. POOH and conduct passing MIT-IA to target pressure of 3300 psi. 5. RDMO and turn well over to production to put back online. Attachments: x Procedure x Current Wellbore Schematic x Proposed Wellbore Schematic x Sundry Change Form Reset Patch on Injector Well: S-217 PTD: 207-095 API: 50-029-23362-00 Current Wellbore Schematic: Reset Patch on Injector Well: S-217 PTD: 207-095 API: 50-029-23362-00 Proposed Wellbore Schematic: New Single Trip Patch covering leak @ 6,457’ MD Live GLV Live GLV Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: September 15, 2025Subject: Changes to Approved Sundry Procedure for Well S-217Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 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 S-217 Pull Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-095 50-029-23362-00-00 7049 Conductor Surface Intermediate Production Liner 5490 4312 7012 6804 9-5/8" 7" 5279 28 - 4340 26 - 7038 28 - 3478 26 - 5480 6860 3090 5410 6804 5750 7240 6513 - 6782 3-1/2" 9.2# L-80 23 - 6847 5027 - 5260 Structural 3-1/2" HES Dual Feedthru Packer 6454, 4976 3-1/2" HES Single Feedthru Packer 6723, 5208 6454, 6555, 6598, 6723 4976, 5063, 5100, 5208 Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com 907-777-8326 PRUDHOE BAY, POLARIS 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 0028257, 0028258, 0028261 23 - 5316 N/A N/A Well Not Online 1150 1300 700 1270 1050 N/A 13b. Pools active after work:POLARIS OIL 3-1/2" HES Dual Feedthru Packer 6555, 5063 3-1/2" HES Single Feedthru Packer 6598, 5100 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 No SSSV Installed By Grace Christianson at 1:30 pm, Sep 03, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.03 11:07:15 - 08'00' Torin Roschinger (4662) DSR-9/11/25 RBDMS JSB 091225 J.Lau 11/4/25 ACTIVITY DATE SUMMARY 8/24/2025 ***WELL S/I ON ARRIVAL*** DRIFT WITH 2'x1.875", 3 1/2" BLB, 2.79" GAUGE RING TO PATCH AT 6,434' MD WHILE LOADING WELL WITH 70 bbls (all clear) SET OLD STYLE ER PULLING TOOL AT 6,434' MD PULLED UPPER PATCH AT 6,434' MD PULLED LOWER PATCH AT 6,436' SLM RAN 2-1/2" PUMP BLR TO 6,626', BLR EMPTY AND GOOD METAL MARKS SET 3-1/2" X-SELECTIVE TEST TOOL AT 6,549' MD PULLED ST# 5 RK-WFR AT 6,533' MD ***CONTINUE ON 8/25/25*** 8/24/2025 T/I/O= 1120/695/0 Assist SL ( WFRs ) Pump 70 bbls 180* diesel down tbg FWHPs=1200/1315/45 8/25/2025 ***CONTINUED FROM 8/24/25*** SET ST# 5 RK-DGLV AT 6,533' MD PULLED X-SELECTIVE FROM 6,549' MD PULLED ST# 4 RK-WFR AT 6,576' MD SET ST# 4 RK-DGLV AT 6,576' MD PULLED RMX PRONG AT 6,626' MD (1.188" fn) PULLED 3-1/2" RMX BODY AT 6,626' MD RAN 10' x 2-1/2" PUMP BAILER 5 TIMES (recovered 6 gal of schmoo) PULLED ST# 3 RK-FLOW SLEEVE AT 6,632' MD SET ST# 3 RK-SWELL FIX AT 6,632' MD PULLED ST# 1 RK-WFR ***CONTINUE ON 8/26/25*** 8/26/2025 ***CONTINUE FROM 8/25/25*** RAN 1.50" LIB TO ST# 1 AT 6,775' MD VALVE IN POCKET PULLED PRONG AT 6,804' MD RAN 2-1/2" PUMP BAILER TO PX PLUG AT 6,804' MD (1 gal OF SCHMOO) PULLED PX PLUG BODY FROM 6,804' MD RAN 3 1/2 BLB & 2.71" GAUGE RING TO BRUSH NIPPLE @ 6,804' MD SET 2.81" RMX AT 6,804' MD RAN 3 1/2" X CHECK SET TO RMX BODY(Confirmed good set) SET MODIFIED RMX PRONG w/ DGLV IN RMX BODY(17" of 1.25" & 1.188" fn on top of standard 1.75" rmx prong) RAN 3 1/2" BLB & 2.79" GAUGE RING TO BRUSH PATCH AREA FROM 6,400' TO 6,470' SLM RAN 34' x 2" DUMMY GUNS(2.16" SWELL) AS LDL DRIFT TO RMX AT 6,804' MD ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU S-217 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-217 PRUDHOE BAY UN POL S-217 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2023 S-217 50-029-23362-00-00 207-095-0 G SPT 4977 2070950 3250 1710 1727 1712 1712 21 58 58 57 REQVAR P Adam Earl 10/22/2023 MIT-IA to 3250- tested as per AIO 25A.019 to max ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL S-217 Inspection Date: Tubing OA Packer Depth 1184 3514 3336 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE231025104655 BBL Pumped:3 BBL Returned:2.8 Wednesday, December 6, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9999 9 9 9 AIO 25A.019 James B. Regg Digitally signed by James B. Regg Date: 2023.12.06 09:32:06 -09'00' From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Date:Thursday, November 18, 2021 10:57:26 AM Attachments:image003.png image001.png From: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Sent: Thursday, November 18, 2021 9:04 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Re: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Ryan, Keep the well on injection while we process your application. Please send the latest 90 days TIO if not included in your application. Thanks Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 18, 2021 8:59:41 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Mr. Wallace, WAG injector S-217 (PTD #2070950) is on day 28 of the under eval clock. My understanding is an AA was submitted to AOGCC on 11/15/21. Would it be unreasonable to keep this well online until the AA is processed? There is forecasted inclement weather over the next 24 hours and I would prefer to not request a well shut in and freeze protect if phase conditions develop. Thank you, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 21, 2021 11:06 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Mr. Wallace, WAG injector S-217 (PTD# 207095) has been found to have suspected TxIA pressure communication while on MI service. This repressurization indicates a potential failure or impairment of one or more barriers. The last AOGCC witnessed MIT-IA was conducted on 4/27/2018 which passed to 3466 psi. We plan to leave the well on injection to aid in initial diagnostics. Annulus pressures will be maintained under MOASP while diagnostics are performed, if the IA pressure cannot be managed with periodic bleeds the well will be shut-in. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD- PPPOT-T, PPPOT-IC 2. DHD/ Fullbore- MIT-IA 3. Well Integrity- Additional diagnostics as needed. Please contact me with any questions or concerns. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intendedrecipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error,please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and anyattachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Date:Monday, October 25, 2021 9:12:42 AM Attachments:image001.png image003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 21, 2021 11:06 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector S-217 (PTD# 207095) Anomalous IA Repressurization Mr. Wallace, WAG injector S-217 (PTD# 207095) has been found to have suspected TxIA pressure communication while on MI service. This repressurization indicates a potential failure or impairment of one or more barriers. The last AOGCC witnessed MIT-IA was conducted on 4/27/2018 which passed to 3466 psi. We plan to leave the well on injection to aid in initial diagnostics. Annulus pressures will be maintained under MOASP while diagnostics are performed, if the IA pressure cannot be managed with periodic bleeds the well will be shut-in. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD- PPPOT-T, PPPOT-IC 2. DHD/ Fullbore- MIT-IA 3. Well Integrity- Additional diagnostics as needed. Please contact me with any questions or concerns. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intendedrecipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error,please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and anyattachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, November 2, 2021 / ,� P.I. Supervisor ,dry 1/I p'C'C�Z� SUBJECT: Mechanical Integrity Tests l 6 I Hilcorp North Slope, LLC S-217 FROM: Brian Bixby PRUDHOE BAY UN POL S-217 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,,, NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S-217 API Well Number 50-029-23362-00-00 Inspector Name: Brian Bixby Permit Number: 207-095-0 Inspection Date: 10/28/2021 Insp Num: mitBDB211028110648 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 5-217 ;Type Inj G 'ITVD 4977 ',I Tubing I 2072 2083, 2075 2070 - BBL Pumped: 3.2 IBBL Returned 3250 jA 1324 3525 3398 3356 -.2 -54 - PT pzo7o9so est sPT i est psi 3 _ OA sa � 192 - �1ss �-� 180 � ' !Type Interval OTHER P/F P Notes: This well was under EVAL for a suspected TXIA communication. Tested to Maximum gas header pressure. Tuesday, November 2, 2021 Page 1 of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:207-095 6.50-029-23362-00-00 PRUDHOE BAY, POLARIS OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 7049 6626 5124 6454, 6555, 6598, None 6804 497, 5063, 5100, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 29 - 108 29 - 108 Surface 4312 9-5/8" 28 - 4340 28 - 3478 5750 3090 Intermediate Production 7012 7" 26 - 7038 26 - 5480 7240 5410 Perforation Depth: Measured depth: 6513 - 6782 feet True vertical depth:5027 - 5260 feet Tubing (size, grade, measured and true vertical depth)23 - 6847 23 - 5316 Packers and SSSV (type, measured and true vertical depth) Liner Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Glasheen, Brian P Brian.Glasheen@bp.com Authorized Name:Glasheen, Brian P Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 5905 13. Production Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured5490 Sundry Number or N/A if C.O. Exempt: 319-321 Junk Packer Printed and Electronic Fracture Stimulation Data 5 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028257, 028258 & 028261 PBU S-217 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Operations shutdown Change Approved Program Other:Pull / Set PatcK API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" 9.2# L-80 3-1/2" HES Dual Feedthru Packer 3-1/2" HES Dual Feedthru Packer 6454 4977 6555 5063 3-1/2" HES 6LQJOH Feedthru Packer 655 65 12.Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 3-1/2" HES 6LQJOH Feedthru Packer Brian Glasheen Digitally signed by Brian Glasheen Date: 2020.05.19 13:28:08 -08'00' By Samantha Carlisle at 2:35 pm, May 19, 2020 SFD 5/21/2020RBDMS HEW 5/20/2020DSR-5/20/2020MGR22MAY20 ACTIVITYDATE SUMMARY 12/30/2019 ***WELL S/I ON ARRIVAL***(wfr) EQUALIZED & PULLED MCX FROM 2891' MD. ***CONT ON 12-31-19 WSR*** 12/31/2019 ***CONT FROM 12-30-19 WSR***(wfr) JAR ON PATCH FOR 5 HOURS TOTAL, NO MOVEMENT. ***CONT ON 1-1-20 WSR*** 1/1/2020 ***CONT FROM 12-31-19 WSR***(wfr) JAR ON PATCH FOR 2 HOURS ON .125" WIRE (7 HOURS TOTAL) SWAP TO .160" WIRE JAR ON PATCH FOR 6 HOURS ON .160" WIRE ***CONT ON 1-2-20 WSR*** 1/2/2020 ***CONT FROM 1-1-20 WSR***(wfr) PULLED PATCH FROM 6,418' SLM. (8:45 HOURS ON 1.60") ***WSR CONTINUED ON 1/3/20*** 1/3/2020 ***WSR CONTINUED FROM 1/2/20*** (wfr) RAN 2.625" WIRE GRAB & SAT DOWN @ 6,538' SLM (no recovery) RAN 3-1/2" BRUSH & 1.5" GLM POCKET POKER BRUSH & SAT DOWN IN RMX RECEPTACLE @ 6,539' SLM (no recovery) RAN 3-1/2" DOGLESS GS & SAT DOWN @ 6,537' SLM (sheared) PULLED 3-1/2" X-LOCK W/ RMX RECEPTACLE FROM 6,549' MD SET 3-1/2" PX PLUG IN X-NIPPLE @ 6,549' MD (check set sheared) ***WSR CONTINUED ON 1/4/20*** 1/4/2020 ***WSR CONTINUED FROM 1/3/20*** (wfr) LRS ATTEMPTED PRESSURE TEST TO 2,000 psi (See LRS log, Established LLR .32 bpm) PULLED 3-1/2" PX-PLUG FROM 6,537' SLM / 6,549' MD RAN 2.70" CENT, 2-1/2" JDC, S/D HIGH @ 6,579' SLM (Unable to latch prong) RAN 10' x 2-1/2" PUMP BAILER TO 6,579' SLM (~1/2 gal of schmoo/silt mix) RAN 10' x 1-3/4" DD BAILER TO 6,589' SLM (~1/2 gal of schmoo/silt mix) RAN 10' x 2-1/2" DD BAILER TO 6,589' SLM (~1/2 gal of schmoo/silt mix) MADE 2 RUNS W/ 10' x 2-1/2" P-BAILER, BAIL DOWN TO 6,596' SLM (~2 gal schmoo sand mix) LAY DOWN EQUIPMENT DUE TO AMBIENT LOW TEMP CUT OFF ***MOVE TO WEATHER STBY TICKET*** 1/4/2020 T/I/O= 0/240/Vac Temp= S/I Assist SSL (WATERFLOOD REGULATOR) Pumped a total of 14.35 bbls diesel down TBG in attempt to pressure test TBG, Established a LLR of .32 bpm at 2170 psi for 5 min, Job postponed do to -40* temps, WHP= Vac/237/Vac 1/7/2020 ****CONT. JOB FROM 1/4/20**** (wfr) SLB SLICKLINE SWCP #4522 STANDBY FOR P-272 RIG MOVE ****CONT JOB ON 1/8/20**** 1/8/2020 ****CONT. JOB FROM 1/7/20**** (wfr) MADE 7 RUNS W/ 10' x 2-1/2" BAILERS, BAIL DOWN TO 6,610' SLM (~5 gal sand) MADE 2 ATTEMPTS TO PULL RMX-PRONG FROM 6,611' SLM (Rubber element pcs in JDC) RAN 10' x 2-1/2' P-BAILER TO 6,611' SLM STANDBY 1.5 HRS DUE TO LOW AMBIENT TEMP CUT-OFF ****CONT. JOB ON 1/9/20**** Daily Report of Well Operations PBU S-217 Daily Report of Well Operations PBU S-217 1/10/2020 ****CONT. JOB FROM 1/8/20**** (wfr) PULLED RMX PRONG W/ P15-XJR FROM 6,611' SLM RAN 10' x 2-1/2" P-BAILER TO RMX PLUG BODY @ 6,617' SLM (Empty) PULLED 3-1/2" RMX-PLUG BODY FROM 6,617' SLM / 6,626' MD (3.5 hrs jar time) PULLED STA #3 RK-FLOWSLEEVE FROM 6,627' SLM / 6,632' MD SET STA #3 RK-DGLV @ 6,627' SLM / 6,632' MD STANDBY FOR LRS PUMP TRUCK ****CONT JOB ON 1/11/20**** 1/11/2020 ****CONT. JOB FROM 1/10/20**** (wfr) RAN KJ, 3-1/2" OM-1 TO STA #1, S/D @ 6,770' SLM (Unable to pass sta #1) RAN 10' x 2-1/2" P-BAILER TO 6,782' SLM (Recovered ~1 gal schmoo/sand mix) PULLED STA #1 RK-P15-XJR FROM 6,772' SLM / 6,775' MD B&F W/ 3-1/2" BRUSH, 3.80" G-RING TO 6,784' SLM LRS PUMPED 60 BBLS DIESEL FOR B&F (See LRS log) SET STA #1 RK-RWF-2AIC @ 6,775' MD LRS PERFORMED STEP RATE TEST (Results =1.5 BPM @ 220 psi) SET 3-1/2" X-SELECTIVE TEST TOOL @ 6,617' SLM / 6,626' MD PULLED STA #4 RK-P15-XJR FROM 6,573' SLM / 6,576' MD LRS PERFORMED OPEN POCKET TEST ON STA #4 (OBa sandface / >3 BPM @ 350 psi) ****CONT JOB ON 1/12/20**** 1/12/2020 ****CONT. JOB FROM 1/11/20**** (wfr) LRS PUMPED 200 BBLS 2% KCL W/ RED DYE DOWN TBG (See LRS log) WELL BROUGHT ON PWI FOR RED DYE TREATMENT OVERFLUSH NO RED DYE RECOVERED OVER DURATION OF PWI OVERFLUSH LRS FREEZE PROTECTED INJECTION LINE & TUBING SET STA #4 RK-DGLV @ 6,573' SLM / 6,576' MD PULLED 3-1/2" X-SELECTIVE TEST TOOL FROM 6,619' SLM / 6,626' MD JOB POSTPONED, INSTRUCTED TO RDMO PER WSL ****WELL LEFT S/I & PAD-OP NOTIFIED OF STATUS UPON DEPARTURE**** 3/18/2020 ****WELL S/I UPON ARRIVAL**** ((Waterflood) R/U SLB SWCP #4522 FOR WFRV C/O ****CONT JOB ON 3/19/20**** 3/19/2020 ****CONT. JOB FROM 3/18/20**** (Waterflood) PULLED RK-DGLV FROM ST#3 @ 6632' MD. SET RK-FLOWSLEEVE IN ST#3 @ 6632' MD. LRS LOADED W/ 40 BBLS OF 2% KCL W/ FREEZE PROTECT. PULLED RK-FLOWSLEEVE FROM ST#3 @ 6632' MD. SET RK-DGLV IN STA#3 AT 6,632' MD PULL RK-DGLV FROM STA#3 AT 6,632' MD SET RKP-FLOWSLEEVE IN STA#3 AT 6,632' MD ***CONT ON 3/20/20 WSR*** 3/20/2020 ***CONT FROM 3/19/20 WSR*** (waterflood regulator) LRS LOADED TBG WITH 60 BBLS KCL & 20 BLLS 60/40 FREEZE PROTECT SET 3-1/2" X-SELECTIVE TEST TOOL AT 6,626' MD LRS ESTABLISHED LLR OF .28 bpm AT 1,610 psi (see log) LAY DOWN EQUIPMENT FOR UPCOMING WINDS ***MOVE TO 3/20/20 WEATHER AWGRS*** Daily Report of Well Operations PBU S-217 3/22/2020 ***CONT FROM 3/20/20 WSR*** (waterflood regulator) PULLED RK-DGLV FROM ST#4 @ 6576' MD. SET RK-RWF-2A1C(300bwpd) IN ST#4 @ 6576' MD. LRS PERFORMED STEP RATE TEST ON ST#4 WFR.(see lrs log) PULL RK-RWF-2A1C FROM STA#4 AT 6,576' MD SET RK-DGLV IN STA#4 AT 6,576' MD ***CONT ON 3/23/20 WSR*** 3/23/2020 ***CONT FROM 3/22/20 WSR*** (waterflood regulator) LRS PERFORMED SRT ON LEAK (see log) PULLED RK-DGLV FROM STA#6 AT 6,479' MD (see log) SET RK-DGLV (extended packing) IN STA#6 AT 6,479' MD RAN BARBELLED 2.50" LIB TO X-SELECTIVE TT AT 6,626' MD (impression of fn) PULLED RK-DGLV FROM STA#4 AT 6,576' MD ***CONT ON 3/24/20 WSR*** 3/24/2020 ***JOB CONTINUED FROM 23-MAR-2020*** Pumped 37 BBL's of 2% KCL in an attempt to perform step rate test. Pumped 10 BBL's of 60/40 to FP surface lines and well head. Pumped 15 bbls 60/40 verify valve set . Slickline rigging down due to weather, in control of well on LRS departure. 3/24/2020 ***CONT FROM 3/23/20 WSR*** (waterflood regulator) SET RK-RWF-2AIC IN STA#4 AT 6,576' MD LRS UNABLE TO CATCH PRESSURE TO PERFORM STA#4 SRT RAN 2.60" BELL GUIDE & 1-5/8" JD (gutted) TO 6,626' MD (no recovery) RAN 1.70" LIB TO STA#4 AT 6,576' MD (impression of latch) RAN 1.70" LIB TO STA#6 AT 6,479' MD (impression of latch) LRS UNABLE TO CATCH PRESSURE AFTER 15 MORE BBLS 60/40 DOWN TBG PULLED X-SELECTIVE TEST TOOL FROM 6,626' MD (missing o-rings) RIG DOWN FOR WINDS/ PHASE 2 & GO INTO MAINTENANCE ***WELL S/I ON DEPARTURE, JOB INCOMPLETE*** 3/25/2020 ***CONT FROM 3/24/20 WSR*** (waterflood regulator) SWCP4522 RIG UP ***CONT ON 3/26/20 WSR*** Daily Report of Well Operations PBU S-217 3/26/2020 *** WSR continued from 03/25/20 ***LRS unit 46 assist Slickline (WATERFLOOD REGULATOR) Pumped SRT on station #4 with 55 bbls of 2% KCL 1st 5 min= .77 bpm 2nd 5 min= .74 bpm @ 1000 psi 1st 5 min= .78 bpm 2nd 5 min= .77 bpm @ 1200 psi 1st 5 min= .84 bpm 2nd 5 min= .84 bpm @ 1400 psi 1st 5 min= .86 bpm 2nd 5 min= .81 bpm @ 1600 psi Pump 15 bbl 60/40 tbg freeze protect Pumped SRT on station #5 with 19 bbls of 2% KCL 1st 5 min= .35 bpm 2nd 5 min= .25 bpm @ 1200 psi 1st 5 min= .22 bpm 2nd 5 min= .24 bpm @ 1400 psi 1st 5 min= .29 bpm 2nd 5 min= .28 bpm @ 1600 psi pumped 15 bbl tbg freeze protect Pumped SRT on station #5 open pocket with 37 bbls of 2% KCL 1st 5 min= 3 bpm @ 500 psi Pump SRT on #5 station with 23 bbls of 2% KCL 1st 5 min= .37 bpm 2nd 5 min= .37 bpm @ 1000 psi 1st 5 min= .39 bpm 2nd 5 min=.39 bpm @ 1200 psi 1st 5 min= .51 bpm 2nd 5 min= .46 bpm @ 1400 psi 1st 5 min= .40 bpm 2nd 5 min= .40 bpm @ 1600 psi Pump 15 bbl 60/40 tbg freeze protect Attempted a combined SRT on Stations 1,4,5 with 35bbls of 2% KCL established an injectivity of ~2 bpm @ 1000 psi Freeze protected Tbg with 15 bbls 60/40 *** WSR continued on 03/27/20 *** 3/26/2020 ***CONT FROM 3/26/20 WSR*** (waterflood regulator) SET 3-1/2" X-SELECTIVE TEST TOOL AT 6,626' MD. LRS PERFORMED SRT ON ST#4.(see lrs log) SET 3-1/2" X-SELECTIVE TEST TOOL IN X-NIPPLE @ 6549' MD. PULLED RK-DGLV(ext pkg) FROM ST#5 @ 6533' MD. LRS PERFORMED SRT ON TBG LEAK.(see lrs log) PULLED RK-DGLV(ext pkg) FROM ST#5 @ 6533' MD. LRS PERFORMED SRT ON OPEN POCKET TEST ON ST#5.(see lrs log) SET RK-RWF-2AIC(160bwpd) IN ST#5 @ 6533' MD. LRS PERFORMED SRT ON ST#5.(see lrs log) PULLED 3-1/2" X-SELECTIVE TEST TOOL FROM X-NIPPLE @ 6549' MD. PULLED RKP-FLOWSLEEVE FROM ST#3 @ 6632' MD. SET RK-DGLV IN STA#3 AT 6,632' MD LRS ATTEMPTED STA#5, 4 & 1 SRT (see log) ***CONT ON 3/27/20 WSR*** 3/27/2020 *** WSR continued from 03/26/20 *** LRS unit 46 assist Slickline (WATERFLOOD REGULATOR) Pumped down Tbg with 74 bbls of 2% KCL for SRT on stations 4, 5 and plug w/ WFR. 1st 5 min= 1.15 bpm 2nd 5 min= 1.14 bpm @ 1000 psi 1st 5 min= 1.19 bpm 2nd 5 min= 1.18 bpm @ 1200 psi 1st 5 min= 1.22 bpm 2nd 5 min= 1.18 bpm @ 1400 psi 1st 5 min= 1.08 bpm 2nd 5 min= 1.06 bpm @ 1600 psi Pumped water flush and a 25 bbl 60/40 freeze protect. Well left under SL control per LRS departure. FWHp's=0/220/0 IA,OA=OTG Daily Report of Well Operations PBU S-217 3/27/2020 ***CONT FROM 3/26/20 WSR*** (waterflood regulator) PULLED RK-DGLV FROM STA#3 AT 6,632' MD SET RKP-FLOWSLEEVE IN STA#3 AT 6,632' MD SET 3-1/2" RMX RECEPTACLE IN X-NIPPLE AT 6,626' MD RAN CHECK SET TO RMX RECEPTACLE AT 6,626' MD (sheared) SET RMX PRONG W/ RWF-2AIC(500 bpd) IN RMX BODY @ 6626' MD. LRS PERFORMED STEP RATE TEST ON ST#5, ST#4 & RMX PRONG.(see log) DRIFTED TBG W/ 31' x 2.70"/2.66" DRIFT TO 6500' SLM.(no issues) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 4/20/2020 ***JOB STARTED ON 20-APRIL-2020*** (SLB ELINE: SET LWR PKR) WELL S/I ON ARRIVAL. INITIAL T/I/O = 0/200/0. PT LUBE TO 3400 PSI (pass). SET 3.5" WFD WIDEPAK LOWER PACKER @ 6,464' MD MID-ELEMENT. LAY DOWN FOR THE NIGHT. WELL SECURED. ***JOB CONTINUED ON 21-APRIL-2020*** 4/21/2020 ***JOB CONTINUED FROM 20-APRIL-2020*** (SLB ELINE: SET PATCH) RIG UP PCE AND TOOLS. PT LUBE TO 3600 PSI. STING INTO LWR PKR AT 6,464' (RS ANCHOR) w/ WFT 3.5" WIDEPAK PATCH (verify engaged w/ 500 lb overpull). SET TOP PACKER - MID ELEMENT AT 6,438' MD, TOP OF UPPER PACKER AT 6,434' MD. RIG DOWN ELINE. FINAL T/I/O = 0/200/0. WELL SHUT IN ON DEPARTURE, DSO NOTIFIED. ***JOB COMPLETE ON 21-APRIL-2020*** ***3-1/2" WEATHERFORD 2-TRIP PATCH. TOP ELEMENT = 6438' MD, BOTTOM ELEMENT = 6464' MD, TOP OF PATCH ~ 6434' MD, OAL LIH ~ 31.16', MIN ID = 1.75" AT ~6459' MD*** Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, May 4, 2020 7:38 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Glasheen, Brian P; Huber, Kenneth J Cc: Regg, James B (CED); AK, GWO DHD Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Dempsey, David G; Janowski, Carrie; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C Subject: OPERABLE: Injector S-217 (PTD #2070950) completed monitoring of IA on water injection All, Injector S-217 (PTD # 2070950) recently underwent wellwork to configure it for water injection, per Sundry 319-321. The well was put on injection on 04/24/20, and monitored for IA re -pressurization for 10 days. No IA re -pressurization was observed. It is reclassified OPERABLE. Please respond with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 4, 000 3,50D 3,000 2,500- 2,000- 1,500 ,5002,00{71.500 1,000 0204120 02/11i'20 02'1&.'20 02,'2520 03TY20 03110120 03117.120 0324,20 From: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com> Sent: Friday, April 24, 2020 5:56 AM To: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; 'chris.wallace@alaska.gov' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Injector S-217 (PTD #2070950) monitor IA on water injection All, Injector S-217 (PTD # 2070950) recently underwent wellwork to configure it for water injection, per Sundry 319-321. The well was put on injection this morning. It is now reclassified as UNDER EVALUATION, to monitor the inner annulus (IA) for repressurization. Plan Forward: 1. Operations: put well on water injection — Completed 04/24/20 2. Well Integrity: monitor IA—In progress 3. Well Integrity: Consider AA if IA repressurization is observed. Please respond with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, July 28, 2018 2:30 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilitvOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin <Austin.Draughon@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>; Zoesch, Eric <zoese0@BP.com>; 'ch ris.waIlace @alaska.gov' <chris.waIla ce@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProlectsweIIIntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.TempeI@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector S-217 (PTD #2070950) TxIA communication to MI mitigated with patch All, Injector S-217 (PTD # 2070950) was put on miscible gas injection on 07/14/18 to commence the 14 day evaluation period BP was granted to asses TAA communicaiton post patch repair. Since the well was put online, daily monitors have proven the TxIA communication on MI has been successfully mitigated. The AOGCC has granted permission to leave the well online while an AA cancelation is progressed. At this time the well is reclassified as Operable. A follow up communication will be sent once the AA cancelation is approved. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ti„f,e From: AK, GWO Well Integrity Engineer Sent: Saturday, July 14, 2018 8:44 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead @bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN(c@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin <Austin.Draughon@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>; Zoesch, Eric <zoese0@BP.com>; 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProlectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsevl@bp.com>; Dickerman, Eric <Eric.Dickerman @bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.lanowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIG EWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.TempeI@bp.com>; Worthington, Aras 1 <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (iim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: S-217 (PTD #2070950) Continue MI evaluation post patch set All, Injector S-217 (PTD #2070950) was previously put on MI to evaluate for TxIA communication post patch set. An MI outage during the evaluation period did not give the optimal time period to assess the results. The state has granted BP 14 more days of injection on MI to continue the evaluation period. The well is now classified as UNDER EVALUATION for 14 days to monitor for TxIA communication. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Wednesday, May 16, 2018 10:44 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Youngmun, Alex <vounak@BP.com>; 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProlectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.TempeI@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (aim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <a kgwowellintegritywe@bp.com> Subject: NOT OPERABLE: S-217 (PTD #2070950) MI evaluation period complete All, Injector 5-217 (PTD #2070950) was made under evaluation on 4/21/18 to assess for TxIA communication post patch repair. The well was on MI injection for 21 days before it was shut in for an outage on 5/12/18. MI is currently unavailable on the WOA and will not become available until after the 28 day clock expires. At this time the well is reclassified as Not Operable and will remain shut in. Real time pressure data for the 21 day injection period will be reviewed and application for AA cancelation will be progressed accordingly. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 wo From: AK, GWO Well Integrity Engineer Sent: Saturday, April 21, 2018 9:13 AM To: 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 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Amy; Youngmun, Alex; 'chris.wallace@alaska.gov' 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; 'Regg, James B (DOA) (jim.regg(aalaska.gov)' Subject: UNDER EVALUATION: S-217 (PTD #2070950) monitor on MI post patch set All, Injector 5-217 (PTD #2070950) is a produced water injector that operates under AIO 25A.010 for having TxIA communication when on MI. In July 2017 slickline was performing a leak detect log to troubleshoot a water flood regulator when they discovered a hole in the production tubing at 6,457' MD, just below the cement squeezed production packer and above the OA sands isolation packer. It is believed the TxIA communication was due to MI gas leaking though the hole and up the cement squeezed production packer causing IA repressurization. On 01/26/18 Eline set a patch to repair the hole in accordance with approved Sundry 317-415. The state has granted BP permission to put the well on MI injection for 14 days to monitor for IA repressurization. Once the well is on stable injection an AOGCC witnessed MIT -IA will be performed. If there is no evidence of IA repressurization and the well passes the MIT -IA the well will be monitored for another 14 days to prove the TxIA communication has been mitigated. If the well does not show any signs of communication the AA will be cancelled and the well will return to WAG status. The well is now classified as UNDER EVALUATION and is on the 28 day clock for the previously mentioned plan. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Friday, April 24, 2020 5:56 AM To: AK, GWO SUPT Well Integrity; Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Glasheen, Brian P Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD 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; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J Subject: UNDER EVALUATION: Injector S-217 (PTD #2070950) monitor IA on water injection All, Injector S-217 (PTD # 2070950) recently underwent wellwork to configure it for water injection, per Sundry 319-321. The well was put on injection this morning. It is now reclassified as UNDER EVALUATION, to monitor the inner annulus (IA) for repressurization. Plan Forward: 1. Operations: put well on water injection — Completed 04/24/20 2. Well Integrity: monitor IA— In progress 3. Well Integrity: Consider AA if IA repressurization is observed. Please respond with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, July 28, 2018 2:30 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin <Austin.Draughon@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Frankenburg, Amy <Amy.Fra nkenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>; Zoesch, Eric <zoese0@BP.com>; 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector S-217 (PTD #2070950) TxIA communication to MI mitigated with patch All, Injector S-217 (PTD # 2070950) was put on miscible gas injection on 07/14/18 to commence the 14 day evaluation period BP was granted to asses TxIA communicaiton post patch repair. Since the well was put online, daily monitors have proven the TxIA communication on MI has been successfully mitigated. The AOGCC has granted permission to leave the well online while an AA cancelation is progressed. At this time the well is reclassified as Operable. A follow up communication will be sent once the AA cancelation is approved. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: AK, GWO Well Integrity Engineer Sent: Saturday, July 14, 2018 8:44 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilitvOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WelIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin <Austin.Draughon@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupert, C. Ryan <RVan.Rupert@BP.com>; Wellman, Julie <Julie.Wellman@bp.com>; Youngmun, Alex <younak@BP.com>; Zoesch, Eric <zoese0@BP.com>; 'ch ris.waIlace@alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProlectsWeIIIntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity<AKDCWelllntegritVCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <RVan.Daniel@bp.com>; Dempsey, David G <David.Dem pseVl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIG EWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras 1 <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: S-217 (PTD #2070950) Continue MI evaluation post patch set All, Injector S-217 (PTD #2070950) was previously put on MI to evaluate for TxIA communication post patch set. An MI outage during the evaluation period did not give the optimal time period to assess the results. The state has granted BP 14 more days of injection on MI to continue the evaluation period. The well is now classified as UNDER EVALUATION for 14 days to monitor for TxIA communication. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Wednesday, May 16, 2018 10:44 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnpinee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilitVOTL@bp.com>; AK, OPS GC2 Field 0&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WelIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com>; Youngmun, Alex <younak@BP.com>; 'ch ris.waIlace @alaska.gov' <chris.waIlace@alaska.>;ov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelIIntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegritVCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <RVan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis. Montpomery@ bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo @bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (lim.regg@alaska.gov)' <]im.regg@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: NOT OPERABLE: S-217 (PTD #2070950) MI evaluation period complete All, Injector S-217 (PTD #2070950) was made under evaluation on 4/21/18 to assess for TxIA communication post patch repair. The well was on MI injection for 21 days before it was shut in for an outage on 5/12/18. MI is currently unavailable on the WOA and will not become available until after the 28 day clock expires. At this time the well is reclassified as Not Operable and will remain shut in. Real time pressure data for the 21 day injection period will be reviewed and application for AA cancelation will be progressed accordingly. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 wo From: AK, GWO Well Integrity Engineer Sent: Saturday, April 21, 2018 9:13 AM To: 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 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Amy; Youngmun, Alex; 'chris.wallace@alaska.gov' 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; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: S-217 (PTD #2070950) monitor on MI post patch set All, Injector S-217 (PTD #2070950) is a produced water injector that operates under AIO 25A.010 for having TxIA communication when on MI. In July 2017 slickline was performing a leak detect log to troubleshoot a water flood regulator when they discovered a hole in the production tubing at 6,457' MD, just below the cement squeezed production packer and above the OA sands isolation packer. It is believed the TxIA communication was due to MI gas leaking though the hole and up the cement squeezed production packer causing IA repressurization. On 01/26/18 Eline set a patch to repair the hole in accordance with approved Sundry 317-415. The state has granted BP permission to put the well on MI injection for 14 days to monitor for IA repressurization. Once the well is on stable injection an AOGCC witnessed MIT -IA will be performed. If there is no evidence of IA repressurization and the well passes the MIT -IA the well will be monitored for another 14 days to prove the TxIA communication has been mitigated. If the well does not show any signs of communication the AA will be cancelled and the well will return to WAG status. The well is now classified as UNDER EVALUATION and is on the 28 day clock for the previously mentioned plan. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 5 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Thursday, April 23, 2020 2:33 PM To: AK, GWO SUPT Well Integrity Cc: Regg, James B (CED); Mel Rixse Subject: RE: Injector S-217 (PTD #2070950) MIT -IA Required? Adrienne, Looking at the sundry I see all the patch and flow regulator work is basically below the IA cement packer equivalent, and any injection from a bad patch would go to the approved injection zones anyway. A sundry MITIA wouldn't tell us anything different than a week of IA monitoring would and so it isn't required. Regards, Chris -------- Original message -------- From: "AK, GWO SUPT Well Integrity" <AKDCWelllntegrityCoordinator@bp.com> Date: 04/23/2020 6:17 AM (GMT -09:00) To: "Wallace, Chris D (CED)" <chris.waIlace @alaska.gov> Cc: "Regg, James B (CED)" <jim.regg@alaska.gov> Subject: Injector S-217 (PTD #2070950) MIT -IA Required? Hello Chris, We have recently completed the work approved via Sundry 319-321. The sundry does not indicate that a witnessed MIT - IA is required after we put the well back on injection. I wanted to confirm with you that this is correct. The last witnessed MIT -IA passed on 04/27/18 to 3466 psi. Please respond or call with any questions. Thanks, Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 MC s - 217 Regg, James B (CED) �1-b6 76gGr; From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Saturday, May 2, 2020 7:18 AM 7AM / S/(jl Z�lp To: Regg, James B (CED) Cc: AK, OPS FF Well Ops Comp Rep; AK, OPS GP Subject: FW: BPXA PBU Low PSI H2O Injector SVS Defeat - S-217 Jim, BPXA Notification that the low pressure pilot is back in service on S-217 and removed from the Safety Defeated Log. Please call with any questions that you may have. Vince Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska)Inc. Cell (907) 354-1352 Alternate: Lee Hulme From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, April 24, 2020 11:27 AM To: Regg, James B (DOA) <iim.regg@alaska.gov>; Alaska Oil & Gas Conservation Commission Inspectors <aogcc.inspectors@a Iaska.Pov> Cc: AK, OPS FF Well Ops Comp Rep <AKOPSFFWeIIOpsCompRep@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntearityCoordinator@bp.com>; AK, GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com>; AK, RES GPB East Wells Opt Engr<AKRFSGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Daniel, Ryan <Rvan.Daniel@bp.com>; Ketchum, John M <John.Ketchum@bp.com>; Ohms, Danielle H <Danlelle.OhmsC@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2 W e I I pad Lead @ bp.com> Subject: BPXA PBU Low PSI H2O Injector SVS Defeat - S-217 Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that Well S-217 (PTD# - 2070950) is currently operating with the SVS defeated with a well pressure of < 75 psi. The Reservoir Engineer has estimated that it would take about a month to reach an operating pressure enabling the return of the LPP to normal due to reservoir conditions and injection rate restrictions. Per the waiver, BPXA has tagged and logged the defeated components in our Defeated Safety Device data base and we will notify AOGCC once the SVS is returned to service. Please feel free to contact me with any questions that you may have Pkk s-zc7 P7b 7,070%-0 Regg, James B (CED) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Friday, April 24, 2020 11:27 AM 1� 1 4 To: Regg, James B (CED); DOA AOGCC Prudhoe Bay 1 IZ Cc: AK, OPS FF Well Ops Comp Rep; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Engineer; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Daniel, Ryan; Ketchum, John M; Ohms, Danielle H; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead Subject: BPXA PBU Low PSI H2O Injector SVS Defeat - S-217 Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that Well S-217 (PTD# - 20 950) is currently operating with the SVS defeated with a well pressure of < 75 psi. The Reservoir Engineer has estimated that it would take about a month to reach an operating pressure enabling the return of the LPP to normal due to reservoir conditions and injection rate restrictions. ✓ Per the waiver, BPXA has tagged and logged the defeated components in our Defeated Safety Device data base and we will notify AOGCC once the SVS is returned to service. Please feel free to contact me with any questions that you may have. Thank you, Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Cell: (907) 229-5795 (Alternate: Vince Pokryfki) THE STATE "'ALASKA GOVERNOR MIKE DUNLEAVY Lea Duong Senior Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU S-217 Permit to Drill Number: 207-095 Sundry Number: 319-321 Dear Mr. Duong: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JJ Si: hmielowski Commissioner DATED this I qday of July, 2019. "IBDMS -(��JUL 18 2"9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED OTS -7l/ 717 P! 4 ' 7019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdol ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program- ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Pull / Set Patch to 0 Control Movement in Zone 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 207.095 3, Address: P.O. Box 196612 Anchorage, AK 1 99519-6612 Stratigraphic ❑ Service m. 6 API Number: 50-029-23362-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S-217 9, Property Designation (Lease Number): I 10. Field/Pools: ADL 028257. 028258 8 028261- PRUDHOE BAY. POLARIS OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (10: Total Depth TVDi Effective Depth NO Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7049 5490 6549 5058 6549.6626.6804 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 29-108 29-108 Surface 4312 9-5/8" 28-4340 28-3478 5750 3090 Intermediate Production 7013 T' 26-7038 26-5480 7240 1 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6613- 6782 1 5027-5260 3-1/2" 9.2# L-80 L-80 23-6847 Packers and SSSV Type: 3-1/2" HES Dual Feedthru Packer Packers and SSSV MD (ft) and TVD (ti 6454 / 4977 3-12" HES Dual Feeethru Packer 6555/5063 3-12" HES Single Feedthru Packer 6598 / 6100 3-1/2" HES Singel Feedthru Packer 6723 / 5208 12. Attachments: Proposal Summary 0 Wellbore Schematic 71 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: July 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Duonq, Lea be deviated from without prior written approval. Contact Email: Lea. Duongabp.com Authorized Name: Duong, Lea Contact Phone: +1 907 564 4840 Authorized Title: Senior Petroleum Engineer Authorized Signature: Date: W-5/11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I - lj2— 1 - Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS1�'JUI 1 g 2019 Post Initial Injection MIT Req'd? Yes No ❑ , U.........�cc/// Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: �~ 1 pN\A, � APPROVED BYTHE Approved by: L' '�Li COMMISSIONER COMMISSION Date: 4b V 1 1 I ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of appro I. Attachments in Duplicate /�/rl ��,e/iTr.�Y�f f� ,"i 10-403 Sundry Application for Well PBU S-127 PTD #207-095 Expected Start Date: July 15, 2019 Current condition of well: WAG Injection Well, Operable, Offline: Well objective(s): J01 -e- � C S-217 was recently setup to swap back from MI to Water. While ping for the PW, fullbore jumped non -freezable fluid and began injecting PW. The well pressured up and the thought is the waterflood regulator valves are plugged. During the pump in, no response in the downhole gauges also confirm no communication with the wellbore. Also, perform opportunistic red dye testing. Proposed program: 1. Pull patch. Pull RMX and set dummy pont. Pressure test. C/O WF RVs. SRT. Opportunistic Red Dye testing.._.. 2. Fullbore to assist SL. 3. Set Patch. !rf✓la BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Gas Injection Rate: Injection Pressure: 1750 psi Shut-in Wellhead Pressure: 600 psi Reservoirpressure: 1403 psi Well objective(s): J01 -e- � C S-217 was recently setup to swap back from MI to Water. While ping for the PW, fullbore jumped non -freezable fluid and began injecting PW. The well pressured up and the thought is the waterflood regulator valves are plugged. During the pump in, no response in the downhole gauges also confirm no communication with the wellbore. Also, perform opportunistic red dye testing. Proposed program: 1. Pull patch. Pull RMX and set dummy pont. Pressure test. C/O WF RVs. SRT. Opportunistic Red Dye testing.._.. 2. Fullbore to assist SL. 3. Set Patch. !rf✓la BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 I Slickfine Drift tubing. WSL discretion to callout fullbore. Bailing may be required. Pull Patch 2 Pull RMX body @ 6549' MD. Set PX Plug @ 6,549' MD 3 Fullbore Fullbore to assist SL Unit 4 Pressure lest tubing to 2000 psi. If fail, Record LLR. Communication into OA sand inwell report. OA Sand face gauge is working. 5 Slickline Pull Px Plug @ 6,549' MD. Pull RMX Body and WFRV @ 6,626' MD. 6 Pull Flow Sleeve set @ 6,632' MD. Install Dummy valve in Station #3 (6,632' MD). 7 Pull Plug at 6,804' MD. Fullbore to assist in B&F. 8 Fullbore Brush and Flush 60 bbls of 180 F of diesel and flush down tubing tail. 9 Slickline Reset plug @ 6,804' MD. . 10 Pull Station #1 at 6,775' MD (Port Size 16, Light 345 bwpd). 11 Replace Station#1 at 6,775' MD with port size 17, Light, 395 bwpd. 12 Fullbore Perform step -rate infectivity at 1000, 1200, 1400, and 1600 psi to check valve performance. 13 Target injection of 0.48 bpm on 2% KCL water. -If Station #4 may be plugged, may see rate 0.27 brim. Also hole across the OA sand below the acker."' 14 Slickfine Reinstall RMX body and dummy prong @ 6,626' MO 15 Pull Station #4 @ 6,576' MD (Port Size 15, Light, 300 bwpd) "`Once pulled, well may fall under a vacuum" 16 Fullbore Perform open -pocket iryectivity#1 at 200, 400, 600, and 800 psi. Hold each interval for 10 minutes. Maximum allowable rate is 3 bpm. Indicate (08a Sand) In WSR. 17 If rate is >2 bpm @ 1,000 psi, perform Red Dye Treatment See Red Dye Steps in other tab. 18 Slickline Replace in kind (Port Size 15, Light, 300 bwpd) 19 Fullbore Perform step -rate injectivity at 1000, 1200, 1400, and 1600 psi to check valve performance. 20 Target injection of 0.21 bpm on 2% KCL water. ***Target injection may be affected if tubing leak into the OA sand below the productionpacker- 21 Slicklme Pull dummy valve from Station#5 (6,533' MD). Has extended packing. 22 Slickline Set new WFRV port size 11, Light, 160 bwpd 23 Fullbore Perform step -rate injectMty at 1000, 1200, 1400, and 1600 psi to check valve performance. 24 Target injection rate of 0.32 bpm on 2% KCL water. 25 Slickfine Pull dummy prong @ 6,626' MD 26 Fullbore Perform step -rate injectivity at 1000, 1200, 1400, and 1600 psi to check valve performance. 27 Target injection rate of 0.59 bpm on 2% KCL water. 28 Sfickline Pull dummyvake from Station #3 (6,632' MD). Set Flow Sleeve. 29 Install new live WFRV in nipple profile at 6,626' MD. Set port size 19, Light, 500 bwpd 30 Fullbore Perform step -rate injectivityat 1000, 1200, 1400, and 1600 psi to check vaNe performance. 31 .packer.*** Target injection rate of 0.66 bpm with 2% KCL water. -May be off due to a leak below production 32 "'Send valves to GL Engineer for teardown• 33 Eline ""Attempt to redress the 3 112" one trip patch pulled by SL if possible, if not will set a 3 12" two trip WFO assembly with the Relay unit - Set one or two trip WFD 3 12" WidePak VO rated patch over 6.439' MD to 6,464' MD. Reference Tie -In Log HAL LDL O8111/17. IKE= 4-1116"QW WR I FFAs= 11" Fw. -518" CSG 400, L-80 BTC, D = 8.835" CSG, 26#, L-80 TGI XO TO L-80 BTC SAFETY NOTES: H2S READINGS AV ERAGE 125 ppm S-217 WHEN ON MI — WELL REQUIRES A SSSV WHEN ON MI ^' 24' 22D9 75924 - GAS LIFT MD DEV TYPE 1 7 6395 492 2 STA #7 = CB 41 NTE) 6423' 3-12" FTS X NP, Minimum ID =1.50" @ 6549" 34/2" X -LOCK w/RMX BODY 3-1/2' WFD WOEPAK 1 TRP PATCH,6444' - 6476' D= 1.81"(1/26/18) 7" X 3-12" FBS DUAL F®THIRU PKK. D = 2.965' 3-1/2' RA PP TAG 6499' 1 JOINT w / RA TAG PERFORATION SLI40ARY REFLOG: IISfT ON 10/15/07 ANGLE AT TOP PERF: 31-@6513' Nbk1: Refer to Production OB for hsloricai perf data SIZE I SPF I ZONE I INTERVAL OpVSgz SHOT SOZ 4-12' 5 OA 6513 - 6547 O 10/14/07 0727/17 4-11Z 5 OBa 6568-6586 O 10/14107 RK 4-1/2' S OBb 6614-6636 0 1014/07 MMG-W 4-12' S OBc 6674 -6693 O 1014/07 5130 4-12' S OBd 6734-6782 O 1014/07 2 TBC, 17' CSG, 26#, L-80 BTC, .0383 bpf, D = 6.276' 1 *CEMENTED 106104/091 WATER INIE.TION MANDRELS ST NU [TVDIDFVI POLARB UNIT WELL' 5.217 PERMIT No: 2070950 AR No: 50-029-23362-00 SEC 35, T12K R12E, 2123' FNL 8 714' FWL TYPE VLV LATCH FORE DATE 6 6479 4998 31 KW&W 'DI& w 0 0727/17 5 6533 5044 31 K#.rrW `OM1' RK 0 0727/17 4 6576 5081 30 MMG-W R15XJR FEC 15L 01/12/18 3 6632 5130 30 MMG-W FS RK - 10/18/14 2 6694 5183 30 AMrW DMY RK 0 09120/14 1 6775 5253 30 MMGW R15XJR RK 16L 0727117 'STA 06 S #5 = DCTE DM PACKING 646T SUB, D = 2.992* .992'WWSLJWACENb 3-12' X -LOCK w /RAD( BODY, D= 1.50•(03/26/18) 7'X 3-12" HES DLAL F®THRU R97, D=2.965' 7- X 3-12' SINGLE F®THRU FKR D = -2 PHOBND( SENSOR SLB, D = 2.992" w / DUAL WIRE TO SURFACE N b 3-12-X NP, D= 2.813' 3-12' X -LOCK w fF MX BODY, w/P15XJR VVFR- 18L(01/12/18)] 7" X 312' SINGLE FES)YHRU PICK D = 2.965' 3-12" FESS X NP, D = 2.813' 13-12" FES X NP, D = 2.813' 1 1 6824' 1-13-12' H6 XN NP, ID = 2.750' s847' 3-1/2' WLEG, D=2.992' B.AD NOT LOGGB) POLARB UNIT WELL' 5.217 PERMIT No: 2070950 AR No: 50-029-23362-00 SEC 35, T12K R12E, 2123' FNL 8 714' FWL DATE REV BY I 000AENTS DATE REV BY C0MAB4T8 18118107 MKS JIMMLCOMPLEnON M14117 J WJAD WFRCIO(0&10117) 0526!16 RCP/ PULLED XX E SET PX PLUG (032911 0124118 JWJK RESET RAN( 8 SET NEW FMX (1/12118) 05/26116 RCT/RESET RAM( BCWY(03131116) 0124/18 RCEYJK WFRCI0(01/12118) 7 0526/16 MSS/ WFR CIO (0429/16) 01/30118 I SET WFD ONETRP PATCH (0126/18) 08/(12117 JGL/JAO R25ET RMX PRONG w /OM1' WFR 03/27/18 BSEIJK FALL® DW PROM (326118) BP Exploration (Alaska) 08!02117 JGLIJAD WFR CIO (07/27/17) Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Monday, July 1, 2019 3:02 PM To: Obrigewitch, Beau Cc: Rixse, Melvin G (CED) Subject: RE: PBU S-217 Proposal and Request for Meeting PTD ZO 7 0 I .-Q Beau, I am thinking a meeting is not required. Basically with the well work proposed, the Sundry Application process with the resetting of the patch will require a new witnessed MITIA. Assuming that will pass the well will be good for water and MI without an AA. Ongoing, the pressure observations will indicate if anything else is required. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 711 Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.¢ov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,. use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Obrigewitch, Beau <BEAU.OBRIG EWITCH@bp.com> Sent: Monday, July 1, 2019 2:18 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: PBU S-217 Proposal and Request for Meeting Good afternoon Chris, I would like to request a meeting with you regarding a proposal we (BPXA) are working on around PBU Well S-217, and WAG Injection well. Brief History: • Previously operated under AIO 25A.010 for PWI only due to TxIA while on MI (March 2012 - August 2018); There were no indications of IA repressurziation while on PWI • The AA was cancelled because a patch set across the upper most packer mitigated the IA repressurization while on MI • This well was most recently on MI, being shut-in in March 2019 in preparation for a swap to PWI, and remains shut-in until we have agreement with all parties on our proposal • The well is currently in the configuration that allowed the AA to be cancelled (patch is still installed) • The well is currently classified as Operable by BP Wellwork Currently Planned: • We need to pull the patch to perform some water flood regulator valve (WFRV) work to swap it back to PWI; This WFRV will include putting a live valve in STA #5, allowing injection into that zone • Due to the known tubing hole near the upper most packer, the patch will need to be reset, to regulate water injection through the WFRV only Proposal: BPXA requests permission to perform this proposed wellwork, put on PWI, and monitor the IA for repressurization, without applying for an AA BPXA requests permission to keep this well operating without an AA (provided there is no IA repressurization while on PWI), to include returning it to MI in its current state (dummy valves in STAs # S & 6 and a patch across the upper packer), while continue monitoring IA for repressurization I've attached a wellbore schematic, with a red line that shows the path of IA repressurization, for your reference. Please note that our proposal is to continue operating this well without an approved AA. Our intent is to ensure AOGCC is fully aware of our intent, and to gain acceptance of our plan. Please let me know a convenient time to discuss this, either in person or over the phone. Kind regards, Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Assigned Seat: 790D Office: (907) 564-4854 Cell: (907) 952-6271 WO 00bM ... d...n..m,. • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, May 16, 2018 10:44 AM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL; K, 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 Well Pad LV;A , 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 TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Frankenburg, Amy;Youngmun,Alex;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects 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; 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; Regg,James B (DOA);AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: S-217 (PTD#2070950) MI evaluation period complete All, Injector S-217(PTD#2070950)was made under evaluation on 4/21/18 to assess for TxIA communication post patch repair. The well was on MI injection for 21 days before it was shut in for an outage on 5/12/18. MI is currently unavailable on the WOA and will not become available until after the 28 day clock expires. At this time the well is reclassified as Not Operable and will remain shut in. Real time pressure data for the 21 day injection period will be reviewed and application for AA cancelation will be progressed accordingly. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCOW ' *_ From: AK, GWO Wel - -.rity Engineer Sent: Saturday, April 21, 20 •• 3 AM To: AK, OPS EOC Specialists; AK, OP Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, •• • .d Controllers; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAP ; e OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; - •ES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Amy; Youngmun, Alex; 'chris.wallace@alaska.gov' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO • •'-• Well Integrity; AK, GWO SUPT 0 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 30,2018 TO: Jim ReggT ((yy 511 Il©j P.I.Supervis Ji SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-217 FROM: Brian Bixby PRUDHOE BAY UN POL S-217 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry;J�P-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S-217 API Well Number 50-029-23362-00-00 Inspector Name: Brian Bixby Permit Number: 207-095-0 Inspection Date: 4/27/2018 Insp Num: mitBDB180427142824 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j S-217 " Type Inj G-'TVD4977 , 1 Tubing 2153 - 2191 - 2166 r 2158 ' PTD 1 2070950 " Type Test SPT Test psi 1500 - 1 IA 754 3601 - 3500 - 3466 BBL Pumped:1 31 - BBL Returned: 3.2 OA 160 521 - 514 504 ' Interval INITAL P/F P ,/ Notes: Sundry 317-415 Post Tubing Patch '.." SCANNED Monday,April 30,2018 Page 1 of I • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,April 21, 2018 9:13 AM 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 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 TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Frankenburg,Amy;Youngmun,Alex; Wallace, Chris D (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; Regg,James B (DOA) Subject: UNDER EVALUATION: S-217 (PTD#2070950) monitor on MI post patch set All, Injector S-217(PTD#2070950) is a produced water injector that operates under AIO 25A.010 for having TxIA communication when on MI. In July 2017 slickline was performing a leak detect log to troubleshoot a water flood regulator when they discovered a hole in the production tubing at 6,457' MD, just below the cement squeezed production packer and above the OA sands isolation packer. It is believed the TxIA communication was due to MI gas leaking though the hole and up the cement squeezed production packer causing IA repressurization. On 01/26/18 Eline set a patch to repair the hole in accordance with approved Sundry 317-415.The state has granted BP permission to put the well on MI injection for 14 days to monitor for IA repressurization.Once the well is on stable injection an AOGCC witnessed MIT-IA will be performed. If there is no evidence of IA repressurization and the well passes the MIT-IA the well will be monitored for another 14 days to prove the TxIA communication has been mitigated. If the well does not show any signs of communication the AA will be cancelled and the well will return to WAG status.The well is now classified as UNDER EVALUATION and is on the 28 day clock for the previously mentioned plan. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SCANNED } 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, February 13, 2018 8:09 AM To: 'AK, GWO Well Integrity Engineer' Subject: RE: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Joshua, Injection of MI for up to 28 days diagnostics and monitoring as per plan below is approved. Looking at the Sundry 317-415, a post injection MIT is specified in the sundry(last MIT I have was 2/28/2016 so I do not have this record if it was completed)and this will be critical to confirming TxIA(inner annulus repressurization) is mitigated, MI continuity and AA cancellation. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information mayviolate state or federal law. Ifyou are an unintended recipient of this e-mail, p please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:AK, GWO Well Integrity Engineer [mailto:AKGWOWeIISiteEnginee@bp.com] Sent: Monday, February 12, 2018 5:37 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: FW: Injector 5-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Chris, It's been a while since we last spoke about S-217 so to give you a short recap. S-217 is a PWI that operates under AIO 25A.010 for slow TxIA communication while on MI. In July 2017 BP was granted permission to place the well on MI for 14 days in order to run a leak detect log. In September slickline was preparing the well for MI injection when they found a hole in the production liner that we think may have been the cause of the TxIA communication. We discussed changing the diagnostic plan and it was recommended that we capture it in the 10-403 for the patch repair. The patch was set on 1/26/18 and I was reviewing the approved sundry and noticed the diagnostic plan forward was not adequately communicated. Looking a bit deeper I noticed the sundry was actually submitted prior to our conversation on Sept. 5th where we agreed to outline the plan in the 10-403. I apologize for not catching earlier and having a revised 10- 403 submitted. Moving forward BP is requesting that we bring the well on MI injection for 14 days post patch repair to monitor for IA repressurization. If the well does not show signs of IA repress we will extend the monitor period an additional 14 days to confirm the TxIA communication has been mitigated. If the patch repair is successful we will move to get the AA canceled and the well reclassified as WAG. Please let me know if you approve of this plan forward or need any further information to make a decision. 1 • • • . Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 'What wires 6.0104.1410t411 From:Wallace,Chris D(DOA) mailto:chris.wallace@alaska.gov Sent:Tuesday,September 5, 2017 11:21 AM To:AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Cc:AK,GWO SUPT Well Integrity<AKDCWellIntegrityCoordinator@bp.com>;Youngmun,Alex<younak@BP.com>;AK, GWO Well Integrity Well Information<akgwowellintegritywe@bp.com> Subject: RE: Injector 5-217(PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Joshua, The new plan for a tubing patch would require a 10-403 I believe, and that 10-403 can detail the plan and contingency for MI injection and monitoring. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:AK,GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent:Tuesday,September 5, 2017 9:38 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:AK,GWO SUPT Well Integrity<AKDCWelllntegritvCoordinator@bp.com>;Youngmun,Alex<younak@BP.com>;AK, GWO Well Integrity Well Information<akgwowellintegritywe@bp.com> Subject: RE: Injector 5-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. 2 • • Hi Chris, Since we last spoke about S-217 slickline went out and performed a water flood regulator change out in preparation for the MI swap and leak detection log. During the course of the work we believe we may have found the source of the TxIA communication. A spinner/temp/pressure log was ran on 8/11/17 to trouble shoot a water flood regulator and a hole was found at 6457'which is between production packer and the OA sands isolation packer. We currently think the TxIA communication on gas was caused by MI leaking through this hole,and past the cement squeezed packer at 6,454' and into the inner annulus(see attached schematic). Given this new information we would like to change the diagnostic/repair plan for this well. The new request is for permission to set a patch over the hole at 6,457', place the well on MI injection for 14 days and monitor for IA repressurization. If we do not see IA repressurization after 14 days we will continue to monitor for an additional 14 days to verify the TxIA communication has been mitigated. If we do see IA repressurization at any time during the monitor period we will run the ACX leak detect log as originally planned. Please let us know if this revised plan forward is acceptable; if you have any questions feel free to call or email me. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 wo .ye.r-»b....r..«r- From: . .ce, Chris D (DOA) [mailto:chris.wallace©alaska.gov] Sent: Monda, July 17, 2017 1:26 PM To: AK, GWO We ntegrity Engineer Subject: RE: Inject• S-217 (PTD# 2070950) Request permission to inject MI Under Evaluation for diagnostics. Adrienne,Joshua, Thank you for the follow up ca . Permission is granted for the proposed MI for the leak detect as per the plan below. Victoria is out for the day,so you ould check with her directly tomorrow on your question of 10-403/sundry requirements,or when you get rea• to do this work. Thanks, Chris From:AK,GWO Well Integrity Engineer[mailto:AKGWO ellSiteEn_inee ' b..com] Sent:Wednesday,July 5, 2017 2:49 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: Injector 5-217 (PTD#2070950) Request permission to in -ct MI Under Evaluation for diagnostics. 3 STATE OF ECE �LASKA OIL AND GAS CONSERVATION COMMIS IVE • REPORT OF SUNDRY WELL OPERATIONS FEB1. Operations Performed B 1 3 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Prra i 4•L�d1.0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Patch �/ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-095 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-23362-00-00 7. Property Designation(Lease Number): ADL 0028261 8. Well Name and Number: PBU S-217 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: . PRUDHOE BAY,POLARIS OIL 11.Present Well Condition Summary: Total Depth: measured 7049 feet Plugs measured 6549/6804 feet true vertical 5490 feet Junk measured 6860 feet Effective Depth: measured 6549 feet Packer measured See Attachment feet true vertical 5058 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 Surface 4312 9-5/8" 28-4339 28-3478 5750 3090 Intermediate Production 7013 7" 26-7039 26-5481 7240 5410 Liner Perforation Depth: Measured depth: 6513-6782 feet t True vertical depth: 5027-5260 feet Tubing(size,grade,measured and true vertical depth) 4-1/2x3-1/2,L-80 24-6848 24-5317 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -208 360 1985 Subsequent to operation: Shut-In 100 50 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.2831 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 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: 317-415 Authorized Name: Youngmun,Alex Contact Name: Youngmun,Alex Authorized Title: Kuparuk&Schrader Bluff PE Contact Email: younak@BP.com Authorized Signature: //by i Date: a/�'/(u Contact Phone: +1 907 564 4864 Form 10-404 Revised 04/2017 V`1' 311 . Ala RP€�:s! s u" FEE, . X018 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 12, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Patch to Repair the Tubing covered under Sundry Approval # 317-415 for Well S-217, PTD # 207-095. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • L CB Zr) C Y Y U U O 0 (t3 (d Ca (B d 0- 0..a. C L L L L L -c G.a) N LU) U) y LL LL U) U) (is (6 C7) C3) d C C 00 Ci) W W W I I I I }r N N N N r r r w AAAA E co co O) — O d7 O) < > Ch OO) ti I— O O O r in LO In ` N Cn m • a _ cC N t!) 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SAF TES:H2S READINGS AVERAGE 125 ppm ✓ACTUATOR= BAKER WHEN ON MI" WELL"WELL RtRES A SSSV WHEN ON MI"' NTIAL KB.ELE 67' "CONDUCTOR - ? l I BF.l3EV 38.5' 24' -14-1/2"X 3-1/7 XO,D=2.997 KOP= 300' 0= Max Angle= 50'@ 4370' j I I 2891' -j 3-1/2"I C5 X NP,D=2.813" Datura M D= 6559'TAM FORT COLLAR -1 996' Datura W D= 5000'SS , GAS LFT MANDRELS 9.5/8"CSG,40#,L-80 BTC,D=8.835' H 4340' I ST NO TVD DEV TYPE VLV LATCH'PORT DATE 7 6395 4926 32 MMG EMPTY 'CEMENTED 06/04/09 r CSG,26#,L-80 TC-I XO TO L-80 BTC-M -H 5924' +mac 'STA#7=CEMENTED EST TOP OF CEMENT(07/10/09) H 6224' , 6423' 3 1/2 1 X NP,D=2.813" Minimum ID = 1.81" @ &444" �' e : WATER INJECTION MANDRELS 3-1/2" WFD WIDEPAK PATCH ST MD TVD DEV TYPE VLV LATCH PORT DATE ' 41 r, 6 6479 4998 31 MMG-W `DMY RK 0 07/27/17 3-1/2'WFD WDEPAK 1 TRP PATCH, --I 6444'-6476' >t« `✓.: 5 6533 5044 31 MMG-W *OW RK 0 07/27/17 0=1.81"(1/26/18) .* 4 6576 5081 30 MMG-W P-15XJR RK 15L 01/12/18 [r X 3-1/2"FES DUAL FE8)1}F U PKR,O=2.965' —I 6464" *•- 210' 3 6632 5130 30 MIVG-W FS RK - 10/18/14 I/� 2 6694 5183 30 MMG-W DMY RK 0 09/20/14 1 6775 5253 30 MMG-W P-15XJR FE 16L 07/27/17 � "STA#6 8#5=EJ(TE�DEii PACKING 6467' i-PHO8IX SENSOR Sill,D=2.997 3-1/2"RA PP TAG -{ 6499' * w I DUAL WIRE TO SURFACE NIA 7"MARKER JOINT w/RA TAG - 6530' © Li IBI---- , 6549` -3-1/7 HES x NP,D=2.813" 6549' -3-1/2"X-LOCK w/RAX BODY, w/DMY WFR(01/12/18) 6555' ,-7"X 3-1/7 HES DUAL FE£)1 HRU PKR,D=2.965" X X 6598' 7'X 3-1/7 S1 NGLE FEHfl-RU PKR,D=2.965" I 6606' F-PHOB'X SENSOR SUB,D=2.992' PERFORATION SUMMARY REF LOG: UST ON 10/15/07 - w/DUAL WRE TO SURFAC E N IA ANGLE AT TCP PERF: 31'0 6513' I 6626' -3-1/7 HES X NP,D=2.813" Nbte:Refer to R-oduction DB for historical perf data IIM 6626' _-3-1/2'X-LOCK w/RMX BODY, SIZE SPF ZONE INTERVAL Opn/Sqz SHOT S[)7 fl w/P15XJR WFR-181(01/12/18) 4-1/7 5 OA 6513-6547 0 10/14/07 Mr 4-1/2" 5 OBa 6568-6586 0 10/14/07p v 6723' --I T'X 3-1/7 SIV(3LE FEEDT)-RU PKI,D=2.965" 4-1/2" 5 OBb 6614-6636 0 10/14/07 /" /� 4-1/7 5 OBc 6674-6693 0 10/14/07 I I 6754' -3.1/2"HIS X NP,D=2.813" 4-1/7 5 OBd 6734-6782 0 10/14/17 IbI6804' --I3-1/2"HES X NP,D=2.813' 6804' IH3-1/2'PX PLUG(03/29/16) I I 6824' H 31/2"FES XN NP,D=2.750' 3-1/2"TBG,9.2#,L-80 TCI, .0087 bpf.D=2.997 -- 6847' 6847' -3-1/2"WLEG,D=2.997 I PBTD -i 6954' 1111111111 -{�k,D NOT LOGGED 7'CSG,261,L-80 BTC,.0383 bpf,D=6.276" -I 7038' ,.......4......V. -1 DATE REV BY CONSENTS DATE REV BY CONSENTS POLARIS UNIT 10/18/07 N9135 INITIAL COM PLETiON 08/14/17 JFK/14.4D WFR CO(08/10/17) WELL S-217 05/26/16 RCT/JMD PULLED XX&SET PX PLUG(03/29/1 01/24/18 JMG/JMD RESET RM)(&SET NEIN FdW(1/12/18) PERMIT No: 2070950 05/26/16 RCT/AID RESET RSV BODY (03/31/16) 01/24/18 RCB/A413 WFR C/O(01/12118) AR Pb: 50-029-23362-00 05/26/16 MSS/JMD WFR C/O(04/29/16) 01/30/18 KFtuMJWD SET WFD ONE TRP PATCH(01/26/18) SEC 35,T12N,R12E,2123'FM..&714'FWL 08/02/17 JGUJMD RESET MAX PRONG w/DM1'WFR 08/02/17 JGUJMD WFR GO(07/27/17) BP Exploration(Alaska) - a°► 5 RECEIVED • • OCT 19 2017 WELL LOG TRANSMITTAL#904229095 TolkOiackicil and Gas Conservation Comm. October 16, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ,0 ,� „-� Anchorage, Alaska 99501 `` RENLJLR RE: Leak Detect Log: S-217 Run Date: 8/11/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 S-217 Digital Log Image files 1 CD Rom 50-029-23362-00 Leak Detection Log scotE . � 1 Color Log 50-029-23362-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: ✓�� vV��N • VOF Tyi A THE STATE Alaska Oil and Gas s ®f sK A Conservation Commission t�t ,� 333 West Seventh Avenue INN c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Alex Youngman Kuparuk And Schrader Bluff PE BP Exploration(Alaska), Inc. PO Box 196612 SCANNED SEP 1 12017, Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-217 Permit to Drill Number: 207-095 Sundry Number: 317-415 Dear Mr. Youngman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Commissioner DATED this (p day of September, 2017. RBDMS [.,v - 8 2017 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 • Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 ChangeApp�oved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Se/14%h�' 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 207-095 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service 0. 6. API Number: 50-029-23362-00-00- 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number. Will planned perforations require a spacing exception? Yes 0 No 0 PBU S-217 • RECEIVED 9. ADL Property Designation(Lease Number): 10. Field/Pools: 9 n PRUDHOE BAY,POLARIS OIL AUG 2 2017 11. PRESENT WELL CONDITION SUMMARY A 6r(ri ./ /2 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 7049 ' 5490 • 6626 5124 6626/6804 6860 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"215.5#A-53 28-108 28-108 Surface 4312 9-5/8"40#L-80 28-4339 28-3478 5750 3090 Intermediate Production 7013 7"26#L-80 26-7039 26-5481 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 ' WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name Youngmun,Alex be deviated from without prior written approval. Contact Email: younak@BP.com Authorized Name: Youngmun,Alex Contact Phone: +1 907 564 4864 Authorized Title: Kuparuk&Schrader Bluff PE Authorized Signature: MAW Date: e'o?9 'ac (i COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number-:/ I PlugIntegrity _/ 3 t `-L-( `5 9 ty 0 BOP Test 0 Mechanical Integrity Test IV Location Clearance 0 Other. Post Initial Injection MIT Req'd? Yes Er No I:21/Spacing Exception Required? Yes 0 No Q Subsequent Form Required: 1 0-4-0' D ¢r CBYTHE HEApproved byU / ...4.1.44.__ COMMISSIONER COMMISSION Date:g_G_/7 VrL- 'IN/7. o R I C I NA L RBDMS L� `Jtel' - x2017 ,4, 00 7 gr- 3c)-t7 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED AUG 2 9 2017 , OC+ 0 Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) August 29, 2017 To Whom it May Concern: Attached please find the Sundry Application for Setting of a Patch for Well S-217, PTD # 207-095. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR,LHD,EAZ, BPG 10/12/15) General Information Well Name: S-217 Well Type: i Water Injection Well API Number: 50-029-23362-00 Well Activity Conventional 4 Classification: Activity Description: Install WFRV's and Set Patch Cost Code/AFE: APBINJEC Field/Reservoir: POLARIS 12 Month Avg IOR, bopd: Job Type: UNDER EVAL Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory Wavier from AOGCC-Already requirements? granted Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Alex Youngmun Contact numbers: (907)564-4864 (907)250-1228 Well Intervention Engineer: Beau Obrigewitch Contact numbers: (907)564-4854 (907)952-6271 Lead Engineer: Ryan Rupert Contact numbers: (907)564-4238 (907)301-1736 Date Created: August 23. 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate ori Oil Rate In) Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 7/3/2017 0 0 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) NA NA Maximum Deviation(Angle and Depth) 50' 4,370'MD Datum depth,ft TVDss -5,000'TVDss Dogleg Severity(Angle and Depth) 5° 6.090'MD Reservoir pressure(date, psig) 4/26/2016 2.039 psi Minimum ID and Depth 2.750" 6.824'MD Reservoir Temp, F 86° F Shut-in Wellhead Pressure 430 psi(8/11/17) Known mech. integrity TxIA when on MI. IA cement packer squeeze on 7/10/09 to repair failed packer Passes MIT-IA to fluid. problems(specifics) Tubing leak to formation at 6,457'(conformance issue does not affect operability of well). Last downhole operation(date,operation) 8/11/2017 SL ran STP LDL. Most recent TD tag(date, depth, toolstring OD) 5/3/2009 6.896'MD 2.5"drift during WFRV C/O MI line is currently operable. Will be placed on MI post job. PWI line is not Surface Kit Fit-for-Service? YES If No,Why? currently operable due to header leak. • i Comments,well history, Pertinent Intervention History: background information, A WFRV changeout was conducted in July 2017 in preparation for HES's ACX log to MI. During the job, a etc: leak to fluid was identified and confirmed with a STP LDL just below the packer at 6.457'. The leak is to the formation and was observed on the OA sandface pressure gauge. There was no pressure response seen on the IA. The ACX log has been cancelled due to the identified leak to fluid. An open pocket injectivity test was conducted on the OBa sand during this job. The tubing was on a vac at an injection rate of 3 bpm. FB was unable to catch pressure after 43 bbls were pumped, indicating an MBE. A flow sleeve is set in ST#3 as the mandrel is washed out. This has resulted in the lower two sands having commingled injection with a WFR set in the X-nipple above ST#3 to regulate total flow into the OBb/c and OBd to prevent over-injection into the OBb/c. Background Information: S-217 is currently classified as Not Operable for tracking purposes to ensure the well is not inadvertently placed on MI. S-217 is an operable Polaris PWI with known TxIA communication when on gas. S-217 has only injected one slug of MI, from June - October of 2010. The well has —230' of cement in the IA for a packer repair performed in 2009. Attempts to pinpoint the location of the TxIA communication while on MI injection to date have been unsuccessful. S-217 currently operates under A1O 25A.010 for water only service.AOGCC granted permission to return S-217 to MI injection on 7/18/17(PTD#2070950)for 14 days to conduct diagnostic work while injecting MI. S-217 will be reclassified as under evaluation and the clock will be set to 14 days once it's ready to put online. Job Justification: The leak point at 6,457'below the packer is thought to be the culprit for the IA re-pressurization to gas. See risk#4 below for IOR justification. MI injection is not planned in the OA sand interval as it is thought to be a potential leak path for gas to migrate into the IA via micro-annulus in the cement by tubing/I-wire. S-217's Relevant MIT's/LLR's: •08/11/17: LLR of 0.3 bpm was established down the tubing at 2950 psi during the LDL. •02/28/16: AOGCC MIT-IA passed to 2374 psi • •02/19/16: MIT-IA passed to 2500 psi •09/25/10: MIT-IA to fluid passed to 4000 psi • • ITU= 4 1/16-CON r _ VW...1J-1E-AD- 1r i. S-217 I SAFETY NOTES:1425 READINGS AVERAGE 125 ppm I WHEN ON Mi-WELL REQUIRES A SSSV WHEN ON MI- ACTUATOR- BAK:'• J i U 1114716, KB R F i.-17. ,i,N,i 4 8 MV 35',' rs ; 1 24' -4 1,7"X.1 I".?"N'7' 43'i 997'j KOP--. 390' Mer Angle- 50 tg 4377 / II 2891- J-3-12-1-ES X FOP ID-2 813' CutumND- 6559, TAM PORT COLLAR -L 996. . DatL,rn TVD - 1000.5.,- GAS IFI MANDRELS 4 S11"("N.G.40P.1 If)rile 1) 9 a 11,- '.• 4340' -ST _,I.. MD TY0 OEY' rem VLV LATCH Ti DATE T1639 - _- __ . 5 4926 32 WAG IENFTY •cEmENTED 06.40.U00- r-2--OS-C2c.ii t '6;0 Foil.xisititi-..4 H --stri.-.4,-; i ,-,.. 'STA 47 CEMENTED ,. .. . .... ESI COCE P Of MENT(07)10109) 1--, 6224' 1 ,.-- / 6423 it,... [Minimum ID =2.750 @ CI324" r.,- ;ea WA Tin 814JcerioN1144•630CES - I r..... TYPE--VLS7- LATCH FORT DATE 3-1/2" HES XN NIPPLE 1 N.. 6 647914996• 31 IWAG W 'WY RK 0 3127/17 jr..1'..r.; ill 5 6533 5044 11 MIAG 1/4 'MAY RK 0 37,27212' 4 6576;5061 10 MING IN flIJIY RK 0 ;361W1, tr- • tie I1. 11 3 6632 5130• 36 .4310-W FS RK - J 1001 /14 ;7"X 3 1/2-HES DUA; FOE01)46)PKR,ID.-7965- - 6464' 1":"14 669415183 30 MIAG-VV DOW PK 1 o I moor 14 vi LI 6775 5253 312 [W.&-W P-15XJR FM j 16 1 0712711/ '57*66 1P5=izknacimeAckiNG . mir6467' -R-10E14.3t SENSOR SUB.0-2.997 3 1/7 RA PE,TAG - 8499' - a I w/:AJAL NINE TO SURFACE IN IA _ . . _ . Al L-^MARKER if W41 sr,'RA If AC. i 6530' '--- '' • [ 164.• -43-l/7 FES X MP II=2 513" S. ilrizi r x 1.-1,2-i tt..-;AAA L FEEOTHRU ERR ID=2 965" !WI I I _ PexpoP.Anon SILS.41.44RY 65138- a r-X 3 1,7 SIVOLE FEEDTEWIJ ERR,33=2 96-5----1 PEI-LOG LCIT ON 10/15,07 fr I ANC*E Al Top wg,IF 31 g 11513 $806' i 4 Or Nu,.:i-nr,nii.r;u3 i.i.2 1 w,I 43 1 Mete Refer Li Production E6 fsw nislorical perf data UUAL 4,40 sat)ALL NA ...__ 1_SIZE SF*_ZOnts.'.1141TY3=5/Ai OpniSor SHOT SOZ IR li I 662Er ---:i.1,7 HES x MP IL,-2 313'1 I 4-10^ 5 , OA 0513-9541 o 10'143)7 -. ___. _ 4 1,2- 5 (BLi 6566 55036 0 10'143)7 Mr! L 6626 j- 3.1/2•tc-100(*tR11.0(BODY w l ONY WFR(07,-2E217 1,4-1,2- 5 cab 6614 66311 0 10'14107 14 127' 5 CO. 6674 6693 0 1014317MU . :„.., No 4773' ' IT-'at I.1,,-3144'11 Prrrrinni.J114R,ID-2 985' It 1,-r ; i-,14.-1,8114 8790 n 10214437 1 1 1 1 I 6764' 3-1'”i IFS X 111' ED'--• -,313' IMP I 1004' + I,'HE,:X NV I.) 281 _... --'----• 44304. _-1-3-1 i 2-PX PLUG(03,729/18)I 6624' H3-1/2"HES X14 NP ID-,2 750' 3 117 MG 970 L 80 Tat 008'hpf 0 -2897j-1 6647' J = 68410-' H3-1/74-gG,ii3. --iir. --13)-70--] i iii -1 ,„ - i-1 n kin 30T'000E0 ' .,.___._... „____._.._ A 4.6.046.4.0.64 1 .J1.11.4.11,11.0.1 I'CSC.264.1. 101:11e, 0363 EV.0 6 2(6' I 1 7036' , TY*TEL REV BY II ODMIIEN1S I [ATE REV BY 03466NiS POI AF-tt-;LW, *- r - 10,18,07 PL S TINITIA t,COMPLETION 108r14/171=JFKi.A43 wyp on(08,Mr 17) WEIL 521! i - ;-0tv?f....,07, RI..:-J/4.4)Pu_t_a!KX 3 SET PX Pt L10(03129.16) i-i-pkin No"20/0950 _ cr2c,i 16 WI/JIAJ1Rts-L"RAM aour(03131/16) + - Ail 5.... 50 029 23362 00 05,,m416 mS_Si.0411%M-R CFO(04:29/16) SEC 35.TUN,R12E 2123'1-1•41.8/14*Fv4 I 38ia2i1 7 Jr.i*AC,RESET RIM PRneen NW/LIMY WER 1;013,1132/17.X il 0114)VIER 00(07(2 Fl -in Bp E,plor Wien in laa ka) r • 1 of 1 Bottom Hole Assembly Schematic OPs Document Number Classification Document Level Revision Issue Date Prepared By Approval GL-WLS-OEPS-L4-01.03 Controlled L5 1 08-Nov-16 WCT Technical Documentation Group WCT TWIC Customer BP Weatherford Location Deadhorse Job Number Contact Alex Youngman Operation Set 25'One Trip Patch Prepared by Chris Moloney Field/Well Number S-217 Rig/Platform Date 8/25/2017 BHA Item Description OD ID Length Fish Neck SWL Make-Up Serial (schematic) (in.) (in.) (ft.) (lbs.) (ft-lbf) Number Setting Sleeve 2.7 0.6 E WidePak One Trip 2.72 1.81 5.43 Upper Packer Top Of Packer to Center Element 4.0' Spacer Pipe 2.375 1.975 9.07 Collar 2.71 1.992 0.93 Spacer Pipe 2.375 1.975 7.06 Collar 2.71 1.992 0.93 evw Spacer Pipe 2.375 1.975 4.06 WidePak One Trip 2.72 1.81 4.8 Lower Packer Shear Ring Setting Force 15,000 Center Element to Bottom of Packer , 3.05' Overall BHA Length(ft) 32.88 Verified by Date Note:All dimensions are approximate until verified by Weatherford supervisor in the field prior to run in hole. • • • 1 011 Bottom Hole Assembly Schematic 02 PS Document Number Classification Document Level Revision Issue Date Prepared By Approval GL-WLS-DEPS-L4-01.03 Controlled L5 1 08-Nov-16 WCT Technical Documentation Group WCT TWIC Customer BP Weatherford Location Deadhorse Job Number Contact Alex Youngmun Operation Set 25'One Trip Patch Prepared by Chris Moloney Field/Well Number S-217 Rig/Platform Date 8/25/2017 BHA Item Description OD ID Length Fish Neck SWL Make-Up Serial (schematic) (in.) (in.) (ft.) (lbs.) (ft-lbf) Number "NEED WEATHERFORD OTS RETREIVAL TOOL" WidePak One Trip 2.72 1.81 5.43 Upper Packer Top Of Packer to Center Element 4.0' Release Force 7,200 Lbs Element Set at 6448'MD Spacer Pipe 2.375 1.975 9.07 Collar 2.71 1.992 0.93 Spacer Pipe 2.375 1.975 7.06 Collar 2.71 1.992 0.93 Spacer Pipe 2.375 1.975 4.06 WidePak One Trip 2.72 1.81 4.8 CPAI Lower Packer Center Element to Bottom of Packer 3.05' =gement Set at 6473'MD "NEED WEATHERFORD OTS RETREIVAL TOOL" I I I Overall BHA Length(ft) 32.28 Verified by Date Note:All dimensions are approximate until verified by Weatherford supervisor in the field prior to run in hole. 0 • . LEAK DETECT LOG HALLIBURTON . Cl < 8 I' 0 Company BP EXPLORATION (ALASKA) INC. , Well S-217 45.,..._. 2 (/) >zoo zzoco Z Field PRUDHOE BAY UNIT 0 CO CC 2- zz' --, 0 C aunty N. SLOPE State ALASKA 00 LU API No- 50 029,23362-00 Sery 4: 904229095 Other Services 0 LLI CL. i 0- Location: 2123'FNL& 714'FWL t.L.i to LL LU ? Lsa =L-, > 0,'S 1-- __] 1-- D co LLSRui ›— CO CO 0 Z NONE >.. C r:- .,,tg CO - <W I= CO a ,•4' c5 0 CC 0 Sec:35 Twp: 2N Rge:12EaLcricc• oc o_FD E i.... —.3 u.i>--cc Permanent Datum MSL Elevation 0' Elevation Z-§ri-7- 2 E < ILI Log Measured Measured From KB. , 67 Ft above perm.datum KB. 6T >_ z _?_ ''o" , 0 Drilling Measured From KB. GL 38,5' < 4L_treii il. Date @ Time Logged 11-AUG-2017 —Type Fluid in Hole0 DIESE.L VI...„.RAJ ..... , Run No. 'ONE Density of Fluid N thIA LI 0 tu M Cr Dep -Driller -7038' Fluid Levet T SURFACE' Depth-Logger 6620' Cement Top Est Logged N/A OD cl' Wa.ILLI 1 CL. OzCOt— 0 < Bottom-Logged Interval 6620' Equipment/Location r 3,3 SL i GPS <L-14 cc x '-op Log interval SURFACE Recorded by RYAN GOODVVIN uu„a LL LU 0 --M-ax Recorded Temp. 96 DEG F Witnessed by PJTI INTAN F- 0——1''L • 1 w U>.C-2 LL u j LLI CEMENTING DATA Surface Protection Production Liner wiLizio0 I- 1.... ccazz String String String zce—OF= < -. r Date i Time Cemented , g 0 Et 5,, , -,,_ Primary/squeeze <,,,u) w CI) I-- Lf, Expected =L''''U.' LX-Itil ..el. , tr CD QD < Compressive strength psi( hrs, psi@ hrsi psi ffi hrs psi@ hrs I--La 2 2 w WCement Volume I-- 1"-- —4 Cement-TypeVV eight , / / i <›-Z Lu _I Formulation krj ,C,-‹ U.j 0 LU z 2 mud Ire 2:Mud VVgt i I — Borehole Record Casing&Tubing Record 0 tr cc 9_3,0 i--, c 0 Run Number Bit From -o Size Weight From To or 'C 0 _Ti cf3 c.) i.1_ co 9.625" 40# SURFACE 4340' SURFACE 7038' f— , _ U_ --,>-1.....I.,,<.,f r—I, a, 00 35" 9.2# — SURFACE 6847' -g•z 4_x L.-., i-i-i w -,- v • 0 f • t 1r ( t T 7 Set Top Packer o ; Element at 6,448' ' , ' MO i r r _..___. !_..1 , iii I) _ . ( a " �'i t, I '_EAK FOUND AT 645T� �� • _' ch depth E Set Bottom S r Packer Elemen ' It e { Sa00t. 93 7; 4171 6 t ) i f <,...___, i 17... -;' it (fir S.t t sy r: t t e t.- t _... _ e550 r 1. eree 7- i Ct 0600 - --•.--- 95.1, 4206 5 . , c X sS t 'I ;It ly _I ' 0 Temperature-CTF(degF) 200 0 Temperature CTF(degF) 20 0 Pressure-OPC(psi) 5000. 0 Pressure OPC(psi) 500 0 Gamma(x10 Of(scale)(GAPI)'50 -20 in-Lase Spinner(ree) 20 CCL -20 Primary Spumes-CFS net 20 200 Cable Speed(omen), 200 0 Water+.01d Up CTP 2 -- -- -- Temp .1 Dere Temp CTF 1de9F) • • S-217 WFRV Install and Patch Setting Program tomes - Please obtain updated WBS. • ST#1 has a live WFRV installed. • ST#3 has a flow sleeve installed. • All other stations are dummied. - High inter-sand pressure differentials can result in crossflow and inflow of sand if proper pressures are not held when pockets are open. Sand face pressure gauge readings at time of submitting program (8/23/17) are listed below.S-217 was S/I for 158 days at time of taking readings. • OA(ST#5&6)=2280 psi(in communication with tubing) • OBa (ST#4)=1550 psi • OBb/OBc(ST#2&3)=gauge failed(expect 2200 psi) • OBd(ST#1&TT)=gauge failed (expect 2200 psi) - Reference table below for recommended WHP's to hold when pulling valves. Do not conduct drawdown tests to prevent from OA sand inflow through the tubing leak. - Do not exceed 1 bpm during any of the SRT's. 1. Drift to "6500' MD for patch. • Patch to be set from 6,448'—6,473' • This is a relatively long, 1-trip patch (33' OAL). Attempt to duplicate patch dimensions as shown in the SoR. 2. Pull dummy from ST#4 and install live valve. Conduct pull test to determine valve is properly set. • Perform SRT at 1000, 1200, 1400,and 1600 psi to check valve performance. • Target injection rate to diesel is 0.23 bpm.Will be in communication with tubing leak. 3. Pull dummy prong & install live valve in RMX at 6626' MD. Conduct pull test to determine valve is properly set. • Perform final SRT at 1000, 1200, 1400, and 1600 psi. • Target rate is 0.57 bpm.Will be in communication with tubing leak. 4. Set RMX with dummy prong at 6549' MD. • This is to allow the patch to be tested once set. 5. Conduct MIT-T and establish LLR as expect MIT-T to fail. Ensure the OBa sandface pressure gauge is not seeing a response during the MIT-T.This will determine if the RMX and dummy prong are set properly. • If the OBa sandface gauge is showing a response,troubleshoot as necessary. E tine 6. Set 1-Trip WFD WidePak VO rated Patch with lower Packer Element at 6,473' MD; Reference tie-in attached:Halliburton LDL 8/11/17. • This should place top of patch at 6,448' MD. yy . ..., ,.; ,� , 5Iam�.Ri ° , • f, ll 7. Pull dummy prong from X-Nipple at 6,549' MD. 8. Set Red Spider valve sized for 1.7 MMSCF/D at 2891' MD.Conduct DD test. S-217 Program 1 of 2 Z40 Z wea50Jd LLZ-S C.) C.) y m m w13 03 \ \ W 0 0 /M .. N 0 -0 -0 0 0 Ca Ca 0 0 C a a z . 0 0 0 0 E o ti 0 0 r. ti Ea E_ a) E. O cc eaa a > > .n .n c c o o Ti .0 M 00 L i .0 .0 w . •— w.+ a -0 3 N o O N co.— ca) ca) C = .L .r. -a m -a _ _ = a aan o a� a m as o la o s �_ E a' E a) a� o a c) C) t) c� > 13 -C c a) m a) a a) J > � � z � �� 3 3 Cu as as r , J J J a) m C c 4- _ O _ o a) a) ai 16 13 N CO N ch da) N .E E u E u E -a ' o` .a 'o , 3 C 3 N Cu > r C ce O J J • � RI F. L E E E E E � E E U -0 -0 -0 -0 : 1 J _ a) OCD +r J co Q. M _ • cos E— • • • a) U) CO Cn co N M 0) CO Q. Loo) co N C)) y O co co co in 0 tf) O .- c- N Lc) In to to o1- o.a O ~ t1) 1- CO L O r- O co a) N• • .- co N LI O co 0 ,- ,- LC) > o u) "2 u) Lo 0 > 2 I- CL 0 W Z coLU• CU a 0 5 Q `) ° o' O O Y Y m co CO M N J J J Q Q w W W d co c`oo CO' co N- Q Q w a ° Cm`s z 0 �1C _O _0 0_ -J LU W W C] (o CO CO CO CD Z Z Z O J J J 0 E co ar = _ _ a Fw- . E 0 0 0 W CE DC Z O Z C) 1� 2 2 2 0 co c i ccoo O ca Cti r 4••• N < ch O C y CO CO d- v V- 0 a M ai <- CD r- r- el W O to 10 co co as L d L Z 2 O co co v) co co 0 a. a, 130 0 c m I-- I- HI- I- a Ci) CO Ci) co C a O t a) a 0 Lu J J I- D W 0 d a CO 0 Li J a N- 1-- 1titi 0 O O a c- N- e- O 0 D O O O O O LU Z IL O J J N N N N N Z �- a a < W W — —. — — �a V- O to to co ° w w W J N N u_ a) N N N N Z Cl- 0 0 W W CY a i © i i i Q o o J J D D tL W O m o i J J 0 O w w Q Q m m I IL co co a s a) E to Z1r` Iti � c N N N N N m W W co 0 J O O W d cn U) c%) U) U) < < m m LL tl co cn a R • • as . O O o 0 Cu rn o C co r- U L o0 o 3 r N m r- aoc' co co N- CO 1 CO 1.0 N CO Ln 1 1 i 1— CO CO CO <7' o • N N N N O) COCO In co O N CO I,- CO V p CIS i I � 4.0 Q (V co co CO V in N N N N N n 3 CO M O QLo o co JJ a) *k *k J *k (V O N •.� •N Lo r N C•iW o N O M '"' N CO CO a1 0 �- N C CO CO O co J V N. CO Z 0)O O Cf— uj O O u O Z Z ZfYOmm ODCC » UCf) 0I— I— • L L N Y Y Y - U U o o (0 (a (6 CO d 2 L L O L L C O.-0 -0Q) .L CV CV a) (I) CI) LL U W LL (j) (Q (oCD nmcc O} 00003 .0' rr ` Cl)'' V J Cl)/ Cl)J W W W _ 2 2 F.r N N N N �- Q) c,'") E cv V N 00 C)) .SFr O (A C)) N M O N O CO O O s4- In m Cl) N O co L O O ti O V O M — �' In W N tf) In ("- 0 CO CO CO CO a CL � W W W Y Y Y Y ' O O O a0- a 0 0 0 0 mammm d EtititiN- Z N CV N N (i) cnd) N • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, September 5, 2017 11:21 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO SUPT Well Integrity;Youngmun,Alex;AK, GWO Well Integrity Well Information Subject: RE: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Joshua, The new plan for a tubing patch would require a 10-403 I believe, and that 10-403 can detail the plan and contingency for MI injection and monitoring. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:AK, GWO Well Integrity Engineer[mailto:AKGWOWellSiteEnginee@bp.com] Sent:Tuesday,September 5, 2017 9:38 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>;Youngmun,Alex<younak@BP.com>;AK, GWO Well Integrity Well Information<akgwowellintegritywe@bp.com> Subject: RE: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Hi Chris, Since we last spoke about 5-217 slickline went out and performed a water flood regulator change out in preparation for the MI swap and leak detection log. During the course of the work we believe we may have found the source of the TxIA communication. A spinner/temp/pressure log was ran on 8/11/17 to trouble shoot a water flood regulator and a hole was found at 6457'which is between production packer and the OA sands isolation packer. We currently think the TxIA communication on gas was caused by MI leaking through this hole,and past the cement squeezed packer at 6,454' and into the inner annulus(see attached schematic). Given this new information we would like to change the diagnostic/repair plan for this well. The new request is for permission to set a patch over the hole at 6,457', place the well on MI injection for 14 days and monitor for IA repressurization. If we do not see IA repressurization after 14 days we will continue to monitor for an additional 14 days to verify the TxIA communication has been mitigated. If we do see IA repressurization at any time during the monitor period we will run the ACX leak detect log as originally planned. Please let us know if this revised plan forward is acceptable; if you have any questions feel free to call or email me. 1 PTS 2 07 -a q5�' • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,July 18,2017 10:55 AM To: Lastufka,Joseph N Cc: AK,GWO SUPT Well Integrity Subject: RE:Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Follow Up Flag: Follow up Flag Status: Flagged Approval is granted to inject MI for up to 14 days for the purpose of leak detection diagnostic work. No sundry is required for the leak detection testing. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission p Anchorage,AK 99501 �CAao Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALI►Y NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Monday,July 17,2017 10:43 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Subject: FW: Injector S-217(PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Victoria, Please let me know if you would like a 10-403 for the MI at your earliest convenience. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 1 • • BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788DIAnchorage, AK From:AK,GWO SUPT Well Integrity Sent: Monday,July 17,2017 7:20 PM To: Lastufka,Joseph N<Joseph.Lastufka@bp.com> Subject: FW: Injector S-217(PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Joe, Could you confirm with Victoria whether a 10-403 is required for the work described below? Thanks, Adrienne From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday, July 17, 2017 1:26 PM To: AK, GWO Well Integrity Engineer Subject: RE: Injector S-217 (PTD# 2070950) Request permission to inject MI Under Evaluation for diagnostics. Adrienne,Joshua, Thank you for the follow up calls. Permission is granted for the proposed MI for the leak detect as per the plan below. Victoria is out for the day,so you should check with her directly tomorrow on your question of 10-403/sundry requirements,or when you get ready to do this work. Thanks, Chris From:AK,GWO Well Integrity Engineer[mailto:AKGWOWelISiteEnginee@bp.com] Sent:Wednesday,July 5,2017 2:49 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: Injector S-217(PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Hi Chris, S-217(PTD#207950) is an operable produced water injector with known TxIA communication when on gas; it currently operates under AIO 25A.010 f for water only service. The production engineer is wanting to restore integrity of the well so that it may be returned to MI service. Historically we have had little success with finding small leak on gas injectors, but recently we have had high success using Halliburton's acoustic ACX tool. We would like to use this tool on S-217 and are requesting permission to temporarily inject MI into the well for a period of no more than 14 days in order to heat the well and run the diagnostic log. Please advise if the commission will need further information to make a formal decision on the request to temporarily return this well the MI injection for diagnostics. Thanks, 2 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday,July 17, 2017 1:26 PM To: AK, GWO Well Integrity Engineer Subject: RE: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Adrienne,Joshua, Thank you for the follow up calls. Permission is granted for the proposed MI for the leak detect as per the plan below. Victoria is out for the day,so you should check with her directly tomorrow on your question of 10-403/sundry requirements,or when you get ready to do this work. Thanks, Chris From:AK, GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent:Wednesday,July 5, 2017 2:49 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Subject: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Hi Chris, S-217(PTD#207950) is an operable produced water injector with known TxIA communication when on gas; it currently operates under AIO 25A.010 f for water only service. The production engineer is wanting to restore integrity of the well so that it may be returned to MI service. Historically we have had little success with finding small leak on gas injectors, but recently we have had high success using Halliburton's acoustic ACX tool. We would like to use this tool on 5-217 and are requesting permission to temporarily inject MI into the well for a period of no more than 14 days in order to heat the well and run the diagnostic log. Please advise if the commission will need further information to make a formal decision on the request to temporarily return this well the MI injection for diagnostics. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED AUG I 0 2017 wo -ewes.+rr..«.e. 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,July 5, 2017 2:49 PM To: Wallace, Chris D (DOA) Subject: Injector S-217 (PTD#2070950) Request permission to inject MI Under Evaluation for diagnostics. Hi Chris, S-217 (PTD#207950) is an operable produced water injector with known TxIA communication when on gas; it currently operates under AlO 25A.010 f for water only service. The production engineer is wanting to restore integrity of the well so that it may be returned to MI service. Historically we have had little success with finding small leak on gas injectors, but recently we have had high success using Halliburton's acoustic ACX tool. We would like to use this tool on S-217 and are requesting permission to temporarily inject MI into the well for a period of no more than 14 days in order to heat the well and run the diagnostic log. Please advise if the commission will need further information to make a formal decision on the request to temporarily return this well the MI injection for diagnostics. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO SCANNED An, 0 8 2017 .►..«weft..,w..a.. • • 2.0-1-0015 2i 203 •S WELL LOG TRANSMITTAL PROACTIVE DIAC,NOSTIC SERVICES, INC. DATA LOGGED 5/Z5d201C. rb' Ji I:'E.I.K NDER MAY 13 e,,:� To: AOGCC Makana Bender A _ G ,(4. 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. - - -• Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 uancpdc@bp.com SCONE and ProActive Diagnostic Services, Inc. Attn: Diane F.Williams 130 West International Airport Road =A Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 27-Apr-16 S-217 BL/CD 50-029-23362-00 2) Signed : o_e„,et, Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,March 02,2016 TO: Jim ReggG I '1, P.I.Supervisor ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-217 FROM: Chuck Scheve PRUDHOE BAY UN POL S-217 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry CAR-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S-217 API Well Number 50-029-23362-00-00 Inspector Name: Chuck Scheve Permit Number: 207-095-0 Inspection Date: 2/28/2016 Insp Num: mitCS160228123946 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-2I7 Type Inj W'TVD 4977 ' Tubing 1291 • 1301 1294 - 1297 ' PTD 2070950 ' Type Test SPT Test psi 1500 IA 407 2497 ' 2394 2374 - Interval REQVAR P/F P OA 10 18 , 19 - 20 • Notes: Tested per AIO 25A.010. SCANNED SEP 2 6 2016 Wednesday,March 02,2016 Page I of I 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 ~ - (~ ~~ Well History File Identifier Organizing (done) RE CAN Color Items: ;~y ~Greyscale Items: ^ Poor Quality Originals: ^ Other: o..o=aea uiuimuioiim DIGITAL DATA Diskettes, No. Other, No/Type: G~ rIO I ae.~a~~erded iuumuiuiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~~ ~ U /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: ~V D /sl Scanning Preparation ~_ x 30 = ~ + ~ =TOTAL PAGES_ ~~~ BY M i D t I ( ount does not include covers et) 8 : ar a a e: O ~ /s/ Production Scanning IIIIIIIIIIIIII VIII Stage 7 Page Count from Scanned File: (Count does include cover sheet) T Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ ~. ~ ~ ~ 8 /s/ Stage ~ If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II III II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked I I I I I ~I (~ I~ I I~' ~ 1N P P 10/6/2005 Well History File Cover Page.doc y A) Or 714, S • 0"' I%7, s, THE STATE Alaska Oil and Gas LALAsKA Canaervalitltl.l mission orth GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Matt Brown SCANNED NOV 31 ; Wells Interventions BP Exploration (Alaska), Inc. P.O. Box 196612 �� "� .- oy,' Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PLRS S-217 Sundry Number: 313-485 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this it, day of October, 2013. Encl. III • c RECEIVED STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION 10 5E,P 10 2013 APPLICATION FOR SUNDRY APPROVALS E 3 20 AAC 25.280 AOG 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well si • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown A4 5u/eII �� ❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other . Er(„7,,,,-, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill umber. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 207-095-0 ' I4---" 3.Address: Stratigraphic ❑ Service Q 6.API Number. 10/ST/ P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23362-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PLRS S-217 ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028261 • PRUDHOE BAY, POLARIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7049 • 5490 ' 6804 5279 None 6860 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"215.5#A-53 29-109 29-109 Surface 4312 9-5/8"40#L-80 28-4340 28-3478.03 5750 3090 Intermediate None None None None None None Production 7012 7"26#L-80 26-7038 26-5480.12 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 23-6847 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Email Matt Brown @BP.Com Printed Name - Matt Brown Title Well Interventions Signature j/ fir Phone 564-5874 Date. Prepared by Garry Catron 564-4424 / I c1 if /13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. S i:2a `'44.:`6 S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No u Subsequent Form Required: /0 — // 0 4- n APPROVED BY Approved by: / � (,plL-�- COMMISSIONER THE COMMISSION Date: lb /D / Form 10-403 Revised 10/2012 �� eiRiasithisAito:12 months from the date of a royal. ubmit Fo nd A h nts in Dupl t'/b/ /l3 RBDMB OC�� 11 20 cA • • Perforation Attachment ADL0028261 Well Date Perf Code MD Top MD Base TVD Top TVD Base S-217 ' 5/16/13 STO 6513 6547 5027 5056 S-217 5/16/13 STO 6568 6586 5074 5090 S-217 5/16/13 STO 6614 6636 5114 5133 S-217 5/16/13 STO 6674 6693 5166 5182 S-217 5/16/13 STO 6734 6782 5218 5260 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028261 Well Facility Type MD Top Description TVD Top S-217 PACKER 6454 3-1/2" HES Dual Feedthru Packer 4976 S-217 PACKER 6555 3-1/2" HES Dual Feedthru Packer 4996 S-217 PACKER 6598 3-1/2" HES Single Feedthru Packer 5033 S-217 PACKER 6723 3-1/2" HES Single Feedthru Packer 5141 • • bp s;ioop. Memorandum To: C. Olsen/J. Bixby Date: August 8, 2013 GPB Well Ops Team Leaders AFE: APBINJEC From: Irwin Chou V&S Pad Orion Production Engineer Est. IOR 226 Subject: S-217i Dummy Swell Fix Est. Cost: $70,000 1 S n Pull WFRVs, Set Dummys/Swell Packing/ Plug 2 F MIT to 2000 psi, Cumulative injectivity test 3 SP WFRV C/O Injectivity: Shut-In Max Deviation: 50° at 4370' MD Deviation at Perfs: 31° at 6513' MD Min. ID: 2.750"- HES XN Nipple at 6824' MD Last Downhole Op: 07/27/2013: Caliper Log Last TD tag: 07/27/2013: Tagged sand @ 6780' SLM Latest H2S value: N/A-offset S-213A= 16 ppm 2/27/2013; S-217A is a Schrader Bluff injector configured to inject into different sands using downhole regulators (WFRs). On 5/8/2013, SL went out and attempted to reset the WFRV's in this well because it was not passing the step rate test. All live valves were replaced with dummies. An MIT-T failed at a large leak rate so a LDL was run on 5/13/2013. According to the LDL, GLM station #3 seems to be the leaking culprit. Then, a caliper log was run on 7/27/2013 to check the initegrityio ie-tu g The resulli-didrilshow any apparent damage or holes to the tubing, so its highly likely that the mandrel is damaged. It is ideal to avoid doing a patch job as that will be a last resort. This program seeks to dummy off the w ell and the n run a dummy valve with swell packing into the suspecte eaking mandrel. Then, an MIT-T will be done to ensure if the valves are set properly and if the leak is ffxed For questions or comments: Contact Office Cellular Irwin Chou 564-5538 907-632-3992 cc: w/a: Well File Obiective: 1. Dummy off WFR mandrels 2. Set dummy valve with swell packing into leaking mandrel 3. MIT-T 4. Pull dummy valves, set live WFRVs S-2171 Swell Fix-8/8/2013 • • • Procedure: Set/Dummies 1. MIRU SL 2. Set Whiddon catcher sub on XX-plug at 6804' md. 3. Pull all live WFR from stations #2, 4, 5, and replace with dummy valves. Be sure to maintain surface pressure that is at least 100 psi in excess of the zonal over pressures listed in table below to ensure there is no backflow into the tubing. Diesel should be used for this step and for all injectivity tests. See table for valve design size and zonal over pressures. 4. Send WFRV's to the slope GL Engineers (Johnny Kenda / Larry) for inspection. 5. Set plug in HES X-Nip at 6754' md. Note: This is done to save us from running valve change out for sta# 1. Can run dummy into Station #1 at SL discretion. 6. Pull dummy valve with extended packing from station #3. 7. Set dummy valve with swell packing into station #3. Note: Swell fix dummies take a week to fully expand and set. ***Leave dummies in place and well SI for -7 days for swell packer to fully expand and set.*** Fulibore-MIT-T 8. MIRU FB 9. Perform an MIT-T to 2000 psi to ensure valves are holding and all mandrels have integrity. a. If the MIT-T passes, this means the swell fix worked and to continue with the procedure. b. If the MIT-T fails, leave well SI and RDMO. 5 - ullbore-WFRV C/O 10. If the MIT-T passed, RU SL & FB We will be re-running the design listed in table below. 11. Pull plug from HES X-Nip at 6754' md. Note: If a dummy valve was run in Sta #1 instead of using a plug, pull dummy valve from Sta #1 and Rerun WFR sized for 275 bwpd valve (14 port size w/ light spring). Do injectivity test at 1600, 1800, and 2000 psi. Expected rate isl 0.21 bpm +/- 10%. Record injection rate and pressure at 5 & 10 mins for each pressure cycle. 12. Pull dummy valve from Sta#2. Rerun WFR in sta# 2. 13. Ensure well is fluid packed for injectivity tests. Perform combined step rate test for station #1 & 2 at 1600, 1800, and 2000 psi. Expected rate is 0.33 bpm +/- 10%. Record injection rate and pressure at 5 and 10 mins for each pressure cycle. 14. Pull dummy valve from Sta#4. Rerun WFR in sta#4. 15. Perform combined step rate test for station #1, 2 & 4 at 1600, 1800, and 2000 psi. Expected rate is 0.45 bpm +/- 10%. Record injection rate and pressure at 5 and 10 mins for each pressure cycle. S-217i Swell Fix-8/8/2013 16. Pull dummy valve frorlia#5. Rerun WFR in sta#5. • 17. Perform final combined step rate test for station #1, 2, 4 & 5 at 1600, 1800, and 2000 psi. Expected rate is 0.57 bpm +/- 10%. Record injection rate and pressure at 5 and 10 mins for each pressure cycle. Do not exceed 0.63 bpm of diesel or 2000 psi. 18. Pull Whiddon catcher sub from XX-Plug @ 6804' md. 19. Cap well with 5 bbl MEOH. If injectivity test was good, RDMO and release to Pad Operator to POI at target WHIP for PWI. Operator to start water injection immediately if injectivity is acceptable as defined in step 17. Recommended rate & pressure: 755 bwpd, 1700 psi WHP. Max injection pressure: 1900 psi S-217i New WFRV Design Table Station Depth New Design Diesel Rates BPM Test Zone (s) GLM 5 6533' MD WFR ported for 160 BWPD, 0.12 OA Light spring, 11 port size GLM 4 6576' MD WFR ported for 160 BWPD, 0.12 OBa Light spring, 11 port size GLM 2 6694' MD WFR ported for 160 BWPD, 0.12 OBb/OBc Light spring,11 port size Note: All WFR's to include check valves. S-217i Pressure Table Sandface pressure Diesel Column (psi) Station Zone(s) (psi) Pressure Zonal Overpressure ) GLM 5 OA 2051 1765 286 GLM 4 OBa 1870 1778 92 GLM 2 OBb/OBc N/A 1814 - GLM 1 OBd N/A 1839 - Note: All WFR's to include check valves. S-217i Swell Fix—8/8/2013 P It 0 • TRIM.= 4-1116"CM/ SAFETY NO TES:NMI READINGS AVERAGE 125 ppm WilitEAD= It'F61D WHEN ON la WELL.REQUIRES A SSW WHEN ON ACTUATOR= BAKER S-2 1 7 An. INNIAL KB.ELE 6T 'EC MEV= 35.5 I=■ 24, Htia.X 3-1/2.20,o.agar KOP= 300' Mai Angle= 50;44370" Datum ND= 6569. irr OOSIEUCTOR ? 1 N = 2881• 1-13-712-1-109 Am..0=Laix DatisaND= sow sg iAm row COLLAR illEalli 1 li OAS LET 1AMERELS ST MD UM OW Eon=LATCH Puff DATE 19-51WC30,400,L-80 BIC,0,*•.83W J--1 4349. Vill I. 6366 4026 32 WAG L-.4004"1"rn 'V EMOT TED 066405 -,--- ,, 17-cso,214S,L-so Tel xo To IA°row H MO j - 'STA it*caw'twist) jeTT TCPOF Cail34T{OMOK1011-1 8224* .;;,.; •di 84231 1-13.-ii?M S X NIP,ID=2417 :4! 24`0,70 .I 1 4,44. WATER MICRON PAAM2(18.3, ST MN EVE) ow -re pE VLV LATCH paw DATE 8 6479 4996 31 MMG-W DAN RK 0 10117107 5 6533 5044 31 MMC-W P-I5XJR FK 11 05/16/13 A•r. P0•4 e.s, ..4,4,1 4 6576 5081 30 84151646 P-I5XJR RK 11 05/16113 kilninum ID 2.760" 6824" est ■4,• 3 66X2 5130 30 MMG-W ¶W RK 0 05/16113 st @ i *IV $1,4% IIA 2 8694 5183 30 MMG-W P-15XJR FK 11 05/16/13 3-1/2"HES XN NIPPLE :44. :1.1 1 6775 6263 30 6161049 R15)(JR fIX 14 05116/13 ergo I i 61 %IA 0 3,41NOY HAS EXT04DED PPG mon i I Mir Hr x 3•tir 143o DUAL IFEEDD-RU PKR,0=2.665- 3-1,2.RA RP TAO H 44$11. h- I sitar I-pi-gym SERSCP SIM n-7 iikl r MA RKEP Jratt yr i RA TAG 8630' I vir r DUAL ME TO SLFFACE NIA 654,1--Fir-4.6 X NII,0 -2761-39 PI i_iv, I..1 ii . e -L.,. 7'X 3-1/T HES DUAL, (,1_M3 9 ll ni:3 II ilin 6,,447K, .2105* I II PEPEORATION SOMA/ARV \ \ 16,74 IIE 24 659W 7.x 3-11r SINGLE RMIYINFILI PIKR,C"2.1105' REF LOG: tISE ON 10115/07 A14311 AT TOP FERF 31-(0 6513' \ OW Pwea seam sue.D a 2 or w i CUAL VINE TO SURFACE ri rok t Refer 10 Roductoi DB fur N9106041 perT 094 SIZE St* ZONE. INTEF9/AL I Cin/Sqz SHOT 902 ' ! 6626* 3-112"HES X NP,13.2.817 4-112" 5 OA 6513-6547 0 1014/07 min a 1 L to q74-- I 4 1.12" 5 Cea 6568-6686 0 10114107 4_ ;tow__ 6 L_AA4i.s .....- 4-1/2' 5 CM 0614-6636 CI 10114107 4-117" 5 Cc 6674-6893 0 10114107 1111111 di c 4-1.e 6723 r x 3-irr MOLE P8071-1401 PKR,U 2.006* 1 r CIFtd Art4-970? r+ Im14A17 r::3 ii0. i NI 62,64* ..F11:1027_14BS X 943,43,„ _... _ •I e$ov -13-irr XX FILC403+1 OHM I --- 4/11 %,,./(;) — ia(4. 1-{311177 ur-s x*"...,..,.1)-F.a lii 4, f $824* 1,-13--1717 FES XN MP D=2.750* I3-1 ir 190,020,L-$0 70I,00137 bpf,0.2.092' H tow 634T H 3 VT%LEG,13,-2.992"' FWD 6964' 14.417174T4W1 NOM,NOT LOGGED I 41104444114 r OBO,2ek L-00 OTC,.0303 WT.53-,-.6.276"1---t—TCr-03 ----‘ DATE Rev BY COWENTS 041°E Fev BY C060.434T5 POLARIS LINT 1018/07 P63 •MULL COMPLETION 05116113 LEN PJC GLV 00(05112/13) VEIL 5-217 0545/11-GRDY PJC BR KB COPPEC1DN5 05.23/13 mGEIJOAD 1M1fR 00(06116113) ,.. PFPA4T lb 070050 01/19112 11114UND ADDED MS SAFETY MOTE AM Na'50,029-233152-03 -.... 0441513 L13:299) FOJI XX FLU (13311913) SEC 35,112N,R12E.2123'F14.a 714'PAL 044)5/13 NISSUNC)INFR CIO{0301113) 05t11/13 LENRIC MIER CI0(05109/13) BP Ezpiloration(Alma M S-217i Swell Fix-8/8/2013 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 21, 2012 TO: Jim Regg P.I. Supervisor � 3 1� 1 d� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -217 FROM: Bob Noble PRUDHOE BAY UN POL S -217 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J� — NON- CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S - 217 API Well Number 50- 029 - 23362 -00 -00 Inspector Name: Bob Noble Permit Number: 207 - 095 - Inspection Date: 3/19/2012 Insp Num: mitRCN120320074900 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-217 Type Inj W ' TVD 4977 IA 508 1967 - 1934 1942 - PTD 2070950 " Type Test SPT Test psi 1500 OA 49 264 _ 276 291 - Interval OTHER P/F P Tubing 928 928 932 932 – Notes: Pre -AA. Second test after temp. stabilized `t \MR 2 8 'ZLJ1 Wednesday, March 21, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 21, 2012 TO: Jim Regg P.I. Supervisor 1? �Z4 �� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -217 FROM: Bob Noble PRUDHOE BAY UN POL S -217 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S - 217 API Well Number 50 - 029 - 23362 - 00 - 00 Inspector Name: Bob Noble Permit Number: 207 - 095 - Inspection Date: 3/18/2012 Insp Num: mitRCN120319175113 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 5-217 Type Inj W TVD 4977 IA 471 2173 - 2183 2192 PTD 2070950 Type Test SPT Test psi' 1500 ' OA 352 - 551 562 570 -- Interval OTHER - P/F I Tubing 1520 1509 1508 1508 Notes: Pre -AA required MIT -IA. 20 bbls of meth were pumped to pressure well up. Well failed to show temp. stabilization. Test found inconclusive (I) per J. Regg. ® �3!� 1VlAR Js / ! Wednesday, March 21, 2012 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 - 6612 s'YA ± j { n t, Y, j a M A t n August 5, 2011 is WI + '. "',etftllSSlf)ti • Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well S -217 (PTD# 2070950) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well S -217. Well S -217 exhibits inner annulus repressurization where the inner annulus tracks the tubing pressure while on both water and gas injection. However, a mechanical integrity test on the inner annulus passed to 2500 psi on 11/01/10. Two barriers have been established and the well can be safely operated on water injection. Therefore, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay Well S -217 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564 -4303 or Gerald Murphy / Mehreen Vazir at 659 -5102. Sincerely, oug as A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments: • • Technical Justification TIO Plot Injection Plot Welibore Schematic i I Cc: Doug Cismoski Bixby /Liddelow MurphyNazir West Onshore Site Manager Gathering Center 2 Operations Team Leader Mike Warren Ryan Daniel Prudhoe Bay Oil Pool Well S -217 • Technical Justification for Administrative Approval Request August 5, 2011 Well History and Status Prudhoe Bay Well S -217 (PTD # 2070950) exhibits inner annulus repressurization while on both water and gas injection indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 2500 psi passed on 11/01/10 indicating competent tubing and production casing. Recent Well Events: > 05/02/09: MIT -IA Failed to 2500 psi. LLR - 0.06 bpm > 05/14/09: Set TTP @ 6423' > 05/15/09: MIT -T Passed to 2500 psi > 07/10/09: Cement packer squeeze > 11/17/09: AOGCC MITIA Passed to 2500 psi > 12/08/09: IAP @ 2010 psi, showing signs if TxIA comm. > 12/19/09: AOGCC MIT -IA Passed to 2500 psi > 09/14/10: PPPOT -T Passed > 09/25/10: MIT -IA Passed to 4000 psi > 09/27/10: Approval from AOGCC to begin M -I injection and monitor TIO plot for IA repressurization > 10/28/10: Confirmed TxIA comm while on MI > 11/01/10: MIT -IA Passed to 2500 psi > 04/07/11: Approval from AOGCC to place well on PWI for further evaluation > 05/11/11: LDL, no leak detected Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2500 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. The MI line will remain blinded to limit the well to water injections 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 2 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 5. The well will be shut -in and the AOGCC notified if there is any change in the well's mechanical condition. 2 4d. ..-Suoo io +I ha2.18 WIIII MRPARRIR!IFF4FF”1-h§M? _ ! 7 . — • . - .-. I CI E 'i a: a r 0 .4.7. o i .; i ; ) U) ,8 c l i TD— i . , • I i 1 ,-- * _.... 1 , 1 : i 1 1 ommERFAmF,§.§.0§.§5.gg§§§§5 , --.----- .,,, .,.. m" _ _ TREE= 4 -1/16' CM/ -2 S I WELLHEAD = 11" FMC • SAFETY NOTES: . RF UIRES A SSSV WHEN ACTUATOR= BAKE32 ON MI. KB. E LEV = 67' BF. E3.EV = 385 owl . ■ KOP= 300 24' f (4 -117' X 3-1/2" xo, D = 2.992" mu Angle = 50'@ 43.70 III Datum MD = 6559 120' CONDUCTOR H ? DatumTVD= 5000' SS � TAM PORE COLLAR H 996' 2891' H3-1/2 FES XNP, D 2.813" I 9261 GAS LET MANCRaS TVD 19.518' CSG. 404. 0.80 BTC. D = 8.835' H 4340' ST 32 LEVI VLV LATCH' PORT 106/0 091 IT CSG. 264, L -80 TCJI XO TO L -80 BTC-M H 5924' l I EST TOP OF CEMENT (07 /10109) H 6224' 6 4 2 3 ' 1•-1 3-117 FES X NP, D = 2.813" I P�� : ;j WAT ER INJECTION MANDRELS * * * 01, ST MD 1VD DEV TY FE VLV LATCH PCRT DATE Oi: "Po 6 6479 4998 31 MMGW CMY R< 0 10/18/07 �i 4�i� 5 6533 5044 31 MMGW P -15XJR FE 11 09101/09 iii ..i 1 4 6576 5081 30 MMGW P -15X1R RK 11 09101/09 . 4.4 An 3 6632 5130 30 MMG-W DAY RK 0 10/18/07 Minimum ID = 2.750" @ 6824" ;•;' PIN sP *P, AN 2 6694 5183 30 MMGW P -15XJR RX 11 0910//09 3 -1/2" HES XN NIPPLE OA AN 1 6775 5253 30 MMGW P-15XJR RK 14 05/20/10 ►Z1 ►3 l'U 7' X 3.1/2" HES DUAL FE.DTI -RU PKR, ID= 2.965" �� 6467` 1� PHOENIX SENSOR SW, D = 2.99T 31 /2'RAPP TAG 6499' w/ DUAL IMRETOSLRFACENIA I- I7'MARKERw/RA TAG H 6530' I ' I 6549' 113 -1/Z I-ESXNP, D= 2.813' I 6 7" X 3-1/2" HES DUAL ► II g► � FEEDThRU PKR, ID = 2.965' .'0 6598' H7' X 3 -1 /T SNGLE FEEDTHRU PKR, D = 2.965' I imi ►/ PERFORATION SUMMARY REF LOG: USfT ON 10/15/07 1 6606' 11 PHOD4FX w/ DUAL SENSOR SW. RE TO SLR FACE D = 2.99T I ANGLE AT TOP PERF: 31° @ 6513' WIRE N to Note: Refer t o Roduction DBfor historical pert data I 1 6626' H3 -1/2" H E S NP, D =2.813' I SIZE SPF ZONE NTER/AL Opn /Sqz DATE 4 -1/7 5 OA 6513 - 6547 0 10/14/07 _ 4 -117 5 OBa 6568 -6566 0 10/14/07 ' 4 -1/7 5 OBb 6614 -6636 0 10/14/07 6 7' X 3-1/T SINGLE FEEDTHRt.I PKR. D= 2.965" I 4 -1/7 5 OBc 6674 -6693 0 10114107 11 ►ir 4.1/2" 5 OBd 6734 - 6782 0 10/14/07 1 6754' 1-13.1/7 FESX NP. D =2.813' I MP 6804' j 3-ll? XX PLUG (05/21110 6804' r } 3.1/2' FES X NP, D =2.813" 6824' H3•1/7 FESxN NP, ID= 2.750" 1 03.1/2' TBG, 9.24, L -80 TCIL .0087 bpf. ID= 2.992' H 6847' 6847' H3 -1/7' WLEG, ID= 2.997 I I PBTD I --I 6954' eze,weede I H ELMD NOT LOGGED I .35 592;911 17 CSG. 264. L•80 B1C..0383 bpf, ID= 6.276' H 7038' DATE REV BY COMMENTS DATE PEV BY COMMENTS POLARIS UNIT 10/18/07 NOES INITIAL COMPLETION 0505/11 GRO PJC BF/ KB CORRECTIONS WELL: S-217 08/24/09 RDBIPJC FOO! CMT PLUG (07 /10/091 PERMIT No: / `2070950 09/29 DMS/SV SET XX PLUG (08/29/09) API No: 50-029-23362-00 09/29/09 DMS /SV GLV CO (09101/09) SEC 35. T12N, R126E, 2123' FN_ & 714' FWL 05/30'10 RCT/ PJC RESET XX PLUG/ GLVS (05122/10) 02115/11 MB/JMD ADDED SSSV SAFETY NOTE ] _ BP Exploration (Alaska) III • WELL LOG TRANSMITTAL PROAcrivE DIPANOSTic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection[Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 4/r , \A J• J I L 7 0 k - and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD / WAF 11- May -11 S -217 BL/ CD 50-029- 23362 -00 2) # / ( 1 6C7 Signed : Date : 36 - I Print Name: 1S w o v k.10. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E : PDSANCHORAGECD.MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmit.docx oZ -3qi_ RE: UNDER EVALUATION: Iri ector S -217 (PTD #2070950) Plan forward Page 1 of • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, June 03, 2011 7:37 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; 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; Warren, Mike Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: OPERABLE: Injector S -217 (PTD #2070950) No Signs of IA Repressurization While On PWI Attachments: Injector S -217 (PTD #2070950) TIO and Injection ( ) ection Plot.doc 1 All, Injector S -217 (PTD #2070950) has been on produced water injection since 04/16/2011 in an attempt to identify TxIA communication in the wellbore. A leak detect detect log performed on 5/11/2011 did not find any leaks in the tubulars. Over the last 3 weeks, the well has been on continued injection with no indications of IA repressurization. The well is reclassified as Operable. Plan forward: 1. Continue to monitor the TIO plot for TxIA communication for 2 months while on PWI injection (Well to remain on the Monthly Injection report to the AOGCC) 2. Apply for an Administrative Approval for produced water injection only A TIO and Injection plot are included for reference. Please call if you have questions or concerns. Thank you, JUL 1 1 MI Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 Fro . + D &C Well Integrity Coordinator Sent: Frida , • it 15, 2011 9:08 PM To: 'Maunder, Thom. DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, • • • od Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services •.,- - ions Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan; Warren, Mike Cc: AK, D &C Well Integrity Coordinator; Walker, Gre• ; C ; Clingingsmith, Mike ] (Swift) Subject: UNDER EVALUATION: Injector S -217 (PTD #2070• resume Water Injection To Perform Diagnostics All. Injector S -217 (PTD #2070950) has confirmed TxIA communication while on water injection. - -II is being returned to water injection in an attempt to reestablish the TxIA communication for logging with a leak • - ect log. The well is reclassified as Under Evaluation. 7/1/2011 • • Injector S -217 (PTD #2070950) TIO Plot 06 -06 -2011 Wet 5 -217 4 000 • 3,000 - -*- Thg -U-L6 2000 - mac' 00A -i- 000A 200 f M 03105111 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 05/20/11 Injector S -217 (PTD #2070950) Injection Plot welt 5 -217 1,600 - _ 800 1,500 - 750 1 - 700 ,400 1,300 _ 650 1,200 - _ 600 1,100 - : 550 1,000 - 500 W -WHIP 900 _ 450 0 5W pw _ - - 400 - 8 00 ; MI 700 _ 350 0 ----- O 600 - - 300 - On 500 - -250 400T - 200 300 - -150 200- -100 100 - - 50 03/12/11 03126/11 04/09/11 04/23/11 05/07/11 05121/11 Monthly Injection Report for GPB, •MA, Northstar, Milne Point & Endicott April 2... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, May 19, 2011 2:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for April 2011 Attachments: AOGCC Inj Report 05- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the April 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 05- 11.zip» SKANNEU JUN 0 � 2011 Notes on wells: Added to Report: L -119: Added for being Under Evaluation for potential TxIA communication. L -210: Added for being Under Evaluation for potential TxIA communication. S -217: Added for evaluation of TxIA communication diagnostics. The Well Integrity Coordinator will apply for an administrative approval pending IA repressurization. a.o\ - S W-44: Added for being Under Evaluation for potential TxIA communication. Taken off Report: X -24A: Removed after showing no signs of IA repressurization since December, 2010. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 5/31/2011 Well S -217 Injection Plot TIO Plot MITIA Passed to 4000 psi - 09/25/10 o Pressure vs. Rate o 0 0 o Well has exhibited TxIA commiunication CV N - Tbg __ IA when on M -I injection. o OA • • co ! Well began water injection on 4/16/2011 to • • - I evaluate for an AA for PWI only. m 9) a o 4• a o L_ � _ • _ - o o co I � LO • Last 90 days • Last Month , -- J ,_r o • , , , , , o 0 100 200 300 400 500 600 700 800 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 05/01/11 750 1,359 05/01/11 1,550 440 520 04/30/11 711 1,613 04/30/11 1,650 440 520 04/29/11 743 1,532 04/29/11 1,460 400 440 04/28/11 688 1,336 04/28/11 1,460 400 440 04/27/11 517 1,041 04/27/11 1,000 300 300 04/26/11 509 1,066 04/26/11 1,060 900 500 04/25/11 510 1,096 04/25/11 1,060 900 500 04/24/11 486 1,117 04/24/11 1,060 900 500 04/23/11 483 1,108 04/23/11 1,060 900 500 04/22/11 488 1,065 04/22/11 1,060 900 500 04/21/11 473 1,040 04/21/11 1,060 900 500 04/20/11 495 1,053 04/20/11 1,060 700 340 04/19/11 487 1,025 04/19/11 1,060 720 340 04/18/11 501 1,048 04/18/11 1,060 720 340 04/17/11 535 1,017 04/17/11 1,060 1,420 740 04/16/11 361 910 04/16/11 900 660 40 • 04/15/11 0 0 04/15/11 40 240 40 04/14/11 0 0 04/14/11 40 240 40 04/13/11 0 0 04/13/11 40 240 40 04/12/11 0 0 04/12/11 40 240 40 04/11/11 0 0 04/11/11 40 240 40 04/10/11 0 0 04/10/11 40 240 40 04/09/11 0 0 04/09/11 40 240 40 04/08/11 0 0 04/08/11 40 240 40 04/07/11 0 0 04/07/11 40 240 40 04/06/11 0 0 04/06/11 40 240 40 04/05/11 0 0 04/05/11 40 240 40 04/04/11 0 0 04/04/11 40 240 40 04/03/11 0 0 04/03/11 40 240 40 04/02/11 0 0 04/02/11 40 240 40 04/01/11 0 0 04/01/11 40 240 40 Injector S -217 (PTD #2070950) Leak Detect Log Unable to Find TxIA Communication Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Thursday, May 12, 2011 4:17 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Injector S -217 (PTD #2070950) Leak Detect Log Unable to Find TxIA Communication Attachments: Injector S -217 (PTD #2070950) TIO & Injection Plot.doc; Injector S -217 (PTD #2070950) wellbore schematic.pdf Jim and Tom, S -217 (PTD #2070950) is a WAG injector that had shown TxIA communication when on M -I gas injection. The well is currently classified as Under Evaluation and on injection in an attempt to activate the leak to perform a Leak Detect Log. We have been unable to locate a leak with a leak detect log. The well showed IA repressurization by the operators reads on 05/03 and 05/04 but I strongly suspect this may be a mistyping of the tubing pressure into the IA input in our system. My reasoning for this can be seen in the timeline below. The well has not shown signs of repressurization when we have monitored with the DHD crew. Proposed path forward: 1. Leave the well on PWI for 2 months in an attempt to build a case for an AA for TxIA communication for PWI only 2. Well to remain on Monthly Injection Report for continued monitoring 3. Once sufficient TIO data is present, apply for AA for continued injection A TIO, injection plot and wellbore schematic have been included for reference. «Injector S -217 (PTD #2070950) TIO & Injection Plot.doc» «Injector S -217 (PTD #2070950) wellbore schematic. pdf» Recent Well History: 04/07/2011: Telephone discussion with Tom Maunder regarding placing well on PWI injection to attempt to find leak 04/16/2011: Well was started produced water injection 05/02/2011: Operator recorded the T /I /O as 1600/440/540. 05/03/2011: Operator recorded T /I /O as 1600/1650/540. It appeared that the leak was active and had pressurized over a 24 hour period. 05/04/2011: Operator recorded T /I /O as 1650/1650/540. The operator who recorded these pressures left the North Slope on for time off. 05/06/2011: DHD was mobilized on to bleed the IA pressure off to confirm that the leak was active. When they arrived on location, the T /I /O pressure was recorded as 1580/450/550 and then bled to 1550/450/200. The operator who was on duty confirmed he had not bled the well and no record of bleeds was recorded in his notes. The leak detect log was scheduled. 05/07/2011: DHD recorded pressures of 1600/450/210. 05/08/2011: DHD recorded 1610/450/280. In an effort to confirm the leak was active, the IA was bled to 120 psi with gas and fluid slugs. The final recorded pressure after the bleed was 1610/130/280. 05/09/2011: Operator recorded 1600/160/200. 05/10/2011: Operator recorded 1600/160/240. The injection temp was up 10 degrees from the previous day. 6/2/2011 Injector S -217 (PTD #2070950) Leak Detect Log Unable to Find TxIA Communication Page 2 of 2 • • 05/11/2011: Operator recorded 1500/180/240. 05/12/2011: E -line ran the Leak Detect Log with no success of finding a leak in the tubulars. While running in the wellbore taking returns from the IA, the returns bled to zero and showed no signs of flow during the logging . Recent MIT -IA history: 12/19/2009 Passed AOGCC MITIA to 2500 psi (Bob Noble) 09/25/2010 Passed 4000 psi MITIA prior to M -I injection 11/01/2011 Passed 2500 psi MITIA prior to PWI Thank you for your time and consideration, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 6/2/2011 • • Injector S -217 (PTD #2070950) TIO Plot Well: S -217 4 000 3,000 -0" Tbg —MI— IA 2,000 — OAA - 000A On 1,000 02/12/11 02/26/11 03/12/11 03/26/11 04/09/11 04/23/11 05/07/11 Injector S -217 (PTD #2070950) Injection Plot Welk 5 -217 1.600 750 fir �R 656 1,400 650 600 1.200 t 550 -. „,P-41 500 _WHiP 1,000 450 £ SW 40 —pW q --W 600 3 $ — Oth. 250 — On 400 200 150 200 100 50 02/12/11 02/10/11 02/2611 03/05/11 03/12/11 03/19/11 03/26/11 06/02/11 00/09/11 04 /16/11 04/23/11 04/30/11 05/07 /11 RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Page 1 of 4 . . Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.comj Sent: Friday, April 15, 2011 9:08 PM To: Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan; Warren, Mike Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: Injector S -217 (PTD #2070950) Resume Water Injection To Perform Diagnostics All. Injector S -217 (PTD #2070950) has confirmed TxIA communication while on water injection. The well is being returned to water injection in an attempt to reestablish the TxIA communication for logging with a leak detect log. The well is reclassified as Under Evaluation. Please be aware of the potential for annular pressure expansion when beginning injection. Please call if you have 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 m: AK, D &C Well Integrity Coordinator Sent: . rday, November 27, 2010 8:52 PM To: 'Maunde , somas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; • PS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D& • -line Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; ■, : -n, Mike; Janowski, Carrie Subject: NOT OPERABLE: Injector S -217 (PTD ! 0950) Unmanageable IA repressurization while on water injection All, Injector S -217 (PTD #2070950) has confirmed TxIA communication while on water ink- '•n. The IA repressurization rate is -105 psi /day making it unmanageable. The plan forward is to run a -= detect log to identify the leak depth for remediation. The well will be reclassified as Not Operable until repaired. = -cent TIO plot has been attached for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) 6/2/2011 RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Page 1 of 4 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, April 07, 2011 6:39 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Injector S -217 (PTD #2070950) Permission to Resume PWI for Upcoming Leak Detect Log Jerry, It is acceptable to bring the well back on for diagnostic purposes as described. Please keep me informed. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thu 4/7/2011 4:42 PM To: Maunder, Thomas E (DOA) Subject: Injector S -217 (PTD #2070950) Permission to Resume PWI for Upcoming Leak Detect Log Tom, Per our telephone discussion, we would like to return S -217 (PTD #2070950) to produced water injection in an attempt to re- establish the TxIA communication so that we perform a Leak Detect Log in an attempt to identify the problem. The plan is to reclassify the well as Under Evaluation and we will add the well to the Monthly Injection report until it's reclassified. Regards, Jerry Murphy BPXA Well Integrity Coordinator Fro . & K, D &C Well Integrity Coordinator Sent: Sat 7/2010 8:52 PM To: 'Maunder, . as E (DOA)', 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; A , • GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C I - line Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator 1 . -n, Mike; Janowski, Carrie Subject: NOT OPERABLE: Injector S -217 (PTD - 070950) Unmanageable IA repressurization while on water injection All, Injector S -217 (PTD #2070950) has confirmed TxIA communication while on .ter injection. The IA repressurization rate is -105 psi /day making it unmanageable. The plan forward i '.run a leak detect log to identify the leak depth for remediation. The well will be reclassified as Not Operable un -*aired. A recent TIO plot has been attached for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator 6/2/2011 RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Page 1 of L • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Saturday, November 27, 2010 8:52 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Warren, Mike; Janowski, Carrie Subject: NOT OPERABLE: Injector S -217 (PTD #2070950) Unmanageable IA repressurization while on water injection Attachments: S -217 TIO Plot 11- 27- 10.doc All, Injector S -217 (PTD #2070950) has confirmed TxIA communication while on water injection. The IA repressurization rate is -105 psi /day making it unmanageable. The plan forward is to run a leak detect log to identify the leak depth for remediation. The well will be reclassified as Not Operable until repaired. A recent TIO plot has been attached for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, November 11, 2010 12:52 PM To: 'Maunder, Thomas E (DOA)' Cc: AK, D &C Well Integrity Coordinator Subject: Update on UNDER EVALUATION: Injector S -217 (PTD #2070950) Swap to Water Injection Tom, Per your request to update you on the returning S -217 to water injection, post M -I injection. Operations has finally reached a point to start water injection on S -217 planned for this evening. The well is still classified as Under Evaluation. If you approve, I would like to allow the well to be on water injection, and update you further when we have have established a stable TIO plot (10 to 14 days). I am including a current TIO and injection plot for reference. Please call if you have questions or concerns. 6/2/2011 • • I 1 5 -217 T O Plot 11- 27- 10.doc Welk S -217 4.000 • 3,000 • # T6g - IA 2,000 — OA • 00A • OOOA On 1.000 • 06/28/10 09/11/10 09/25/10 10/09/10 10/23/10 11/06/10 11 /20/10 • • • . Injector S -217 (PTD #2070950) TIO Plot Well: 5 -217 4,000 3,000 - 1P iThi lbg -AI IA 2,000 - -A- OA rr""' ... 004 -+- OOOA �On 1,000 - 08/14/10 05/2810 09/11/10 09/28110 10/09/10 10/23/10 11/06/10 Injector S -217 (PTD #2070950) Injection Plot Well: 5 -217 - 3,000 3,000 - - 2,800 i , - 2,600 2,800 2,600 - - 2,400 2,400: ` - 2,200 P r--"\—, - 2200 - 2,000 2,000 - 1,800 - _ 1,800 72 - WHIP o SW a. - 1,600 ° - PW = 1,600 MI 1,400 - 1,400 q GI co - 1 ,200 Other 1.200 - On . . 1,000 _ 1,000 800 I : 800 600 I : 600 400 - - 400 200 1 - 200 08/14/10 08/28/10 09/11/10 09/25/10 10/09/10 10/23/10 11/06/10 AOGCC MITIA Forms for END 1 -1 30560), BADAMI BI-14 (1980630), &F -13 (1950270... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] Sent: Sunday, October 31, 2010 3:10 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: AOGCC MITIA Forms for END1 -15 (1930560), BADAMI B1 -14 (1980630), MPF -13 (1950270), MPG -13 (1971200), NGI -07A (2061260), NGI -10 (1760690), S -20A (2010450), S -217 (2070950) Attachments: Oct 2010 MIT Forms.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: END 1- 15/P -25 PTD #1930560 BAD B1 -14 PTD #1980630 MPF -13 PTD #1950270 MPG -13 PTD #1971200 NGI -07A PTD #2061260 NGI -10 PTD #1760690 -20_A_ _ _ _ _ _ PTD #2010450 S -217 PTD #2070950 NO V <<Oct 2010 MIT Forms.zip>> Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/1/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.reggOalaska.gov: doa .aocicc. Prudhoe. bav @alaska.gov: phoebe. brooksabalaska.gov: tom.maunderoalaska.gov OPERATOR: BP Exploration (Alaska), Inc. �� ji�ZZ�I a FIELD / UNIT / PAD: Prudhoe Bay / PBU DATE: 09/25/10 OPERATOR REP: Jerry Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S -217 I Type In'. I N TVD 1 4,976' Tubingl 1050 1050 1050 1050 Interval 4 P.T.D. 12070950 1 Type test I P Test si ' 1500 Casingl 1000 4000 ' 3780 3720' 1 1 P/F P Notes: OA1 40 40 40 40 Well I Type Inj. I TVD I Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA I Well I Type Inj.1 I TVD I Tubing Interval P.T.D.1 I Type testi I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D.l I Type testl I Test psi I CasingP/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) i Form 10 -426 (Revised 06/2010) MIT Pau S -217 09- 25- 10.xls RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Page 1 of j • • �. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 28, 2010 3:00 PM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Torin, Returning the well to water is appropriate. It will be interesting to see if the annulus behavior prior to starting MI returns with the well on water. At this time, it is acceptable to keep the well on line. Plan for either you or Gerry to give me an update in 2 weeks. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, October 28, 2010 12:34 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Tom, After further monitoring the TIO plot, it's been confirmed that there is IA repressurization while on MI. The proposed plan forward is to swap Injector S -217 to water injection for a six month cycle (April 2011) and monitor for IA repressurization. During this time further diagnostics will be carried out to identify and mitigate the TxIA communication for future gas utility. Previously, BPXA has been asked to hold off on applying for an AA if there were recent plans to repair the well. Currently, there are plans to mitigate the communication before the next gas cycle in May 2011. Please advise as to how you would like BPXA to move forward with WAG Injector S -217. 1. If the TxIA communication persists while on water injection but passes an MITIA, apply for an AA for water injection only and repair the TxIA communication before May 2011 for gas utility. 2. If the TxIA communication is not apparent on water injection, continue water injection with AOGCC approval and repair the known TxIA communication before May 2011 for gas utility. The TIO plot has been attached for reference. «S -217 TIO Plot 10- 28- 10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) ti• ZOli Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, September 27, 2010 2:56 PM • 6/2/2011 S -217 TIO Plot 10 -28 -10 (2):do c • Wet 5-217 4,000 - 3.000 - Tbg 2,000 - OA 00A 000A - 1 A00 On 1111.11.111111 11 07/31/10 08/14/10 08/28/10 09/11/10 09/25/10 10/09/10 10/23/10 RE: UNDER EVALUATION: Injector S -217 (PTD #2070950) Plan forward Page 2 of )'- • • To: 'Maunder, Thomas E (DOA)' Cc: AK, D &C Well Integrity Coordinator Subject: Re: UNDER EVALUATION: Injector S -217 (PTD #2070950) IA repressurization while on MI - Discussion regarding resetting 28 day clock Tom, To summarize our phone conversation regarding resetting the 28 day clock on S -217 (PTD #2070950). The current work done to on the well since the 9/9/2010 notification letter: 09/09/10: Well placed under evaluation for IA repressurization while on M -I injection 09/14/10: Wellhead passed PPPOT -T 09/17/10: MIT -IA to 2500 psi - passed 09/18/10: S -pad injection was shut in for surface work in the module, expected to be completed in first week of October 09/25/10: MIT -IA to 4000 psi (cold) passed Since the 28 day clock would currently expire on 10/07/10, I propose we reset the 28 day clock at the beginning of injection to allow time to adequately monitor for IA repressurization after thermal stabilization takes place (minimum of 10 days monitoring). The well will remain classified as Under Evaluation throughout this time period. Thank you for you time and considerations with this matter. Gerald Murphy BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Thursday, September 09, 2010 7:24 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Ops Lead Cc: AK, D &C Well Integrity Coordinator; Warren, Mike; Janowski, Carrie Subject: UNDER EVALUATION: Injector S -217 (PTD #2070950) IA repressurization while on MI All, Injector S -217 (PTD #2070950) has recently shown signs of TxIA communication while on MI. On 09/09/10, the IAP was bled from 1680 to 0 psi and increased to 1400 psi after a couple hour monitor. The initial plan forward is to perform a pack -off test on the tubing and monitor for IA repressurization. The well has been reclassified as Under Evaluation so it can be placed on injection as needed for diagnostics. A TIO /injection plot and welibore schematic have been included for reference. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 6/2/2011 ill II S -217 TIO Injection Plot 09 -09 -10 (2).doc TIO Plot Welt S -217 J uLr 00U -w- Tbp -11111- LA 2,000 -,- OA 00A - -.- 000A On L000 ill 06/12/10 06/19/10 06/26/10 07/03/10 07/10/10 07/17/10 07/24/10 07/31/10 00/07/10 00/14/10 08/21/10 08/28/10 09/04/10 Injection Plot Wets -n7 • 3. Dij,_. - _ 400 2,800 lir :2200 2,600 nA 2,400 8W 2,200 2,000 - 1,600 - WHIP 1�0 - - 1,400 $ - SW F _ PW l - 1,600 • - 1,200 ; - MI 3 - GI • , 1100 - -1.000 - On �° ' . 1,200- 1.000 - 800 800 - 600 600 400 400 - 200 • 06/12/10 06/19/10 06/26/10 07/03/10 07/10/10 07/17/10 07/24/10 07/31/10 09/07/10 08/14/10 08/21/10 08/28/10 09/04/10 • STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q WAG SWAP Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 207-0950 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-23362-00-00 8. Property Designation (Lease Number) : 9. Well Name and Numbe ~ ADLO-028261 PBU S-217 10. Field/Pool(s): PRUDHOE BAY FIELD /POLARIS POOL 11. Present Well Condition Summary: Total Depth measured 7049 feet Plugs (measured) 6804' feet true vertical 5489.57 feet Junk (measured) None feet Effective Depth measured 6954 feet Packer (measured) 6454 6555 6598 true vertical 5407.97 feet (true vertical) 4976 5063 5100 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 215.5# A-53 SURFACE - 108 SURFACE - 108 Surface 4340 9-5/8" 40# L-80 28 - 4340 28 - 3478 5750 3090 Intermediate Production 7038 7" 26# L-80 26 - 7038 26 -5480 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 SURFACE - 6847 SURFACE - 6847 Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" HES DUAL FEED THRU PKR 454 ~ Gum 4976 7"X3-1/2" HES SINGLE FEED THRU PKR 555 5063 7"X3-1/2" HES DUAL FEED THRU PKR 6598 5100 7"X3-1/2" HES DUAL FEED THRU PKR 6723 5208 12. Stimulation or cement squeeze summary: ~'~ Intervals treated (measured): ~ ai hh nn ~ ~U~y ( `h~'~# ~ ~~; ~ %, ~~~~~< ?411 ,~ ' i Treatment descriptions including volumes used and final pressure: ti ' ~' ~~ { ~~, ~ r, , I ~±M w" W~ V ~/ k tj ~, : ~1 ; 6 a u 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 607 1842 Subsequent to operation: 1405 2211 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 ~~I~~ ~,,,, ,~-~~~ R~CU „~~~R6DMS JUL ~ 8 ~"~~' ~. ?~ ~3~/d ~ J~y,,,a~ ......y S-217 207-095 PFRF OTTOCHMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top - -- Meas Depth Base Tvd Depth Top Tvd Depth Base S-217 10/14/07 PER 6,513. 6,547. 5,027.05 5,056.3 S-217 10/14/07 PER 6,568. 6,586. 5,074.4 5,089.92 S-217 10/14/07 PER 6,614. 6,636. 5,114.11 5,133.13 S-217 10/14/07 PER 6,674. 6,693. 5,166.03 5,182.49 S-217 10/14/07 PER 6,734. 6,782. 5,218. 5,259.58 S-217 2/12/08 BPS 6,824. 6,826. 5,295.92 5,297.65 S-217 5/3/09 BPP 6,824. 6,826. 5,295.92 5,297.65 S-217 5/13/09 BPS 6,824. 6,826. 5,295.92 5,297.65 S-217 5/15/09 BPP 6,824. 6,824. 5,295.92 5,295.92 S-217 5/29/09 BPS 6,829. 6,830. 5,300.24 5,301.11 S-217 6/1/09 SPS 6,595. 6,829. 5,097.69 5,300.24 S-217 6/2/09 SPS 6,420. 6,595. 4,947.5 5,097.69 S-217 7/10/09 SQZ 5,992. 6,420. 4,600.21 4,947.5 S-217 7/11/09 SPR 5,992. 6,860. 4,600.21 5,327.03 S-217 8/22/09 FCO 6,860. 6,925. 5,327.03 5,383.05 S-217 8/29/09 BPS 6,804. 6,805. 5,278.62 5,279.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 5-217 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/18/2010"**WELL INJECTING ON ARRIVAL*** (pre swap to mi) ;LRS PERFORMS 1500# & 1700# INJECTIVITY TEST. SET 3-1/2" WHIDDON C-SUB @ 6775' SLM. ***CONTINUED ON 5-19-10 WSR*** 9 5/18/20101 T/I/0=2000/840/350 temp= 100* Assist Slickline w/ Brush-N-Flush/ infectivity test [WAG Swap] Freeze protect Injection line- Pumped 5 bbls neat meth back to Injection line, 3 bbls up S-risor into tubing. Rigged up to S/L pump-in-sub and pumped 9.4 bbls diesel to perform Infectivity test. **Continued on 5-19-10** 5/19/2010***CONTINUED FROM 05-18-10 WSR*** (pre swap to mi) MADE 2 ATTEMPT TO PULL RK-P15XJR FROM ST. #1 RAN 3-1/2" OM-1, 1.70" LIB & TAGGED OPEN POCKET @ 6759' SLM. PULLED EMPTY CATCHER SUB FROM 6775' SLM RAN 1.74" LIB, S/D @ 6775' SLM, IMPRESSION INCONCLUSIVE. 1 RAN 10' x 2.25" P-BAILER, S/D ON XX PLUG @ 6785' SLM/ 6804' MD, NO RETURNS, METAL MARKS ON FLAPPER MADE MULTIPLE RUNS TO FISH RK-P15XJR FROM XX PLUG. REC. RK-P15XJR FROM XX-PLUG @ 6785' SLM W/ 2.66" CENT, 1-1/2" SSH. B&F W/ LRS FROM SURFACE TO XX-PLUG @ 6785' SLM, W/ 3-1/2" BLB, 2.75 G-RING. SET RK-DGLV IN ST #1 @ 6759' SLM/6775' MD_ LRS PERFORMS 2000# INJ. TEST, RATE MATCHED OPEN POCKET RATE FROM BRUSH&FLUSH. ~***CONTINUED ON 5-19-10 WSR*** • 5/19/2010T/I/O= 1150/0/0 Temp= SI Assist slick-line with WFR redesign (Wag swap) SSL ifound WFR out of pocket at station #1 lying on top of XX plug. Brush and flushed tbg after 80 bbls pumped established injection rate of .74 bpm @ 2000 psi. for 20 additional bbls diesel. -Pumping through WFR design and open pocket at station #1. SSL set DGLV in station #1. Injection rate with DGLV in station #1 - .74 @ 2000 psi. SSL to pull TTP. "**Continue AWGRS om 05-20-10*** 5/19/2010*"Continued from 5-19-10*" Assist Slickline Pumped 10 bbls 180" diesel down tubing to freeze protect surface pipe- Pumped 21 bbls diesel down tubing in attempt to duplicate previous Injectivity test data. Called off job ""Slickline in control of wellhead on departure** t~ F'~ ~,JA~`~ 5/20/2010'***Continued AWGRS from 05-19-10*"* Assist slick-line with WFR redesign (Wag swap) WFR in station #1 fell out of pocket. SSL fished valve out. SSL ran a pocket poker. SSL held WFR in station #1 while holding 2000 psi on WFR then sheared doff getting a injection rate of .22 bpm @ 2000 psi., witch is an appropriate rate. SL pulled DV from station #1. Open pocket Injectivity test = 1 bpm for 5 min. at a stabilized 1900 psi. SSL set WFR in station #1 while holding 2000 psi. 5 min. Injectivity test after shearing off = .36 bpm @ 2000 psi. Perform Injectivity test at 2000 psi. = 0.6 bpm. / 2200 psi. _ .66 bpm and 2400 psi. = 0.7 bpm. SSL bailed. SSL RIH to pull TTP. "**Continue AWGRS on 5-21-10''"* 5/20/2010 *""CONTINUED FROM 5-19-10 WSR*** (pre wag swap) ATTEMPT TO EQ XX PLUG @ 6804' MD, RK LATCH MARKS ON EQ PRONG. RECOVERED RK-DGLV FROM XX PLUG @ 6804' MD RAN K.JT, 3-1/2" OM-1, 1-1/2" POCKET POKER TO STA #1 GLM, SHEARED PINS SET RK-DGLV IN ST #1 GLM @ 6759' SLM/6775' MD WHILE LRS PUMPS jTAGGED RK-DGLV IN ST. #1 W/ 1.70" LIB. PULLED RK-DGLV FROM ST #1 GLM @ 6759' SLM/ 6775' MD .SET RK-P15XJR WFR IN ST # 1GLM @ 6759' SLM/ 6775' MD WHILE LRS PUMPS 'TAGGED RK-P15XJR IN ST. #1 W/ 1.70" LIB. LRS PERFORMED INJECTIVITY TEST (see log) ,MADE SEVERAL ATTEMPTS TO EQUALIZE AND PULL XX PLUG @ 6804' MD/6784' SLM ~ BAILED 1 CUP OF CEMENT FROM 6781' SLM, W/ 2.25" x 10' PUMP BAILER. ***CONTINUED ON 5-20-10 WSR""" 5/21/2010"**CONTINUED FROM 5-20-10 WSR*'`* (pre wag swap) MADE 1 ATTEMPT TO PULL 3-1/2" XX-PLUG FROM X-NIPPLE @ 6777' SLM/6884' MD. RAN RK-RUNNING TOOL & TAPPED ON RK-P15XJR IN ST. #1 @ 6759/6775' MD. !PULLED XX-PLUG BODY FROM X-NIPPLE @ 6777' SLM/6884' MD, W/ LRS ~ ASSISTANCE. ~ PLUG BODY PACKED W/CEMENT. SET 3-1/2" XX-PLUG IN X-NIPPLE @ 6777' SLM/6804' MD. ~ RAN 3-1/2" CHECK SET (good set) `LRS PERFORMED INJECTIVITY TEST (see log) SET MCX VLV IN X-NIPPLE @ 2866' SLM/ 2891' MD (.5" bean, ser #: BPX-331) RAN 3-1/2" CHECK SET (good set) "*''WELL LEFT S/I ON DEPARTURE, TURNED OVER TO PAD OP TO POI**" ~2010'""`Continued AWGRS from 05-20-10"** Assist slick-line with WFR redesign (Wag swap) Performed a step rate infectivity test (5 min. each) with 25 bbls diesel. 2000 psi.= .46 bpm. / 2200 psi.= .48 bpm / 2400 psi.= .58 bpm. / 2600 psi.= .54 bpm. Final WHP= 750/60/40. SSL on well at departure. FLUIDS PUMPED BBLS 8 MEOH 263.5 diesel 271.5 Total TREE = 4-1 /16" CNV _ W LL_FiE?>D`-- 11" F ACTUATOR = BAK ~ ~ ~~ SAFETYIa CfES' KB. ELEV = 35.8' BF. ELEV = 67' KOP = 300' 24' 4-1/2" X 3-1/2" XO, ID = 2.992" Max Angle = 50° @ 4370' Datum MD = 6559' 20" CONDUCTOR ? Datum TVD = 5000' SS TAM PORT COLLAR I 996' 2891' 3-112" HES X NIP, ID = 2.813"~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH F 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 4340 7 6395 4926 32 MMG EM -- 7" CSG, 26#, L-80 TGII XO TO L-80 BTGM 5924 EST TOP OF CEMENT (07/10/09) 6224' / ,,,,, 6423' 3-1/2" HES X NIP, ID = 2.813 - I WATER It~(IGf`TIl11J ne Auncia c Minimum ID = 2.750" @ 6824" 3-1i2"HES XN NIPPLE ~3-1/2" RA ~PTAG 7" MARKER JOINT w / RA TAG PERFORATION SUMMARY REF LOG: USfT ON 10/15/07 ANGLE AT TOP PERF: 31 ° @ 6513' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OA 6513 - 6547 O 10/14/07 4-1/2" 5 OBa 6568 - 6586 O 10/14/07 4-1/2" 5 OBb 6614 - 6636 O 10/14/07 4-1/2" 5 OBc 6674 - 6693 O 10/14/07 4-1/2" 5 OBd 6734 - 6782 O 10/14/07 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" PBTD 7" CSG, 26#, L-80 BTC, .0383 bpf, ID = 6.276" ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6479 4998 31 MMG-W DMY RK 0 10/18!07 5 6533 5044 31 MMG-W P-15XJR RK 11 09/01/09 4 6576 5081 30 MMG-W P-15XJR RK 11 09!01/09 3 6632 5130 30 MMG-W DMY RK 0 10!18/07 2 6694 5183 30 MMG-W P-15XJR RK 11 09/01!09 1 6775 5253 30 MMG-W P-15XJR RK 14 05120!10 U4:)4~ 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 6467' PHOENIX SENSOR SUB, ID = 2.992" w/DUAL WIRE TO SURFACE IN IA 6549' 3-1/2" HES X NIP, ID = 2.813" ti5_55~-17" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 6598' 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 6606 FHOENDC SENSOR SUB, ID = 2.992" ~ ~ w ! DUA L W IRE TO SURFACE IN IA 6626' 3-1/2" HES X NIP, ID = 2.813" 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 3-112" HES X NIP, ID = 2.813" 6804' -j3-1/2" XX PLUG (05121110) 6804 3-1 /2" HES X NIP, ID = 2.813" 6824' 3-1/2" HES XN NIP, ID = 2.750" 6~ 847 I-13-1/2" WLEG, ID = 2.992" ~~ ELMD NOT LOGGED POLARIS UNff WELL: S-217 PERMff No: 2070950 API No: 50-029-23362-00 SEC 35, T12N, R12E, 2123' FNL & 714' FWL BP Exploration (Alaska) u • ~T~+ ~S~ OI~ ~ ~ C~is-7E~QA~~1s C~~SSI~i` 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ADMINISTRATIVE APPROVAL NO. AIO 25A.006 Ms. Diane Richmond GPB West Subsurface Resource Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Request to Allow Enriched Hydrocarbon Gas Injection. PBU S-217 (PTD 2070950) Polaris Oil Pool Dear Ms. Richmond: By letter dated March 29, 2010, BP Exploration (Alaska) Inc. (BPXA) requested approval to allow enriched hydrocarbon gas injection in Well PBU Polaris 5-217 (PTD 2070950). The Alaska Oil and Gas Conservation Commission GRANTS BPXA's request in accordance with Rules 2 and 13 of AIO 25A.000 An Application for Sundry Approval (Form 10-403) is not required; however a Report of S (Form 10-404) should be submitted documel~,~tTn~ the commencement of enriched gas inject DONE at Anchorage, Alaska t Apr' 16, 2010. Daniel T. S amount, Jr. Jo T Commissioner, Chair m issioner Cathy ~'. Foers Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 3 LO5.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by i[. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed [o be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which Che application for reconsideration was tiled. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FTNAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event [he period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holidav. b ~ ~ p n March 29, 2010 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Daniel T. Seamount ~ Chairman Alaska Oil and Gas Conservation Commission ~AF~ ~ a 20~~ 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~.~ RE: Administrative Approval for Enriched Hydrocarbon Gas Injection in Well PBU 5-217~~ Dear Chairman Seamount: BP Exploration (Alaska), Inc. (BPXA), operator of the Prudhoe Bay Unit (PBU), on behalf of itself and the other the PBU Working Interest Owners, requests administrative approval under Area Injection Order No, ZSA (AIO 25A) to allow for the injection of enriched hydrocarbon gas into injection well 5-217. The following wells are approved for enriched hydrocarbon gas injection under AIO 25A Rule 2: 5-215i, W-209i, and W-215i. The rule also states that upon "proper application" additional water injecting wells can be reclassified as WAG injectors. 5-217i was drilled in October 2007 and is currently approved for water injection. Figure 1 provides data on the zonal isolation status of the wellbore. There are two offset wells present within aone-quarter mile radius of 5-217i as depicted by Figure 2. Both 5-21.61 and 5-215i have sufficient cement integrity. The top of cement (TOC) in 5-217 was determined by a cement bond log to be 4980' MD, providing 1325' MD of coverage above the top of the pool. BPXA believes that injected fluids will be confined within the appropriate receiving intervals. Should you have any questions regarding this request, please contact Maggie Orlando at 564 - 4741. Thank you for timely consideration of this request. Sincerely, !~ ' ~~~ ~ ' . Diane Richmond GPB WEST, Resource Manager CC: Mark Agnew (ExxonMobil) Dan Kruse (CPAI) Glenn Frederick (Chevron) Alan Mitchell (BPXA) David Lenig (BPXA) Claire Sullivan (BPXA) Attachments: Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of 5-217i Figure 2: 5-217i % mi Radius Map March 18, 2010 Page 2 Figure 1: Zonal Isolation Status of Wellbores within One-Quarter Mile of 5-217i Well Dist from TOC, TOC Determination Top Pool (D1C Top Injection Coverage injector, ft MD Method sand), MD Sand (Nb), 1`1D 5-217i 0 4980 Cement Bond Log 6305 6393 1325' MD Dated 15/Oct/2007 S-21fii 419 7680 Cement Bond Log 7898 7981 218' MD Dated 26,~Dec/2000 S-21~i 1221 3004 Cement Bond Log 5992 6096 2988' MD Dated O 1 /Aug/2007 2: S-217i '/ mi Radius 5,978,000 5,976,000 5,974,000 5,972,000 Schrader Biuff Nb Depth Structure Map 20' Contour Interval. 1/ mile circle around SB_Nb injection zone for S-217, S-218 616,000 618,000 620,000 STATE OF ALASKA ALASKA O AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ PKR REPAIR Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ ~rrten~" P(~ile Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska) Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 207-0950 3. Address: P.O. Box 196612 Stratigraphic^ Service Q API Number: Anchorage, AK 99519-6612 50-029-23362-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ~ ADLO-028261 S-217 10. Field/Pool(s): MAR ~ ~ 2010 \ . . PRUDHOE BAY FIELD /POLARIS POOL 11. Present Well Condition Summary: ~~~ Total Depth measured ~ 7049 feet Plugs (measured) 6804' feet true vertical 5489.57 feet Junk (measured) None feet Effective Depth measured 6954 feet Packer (measured) 6454 6555 6598 true vertical 5407.97 feet (true vertical) 4976 5063 5100 Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" 215.5# A-53 SURFACE - 108 SURFACE - 108 Surface 4340 9-5/8"40# L-80 28 - 4340 28 - 3478 5750 3090 Intermediate Production 7038 7" 26# L-80 26 - 7038 26 -5480 7240 5410 Liner Liner n~ ~ ~` Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ - = Tubing: (size, grade, measured and true vertical depth) 3-1 /2" 9.2# L-80 SURFACE - 6847 SURFACE - 6847 Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" HES DUAL FEED THRU PKR ~ 4976 7"X3-1/2" HES SINGLE FEED THRU PKR 6555 5063 7"X3-1 /2" HES DUAL FEED THRU PKR 6598 5100 7"X3-1/2" HES DUAL FEED THRU PKR 6723 5208 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 892 1606 Subsequent to operation: 571 1526 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-091 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 3/9/2010 S-217 207-095 DCDC ATTA!`L.IMCIUT Sw Name Operation Date Perf Operation Code ~Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-217 10/14/07 PER 6,513. 6,547. 5,027.05 5,056.3 S-217 10114/07 PER 6,568. 6,586. 5,074.4 5,089.92 S-217 10/14/07 PER 6,614. 6,636. 5,114.11 5,133.13 S-217 10/14/07 PER 6,674. 6,693. 5,166.03 5,182.49 S-217 10114/07 PER 6,734. 6,782. 5,21.8. 5,259.58 S-217 2/12/08 BPS 6,824. 6,826. 5,295.92 5,297.65 S-217 5/3/09 BPP 6,824. 6,826. 5,295.92 5,297.65 S-217 5/13/09 BPS 6,824. 6,826. 5,295.92 5,297.65 S-217 5/15/09 BPP 6,824. 6,824. 5,295.92 5,295.92 S-217 5/29/09 BPS 6,829. 6,830. 5,300.24 5,301.11 S-217 6/1/09 SPS 6,595. 6,829. 5,097.69 5,300.24 S-217 6/2/09 SPS 6,420. 6,595. 4,947.5 5,097.69 S-217 7/10/09 SQZ 5,992. 6,420. 4,600.21 4,947.5 S-217 7/11/09 SPR 5,992. 6,860. 4,600.21 5,327.03 S-217 8/22/09 FCO 6,860. 6,925. 5,327.03 5,383.05 S-217 8/29/09 BPS 6,804. 6,805. 5,278.62 5,279.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 5-217 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/28/2009 ~' `WELL S/I ON ARRIVAL"*" (g/I for rate) RU SWCP #2, FOR WFR INSTALL & INJECTIVITY TESTING. SET 3-1/2" WHIDDON C-SUB @ 6,796' SLM *""CONTINUED ON 4/29/09 WSR""" j 4/29/2009 4/29/2009 ~,e.~ _,~..____.~_. .--. ~____ T/I/0=750/540/140. Assist SL with WFR. (Injection valve change-out,SRT) Step #4 of program.Station #1 Pumped 7 bbls of diesel to reach 1000 psi. Pumped 5 bbls of diesel @ .33 bpm to maintain 1000 psi for 15 mins. Pumped 5 bbls of diesel to reach 1400 psi. Pumped 9 bbls of diesel @ .64 bpm to maintain 1400 psi for 15 mins. Pumped 8 bbls of diesel to reach 1800 psi. Pumped 14 bbls of diesel @ .89 bpm to maintain 1800 psi for 15 mins. SL to RIH and pull WFR from station #1. WFR packing damaged. SL RIH wit valve slot brush. SL RIH and set DGLV in station #1. MIT-T ""PASS"* to 2000 psi. Bled TP back to normal. Restart infectivity test pumped at 1000 psi, captured rate of .32 increased rate to 1400psi, captured rate of .67 Attempted to reach 1800psi at 1 bpm pressure did not rise past 1550. ***AWGRS continued on 4/30/09*** *"*CONTINUED FROM 4/28/09 WSR"**(g/I for rate) PULL RK-DGLV FROM ST# 1 @ 6,771' SLM(6,775' MD).SET RK-WFR ST#1 @ 6,771 SLM. LRS PERFORMED UNSUCCESSFUL INJECTIVITY. TEST.(refer to log tab). PULL RK-WFR FROM ST#1 @ 6,771' SLM(6,775' MD). SET RK-DGLV ST#1 @ 6,771' SLM. LRS PERFORMED SUCCESSFUL MIT-T TO 2000psi. PULL RK-DGLV FROM ST. #1 @ 6,771' SLM(6,775' MD) ***CONTINUED O 4/30/09 WSR*** Continued from 4/29/09 Assist Slick-line with water flow regulators (Repair packer leak) Perform step 4 of procedure on WFR valve. Pumped 4 bbls of dsl @ .20 bpm at 1000 psi. for 15 mins. Pumped 3 bbls of dsl @ .25 bpm at 1400 psi. Pumped 6 bbls of dsl @ .29 bpm at 1800 psi. for 15 mins. '"**Table top drill -what if fitting on down stream side of check valve failed''** SSL reset plug unable to get a passing mit on 4 attempts PE ok'd to pull DGLV in station #2 to continue on. Infectivity test on open pocket- Pumped 7 bbls dsl @ .3 bpm at 1000 psi for 15 minutes. Pumped 15 bbls dsl @ 1 bpm at 1350 psi for 15 minutes. SSL set WFR in station #2. (continue awgrs on 5/01/09) ._, .e___~ ~ ~ .~-. ~ ....~ .__ __. _ ~__ _ ~....~ ~ _._ 4/30/2009 ***CONTINUED FROM 4/29/09 WSR'`*'"(g/I for rate) SET RK-WFR IN ST. #1 @ 6,771' SLM(6,775' MD) LRS PERFORMS INJECT. TEST ON ST. #1, AS PER PROGRAM(pass, see Irs reports) SET 3-1/2" XX-PLUG @ 6,744' SLM( 6,754' MD), UNSUCCESSFUL MIT-T TO 2000 PSI. PULL 3-1/2" XX-PLUG BODY FROM 6,744'(6,754 MD) RE-SET 3-1/2" XX-PLUG @ 6,744' SLM( 6,754' MD), UNSUCCESSFUL MIT-T PTO 2000 PSI. PULL RK-DGLV FROM ST#2 @ 6,68T SLM(6,694' MD). '~*"CONTINUED ON 4/31/09 WSR"** 5/1 /2009 5/1 /2009 5/2/2009 **"CONTINUED FROM 5/1/09 WSR*'`"(gl for rate) j ,SET RK-WFR IN ST. #2 @ 6,68T SLM(6,694' MD) ,LRS PERFORMS SUCCESSFUL INJECTIVITY TEST(see Irs rep.) ;PULL 3-1/2" XX-PLUG FROM 6,744' SLM(6,754' MD) "'' SET 3-1/2" XX-PLUG @ 6,616' SLM (6,626' MD), SUCCESSFUL MIT-T TO ~2000psi. PULL RK-DGLV FROM ST#4 @ 6,572' SLM(6,576' MD). LRS PERFORMED INJECTIVITY WITH EMPTY POCKET(see Irs report). SET RK-WFR IN ST#4 @ 6,572' SLM(6,576' MD). ;LRS PERFORMS SUCCESSFULL INJECTIVITY TEST,(see Irs rep.) ?PULL 3-1/2" XX-PLUG BODY FROM 6,616' SLM(6,626' MD). ' ;SET 3-1/2" XX-PLUG BODY @ 6,540' SLM(6,549' MD). ***CONTINUED ON 5-2-09 WSR*** __ _~_._.~ ~___ _~ __._ w.__~~ _ ~.u__ ~~_ ~__ ~..._~_~ ***Continued AWGRS from 4-30-09**" Assist Slick-line with water flow regulators (Repair packer leak) Slick-line set WFR in station #2. Injectivity test on station #2 passed -Pumped 2 bbls dsl @ .14 bpm at 1000 psi. for 15 minutes. Pumped 5 bbls dsl @ .3 bpm at 1400 psi for 15 minutes. Pumped 4 bbls dsl @ .3 bpm at 1800 psi. for 15 minutes. ** SSL pulled plug from x-nipple at 6754'. SSL set plug at 6626'. MIT-T to 2000 psi. Passed as per SLPE. Pumped 21 bbls of diesel down TBG through open pocket at station #4. Capture 1.0 bpm at 800 psi. Injectivity test -Pumped 2 bbls diesel @ .16 bpm. at 1000 psi for 15 mins. Pumped 3 bbls diesel @ .20 bpm. at 1400 psi. for 15 mins. Pumped 3 bbls diesel @ .22 bpm. at 1800 psi. for 15 mins. Injectivity test on station #4 passed. **SSL pulled plug from x- Fnipple at 6626'. SSL set plug at 6549'. MIT T to 2000 psi Passed. SSL pulled DGLV and set WFR in station #5. '"**Continue AWGRS on 5-02-09*** I*"*Continued AWGRS from 05-01-09*** Assist Slick-line with water flow regulators (Repair packer leak) Slick-line set WFR in station #5. Injectivity test on station #5 -Unable to do 1000 psi test flow meter would not read < .1 bpm. ;Pumped 1.5 bbls diesel @ .1 bpm at 1500 psi for 15 minutes. Pumped 2 bbls diesel @ .15 bpm at 1800 psi for 15 minutes. During test IA pressure increased to 1320 psi and maintained 1320 psi for 15 minutes. Bled pressure down and IA pressure came down with TBG. Pumped 11 bbls of diesel to fluid pack TBG. Pumped 13 bbls of diesel @.85 bpm. at 1000 psi. for 15 mins During test IA pressure increased to 960 psi. Pumped 10 bbls of diesel to increase pressure to €1400 psi. Pumped 12 bbls of diesel @ 1.14 bpm. at 1400 psi. for 13 mins. Ran ;out of fluid. During test IA pressure increased to 1260 psi. Pumped 25 bbls of diesel trying reach 1800 psi @ 1.16 bpm. Could only get to 1420 psi. Rig off of pump-in-sub and on to IA to MIT-IA to 2500 psi. MIT-IA **FAIL"* to 2500 psi. Established LLR of 0.06 bpm. (See Log) TBG never tracked while pumping into IA. oSL still on well at LRS departure. Final WHP= 300/300/100 • ! 5/2/2009 '`'`"CONTINUED FROM 5/1/09 WSR*** PULL RK-DGLV FROM ST. #5 @ 6,527' SLM/6,533' MD SET RK-WFR IN ST. #5 @ 6,527' SLM/6,533' MD LRS PERFORMS SUCCESSFULL INJECTIVITY TEST ON ST. #5, AS PER PROGRAM. EQ. & PULL 3-1/2" XX-PLUG BODY FROM 6,540' SLM/6,549' MD LRS PERFORMS SUCCESSFUL INJECTIVITY TEST @ 1000psi & 1400psi. (see ~Irs reports). iLRS PERFORMED UNSUCCESSFUL MIT x IA TO 2500 psi (see Irs reports) 'SET 3-1/2" WHIDDON C-SUB @ 6,792' SLM. ***CONTINUED ON 5-3-09 WSR""* 5/3/2009***CONTINUED FROM 5/2/09***(gl for rate) PULL RK-WFR FROM ST. # 5 @ 6,527' SLM/6,533' MD SET RK-DGLV IN ST # 5 @ 6,527' SLM/6,533' MD PULL 3-1/2" WHIDDON C-SUB FROM 6,792' SLM RAN MULTIPLE 2.50" BAILER RUNS TO 6,824' MD(~2 cups formation sand ;recovered). PULL P-PRONG FROM 6,80T SLM,PULL 3-1/2" PLUG BDY FROM 6,815'SLM/6,824'MD 'DRIFT W/2.50",TEL, SB, TT@ 6,835' SLM + 12' CORRECTION TO 6,84T MD, TD @ 6,896'MD. SAMPLE OF FORMATION SAND, 114' OF RATHOLE. ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** ..Q 5/12/2009 ***WELL S/I ON ARRIVAL*"" ~ (pre pkr sqz) SET 2.81" C.A.T. VALVE IN XN @ 6818' SLM/6824' MD ..PULL RK-WFR THEN SET RK-DGLV IN ST#1 @ 6771' SLM/ 6775' MD PULL RK-WFR THEN SET RK-DGLV IN ST#2 @ 6691' SLM/ 6694' MD ;PULL RK-WFR FROM ST#4 @ 6572'SLM / 6576'MD RIH W/ RK-DVLV FOR ST #4 *""CONT WSR ON 5-13-09"** 5/13/2009T/I/O= 0/500/140 Temp=S1 Assist Slickline, MIT-T FAILED to 2500 psi ---3 attempts--- (Repair packer). Pressured up Tbg with 2 bbls diesel for MITT. Tbg lost 460 psi in 15 mins, Slickline to reset TTP. Freeze protected Tbg with 3 bbls ,meth, 23 bbls diesel. Final WHP's=1820/520/180. Slickline in control of well at `time of departure 5/13/2009'"""CONT WSR FROM 5-12-09**"(pre pkr sqz) SET RK-DGLV IN ST #4 @ 6572' SLM, THEN ATTEMPTED MITx T (FAIL) SEE s LOG PULL 3-1/2"CAT VLV @ 6816'SLM ;SET 3.5" PXN PLUG BODY AND P-PRONG @ 6,816' SLM xATTEMPT SECOND MIT-T (FAIL) SEE LOG SET 3.5" X-CATCHER @ 6,810' SLM SHIT ON DGLV IN STA. #5 @ 6,533' MD, THEN ATTEMPTED MIT-T (FAIL) SEE ~ LOG SIN THE PROCESS OF RUNNING IN TO CHECK STA'S 1-5 ***CONT. WSR ON 05/14/09*** . ~._ .____ __ 5/14/2009,***CONT. WSR FROM 05/13/09*** €RAN 3.5" D&D HOLEFINDER TO DETERMINE LEAKING MANDREL (UNSUECCUSSFUL) `MADE 3 ATTEMPTS TO MIT-T (FAILED) SEE LOG ;SET 3.5" XX PLUG @ 6,423' MD TO TEST TUBING INTEGRITY &STA #7 '(PAS -- PULLED STA'S #2 &#4 1.5" DGLV'S (RK LATCH) SET STA'S #2 & #4 1.5" DGLV'S (RK LATCH) SIN THE PROCESS OF MIT-T ***CONT. WSR ON 05/15/09'"** 5/15/2009 ***CONT. WSR FROM 05/14/09"** MIT-T TO 2,500 PSI. (PASSED) PULLED 3.5" X- CATCHER FROM 6,810' SLM PULLED P-PRONG FROM 6,811' SLM PULLED 3.5" X-PLUG BODY FROM 6,819' SLM RAN & SET 3.5" BAKER COMPOSITE PLUG ,HAD PROBLEM'S RELEASING FROM PLUG DRAG UP TO XN-NIPPLE SHEAR E-FIRE SHEAR SUB. IN THE PROCESS OF TRYING TO FISH E-FIRE TOOL & BAKER SETTING TOOL **"CONT. WSR ON 05/16/09""* 5/16/2009 ***CONT. WSR FROM 05/15/09**" MADE MULTIPLE RUNS IN ATTEMPT TO FISH E-FIRE & BAKER SETTING .TOOLS UNABLE TO LATCH TOOLS SETTING DOWN IN STA. #4 6,576' MD. I APPEARS THAT THERE IS ,SOMETHING WRONG (BROKE) WITH STA#4 RAN 10' 2.5" PUMP BAILER TO 6,828' SLM (LESS THAN 1 CUP OF RETURN OF SAND) !RUN KOT TO STA #4 @ 6,576' MD IMPRESSION OF EMPTY POCKET ARAN 2.25" PUMP BAILER TO 6,828' SLM (NO RETURN) ARAN 2.60" BELLGUIDE & 1 5/8"JUS (RETRIEVED STA. #4 1.5" DGLV) FROM :6,828' SLM RAN 2.60" BELLGUIDE & 2"JUS TO 6,828' SLM UNABLE TO LATCH. IN THE PROCESS OF RUNNING IN W/ 2.25" PUMP BAILER ;"'"''CONT. WSR ON 05/17/09''** • • 5/17/2009 ***CONT. WSR FROM 05/16/09*** ~~~~~~~~ ~~ ~ ~~~~~~~~~~~~~~~~~~ MADE 2 RUNS W/ 2.50" HYDRO-STATIC BAILER TO 6,828' SLM (2 BAILERS FULL OF SAND & FLUID ) MADE SEVERAL RUNS TO LATCH E-FIRE TOOLS UNABLE TO LATCH ARAN 3 1/2" G-BAIT SUB & BOWEN OVERSHOT W/ 1.5"GRAPPLE LATCHED ;FISH @ 6,832' SLM. MOVED FISH UPHOLE 10' (TO XN NIPPLE). UNABLE TO PULL FISH & UNABLE TO SHEAR OFF, DROPPED 2.125" CUTTER BAR (FN 1.75") (CUT & RETRIEVED ALL WIRE) SIN THE PROCESS OF RIGGING UP .125 WIRE & TOOLS TO RUN IN & FISH CUTTER ***CONT. WSR ON 05/18/09""" 5/18/2009 ***CONT. WSR FROM 05/17/09""* JAR ON FISH FOR 2.5 HOURS TOTAL. 2 ATTEPMTS. UNABLE TO PULL OR SHEAR GR. *FISH STILL IN HOLE @ 6795' SLM (DETAILS IN LOG). RESCHEDULED FOR BRAIDED LINE* ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 5/28/2009 *"* W ELL S/I ON ARRIVAL *** (pre pkr sqz) .JARRED ON FISH @ 6792' SLM W/ 2-1/2" JDC FOR 2 HOURS, MOVED UP TO 6781' SLM TAPPED DOWN FOR 15 MINS, FISH MOVED DOWN TO 6792' SLM *** CONTINUED ON 5/29/09 WSR'"** 5/29/2009 ~v~......,~.nr~.~...w.~~._ __ ~~~,~,~, w~~ ...._ *** CONTINUED FROM 5/28/09 WSR *** (pre pkr sqz) FISHED TOOLSTRING FROM 6837' BLM & E-FIRE W/SETTING TOOL FROM 6824' BLM. TAG BAKER QUICK DRILL AT 6837' SLM W/ 3-1/2" BRUSH & 2.50" BLIND BOX. TAGGED XN NIPPLE AT 6818'SLM/6824'MD W/ 2.80" CENT FOR DEPTH CONTROL. SET 2.55" BAKER QUICK DRILL COMPOSITE BRIDGE PLUG @ 6829' MD ON E-FIRE. NOTE: 1st BAKER QUICK DRILL MISS-SET 05/15/2009 STILL IN HOLE AT 6836' MD. "** CONTINUED ON 5/30/09 WSR **" 5/30/2009"** CONTINUED FROM 5/29/09 WSR *** (pre pkr sqz) =SET 3-1/2" X-CATCHER SUB @ 6614'SLM/6626'MD. SET RK-DGLV IN STA #4 @ 6472'SLM/6476'MD. PULLED 3-1/2" X-CATCHER SUB FROM 6626'MD. ;SET 3 1/2 XX PLUG @ 6626' MD. MIT-T TO 1000 PSI, PASSED. PULLED 3-1/2" XX PLUG @ 6626 MD. 'RIH W/ 2.7" CENT,2.5" LIB TO COMPOSITE PLUG @ 6822 SLM. ***" LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. "'****" 6/1/2009 CTU #6 1.75" CT (Job Scope: Sand Plug) «<InterACT is Publishing»> MIRU CTU. MU Nozzle BHA & Test BOPE. MU JSN BHA and RIH. Tagged Composite Plug at 6824' and corrected depth back to 6822'. PU 5' painted flag and circ bottoms up. Mix 8.56 bbls "Dirty Slurry" and lay in. Tag sand top at 6595', expected top 6420', wait additional 2 hrs due low BHT, top @ 6575', pump 2nd ;batch of 900 lbs. Stby to tag "**Job in Progress"** 6/1/2009~re-job meeting Setup the trailer and job site. Pressure test the pumps and job site. Check the depth on the conductor (4"). Treat the well with Rg 2401 chemical (1.7 Gallons). O/A was at 200 psi and the I/A was at 400 psi and the well was On- line. Demobe off the job site. ..._m® ~ ~..~~m. ~..~ ,. ~~~.. e~,..~ . ~ .._ :CTU #6 1.75" CT (Job Scope: Sand Plug) «<InterACT is Publishing»> Tag sand top after 2nd batch @ 9515', Dress off top w/ 650 Ibs sand, Tag @ 6412', Cdress off to 6420', Jet GLM #7 and chase solids OOH, FP from 2200'. OOH =RDMO CTU "'""Job Complete'"""' 6/4/2009 **" WELL SHUT IN PRIOR TO ARRIVAL'""*(pre packer squeeze) DRIFT TO TOP OF SAND @ 6413'SLM W/2.50" SAMPLE BAILER aRECOVERED 2 CUPS OF SAND 'SET X-LOCK CATCHER @ 6403'SLM/6423' MD. `PULLED 1.5" DGLV W/RK @ 6381'SLM/6395'MD FROM STA#7 PULLED CATCHER- EMPTY `""" TURN WELL OVER TO PAD OP -LEFT SHUT IN - DO NOT FI **" OPEN POCKET, STA #7 @ 6395'MD *** i • 7/1/2009 T/I/0= 200/220/140, Temp= S/I. Load Tubing & IA with diesel (Pre CTU). Pumped 5 bbls ambient methanol followed by 300 bbls of 50" diesel down the tubing threw open pocket at station 7 taking returns up IA threw hardline to tiger tank. Maintained 1000 psi on the backside with the choke, for the duration of the job. FW HP= 850/800/340 Wing, Swab, SSV= Closed Master, IA,OA= Open 7/9/2009=T/I/0= SSV/300/150. Temp= SI. IA FL (Coil). IA FL @ surface. SSV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. __ . r ._ . _ _ _. ~. ~ _ ~ ..__. _ __._ _ ~ ._~._ _._...__.____ 7/9/2009~CTU #6 1.75" CT (Interact Publishing) Job Scope: Cement Plug/Mill ~Cement/Sand and Composite Plug. MIRU CTU. Drop 1.25" ball into coil and chase' =with diesel to determine volume of coil tubing reel. Confirmed volume of Reel to be 34.7 bbls. Recover ball on surface. ''** Continue job on WSR 07/10/2009. 7/10/2009 CTU #6 1.75" CT (Interact Publishing) Job Scope: Cement Plug/Mill , Cement/Sand and Composite Plug. *** Job cont'd from 7/09/2009*"* MU BHA with 2.0" BDN stab on well. Pressure test all valves on the choke manifold to 3000 psi, okay. Change leaking CT Reel Swivel. Fluid pack IA with Diesel. Open up well and RIH with 2.0 BDN. Tag top of sand at 6424' CTM. Made -4' correction. PU to 16410' and flag pipe. Pump 8 bbls 15.8 ppg cement. Place 1.8 bbls in tubing a ,d_ 6.2 bbls in IA. Est. TOC in tubing and IA -6224'. Wait for lab confirmation of 500 psi compressive strength. Confirmed 500 compressive strength after 10 hrs. Call out Baker. Cont' Job on WSR 7/11/2009*** Job in Progress"** 7/11/2009 CTU #6 1.75" CT (Interact Publishing) Job Scope: Cement Plug/Mill Cement/Sand and Composite Plug. '"'* Continued Job from WSR 7/10/2009*'"` MU Fand RIH with motor and 3 bladed 2.67" Junk Mill. Dry tag top of cement at 5992' ;CTM. PU sticky and broke free at 5973' CTM. Begin mill soft cement at 5992' ctm. Did not encounter any increase in motor work from 5992' (tag dept o c m. 'Continue cleaning out clement. Notice a little bit of motor work at 6140' ctm. Tag :hard cement at 6371' ctm and continue milling to 6450' ctmd. POOH for FCO bha. MU and RIH with 1.75" JSN. Jet sand with biozan in 50' bites to 6770' ctmd. E POOH to wait for fluid support. Conduct weekly BOPE test. MU and RIH with 1.75" JSN to finish FCO.Tag top of fill at 6743' ctm. Begin jet into fill at 2.0 bpm. Jet down to too of plug at 6828' ctm. Pump gel sweep and chase to surface at • 80%. Cont' on 7/12/2009. ***Job in progress*"" 7/12/2009~CTU #6 1.75" CT (Interact Publishing) Job Scope: Cement Plug/Mill rCement/Sand and Composite Plug. *** Continued Job from WSR 7/11/2009""* Re- head CT with Baker MHA. MU and RIH Baker 2 bladed 2.67" Junk Mill. Dry tag top Hof plug @ 6828' CTM. PUH to 6805' CTM to establish free spin. Begin mill ;.composite plug. Mill out the first composite plug. RIH and tag second plug at 6836' =CTM. PUH establish free spin and continue milling. Mill/Push pluas to 6860' `~ ~ctmd. POOH freeze protecting tubing with 20 bbls 50/50 methanol. OOH. MIT- IA to 2500 psi. FAIL. Repeat 2 more times without success. Recommend wating ~24 - 48 hours for temperature stabilization and attempting with full bore. Notify operator of well status. RDMO. "**Job Complete*'`* 7/17/2009~T/I/O= 0/vac/90 Temp=S1 MIT IA PASSED to 2500 psi (PROFILE)_ Pressured up IA to 2500 psi with 3.5 bbls meth. 2nd test results- 1st 15 min IA lost 20 psi, 2nd 15 min IA lost 10 psi with a total loss of 30 psi in 30 min test. Bled back 2 bbls. Final WHP's= 0/100/50 "Operator notified of valves as SV,WV=closed, SSV,MV,IA and OA open on departure" 7/22/2009 .Assist SL with W FR. (Profile Modification) SLB Slickline delayed *"*'` Called away to another Job *** Will be back for this job 7/22/2009TI0 = Assist SLB Slickline with WFR (Profile Modification) Load diesel =and travel to location**** Continued on 07-23-09 '"***" • • 7/22/2009***WELL SHUT IN ON ARRIVAL*** (post pkr sqz) .;CURRENTLY RIGGING UP SWCP 4515 TO C/OUT WFR's ***CONT WSR ON 7/23/09*** 7/23/2009 *** Continued from 07-22-09 *** T/I/O = 150/22/150 Temp = SI Assist Slickline with WFR Test (Profile Modification) Pump 88 bbls of 45 * f diesel to assist SSL !RIH. ***Continue AWGRS on 07-24-09*** 7/23/2009 -- ***CONTWSR FROM 07/22/09*** (post pkr sqz) BRUSH & FLUSH TBG W/ 3-1/2" BRUSH, 2.7" GAUGE RING TO 6298' SLM.(UNABLE TO PASS) RAN 3-1/2" BRUSH, VARIOUS GAUGE RINGS (2.35"-2.75").WORKED TIGHT SPOT FROM 6298' SLM TO 6524' SLM. RECOVERED 1 PIECE (approx 6.5" long x 2" wide x 3/16" thick) OF CEMENT ON BRUSH. CURRENTLY RIH W/ 3-1/2" BRUSH, 2.70" GAUGE RING. ***CONT WSR ON 7/24/09*** ..®.®_ . , _........~.~~ ....4 ~~ ,_~~.~ M 7/24/2009'"** Continued AWGRS from 07 23-09 *** Assist Slickline with WFR Test (Profile Modification) Pumped 4 bbls diesel down tbg, tbg pressured up to 2500 psi. SSL unable to get down hole due to cement in hole from previous coil job. Job cancelled. SSL on well at departure. FWHP's=150/220/140 7/24/2009 ***CONT WSR FROM 07/24/09*** (post pkr sqz) RAN 3-1/2" BRUSH, 2.7" GAUGE RING TO 6523' SLM (unable to pass). LRS PUMPED 4 BBLS DIESEL, TBG PRESSURED UP TO 2500#. RAN 2-1/2" BRUSH, 2.25" CENT, 1.75" GAUGE RING TO 6531' SLM (unable to pass). RAN 10' x 2.25" PUMP BAILER TO 6531' SLM (recovered approx 2 cups of gravel ksize cement). ***LEFT WELL S/I, TURNED WELL OVER TO PAD-OP*** 8/22/2009 8/27/2009***WELL S/I ON ARRIVAL"*" ':DRIFT W/ 2.70" CENT, 3 1/2" TEL, 2 1/2" S-BAILER. LOC TT @ 6830' SLM/6847' 3 BEGIN LOADING TUBING W/ 90 BBL DIESEL. FONT JOB ON 8-28-09'"** CTU#5 1 3/4" Job Scope :Mill cement, FCO « < InterAct Publishing »> RIH w/ 2.125" motor, 2.7" five blade cmt mill. Mill thru bridge from 6540' to 6556'. Chase cmt returns to surface. Dry tag btm @ 6953'. Perform injection test; 2 bpm @ 1000 psi, 5.3 bpm @ 1544 psi. Pump 5 bbls final sweep from 6947' and chase to surface.Pooh. RIH w/ 2.25" JSN and wash down mandrels 6-1 and pass thru tbg tail to 6850' .Pooh. FP well w/ 27 bbls of 50/50 meth. "*job complete*" 0= 100/20/160 Temp= SI Assist Slickline pump as directed- MIRU, PT face line, -----Job In Progress----- *"*WSR Continued to 08-28-09*"* ~~ ~.....~ ~.~~ _.__ ~~ m_ JVSR Continued from 08-27-09*'"' Temp SI Assist Slickline pump as directed- mped 3 bbls Neat Meth spear followed by 80 bbls 50* diesel down TBG while L RIH with brush. Pumped 31.4 bbls 50" diesel down TBG in attempt to MIT T ?500 psi, Failed 4 attempts TBG lost 840 psi in 1st 15min, -----Job In egress---- ""*WSR Continued to 08-29-09"*" ®~~ . ~_T~ _..... .~.... ~~~ _, ~.__.~ 8/28/2009 *'"`*CONT JOB FROM 8 27-09**** RUN 3 1/2" BRUSH, 2.73" GAUGE RING TO 6830' SLM/6847' MD. RUN 2.80" GAUGE RING CLEAR TIGHT SPOTS FROM 6523' SLM TO 6807' :SLM ERUN 2.805" BROACH CLEAR TIGHT SPOTS FROM 6523' SLM TO 680T SLM. SET 3 1/2" PXN PLUG @ 6807' SLM/6824' MD. MIT-T TO 2500# (FAIL) =PULLED 3-1/2" PXN PLUG BODY FROM 6807' SLM/6824' MD. SET 3 1/2" PX-PLUG @ 678T SLM/6804' MD. MIT-T TO 2500# (FAIL) RUN 2.70" CENT, 2 1/2" JDC TAG PRONG @ 6783' SLM. MIT-T TO 2500# ~ (FAIL) ****CONT JOB ON 8-29-09***" 8/29/20091***WSR Continued from 08-28-09*** Temp= SI Assist Slickline pump as directed- 1MIT T to 2500 psi PASSED, WFR Infectivity test, Pumped 3.1 bbls 50* diesel ;down TBG to reach test pressure,TBG lost 80 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 120 psi in 30 min test. WFR infectivity test. Could not 'pump slow enough to maintain 1000psi WHIP for Injection test. Swapped out w/ LRS unit #68. FWHP's= 500/0/180. SSL still on well at time of departure. Casing valves left open to gauges. ****CONT JOB FROM 8-29-09**** ATTEMPT TO SET 3 1/2" X EQUALIZING TEST TOOL @ 6737' SLM/6754' MD.(UNABLE TO HOLD PRESSURE) SET 3 1/2" XX-PLUG @ 6737' SLM. MIT-T TO 2000# (GOOD TEST) PULL RK-DGLV FROM STA #2 (6681' SLM/6694' MD). LRS PERFORM INJECTIVITY/BREAKDOWN TEST ON OPEN POCKET IN STA #2. SET RK-P-15 XJR IN STA #2 (6681' SLM/6694' MD). ****CONT JOB ON 8-31-09**** r»~ ~®~., .._.._ ._. 8/30/20093 (continued from 8/29/09) Assist Slickline (Gas-Lift for rate) SSL set a plug at 6754' . MIT-T to 2000 psi. was adequate to proceed .SSL pulled DV from station #2. Perform Injectivty/breakdown test station #2.(step 11) (continued on 8/31/09) 8/29/2009=****CONT JOB FROM 8-28-09**** =PULL 3 1/2" PX PLUG FROM 6804' MD. 'SET 3 1/2" XX-PLUG @ 6787' SLM/6804' MD. MIT-T TO 2500# (PASS). SET 3 1/2" WHIDDON CATCHER SUB @ 6783' SLM. PULL RK-DGLV FROM STA#1 (6762'SLM/6775' MD). LRS PERFORM INJECTIVITY/BREAKDOWN TEST. SET RK-P-15 XJR IN STA #1 (6762'SLM/6775' MD). LRS PERFORM INJECTIVITY TEST (GOOD TEST). PULL 3 1/2" CATCHER SUB FROM 6783' SLM. "***CONT JOB ON 8-30-09**** 8/29/2009 T/I/0= 450/0/160 Assist Slickline (Gas Lift For Rate) (continued on 8 30-09) • 8/31 /2009 8/31 /2009 9/1 /2009 ****CONT JOB FROM 8-30-09'""`* LRS PERFORM INJECTIVITY TEST ON STA #2 PER PROGRAM. (GOOD TEST) PULL 3 1/2" XX PLUG FROM 6737' SLM/6754' MD. SET 3 1/2" XX PLUG @ 6609' SLM/6626' MD. MIT-T TO 2000# (GOOD) PULL RK-DGLV FROM STA #4 (6563' SLM/6576' MD). LRS PERFORM INJECT/ BREAKDOWN TEST ON STA #4. SET RK-P-15 XJR IN STA #4 (6563' SLM/6576' MD. LRS PERFORM INJECTIVITY TEST ON STA #4 PER PROGRAM.( UNABLE TO GET RATE. VALVE PLUGGED) PULL RK-P-15 XJR FROM STA #4 (6563' SLM/6576' MD. LRS PERFORM INJECT/ BREAKDOWN TEST ON STA #4. RESET RK-P-15 XJR IN STA #4 (6563' SLM/6576' MD. ***"CONT JOB ON 9-1-09**** . _.~ ~ _ .. _ ____ _ w._ _.___ . ~ _ ._ _ __._~ (continued from 8/30/09) Assist slickline on WFR (Gas Lift for Rate) Perform step rate test on station #2. At 1000 psi. - 0.15 bpm / 1400 psi. - 0.14 bpm / 1800 psi. - 0.14 bpm. SSL set plug at 6626'. MIT T to 2000 psi. was adequate to proceed. SSL pulled DV from station #4. Injectivity/ Breakdown test station #4 -Pumped for 15 min. 340 psi. at a stabilzed rate of 0.5 bpm. SSL set GLV in station #4. Perform step rate test in station #4 valve plugged wireline pulls valve,do inj test on open pocket wireline resets WFR in sta 4 do step rate test on WFR sta 4 (step 20) (continued on 9-1-09) _ __~ _.._ ~ ~~_ w_._~ .. ~ _u~.._..._ _. (continued from 8/31/09) Assist slickiine on WFR infection tests (see pumping log) / Crew change. SSL set WFR in station #5. Perform station #5 step rate Injectivity test . At 1000 psi. rate = 0.07 BPM. At 1400 psi. rate = 0.11 BPM and at 1800 psi. rate = 0.13 BPM. SSL pulled plug from below station #5. Perform step rate Injectivity test on new WFR design. At 1000 psi. rate = 0.48 bpm. At 1400 psi, rate = 0.63 bpm. and at 1800 psi. rate = 0.64 bpm. Final WHP= 300/20/160. SSL rigging down on departure. ~~d_.~~~.~._._.~_. _~..._ _ 9/1/2009 ****CONT JOB FROM 8 31-09**** LRS PERFORM INJECTIVITY TEST ON STA #4 PER PROGRAM.(TEST GOOD) PULL 3 1/2" XX PLUG FROM 6609' SLM/6626' MD. SET 3 1/2" XX PLUG @ 6536' SLM/6549' MD. MIT-T TO 2000# (PASS) "PULL RK-DGLV FROM STA #5 (6520' SLM/6533' MD) LRS PERFORM INJECTION/ BREAKDOWN TEST. `SET RK-P-15 XJR IN STA #5 (6520' SLM/6533' MD). LRS PERFORM INJECTIVITY TEST ON STA #5 PER PROGRAM. ,PULL 3 1/2" XX PLUG FROM 6536' SLM. €LRS PERFORM FINAL INJECTIVITY TEST ON STA 1,2,4,5 PER PROGRAM. z***WELL S/I ON DEPARTURE***( DISCUSS VALVE POSITION W/ DSO) • 11/15/2009~T/I/O= 1500/1100/350. Temp= 135* (inj). Monitor WHPs (oper call in). SV= C. WV,SSV,MV= O. IA,OA= OTG. NOVP. 11/17/2009aT/I/O=1160/300/0. Temp=Hot. Assist FB w/state MIT-IA's **PASSED**. On inj. !Increased IAP from 300 psi to 2500 psi using 2 bbls of 60/40 meth. IAP lost 140 psi the 1st 15 mins & 20 psi the 2nd 15 mins for a total loss of 160 psi. Bleed IAP from 2340 psi to 700 psi. Monitored IAP for 30 mins, IAP increased from 700 psi Eto 790 psi. Final WHPs=1150/790/20. ESV=Closed. WV, SSV, MV=Open. IA & OA=OTG. NOVP. 11/17/2009~T/I/O=1220/500/50. Temp=129*. WHP's & IA FL for FB. (Pre AOGCC MIT-IA). IA FL @ Surface. SSV =CLOSED. WV, MV &SSV =OPEN. IA & OA = OTG. NOVP. 11/17/2009~T/I/O=1250/380/0 Temp=130* MIT-IA PASSED to 2500 PSI (Pre AOGCC) Pumped 2.4 bbls 60/40 down IA to reach test pressure. Loss of 120 psi 1st 15 gmin. Loss of 40 psi 2nd 15 min for a total loss of 160 psi for 30 min test. Bled down IAP to starting pressure. ~AOGCC MIT-IA PASSED to 2500 psi. (Witnessed by Jeff Jones) Pumped 2 bbls E60/40 down IA to reach test pressure. Loss of 140 psi 1st 15 min. Loss of 20 psi ;2nd 15 min for a total loss of 160 psi for 30 min test. Bled IAP to 700 psi per DHD FW HP=1150/700/0 ;Valve positions at the time of departure: Swab =Closed /Wing, SSV, Master, IA, OA =Open /Caution tag hung on IA valve (MIT Data, Watch for thermal expansion) 12/9/2009. T/I/0=1630/2010/740. Temp=Hot. Bleed IAP to <1000 psi (Eval high IAP). IA & OA FL's @ Surface. Bled IAP from 2010 psi to 930 psi in 2 hours 30 minutes. OAP decreased 150 psi to 590 psi during IA bleed. Bled OAP from 590 psi to 400 psi in 20 minutes. Monitor during rig down. IAP increased 10 psi to 940 psi in 45 minutes. OAP increased 20 psi to 420 psi in 25 minutes. Final WHP's = 1630/940/420. SV =CLOSED. WV, MV &SSV =OPEN. IA & OA = OTG. NOVP. • 12/9/2009~T/I/0= 1630/990/440. Temp= 120*. WHPs (eval high IAP). IAP increased 50 psi, SOAP increased 20 psi ASV=closed. WV,SSV,MV=open. NOVP. .. ~~~ _~ as _~~ .~_.~~ ~~~_ ~ ~R=._~ 12/10/2009 T/I/O = 1500/570/180. Temp=122. WHPs (Eval high IAP). Well on water injection. IA & OA are fluid packed. TP decreased 130 psi, IA decreased 370 psi, =OAP deceased 240 psi. SV=Closed. WV,SSV,MV=Open. IA,OA=OTG. NOVP. _~.~ .~,.~... ~ ~~.~ ~, p. _ _._~.~.._~~m~ 12/11/2009~T/I/O = 1500/620/220. Tem =120. WHPs (Eval high IAP). IAP increased 50 psi, SOAP increased 40 psi overrnght. ASV=Closed. WV,SSV,MV=Open. IA,OA=OTG. NOVP. '`"'^'`'^^9 T/I/O = 1570/540/0 AOGCC MIT IA PASSED to 2500 psi. (Witnessed by Bob Noble) Pumped 1.7 bbls of 60/40 methanol into the IA to reach test pressure. MIT IA lost 100 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 120 psi in the 30 min test. Bled IAP back down. Final WHP's = 1570/600/60 Valve positions at the time of departure: Swab =Closed /Wing, SSV, Master, IA, OA =Open /Tag hung on IA valve. FLUIDS PUMPED BBLS 1058 DIESEL 75 1.5# BIOZAN 159.6 60/40 METH 20 HEG GEL 2325 1 % KCLI 81 GEOVIS 3718.6 Total TREE= 4-1116"CMV WEL I_HEAD = ' 11" F ACTUATOR = BAK hb. r=LtV = 35.8' BF. ELEV = 6T KOP = 300' Max Angle = 54° @ 4370' Datum MD = 6559' 20" CONDUCTOR -~ Datum TV D = 5000' SS -~"`- TAMPORT COLLAR 996' 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 4340 7" CSG, 26#, L-80 TGII XO TO L-80 BTGM 5924' EST TOP OF CEMENT (07!10/09) 6224' Minimum ID = 2.750" @ 6824" 3-1/2" HES XN NIPPLE ~3-1/2" RA PIPTAG ~ 6499 7" MARKER JOINT w i RA TAG 6530' PERFORATION SUMMARY REF LOG: USIT ON 10!15/07 ANGLE AT TOP PERF: 31 ° @ 6513' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTF_RVAL Opn/Sqz DATE 4-1/2" 5 OA 6513 - 6547 O 10/14/07 4-1i2" 5 OBa 6568 - 6586 O 10/14/07 4-1/2" 5 OBb 6614 - 6636 O 10114/07 4-112" 5 OBc 6674 - 6693 O 10/14/07 4-1/2" 5 OBd 6734 - 6782 O 10/14/07 3-1(2" TBG, 9.2#, L-80 TCIi, .0087 bpf, ID = 2.992" PBTD 7" CSG, 26#, L-80 BTC, .0383 bpf, ID = 6.276" S-217 24' ~--~ 4-112" X 3-112" XO, ID = 2.992" 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS EV TYPE VLV LATCH 6423 -~ 3-1 /2" HES X NIP, ID = 2.813" WATER INJECTION MANDRELS DATE ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6479 4998 31 MMG-W DMY RK 0 10118(07 5 6533 5044 31 MMG-W P-15XJR RK 11 09/01/09 4 6576 5081 30 MMG-W P-15XJR RK 11 09!01!09 3 6632 5130 30 MMG-W DMY RK 0 10/18/07 2 6694 5183 30 MMG-W P-15XJR RK 11 09/01/09 1 6775 5253 30 MMG-W P-15XJR RK 14 09/01 /09 64~~7" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" 6467' PHOENIX SENSOR SUB, ID = 2.992" wi DUAL WIRE TO SURFACE IN IA 6549' 3-112" HES X NIP, ID =.2.813" 7" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" 7" X 3-1/2" SINGLE FEIDTHRU PKR, ID = 2.965" PHOENIX SENSOR SUB, ID - 2.992" w/DUAL WIRE TO SURFACE IN IA 3-112" HES X NIP, ID = 2.813" 6723 -j 7" X 3-1i2" SINGLE FEEDTHRU PKR, ID = 2.965" 6754' 3-1/2" HES X NIP, ID = 2.813" 3-1/2" XX PLUG (08129/09) 3-1/2" HES X NIP, ID = 2.813" 3-1(2" HES XN NIP, ID = 2.750" 6~ 847 I-j 3-1/2" WLEG, ID = 2.992" ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18/07 N9ES INITIAL COMPLETION 08/24/09 RDB/PJC FCO/ CMT PLUG (07110/09) 03/05/09 CJN/SV GLV GO (02/14109) 09!29!09 DMS/SV SET XX PLUG (08!29!09) 05/31!09 CJN/TLH QUIKDRILL PLUGS (05!29/09) 09/29/09 DMS/SV GLV GO (09(01/09} 05/31/09 BSElTLH GLV GO (513, 5113 & 5/30/09) 06!02/09 MLUTLH SAND PLUG SET 06!14/09 SWGTLH GLV GO (06/04/09) POLARIS UNff WELL: S-217 PERMIT No: 2070950 API No: 50-029-23362-00 SEC 35, T12N, R12E, 2123' FNL & 714' FWL BP Exploration (Alaska) MEMORANDUM To: Jim Regg ~~~ ~ i Z,~Z~(c~ P.I. Supervisor l FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, December 29, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-217 PRUDHOE BAY LIN POL 5-217 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UN POL S-217 API Well Number: s0-029-23362-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ091228080531 Permit Number: 207-095-0 Inspection Date: 11/17/2009 Rel Insp Num: M1TOP000o02898 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- ~r _ --- ~ --- ~ ~-----~ --- s-z~7 ~ _ We^ ~ TypelnJ. ~ ~' ~TVD ~ 4976 ~ IA -,-- soo zsoo ~; 2s6o 2sao ~~ ~ zo7o9so T eTest fisPT Test si ~ Isoo ~ OA o ~ 2ao ~ zzo~ zoo P.T.D`----~YP-----~---1-p ~---- - - -..-~--------~-------=- ~--~-- lnterval aYRTST p~ P '' Tubing 1160 ~ n6o~_ n6o llso i~ Notes: 2 bbls methanol pumped. Post packer cement squeeze. ~'~~~ JAt~i ~ ~ 20~~ Tuesday, December 29, 2009 Page 1 of 1 MEMORANDUM TO: Jim Regg I/Zmljo P.I. Supervisor ~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-217 PRUDHOE BAY UN POL S-217 Src; Inspector NON-CONFIDENTIAL Reviewed Bye., P.I. Suprv ~J.a~'' Comm Well Name: PRUDHOE BAY UN POL S-217 API Well Number: 50-029-23362-00-00 Inspector Name: Bob Noble Insp Num: mitRCN091223080112 Permit Number: 207-095-0 Inspection Date: 12/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __- - _ _t - - ---- , ------ Well ; --s-2» Type Inj. l ~' _TVD ~ __ '~ '~ sao --i 2a9o a 2s9o I, - z37o ~ ~I zo7o9so ~---- +- -- +- -- ---__ _ ~--- TypeTest ~ x977 IA P.T DI ~ SPT Test psi ~ za9o ~ OA I o ~ zso ~~ zao ~ 2ao ~ I - ._~ - -- --- ~ I~ --. - - -~- r----- - ~ Interv_al__oTHER - _-_ P/F - p________-!_ - Tubing--_IS7o ~-- Is7o --IS7o_-~ 1570 j _ - -----L ---- -~_- --- Notes: MIT-lA to demonstrate tubing integrity ~ ~~~ Wednesday, December 23, 2009 Page 1 of 1 IJNDER EVALUATION: 5-217~TD #2070950) MITIA Passed post pa~r squeeze - P... Page 1 of 1 Regg, James B (DOA) ~ ~ ~~~~ __ _~~.~~ ~ ~.. .~~ ~ ~ ~.~~~. M~~a~x.~ ~,~v.~~.~ m.~,~ _ ~.. From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~14, ~~~~ ~~ j Sent: Sunday, November 08, 2009 1:56 PM 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers; Schwartz, Guy L(DOA) Cc: Makarov, Egor; West, Taylor; Williams, Carrie; NSU, ADW Well Integrity Engineer; Winslow, Jack L. Subject: UNDER EVALUATION: S-217 (PTD #2070950) MITIA Passed post packer squeeze - POI for AOGCC compliance MITIA All, r Well S-217 (PTD #2070950) was repaired with a packer squeeze on 07/10/09. The well has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC MITIA may be conducted for UIC compliance. Please place S-217 on injection when convenient. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 " } ` Pager (907) 659-5100 Ext. 1154 Y"-+ /~ ~ ~ `~I~;' ;i ~' ~~~~ ~~.~K ~.~~~ ~,~ . . . - 11 /9/2009 NOT OPERABLE: 5-217 (PTD #2070950) AOGCC MITIA postponed until rig work is c... Page l~ ~ P~~~I ~,~,~. ~ { ~- ~ q~Z~dJ~~ ~~5~ ~~ 4~E;~~ Regg, James B (DOA) ~-~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, September 19, 2009 1:52 PM °~~'C%y' ~~~5"~~ ( To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor Subject: NOT OPERABLE: S-217 (PTD #2070950) AOGCC MITIA postponed until rig work is complete All, Well 5-217 (PTD #2070950) cannot safely be pressure tested due to the close nroximitv to the rig. The rig should be moving off S-Pad mid-October upon completion of S-218i. The well will be reclassified as Not Operable until rig work is complete. ~~ Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 =~~,~3""^~~~~~~ "e1~4 ,) ~ ~" ~~r;^ Cell (406) 570-9630 Pager (907) 659-5100 E~. 1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, September 02, 2009 8:03 PM To: 'Regg, ]ames B(DOA)'; 'Maunder, Thomas E(DOA)'; Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Welis Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer; Williams, Carrie Subject: UNDER EVALUATION: 5-217 (PTD #2070950) MITIA Passed post packer squeeze - ready for AOGCC compliance MITIA All, Well 5-217 (PTD #2070950) has been repaired with a packer squeeze. The well has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC MITIA may be conducted for UIC compliance. Please place S-217 on injection when convinent. Thank you, Anna ~Du6e, ~.~. ~alt Torin Roschinger) Well Integrity Coardinator Gf~B Wells Group Phone: (907) 659-5102 11/5/2009 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, 1..J ~~~=~~~~~[~~/~~~~-~ ~uL ~ ~ zoos w~~~~p.d ~i" ~p, f~,4 ~:c~r~ce ra~rr~issi~~ ~r?~~~~E~~~ ~a]~~9~ S ~-~ ~ ~' Enclosed please find a spreadsheet with a list of wells from S-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, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, , ~ ~;~~~~ ~u= ~; f~ Zti~'C' ~~'~, ~ . ~_ 4~ ., i~ Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operetio~s (10-404) &pad Date 6/25/2009 Well Name PTD R Initial top of cement Vol. of cement um ed final top of cement Cement top off date Corrosion inhibitor Corcosion inhibitod sealant date ft bbls ft na al 5-07 B 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 7325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA O.s 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26I2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 5-088 2010520 0 NA 0 NA o.e5 5/27/2009 5-09 1821040 1.5 NA 7.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-i 1 B 1990530 025 NA 0.25 NA 7.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1] 6/7I2009 5-13 1821350 8 NA 8 NA 55.3 6/1I2009 S-15 1840170 025 NA 0.25 NA 3 6/2I2009 S-77C 2020070 025 NA 025 NA 2.8 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2l2009 S-t9 18fi1160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.a 5/25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 0.25 NA t.7 5/25/2009 S-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/2~/2009 5-30 7900660 0.5 NA 0.5 NA S.t 5/31/2009 S-3tA 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.a 5/37/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S-36 1921160 0.75 NA OJS NA 425 5/27/2009 S-3~ 1920990 1.25 NA 125 NA 11.9 5/27/2009 S38 1921270 0.25 NA 025 NA 102 5/27/2009 S-a7 1960240 1.5 NA 1.5 NA 77.1 5/30l2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 0.25 NA 0.25 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 1.25 NA 125 NA 11.9 5/29/2009 S-10211 2031560 1.25 NA 125 NA 71.7 5/31/2009 5-703 2001680 1.5 NA i.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-106 2070120 16.25 NA 1625 NA t743 6/2/2009 S-107 2011130 2.25 NA 225 NA 28.9 5/18/2009 S-708 2011000 3.5 NA 3.5 NA ao SI30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-~70 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 Satt 2050510 2 NA 2 NA 19.6 5/30/2009 S-712 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 5-715 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 S-716 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 Sa79 2041620 1 NA 7 NA Sz 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-72s 2041370 7.5 NA 1.5 NA 20.4 5/262009 S-124 2061360 1.75 NA 1.75 NA 71.9 5/26/2009 5,725 2070830 2.25 NA 225 NA 20.a 5/28@009 S-726 20710970 125 NA 725 NA 15.3 6/1/2009 S-2oo 1972390 1.25 NA 125 NA ta.5 5/28/2009 S-2ot 2001840 0 NA 0 NA 0.85 6/19/2009 5-273A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 1B7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 57 5/29/2009 ~ 5-277 2070950 0.25 NA 025 NA t.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 5-407 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 NOT OPERABLE: 5-217 (PTD~070950) TxIA comm - Packer squeez~lanned Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~Q~~ ~l6lL ~l Sent: Monday, May 04, 2009 7:14 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers; GPB, Gas Lift Engr Cc: Makarov, Egor; West, Taylor; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: S-217 (PTD #2070950) TxIA comm - Packer squeeze planned All, ~ The attem~t to reset th~acker on weil S-217 (PTD #2070950) has been deemed unsuccessful. During the injectivity test througTthe WFR at 6533 ft, just below the top packer, the IA pressure tracked the tubing. A repeat MIT-IA to 2500 asi then failed with an estimated liquid leak rate of 0.06 bpm. The well has been reclassified as Not Operable and is to remain sh_ ut_in until a packer squeeze is completed. 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, April 20, 2009 3:50 PM .i ',~F1~Ri'~"„ r ; ii _ ~ ~~~~.'~ ..,r~;.~ .. ~, ~r~_ 4 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers; GPB, Gas Lift Engr Cc: Makarov, Egor; West, Taylor; Roschirtger, Torin T.; NSU, ADW Well Integrity Engineer; Dahlem, Jason E Subject: UNDER EVALUTION: S-217 (PTD #2070950) Return to Injection Post Packer Reset All, Well S-217 (PTD #2040950) has passed a MITIA to 2500 psi after pressuring up the tubing to reset the packer. The AOGCC has granted approval to return the weli to injection and to conduct an AOGCC witnessed MITIA for UIC compliance. The well has been reclassified as Under Evaluation. Once new water flood regulators have been set and a step rate test has been completed, this well may be placed on injection. Please let us know if there are any questions. Thank you, Anna ~Du6e, 2~. E. Weil Integrity Caordinatar GPB Wells Group Phone. (907) 659-5102 Pager: (907) 659-5100 x1154 8/6/2009 NOT OPERABLE: 5-217 (PTD~070950) TxIA comm - Packer squeez~lanned Page 2 of 3 From: NSU, ADW Well Integrity Engineer Sent: Saturday, January 10, 2009 11:03 AM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 QTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: S-217 (PTD #2070950) WAG Injector - Failed MIT-IA All, We~l S-217 (PTD #2070950) failed an AOGCC witnessed MIT-IA with a triplex on 01/05/09 on pressure stabilization. In addition, the IA required almost 10 bbis of fluid to pressure the void each time it was tested. This indicates a small fluid leak and likely TxIA communication. The well has been reclassified as Not Operable and has been secured with a downhole plug as evidenced by a passing MIT-T. 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, January 05, 2009 9:09 PM 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 5-217 (PTD #2070950) WAG Injector with IA repressurization All, Well S-217 (PTD #2070950) failed an AOGCC witnessed test on MITIA on 12/29/08. The MIT-IA was repeated with a triplex pump on 01/05/09 and also failed due to fill volumes required to reach test pressure. From this point the well will remain Under Evaluation and the 28-day clock wili continue to allow the following plan to occur: 1. Fullbore: AOGCC M(TIA - Failed 2. Slickline: Dummy GLV at station #7, set tubing tail plug 3. Fullbore: MITIA 4. Slickline: LDL (if failed step 3 MITIA) An updated TIO plot has been included. Please contact me with any questions or concerns. 8/6/2009 NOT OPERABLE: 5-217 (PTD~070950) TxIA comm - Packer squeez~lanned Page 3 of 3 Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, December 19, 2008 4:50 PM 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Makarov, Egor; GPB, Well Pad SW; GPB, Prod Controllers Cc: Holt, Ryan P(ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 5-217 (PTD #2070950) WAG Injector with IA repressurization All, Well S-217 (PTD #2070950) is exhibiting IA repressurization on water injection. The wellhead pressures were tubing/IA/OA equai to 1600/1450/150 on 12/17/08 when the IA pressure was bled to 600 psi. The IA repressurized to 140 psi overnight. The IA pressure had been bled in November but remained stable post bleed. The well has been reclassified as Under Evaluation and may remain on injection for further diagnostics. The well has been added to the AOGCC Monthly Injection Report. The plan forward is to: 1. Operations: Leave the well on water injection 2. Fullbore: AOGCC MITIA 3. Well Integrity Coordinator: Evaluate MITIA results and possibly apply for AA if the MITIA passes. A wellbore schematic, TIO plot, and injection plot have been included for reference. Please let me know if you have any questions. Thank you, Annac ~Du6e, 2'. E. Weli integrity Caordinator GPB Welis Group Phone: (907) 659-5102 pager: {807) 659-5100 x1154 8/6/2009 REQUEST FOR APPROVAL: 5-217 (PTD #2070950) Put on Injection repeat MITIA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunda , A ril 19, 2009 2:00 PM ~? Y P ~ zz~~' To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ ~~~ ~ ~ ~ Cc: Makarov, Egor; West, Taylor; Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: REQUEST FOR APPROVAL: S-217 (PTD #2070950) Put on Injection to repeat MITIA Attachments: MIT PBU S-217 04-01-09.x1s Hi Jim and Tom, ,~° Well S-217 (PTD #2070950) passed a-MITIA after pressuring upon the tubing and then the IA in an attempt to reset the packer. This is a request for your approval to return the well to water injection and conduct an AOGCC witnessed f~IITIA. The pressure test results from resetting the packer have been included for reference. «MIT PBU S-217 04-01-09.x1s» Thank you, Anna Dude, 2'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, January 10, 2009 11:03 AM -~ w vL'iu ~ 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: S-217 (PTD #2070950) WAG Injector -Failed Mrr-IA All, Well S-217 (PTD #2070950) failed an AOGCC witnessed MIT-IA with a triplex on 01/05/09 on pressure stabilization. In addition, the IA required almost 10 bbls of fluid to pressure the void each time it was tested. This indicates a small fluid leak and likely TxIA communication. The well has been reclassified as Not Operable and has been secured with a downhole plug as evidenced by a passing MIT-T. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 4/20/2009 CJ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. }` ~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / S-Pad DATE: 04/01 /09 OPERATOR REP: Anna Dube AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer De th Pretest Initial 15 Min. 30 Min. Well S-217 Type Inj. N TVD ~ 4,976' Tubing 4,200 4,500 4,500 4,500 Interval O P.T.D. 2070950 ~ Type test P Test psi ''1500 Casing '`2,500 2,420 " 2,380 P/F P f Notes: Hold pressure on tubing while pressure testing IA ,. OA 140 400 400 400 to reset packer. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In~. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well T pe Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-217 04-01-09.x1s ALA58A OIL AHD GA5 COlYSkRQATIOI~T COM~'II55IOH Matt Brown P.E. BP Exploration Alaska Inc. • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 Anchorage AK 99519-6612 ~-~L~~ ~ ~~A~ '~ ~~~~' Re: Prudhoe Bay Field, Polaris 011 Pool, S-217 Sundry Number: 309-091 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum. field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ day of March, 2009 Encl. ,_~ I 4~ 0 ~, r '~ ~ f, f ~ STATE OF ALASKA ro~ J~ ALASKA OIL AND GAS CONSERVATION COMMISSION~'~L- ~~f~ ~ ~ Z~1O~ APPLICATION FOR SUNDRY APPROVA '"~ ~~ ~ ~ ~~sk~ Oli! ~ ~a~ ~~n~- Ggmrnis~i~n 20 AAC 25.280 -J _-- -- ~ - 1. Type of Request: Abandon Suspend Operational shutdown Pertorate W i Othe Alter casing ^ Repair well ^~ ~ Plug Perforations^ Stimulate ^ Time Extension ^ PACKER REPAIR Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 207-0950 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23362-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 5-217 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028261 - 67 RT , PRUDHOE BAY Field !POLARIS Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7049 - 5489.57 - 6954 - 5407.97 ~ 6824' 2-12-08 NONE Casing Length Size MD TVD Burst Collapse Conductor 110 20" 215.5# A-53 Surface 108' Surface 108' Surface 4340 9-5/8" 40# L-80 28' 4340' 28' 3478' 5750 3090 Production 7038 7" 26# L-80 26' 7038' 26' 5480' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.2# L-80 SURFACE - 6847' Packers and SSSV Type: 7"X3-1/2" HES DUAL FEEDTHRU PKR Packers and SSSV MD (ft): 6454' 7"X3-1/2" HES DUAL FEEDTHRU PKR 6555' 7"X3-1/2" HES SINGLE FEEDTHRU PKR 6598' 7"X3-1/2" SINGLE FEEDTHRU PKR 6723' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ , 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/18/2009 OIL ^ GAS ^ PLUGGED ^ .ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0~ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is Vue and correct to the best of my knowledge. Contact Matt Brown Printed Name att Brown Title P.E. Signature Phone 564-5874 Date 3!4/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test "~ Location Clearance ^ Other: Subsequent Form R gyred: y~ d ~. ~~ ~~, ~ APPROVED BY ~ ~ ...COMMISSIONER THE COMMISSION Date: Approved by: ~ Form 10-403 Revised 06/~ i ~, (~ ~'~ ~1 ~ Submit in Duplicate S-217 207-095 Sw Name Operation Date Perf Operation Code PERF A ACHME Meas Depth Top NT Meas Depth Base Tvd Depth Top Tvd Depth Base S-217 10/14/07 PER 6,513. 6,547. 5,027.05 5,056.3 S-217 10/14/07 PER 6,568. 6,586. 5,074.4 5,089.92 S-217 10/14/07 PER 6,614. 6,636. 5,114.11 5,133.13 S-217 10/14/07 PER 6,674. 6,693. 5,166.03 5,182.49 S-217 10/14/07 PER 6,734. 6,782. 5,218. 5,259.58 S-217 2/12/08 BPS 6,824. 6,826. 5,295.92 5,297.65 S-217 1/9/09 BPS 6,412. 6,414. 4,940.71 4,942.41 S-217 2/8/09 BPP 6,412. 6,414. 4,940.71 4,942.41 S-217 2/8/09 BPS 6,549. 6,551. 5,058.02 5,059.74 S-217 2/12/09 BPP 6,549. 6,551. 5,058.02 5,059.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE S-217 Packer Repair • by To: Jerry Bixby /Clark Olsen, Well Operation Supervisors From: Egor Makarov -Pad Engineer Matt Brown -Wells Engineer Subject: S-217 Packer Repair BRSPDWL17-N Please perform the attached packer repair procedure: March 4, 2009 Est. Cost: $240M IOR: 400 BOPD 1. S Set plug in X nipple at 6549'. Re-energize packer; MITIA 2. S Pull plug at 6549'. Pull PXN Plug at 6824'; Tag PBTD. 3. SP Set composite plug at 6830 DD 4. FP MIT-T to check plug &MITIA to confirm leak rate 5. CP Lay in sand plug to 6420' 6. SP Tag Sand top. Pull dummy GLV at 6395'; circ tub & IA with McOH 7. CP Pump balanced plug thru GLM 6395'; mill cmt, sand & composite. Wash jewelry 8. FP MITIA to 2500 psi 9. S Drift tubing. Set PXN plug at 6824'. Pull DGLV/Run WFR at 6533, 6576, 6694, 6775 10. O POI Current Status: Shut In Non-Operable injector due to IA leak Last Injection: 03/03/08: 632 BWPD, 1311 WHIP Deviation: 50° max at 4370' DD, 31 ° at top packer (6453' DD) Minimum ID: 2.750" (XN nipple at 6824' DD) Last Downhole Operation: Dummy GLMs & MIT-T 2/14/09 Last SBHP & BHT: 2344 psi and 92 F at 6467' MD (4988'SS) at Phoenix pres sensor Latest H2S value: No history of H2S; none expected Latest tag: 6954' DD from original completion Note: Sundry approval from the State is required prior to performing this work. S-217 Packer Repair • Background S-2171 is a new Schrader Bluff injector completed with 4 packers to inject selectively into different straddled zones using waterflood regulators. Produced water injection in S-217i began in February 2008. The well has had IA pressurization since September 2008. On 1/05/2009 AOGCC MIT-IA test failed and the well is classified as not operable. Leak diagnostic work in January -February 2009 confirmed leak in top packer. S-217 injection is very important to support penta-lateral horizontal producer S-213A and leak remediation needs to be done soon. Note: Squeezing through packer during cement job is undesirable due to risk of cementing perforations in upper injection zone or damaging the pressure sensor below the packer. Objective The objective for this job is to remediate the leak in the top packer. The top packer at 6454, appears to have partially released. First, a plug will be set in the X nipple at 6549' and the tubing will be pressured up to 4200 psi to try to re-energize the packer element. An MIT-IA after the re-energizing attempt will then be performed to determine if the job was successful. If the MIT-IA passes, no further packer work is necessary and the well may be prepped for POI. If the re-energize job is unsuccessful, the packer leak will be shut off by setting cement plug. Cement will be pumped through GLM#7 at 6395' instead of tubing punch holes which could damage the i-wire and pressure gauges located on the outside of the tubing. Since GLM#7 (6395') will remain open after the cement job, it is necessary to have a cement column above it sufficient enough to hold 2500 psi continuous pressure differential when the well is on injection. GLM#7 is located 50' above leaking packer #4 (6454') and it is also important to have good quality cement between them to prevent injection into zone below packer #4 through GLM#7. Cement will be circulated into the IA thru GLM at 6395' MD to place a balanced plug with the cement to_p at 6332 in the tubing and IA. S-217i has permanent downhole pressure gauges in each straddled zone, real-time data from them can be used during the packer re-energizing job and the. cement job. AnnComm History: > 10/17/07: Rig MIT-T to 4000 psi > 10/17/07: Rig MIT-IA to 4000 psi > 02/10/08: Set TTP @ 6754', set DGLV in STA # 7, MIT-IA Passed to 3000 psi, MIT-T Passed to 2500 psi, set flow sleeve in STA # 2 2 S-217 Packer Repair ~, > 02/12/08: Set DGLV in STA # 2, pulled TTP @ 6754', set flow sleeve in STA # 1, pulled RHC plug @ 6784' SLM, set TTP @ 6804' > 02/26/08: Set WFRs in STA # 1, 2, 4 & 5 > 03/16/08: AOGCC MIT-IA Passed to 2000 psi > 10/30/08: Pulled WFRs from STA #1, 2, 4, 5 > 10/31/08: Set DGLVs in STA #1, #2, #4, #5, MITT Passed to 2500 psi, set WFR in STA #1 MITT Failed (step rate test) > 11/01/08: Set WFRs in STA #2 & #4 > 11/02/08: Set WFR in STA #5 > 11/25/08: IAP BUR ~ 200 psi day > 12/29/08: AOGCC MITIA Failed > 12/31/08: MITIA Passed to 1900 psi > 01 /01 /09: MITIA Passed to 2000 psi > 01/05/09: AOGCC MITIA Failed, LLR ~ 4.43 gpm > 01/09/09: TTP set; MIT-T Passed to 3000 psi, MIT-IA Failed to 2500 psi > 01/15/09: MIT-IA Failed, LLR 10.7 gpm @ 600 psi > 02/08/09: Pull TTP from 6423' Set TTP @ 6549' > 02/12/09: Dummied WFR, MIT-T Passed to 3000 psi against TTP set at 6549', MIT-IA Failed, pulled TTP at 6549', MIT-T failed against plug at 6824' Contacts: Matt Brown Egor Markarov 564-5874 w 564-5687 w 223-7073 c 229 0215 c 344-1130 h CC: Well File 3 S-217 Packer Repair Repair Target The 7" x 3-1/2" HES packer at 6454 DD is leaking at a LLR down IA across packer of 10 gpm at 600 psi MITIA on 1/16/09. • IA volume to packer at 6454 is 170 bbls • Tubing volume to plug at X nipple at 6549' is 57 bbls • Tubing volume to composite plug to be set at 6830' is 59 bbls (plug will be set in case of re-energize procedure unsuccessful). • Tubing volume to top of sand plug is 56 bbls (sand to be set in case packer re- energize procedure unsuccessful) NOTE: Have Dowell lab run tests for cement 2 days Unislurry with 0.2% D046, 0.2% D065, and 0.35% 2434) 2 days prior to rig up. They must be availabl Ensure CT hardline RU will allow accurate cement Repair (below). Slickline Re-energize Packer prior to RU. Cement blend is 15.8 D167. Speak with SWS lab (659- e to run lab sample during the job. pumping per steps in CT Packer 1. Shoot fluid levels on tubing, IA & OA prior to RU 2. RU SL & LRS. 3. RIH & Set plug in X nipple at 6549' DD. POOH. 4. Bleed IA pressure to 0. Pressure up tubing to 4200 psi, monitoring IA, OA and downhole Phoenix gages. IA should not pressure up, however, if it begins to pressure up, do not allow IA pres to exceed 4000 psi. 5. Hold 4200 psi on tbg. MIT-IA to 2500 psi. 6. Bleed tub to 2500 psi. With 2500 psi on tubing, MIT-IA to 2500 psi. 7. Bleed tubing & IA. RIH & pull plug at 6549'. 8. If MITIA passes, RDMO. Notes: a. Tubing, IA & OA should be liquid packed from previous operations b. Mandrels are currently dummied off IF MITIA fails after Re-energize packer procedure, continue with the following steps: 9. RIH & pull PXN Plug at 6824'. 10. Drift thru tubing tail at 6847' with gauge ring and centralizer and tag PBTD. 11. RIH with TTL & locate in TT at 6847'. Mark line for tie-in. POOH. 12. Make up 3-1/2" Baker Quick-drill composite plug (OD = 2.400") & running tool. 13. RIH w/composite plug and running tools. 4 S-217 Packer Repair • 14. Set 3-1/2" Baker Quick-drill plus top at 6830' DD. • This is in the middle of the 3-1/2" pup joint below the XN nipple at 6824' DD. • Please note the distance from the plug top to mid-element in the AWGRS report. The top of the plug will be tagged by coiled tubing to tie-in. 15. MIT-T to 1000 psi confirm plug is holding • Tub vol to plug=59 bbls CTU Set Sand Plug 1. Ensure well is liquid packed. RU CT and RIH with cementing nozzle 2. Tag composite plug at 6830'. PUH 5' & flag pipe. 3. Mix sand slurry as follows using sacks of sand (not bulk sand): • 2150 Ibs of 20/40 river sand into 6.6 bbls gel (8 ppg in 30# HEC gel). • Tubing interval to fill: 6420' to 6830' • Sand top window: 6420' - 6430' (Target = 6420') • Sand volume in 3-1/2": 2.3 bbls (2150# /bulk density = 600.6 Ibs/bbl) • Total slurry volume: 2.3 bbls sand + 6.4 bbls HEC = 8.7 bbls slurry • Please note the actual volume of sand used in the WSR summary. • Grab sample of sand slurry to ensure that HEC breaks and sand settles appropriately. Notes: Sand top of 6420' will allow SL room to pull dummy from GLM at 6395'. 4. RIH to flag and lay in sand plug 1:1 taking returns at surface. Maintain 100 psi over WHP before pumping sand. PUH to safety and allow sand to settle. 5. After sand has settled out for 1 hour, RIH and tag sand top. Re-tag sand after additional 30 minutes and verify sand has finished settling out. 6. If sand is below acceptable window of 6420' to 6430' then calculate sand volume necessary to bring sand top into window and repeat sand dump. If sand top is too high, reverse out extra sand. 7. FP well, RD CTU. Leave SL bonnet on tree for next SL steps. Slickline Prep Work 1. Tag Sand top. Pull DGLV at GLM#7 at 6395'. Report corrected SL tag reference to tubing tally based on GLM #7 at 6395'. 2. Circulate the well with inhibited 60/40 McOH by pumping down the tubing & taking returns up the IA. Ensure no gas in either tub or IA. 5 S-217 Packer Repair • • Tub vol to plug=56 bbls • IA vol to top GLM (6395DD)=169 bbls • With tub & IA loaded with McOH, SITP and SI IA pres should be 400 psi. 3. RDMO SL CTU Packer Repair Notes: All GLVs but the top GLM (6395'DD) are dummied off. Have cement contaminate on hand for contingency. It is important that the IA is liquid packed during the cement repair. Shortly before the CT rig-up, shoot fluid levels on Tbg & IA to plan liquid volumes to order for job. Do not proceed with cement repair unless the tubing and IA are liquid packed and gas free RU CTU and Dowell pumping service. Accurate placement of a small volume of cement is required. a. NOTE: Rig up squeeze trailer to allow returns from both the IA and the CTxTbg annulus. b. RU to get accurate cement vol with dart & dart catcher sub. Drop dart & get CT volume. 2. RIH with cementing ball-drop nozzle (no checks). Tag top of Sand plug. Pick-up until full string weight is observed. Correct depth to SL tag depth. PUH 10'. Flag CT. 3. Batch mix 4.0 pumpable bbls 15.8 ppq UnislurrV cement which will give 500 psi compressive strength in 5-7 hours and 2000 psi ultimate compressive strength. BHT at packer depth of 6454' DD is 92°F. • Catch a sample of the cement for QC testing. (This needs to go to the lab to determine when the blend reaches 500 psi compressive strength. Lab must be notified prior to the job 659-2423.) Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. 4. RIH to flag. Line out cementers to the CT. Pump the following down the coil: • 5 bbl spacer water • 4_0 bbl Unislurry cement • 5 bbl vol of Spacer water • McOH for FP CT With the backside SI, take returns up the IA to the 40 bbl tank while pumping. To get accurate vols into CT, pump as follows: Pump 5 bbl spacer into the coil, close the reel valve, flush surface lines to good quality cement, open the reel valve, pump 4 bbl cmt into coil, close reel valve, flush surface lines to clean water, open reel valve pump and 5 bbl flush water with 6 S-217 Packer Repair • with cementers then switch to pumping McOH down CT with CT pump. Cement will all be in coil at pump swap. Maintain +/-150 psi on tbg x CT annulus. Chase flush water with McOH until cmt at nozzle. With nozzle at flag, lay in 0.5 bbls cmt. Circulate 3.2 bbls through the GLM at 6395' and up the IA using the returns in the 40 bbl tank to gauge volume while reciprocating between flag plug and just below GLM. SAFETY: 4.0 bbls of cement would leave a TOC at 5964' if no cement is placed in the annulus (assuming sand plug top at 6420'). 5. Swap to taking rtns up backside (Tbg x CT annulus). Lay in last bit of cmt in tubing (<1 bbl) while POOH. Estimated top of cmt in tubing is 6332' with 3.2 bbls in IA and 0.8 bbls in tubing. POOH while replacing voidage. NOTE: With sand plug at 6420', the final cement top in the tubing should be 6332. 6. MU motor and 2.60"-2.70" mill & jars and RIH. Wait until lab sample has reached 500 psi compressive strength (about 4 to 6 hours). 7. Mill through ~88' of cement to sand plug top, pumping slugs of Flo-Pro as necessary to adequately lift solids. Clean out +/- 400' of sand to composite plug. When motor work indicates Quick-drill has been reached, PUH a few feet, and pump large Flo-Pro sweep followed by at least one backside volume (39 bbls) of KCI to sweep cmt fines to surface. • It is important to pump one backside volume and sweep fines to surface. If the MHA becomes stuck and cannot circulate while milling the Quick-drill, any debris left in the backside would settle around MHA. 8. Mill through Baker Quick-drill. Push plug thru TT but do not go more than 10' out of TT with mill to avoid getting hung up on fish. Mill is OD 2.700" and composite OD is 2.992" (total of 5.692") while ID of 7" is 6.276". Thus, it is possible to get beside composite in the 7". POOH. 9. MU jetting nozzle. FCO to TT pumping sweeps. Chase any remaining sand OOH, thoroughly washing each mandrel and jewelry. 10. POOH, freeze protect the top 2500'. RDM. Note: Redline WBS showing composite plug fish. 7 S-217 Packer Repair • Fullbore Post Repair 1. After 3 days WOC, MITIA to 2500 psi, establish leak rate if fails. 2. RU SL. Drift tubing & tag PBTD. Be aware of composite plug fish. 3. Set PXN plug at XN nipple 6824'. PT plug. 4. Pull DGLVs in GLMs 1 (6775'), 2 (6694'), 4 (6576'), 5 (6533') 5. Run WFR's in GLMs 1, 2, 4, 5. RD SL per Pad engineer design. 6. POI 8 ' ~ S-217 Packer Repair TREE= 4-1116" CM/ WELLHEAD= 11"F ACTUATOR= BA KB. REV = 35.8' BF. ELEV = 6T KOP= 300' Max An le = 50° 4370' Datum MD = 6559' Datum TV D = 5000' SS S -217 sA~rrnlorES: 24' 4-112" X 3-112° XO. ~ = 2.992" CONDUCTOR I1Z' F1tJ JC rVIY, IU = Z.i GAS LIFT MANDRELS 9-5/8" CSG. 40#, L-80 BTC, ID = 8.835" 7" CSG, 26#, L-80 TGII XO TO L-80 BTGM Minimum ID = 2.750" @ 6824" 3.112" HES XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6479 4998 31 MMG-W DMY RK 0 10!18107 5 6533 5044 31 MMG-W R15 RK 14 11(02(08 4 6576 5081 30 MMG-W R15 RK 13 11!02/08 3 6632 5130 30 MMG-W DMY RK 0 10/18/07 2 6694 5183 30 MMG-W R15 RK 15 11/02(08 1 6775 5253 30 MMG-W R15 RKP 18 11!02(08 PERFORATION SUMMARY REF LOG: USIT ON 10115!07 ANGLE AT TOP PERF: 31° @ 6513' Note: Refer to Production DB for historical pars data SIZE SPF ZONE INTERVAL OpNSgz DATE 4-117' S OA 6513 -6547 O 10!14!07 4-117' 5 OBa 6568 -6586 O 10/14/07 4-11T' S OBb 6614 -6636 O 10/14!07 4-1/2" 5 OBc 6674 -6693 O 10/14/07 4-1/2" 5 OBd 6734 -6782 O 10/14!07 7"X3-1 /2" HES DUA L FffDTHRU PKR ID = 2.965" PHOEND(SENSOR SUB, ID = 2.992" w/DUAL WIRE TO SURFACE IN IA 3-1/2" HES X NIP, ID = 2.813" 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 7" X 3-1/2" SINGLE FEEDTHRU PKR b PHOENIX SENSOR SUB, ID = 2.992" w! DUAL WIRE TO SURFACE IN IA ) 7" X 3-112" SINGLE FE~THRU PKR ID = 2.965° ) 13-1/2" HES X NIP. ID = 2.813" 6804' ~-{ 3-112" HES X NIP, ID = 2.813" ~ 6824' 3-1t2" HES XN NIP, ~ = 2.750" 6824' 3-1(2" PXN PLUG {02/12!08} 684 ' 3-112" WLEG, ID = 2.992" ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18/07 N9FS INITIAL COMPLETION 01114109 BSE/SV SETXX PLUG (01!09/09) 10!30/07 TW/PJC PERF CORRECTIONS 02!16109 CJN/SV PULL XX PLUG 02/08/09 12/07!07 TV+/1PJC DRLG DRAFT CORRECTIONS 02/22/08 KSB/TLH GLV GO (02/12(08) 03/11/08 DTR/TLH PSI PLUG SET (02112108) 11/10/08 KJB/SV GLV GO 11!2/08 POLARIS UNIT WELL: 5-217 PERMIT No:2070950 API No: 50-029-23362 SEC 35, T12N, R12E, 2123' FNL & 714' FWL BP Ekploratlori (Alaska) 9 S-217 Packer Repair . 10 • S-217 Packer Repair • RIG Nabors /ES Data t/f11lMI7 WELL# 5-217t tuuaG ]a° L-ar tl7 TBG WT. 92 23.7/ Q1t0I4 Tfi 22S JTS ON RACK 187 JT6 7.S°L-p Tql 7254.21 FT OM RACK FT3.5"L~90. TCI EMD - inckxles SIZE TYPE,ODNNECTNIM REM qt OD LENGTH TOP BOTTOM 3S"92#YYLEG35"TC-N 2992 3.900 131 6845.55 684686 35° 92# L~ TGI Pu 2992 3900 980 6835.75 684555 35" 92# LA0 TC-II Pu 29,92 3.908 98Z 6825.93 6835]5 3.5"HES7fN'N Ie:ID2]50 2]511 3.960 t.44 6824.49 682593 35" 92#, LAO TC-II Pu 2992 3.900 980 681489 6824A9 35" 92# LAO TC-1 Pu 2.992 3900 9.79 6804.90 681489 3S"HES 7C Ni le: 2813" ID RHC-M PI 2813 3.~0 1.26 6803.64 680490 35' 92# LAO TC-II Pu 2992 3.9~ 9.79 6793.85 680384 3.5"92# L-80 TC-IPu 2992 39tN1 981 678484 679385 GLM #1 -35" x 15' MMG-YVw' RD Du - RK latch 292D 5.968 9,25 6774.79 678484 3S"92#L-80TC-tPu 2992 3.900 981 6764.E 677d79 35"92# L-80 TC-IPu 2992 3.900 9.81 6755.17 676498 35" HES 7C N p1e:2813" I) 2$13 3.960 127 6753.90 6755.17 3.5" 92# L-80 TGI Pu 299'1 3.~ 9.78 6744.72 675390 3.5°92#L-80TC-IPu 2992 3.~ 7.~ 67.32 6744.12 3.5"92# L-8D TC-1 Pu 2992 3900 9.80 6726.52 673632 3S° x7° HESsin lefeedthru Packer Plnrred-60K #1 aclcar 2965 6.100 3.66 6722.E 672652 3.5" 92# L-80 TC-1 Pu 2992 3.9~ 9.80 6713.06 672286 35°92# L-80 TC-IPu 2992 3.9~ 9.79 670327 671386 GLM #2 - 35" x 15' MMG-W wr' RD Du - RK latch 2920 5.968 9.64 6693.63 670327 3S"92#L-80TGIPu 2992 3.~ 9.79 668384 6693b3 1..It.3S"92# LAO TC-II 1 2992 3.900 3235. 6651.49 668384 3S"92#L-80TC-IPu 2992 3900 981 6641.68 6fi51A9 GLM #3 - 3S" x 15" MMG-1RtvW RD Du - RK latch 292(1 5968 925 6632.43 6641 3.5"92# L-80 TGI Pu 2992 3900 4.79 6627.64 6632A3 35' HES'X' N 1e:2813° D 2813 3.960 127 6626.37 662784 3.5"92# L-8D TC-1 Pu 2992 3.~ 389 662328 662637 1 ea.35' 92# LAO TGII Pu 2992 3.900 1480 6608.48 662328 3.5"9.2# L-80 TC-IPu 2.992 3900 1.50 660698 6608A8 PhoanixSerrsorsub 2992 5.062 35 660623 660698 3S' 92# L-ROTC-IP 2992 3.9W 4,78 6601A5 660623 35"xT"NESSin lefeed[hruPacker Pinned-60 #2 adc~ 2~5 6.100 3.f~ 6597.79 6601A5 3 S', 92#, LAO TGI Pu 2.992 3.90D 1.77 659682 6597]9 1 ea.3S"92# L-80TGI P 2992 3.900 5.79 6523 659682 35' 92# LAO TGII Pu 2992 3900 4.79 6585A4 659023 GLM #d - 35" x 15° MMG-INw/ RD Du - RK latch 2920 5968 924 6576.20 6585Ad 3.5'92# L-BDTC-I Pu 2992 3.900 7.79 6568.41 6576211 3.5"92#L-80TC-IPu 2~2 3.~0 980 6558.61 65~d1 3.5" x 7" HES Dual feedthru Padax Pinned89K # 3 ulcer 2965 6.100 3.66 6554.95 6581 35' 92# LAO TGII Pu 2992 390D 4.78 655fl.17 655496 3S' HES 7C Ni 1e:2813°ID 2813 3.960 127 6548.90 6550.17 35" 92# LAO TGI Pu 2992 3900 285 654685 654890 35' 92#, LAO TGII Pu 2.992 3.900 4.79 6542.06 654685 GLM #5 - 35" x 15' MMG-W ur' RD Du - RK latch 2920 5.9p 925 653281 654286 3.5'92#L-80 TGIPu 2992 3.900 9.79 65Y3A2 653281 2 ea.35"92# LAO TC-II Pu 1982 ;483'J1A RAT 6,523' 2992 3.90D 24A5 649857 652382 3.5'92# LAO TC-1 Pu 2992 3.9DD 9.79 6488.78 649857 GLMp6 - 3S" x 15' MMG-W n/ RD Du - RK latch 2920 5968 983 6479.15 6488]8 35"92#LJIOTC-1Pu 2992 3908 9,78 6469.37 6479.15 3.5°92gL-BDTC-IPu 2992 3900 1,50 6467.87 646937 Phoenix Sensor sub 2992 5.062 .75 6467.12 646787 35' 92# L-8II TC-II P 2992 3.9~ 9.78 6457.34 6467.12 35'x7"HES DualfeedlhruPadrer finned-75K #4 ~ 2965 6.100 386 645388 645734 35" 92#, LAO TGII Pu 2.992 3.900 9.79 644389 645368 lea 35' 92# LAO TCJI Pu Jt 981 2992 3.9~ 9.81 6434.08 644389 35" 92# LAO TGI Pu 2992 3.900 9.79 642429 643488 35"HES'%'Ni Ie:2813"ID 2813 3.960 128 642381 642429 3S° 92# LAO TCJI Pu 2992 3.900 9.79 641322 642381 35'92#L-80TC-IPu 2992 3.900 9.79 6403A3 641322 GLMJF7 - 3S' x 15" MMG vA DCR-1 Shear- RKP latch Z92O 5968 885 639458 6403.43 3.5"92#L-80 TG/Pu 2992 3.908 9.78 638480 639458 1~ 3.5'92# L-~ TC-I Tubbs -109 2992 3.9~ 3482.39 290241 638480 35", 92# LAO TCJI Pu 2992 3900 9.79 2892.62 2902A7 35° HES 7C Ni I~ 2813"ID 2813 3.960 1.28 2891.34 289282 35" 92# LAO TCJI Pu 2992 3900 9.79 288155 289134 87 35° 92# LAD TCJI Tubi # 110-196 2992 3.900 2804.46 77.09 2155 2 ea3S° 9.2# LAO TG-I S aca out Pu 81' .79 2992 390D 1560 61.49 7789 1 35"92#LAOTC-ITubbi 197 2992 3.900 3238 29.11 61A9 3.5" 92# LAO TCJ Hap r P 2992 3.900 3.90 2521 29.11 45"X35°TGICrossorer 2992 4.500 1.11 24.10 2521 u an ~ r ors - 11 - ~ S-217 Packer Repair • Cement Volume 3-1 2 x 7 Annulus u mg 6.276 ID of 7" 26# 3.5 OD of 3.5" 9.2# 0.0264 bbl/ft 0.0087 bbl/ft 71 ft of cement above bottom of GLM 88 ft of cmt in tubing (top plug to TOC) 1.9 bbls in annulus above GLM 0.76 bbls in tubing 50.25 ft of cement between GLM & packer top 0.00228 CT bbl/ft 1.3 bbls of cement between GLM & packer top 3.2 total bbls of cement in annulus 0.76 bbls in tubing 4A total bbts of cement to pump Cement top 6332 MD Ft cmt above packer 121 ft bot GLM 6403.43 MD top cmt in IA before U-tube 5965 MD Top sand plug 6420 DD MD 4514 SS Top packer 6453.68 MD cmt to mill in tub 88 169 56 170 12 • S-217 Packer Repair • After U-Tube Cement n~c me TOC in Tu IA Rug 642 U-Tube Cmt into IA Top/Bot of Jewelry Driller's Depth 6394.58 6403.43 19.58' 6423.01 6424.29 . 50.25' 29.39' RIOf sen: Gl 6453.68 ' 6457.34 6467.1 9' 78 6467.87 13 to Packer top S-217 Packer Repair MD (ft) ND (ft) SS (ft) Inclination Azimuth Dog Leg GeoX GeoY -6 10 10 3 0.4 158.1 0. -0. 20 199.9 132.9 0.6 167.7 0. 0. -1. 30 299.9 232.9 1.8 188.8 1. 0. -3. 40 399.8 332.8 3.6 196.81 1. -0. -8. 50 499.5 432.5 5.3 213.4 2. -4.1 -15. 60 599.0 532.0 6.2 211.3 -9. -23. 70 698.2 631.2 7.8 212.1 1. -15. -34. 80 797.0 730.0 9.71 210. 1. -23. -47. 90 895.2 828.2 1 208. 2. -32. -64. 1,00 992.6 925.6 14.4 207.2 2. -02. -84. 1,10 1,089.0 1,022.0 16.3 206.6 1. -54. -108. 1,141 1,128.0 1,061.0 17.3 205.7 2. -59. -119. 1,23 1,219.6 1,152.6 18.1 204.0 -71. -14 1,33 1,309.4 1,242.4 20.4 204.2 2. -83. -174. 1,42 1,397.8 1,330.8 22.71 203.3 2. -97. -207. 1,52 1,486.4 1,419.4 23.9 203.1 1. -111. -242. 1,62 1,573.5 1,506.5 25.6 201. 1. -126. -279. 1,71 1,657.8 1,590.8 29.3 202.2 3. -142. -320. 1,81 1,739.1 1,672.1 33.9 202.4 4. -160. -367. 1,90 1,815. 1,748.4 38.11 203.1 4. -181. -418. 2,00 1,891.0 1,824.0 38.4 202.6 0. -203. -474.1 2,09 1,964.1 1,897.1 40.51 203.1 2. -226. -53 2,191 2,036.1 1,969.1 41.81 203.5 1. -250. -588. 2,28 2,106.4 2,039.4 45.41 203.5 3. -276. -649. 2,38 2,172.4 2,105.4 46.7 203.8 1. -302. -713. 2,47 2,238.2 2,171.2 45. 203.3 1. -329. -776. 2,57 2,303.7 2,236.7 48.2 202.6 2. -355. -841. 2,66 2,366.9 2,299. 47.8 203.2 0. -38 -906. 2,76 2,431.2 2,364.2 47.8 202. 0, -408. -972. 2,86 2,495.6 2,428.6 47.9 202.0 0. -434. -1,038.7 2,95 2,559.2 2,492.2 47.8 202.4 0. -460. -1,104.3 3,05 2,624.5 2,557.5 47.31 202.2 0. -486. -1,170.8 3,14 2,687.5 2,620.5 46.9 202.2 0. -511. -1,234.0 3,2 2,753.5 2,686.5 48.8 203. 2. -538. -1,301.8 3,33 2,816.5 2,749.5 48.3 203.4 0. -56 -1,367.7 3,43 2,880.4 2,813.4 48.1 202.9 0. -593. -1,434.0 3,53 2,944.1 2,877.1 48.1 202. -62 -1,499. 3,62 3,007.7 2,940.7 48. 203. 0. -646. -1,565. 3,72 3,071.4 3,004.4 48.3 203.2 0. -67 -1,632.0 3,81 3,134.3 3,067.3 48.3 202.7 0. -700. -1,697.6 3,91 3,198.0 3,131.0 49.2 204.2 1. -728. -1,764.7 4,00 3,260.5 3,193.5 49.1 204.3 0. -757. -1,831.1 4,10 3,322.4 3,255.4 49.1 204.4 0. -785. -1,896.8 4,20 3,385.8 3,318. 48. 203.8 0. -814. -1,963.6 4,29 3,448.7 3,381.7 48.8 203.4 0. -842. -2,029. 4,37 3,497.2 3,430.2 49.6 203.7 1. -864.1 -2,081.7 4,46 3,559.6 3,492. 49.5 204.4 0. -89 -2,149.2 14 S-217 Packer Repair 4,56 3,621.4 3,554.4 48.4 204.8 1. -921. -2,214.3 4,65 3,685.1 3,618.1 48.2 204.5 0. -950. -2,279.9 4,75 3,749.6 3,682.6 47.2 204.6 1. -979.1 -2,344.9 4,84 3,815.5 3,748.5 45.9 205.6 1. -1,007.8 -2,408.4 4,94 3,881.6 3,814.6 45.4 20 0. -1,036.3 -2,469.8 5,03 3,950.2 3,883.2 44.2 205.2 1. -1,064.9 -2,531.8 5,13 4,017.1 3,950.1 45.6 204.2 1. -1,091.9 -2,593.0 5,23 4,082.6 4,015.6 48.5 202.2 3. -1,118.7 -2,658.2 5,32 4,144.31 4,077.31 49.5 197.7 3. -1,141.9 -2,725.3 5,42 4,206.9 4,139.9 49. 195.5 1. -1,161.7 -2,795.6 5,51 4,269.8 4,202. 48.3 193.6 1. -1,178.7 -2,865.3 5,611 4,333.01 4,266.0 48.4 194.3 0. -1,194.8 -2,934.5 5,70 4,397. 4,330.9 47.1 194. 1. -1,211.8 -3,004.0 5,80 4,464.31 4,397.3 44. 195.6 2. -1,228.8 -3,070.6 5,89 4,532.1 4,465.1 44.1 197. 1. -1,247.0 -3,134.7 5,99 4,601.5 4,534.5 42. 197. 1. -1,265.8 -3,197.8 6,09 4,674.4 4,607.4 38.0 195.91 -1,282.6 -3,257.6 6,18 4,750.5 4,683.5 34.8 190.5 4. -1,294.7 -3,312.5 6,28 4,830.1 4,763.1 33.4 189.4 1. -1,303.3 -3,365.8 6,37 4,911.0 4,844.0 32.5 188. -1,310.8 -3,417.8 6,47 4,992.0 4,925.0 31.0 185. 2. -1,316.0 -3,467.7 6,56 5,074.3 5,007.3 30.4 184.1 0. -1,319.2 -3,516.5 6,66 5,157.1 5,090.1 29.9 183.1 0. -1,321.5 -3,564.6 6,75 5,239.81 5,172.8 29.9 182.1 0. -1,322. -3,612.3 6,85 5,322.8 5,255.8 30.2 17 2. -1,322.3 -3,660.4 6,95 5,405.4 5,338.4 30. 177.4 0. -1,319.6 -3,709.0 7,04 5,489.5 5,422.5 30. 177.4 -1,316.6 -3,759.1 15 MIT Forms: O1-ll (PTD #1770570 , 2-222-14 (PTD #1890340), Y-OSB (PTD #2081380) and 5... Page 1 of 2 • Regg, James B (DOA) ' ~' ~ _ ~~~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, January 21, 2009 9:42 AM To: Regg, James B (DOA) ~~~~ th~l~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: MIT Forms: S-217 (PTD #2070950) f Attachments: MIT PBU S-217 01-05-09.x1s Hi Jim, I just caught want you meant about referencing 17-08. I've clear out this erroneous reference and send you a fresh copy ~- of the MIT form. I hope this helps. Thank you, Anna ~u6e, ~'. E. Wel( Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, January 17, 2009 5:53 PM To: 'Regg, James B (DOA)' Cc: NSU, ADW Well Integrity Engineer Subject: RE: MIT Forms: S-217 (PTD #2070950) Hi Jim, i understand the confusion as l had to research this to understand the farm. I've corrected the attached farm with the following information. The pre-test passed to 2000 psi although it took 8 bbls to reach test pressure. The IA pressure was then bled back to 1000 psi. A second test was attempted so that it could be witnessed by the AOGCC Slope Inspector. Although another 9 bbls were pumped, the IA never reached test pressure of 2100 psi and therefore the test failed, A leak rate of 4.43 gpm at 2040 psi was obtained. Please let me know if you have any additional questions. Thank you, Anna ~Du6e, ~'. E Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907} 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, January 15, 2009 10:23 AM To: NSU, ADW Well Integrity Engineer Subject: RE: MIT Forms: 01-11 (PTD #1770570), 2-22/L-14 (PTD #1890340), Y-05B (PTD #2081380) and 5-217 (PTD #2070950) 1 /22/2009 MIT Forms: 01-11 (PTD #1770570), 2-22/L-14 (PTD #1890340), Y-OSB (PTD #2081380) and S... Page 2 of 2 • • Please check MIT for 5-217; what you provided includes a service rpt for 17-08 (references a failed MITIA}; also, the recorded test pressures do not indicate a failure as shown on report. I just a little confused. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, January 07, 2009 9:04 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: MIT Forms: 01-1i (PTD #1770570), 2-22/L-14 (PTD #1890340), Y-05B (PTD #2081380) and S-217 (PTD #2070950) Jim, Tom and Bob, Please see the attached MIT forms for the following wells: 01-11 (PTD #1770570) MIT-IA for variance compliance. 2-22/L-14 (PTD #1890340) MIT-IA pre-MI swap. S-217 (PTD #2070950) Failed MIT-IA to evaluate for TxIA communication. Plan to secure well. Y-05B (PTD #2081380) MIT-IA post-initial injection, post-CTD. «MIT PBU 01-11 12-20-08.x1s» «MIT PBU Y-05B 12-18-08.x1s» «MIT PBU S-217 01-05-09.x1s» «MIT END2-22 12-20-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /22/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~ ~~~' FIELD /UNIT /PAD: Prudhoe Bay /PBU / S Pad I ~ Z DATE: 01 /05/09 OPERATOR REP: Taylor Wellman AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well S-217 Type Inj. W TVD 4,976' Tubing 1,625 1,625 1,625 1,625 Interval O P.T.D. 2070950 Type test P Test psi 1500 Casing 1,000 2,000 1,880 1,860 P/F P Notes: Pre-test MIT-IA to 2000 psi to eval TxIA comm OA 0 220 220 220 8 bbls to reach test pressure Well S-217 Type Inj. W TVD 4,976' Tubing 1,625 Interval O P.T.D. 2070950 Type test P Test psi 1500 Casing 1,000 P/F F Notes: Re-test for AOGCC witnessed MIT-IA to 2100 psi OA 220 Another 9 bbls pumped and did not reach test pressure. Leak rate of 4.43 GPM at 2040 psi. Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas 1 =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test .i' INTERVAL Codes 1 =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-217 01-05-09.xls NOT OPERABLE: 5-217 (PTD #2070950) WAG Injector -Failed MIT-IA Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, January 10, 2009 11:03 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: S-217 (PTD #2070950) WAG Injector -Failed MIT-IA A11, Well S-217 (PTD #2070950} failed an AOGCC witnessed MIT-IA with a triplex on 01105J09 on pressure stabilization. In addition, the IA required almost 10 obis of fluid to pressure the void each time it was tested. This indicates a small fluid leak and like[v TxIA communication. The well has been reclassified as Not Operable and has been secured with a dawnhoie plug as evidenced by a passing MIT-T. 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, January 05, 2009 9:09 PM t ~c.•. 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Townsend, 5. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-217 (PTD #2070950) WAG Injector with IA repressurization All, Well 5-217 (PTD #2070950} failed an AOGCC witnessed test an MITIA on 12/29J08. The MIT-lA was repeated with a triplex pump an 01105109 and also failed due to fill volumes required to reach test pressure. From this point the well will remain Under Evaluation and the 28-day clock will continue to allow the following plan to occur: 1. Fullbore: AOGCC MITIA -Failed 2. Slickline: Dummy GLV at station #7, set tubing tail plug 3. Fullbare: MITER 4. Slickline: LDL (if failed step 3 MITIA) 1 /22!2009 NOT OPERABLE: 5-217 (PTD #2070950) WAG Injector -Failed MIT-IA Page 2 of 2 An updated TIO plot has been included. Please contact me With any questions or concerns. Thank you, Taylor Wellman filiing in for Anna DubelAndrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, December 19, 2008 4:50 PM 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Makarov, Egor; GPB, Well Pad SW; GPB, Prod Controllers Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 5-217 (PTD #2070950) WAG Injector with IA repressurization All, Well S-217 (PTD #2070950) is exhibiting IA repressurization on water injection. The wellhead pressures were tubing/IA/OA equal to 1600/1450/150 on 12/17/08 when the IA pressure was bled to 600 psi. The IA repressurized to 140 psi overnight. The IA pressure had been bled in November but remained stable post bleed. The well has been reclassified as Under Evaluation and may remain on injection for further diagnostics. The well has been added to the AOGCC Monthly Injection Report. The plan forward is to: 1. Operations: Leave the well on water injection 2. Fullbore: AOGCC MITIA 3. Well Integrity Coordinator: Evaluate MITIA results and possibly apply for AA if the MITIA passes. A wellbore schematic, TIO plot, and injection plot have been included for reference. Please let me know if you have any questions. Thank you, Anna l~u6e, ~'. E. Welt Integrity Coordinator GPB Welts Group F'hane: {907} 659-5142 Pager: {907} 659-5100 x1154 1 /22/2009 MEMORANDUM To: Jim Regg P.I. Supervisor ~~(~ I(lZ'~,:j FROivt: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 07, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-217 PRUDHOE BAY UN POL S-217 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J,~~--- Comm Well Name: PRUDHOE BAY UN POL S-217 API Well Number: 50-029-23362-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090107065524 Permit Number: zo7-o95-0 ~ Inspection Date• vsi2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~~ s-'17 ;Type Inj. ~ w ~ TVD ~ a97~A looo --2oao ~ 1900 ! ~ - I -- - -- - i _10 X10 P.T ~ zo7o9so~TypeTest ~ SPT ;Test psi uoo ~, pA ~ z1o - OTHER = F---~-- Tlll»n '--- ]625 -- 1625 --- 1625- --- ------ -Inter_y_al --- ---- P/F------ ---/--- -- g- -_ -------- ----- - - ~I --- '- NOteS: Test performed to evaluate possible tubing leak. At 2040 psi the IA would take fluid at max rate that could be pumped by triplex. With pump shut down pressure bled to 1900 psi and appeared to hold. Wednesday, ,lanuary 07, 2009 Page 1 of 1 • MEMORANDUM TO: Jim Regg `~~~ ~ ~(~zl~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January O5, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-2l 7 PRUDHOE BAY UN POL 5-217 Src: Inspector NON-CONFIDENTIAL Reviewed B~y.:-p~ P.I. Suprv J~ Comm Well Name: PRUDHOE BAY UN POL S-217 API Well Number: 50-029-23362-00-00 Insp Num: mitJJ081230095747 permit Number: 207-095-o Rel Insp Num: Inspector Name: Jeff Jones Inspection Date• 12~29~2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-2n ~Type~Inj,~~ `~'~ ' TVD x976 IA~ 7so ! zzzo ~~ zt3o I zozo ~ I9~o ~ l 2070950 i SPT i p ~~i QA i 140 ~ 320 P.T. ~~ ,TypeTest -Test ps>< ~ i 300 ~ 2s0 ' 240 i Interval oTi->ER p~F F ~ Tubing's ~s7s ', ~6zs ' _ i6oo I, ts7s ~s7s NOtCS' Well S-217 has a known casing leak and failed the diagnostic MIT. 2.5 BBLS methanol pumped, one well inspected; no exceptions noted. Monday, January O5, 2009 Page I of 1 UNDER EVALUATION: 5-217 (~ #2070950) WAG Injector with IA repressurization Page I of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIllntegrityEngineer@BP.com] Sent: Monday, January 05, 2009 9:09 PM ~~~~ tl ~~~~ 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad SW; GPB, Prod Controllers Cc: Makarov, Egor; West, Taylor; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: S-217 (PTD #2070950) WAG Injector with IA repressurization Attachments: S-217 TIO 01-05-09.ZIP All, Well 5-217 (PTD #2070950} failed an AOGCC witnessed test on MITIA on 12/29/08. The MIT-IA was repeated with a triplex pump on 01/05(09 and also failed due to fill volumes required to rP~ test rp ensure. From this point the well will remain Under Evaluation and the 28-day clock will continue to allow the following plan to occur: 1. Fullbore: AOGCC MITIA -Failed 2. Slickline: Dummy GLV at station #7, set tubing tail plug 3. Fullbore: MlTIA 4. Slickline: LDL (if failed step 3 MITIA) An updated TIO plot has been included. Please contact me with any questions or concerns. «S-217 TIO 01-05-09.ZIP» Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 `=,~~4:~~~` ~~~ ~ ,:~. ~~~ Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, December 19, 2008 4:50 PM 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 MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Welt Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Makarov, Egor; GPB, Well Pad SW; GPB, Prod Controllers Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 5-217 (PTD #2070950) WAG Injector with IA repressurization AI I, Well S-217 (PTD #2070950) is exhibiting IA repressurization on water infection. The wellhead pressures were tubing/IA/OA equal to 1600/1450/150 on 12/17/08 when the IA pressure was bled to 600 psi. The IA repressurized to 140 psi overnight. The IA pressure had been bled in November but remained stable post bleed. The well has been reclassified as Under Evaluation and may remain on injection for further diagnostics. The well has been added to the AOGCC Monthly Injection Report. The plan forward is to: 1 /7/2009 UNDER EVALUATION: 5-217 (~ #2070950) WAG Injector with IA repressurization Page 2 of 2 • 1. Operations: Leave the well on water injection 2. Fullbore: AOGCC MITIA 3. Well Integrity Coordinator: Evaluate MITIA results and possibly apply for AA if the MITIA passes. A wellbore schematic, TIO plot, and injection plot have been included for reference. ~~ Please let me know if you have any questions. Thank you, Anna Dude, ~? E. Well Integrity Coordinator GPB Wells Groin Phone: (907} 659-5102 Pager: {907) 659-5100 x1154 1 /7!2009 • • PBU 5-217 PTD 207-095 1 /5/2009 TIO Pressures 12 Month Plot 1 Month Plot +- -~ Ina ~ '' s + rey ~ a uA as OOOA On -1~ ~a o~ . oo~ ~ o~ is't6"B r:'ifin8 t: r:~rrpr 1.: ~:,qk 1[/.'!i!et 1t/.RrOx r~ 11~+fE NA11.49 v.~fl+5 • ~ `~ O O O T T ___ ___ - oa a a a ~,t cr; T O 0 ~} {~ T O O {y r O O r r r O r ~ i O O O r a a ~ rn v ~ rn 0 0 0 0 N r a_ 1 ooa'~ ~~ O O ~~ w~ W •~ ~ ~ ~ I Ar~g ~Itl-II P, psi g ooo'~ aoo'z ooo' 4 0 Q 0 ~ ~ r a a T oos' 4 aaz' ~ 0 d1~k81'Q ~~ W Q Q TREE= 4-1/16" CM/ WELLHEAD = 11" F ACTUATOR = BAK KB. ELEV = 35.8' BF. ELEV = 67' KOP = 300' 'Max Angle = 50° @ 4370' Datum MD = 6559' 120" CONDUCTOR i- Datum TVD = 5000' SS TAM PORT COLLAR - 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" - 7" CSG, 26#, L-80 TGII XO TO L-80 BTGM Minimum ID = 2.750" @ 6824" 3-1/2" HES XN NIPPLE 3-1 /2" RA PIP TA G i~ s499. 7" MARKER JOINT w / RA TAG 6530' 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" PHOENDC SENSOR SUB, ID = 2.992" w/DUAL WIRE TO SURFACE IN IA 3-1/2" HES X NIP, ID = 2.813" 6555' i~7" X 3-1/2" HES DUAL PERFORATION SUMMARY REF LOG: USfT ON 10/15/07 ANGLE AT TOP PERF: 31 ° @ 6513' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OA 6513 - 6547 O 10/14/07 4-1/2" 5 OBa 6568 - 6586 O 10/14/07 4-1/2" 5 OBb 6614 - 6636 O 10/14/07 4-1/2" 5 OBc 6674 - 6693 O 10/14/07 4-1/2" 5 OBd 6734 - 6782 C 10/14/07 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" C 7" CSG, 26#, L-80 BTC, .0383 bpf, ID = 6.276" S -217 SA~ NOTES: 24' 4-1/2" X 3-1/2" XO, ID = 2.992" 2891' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6395 4926 32 MMG DMY RK 0 02!12/08 6423' 3-1/2" HES X NIP, ID = 2.813" 1 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6479 4998 31 MMG-W DMY RK 0 10/18/07 5 6533 5044 31 MMG-W P-15 RK 14 11 /02/08 4 6576 5081 30 MMG-W P-15 RK 13 11/02/08 3 6632 5130 30 MMG-W DMY RK 0 10/18/07 2 6694 5183 30 MMG-W P-15 RK 15 11/02/08 1 6775 5253 30 MMG-W P-15 RKP 18 11 /02/08 i FEEDTHRU PKR, ID = 2.965" i 6598' 7" X 3-1 /2" SINGLE FEEDTHRU PKR, ID = 2.965" 6606' PHOENDC SENSOR SUB, ID = 2.992" w /DUAL WIRE TO SURFACE IN IA 6626' 3-1/2" HES X NIP, ID = 2.813" bj -7Z3~ ~-~ 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 6754' 3-1/2" HES X NIP, ID = 2.813" 6804' 3-1/2" HES X NIP, ID = 2.813"1 6824' 3-1/2" HES XN NIP, ID = 2.750" 6824' 3-1/2" PXN PLUG (02/12/08) 6847' 3-1/2" WLEG, ID = 2.992" C~ ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18!07 N9ES INITIAL COMPLETION 10/30!07 TW/PJC PERF CORRECTIONS 12/07/07 TW/PJC DRLG DRAFT CORRECTIONS 02/22/08 KSB/TLH GLV C/O (02/12/08) 03/11/08 DTR/TLH PXN PLUG SET (02/12/08) 11/10/08 KJB/SV GLV GO (11/2/08) POLARIS UN(f WELL: S-217 PERMIT No: 2070950 API No: 50-029-23362-00 SEC 35, T12N, R12E, 2123' FNL & 714' FWL BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070950 Well Name/No. PRUDHOE BAY UN POL S-217 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23362-00-00 MD 7049 TVD 5490 Completion Date Completion Status 1 WINJ Current Status 1 WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Surv Ye DATA INFORMATI ON Types Electric or Other Logs Run: MWD. GYRO, GR / RES, AZI-DENS / NEU / PWD, MDT, GR / JB, US (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D C Exc Directional Survey 100 1100 Open 10/12/2007 pt Directional Survey 100 1100 Open 10/12/2007 ' ~D D Asc Directional Survey 0 7049 Open 10/15/2007 Rpt~ ,Cse. Il Directional Surrey 0 7049 Open 10/15/2007 , ~l'og Sonic 5 Col 1 6200 6802 Case 11/9/2007 USIT, GPIT, PPCX2, DSLT, GR, CCL 15-Oct- 2007 ~og See Notes 5 Col 1 6200 6802 Case 11/9/2007 Mod Dynamic Tester, GR, ~ TLC 12-Oct-2007 // ED C Lis 15701~/5onic 116 6765 Open 11/19/2007 LIS Veri, USIT, CCL w/ PDS and TIF graphics ED C Lis 15702" Induction/Resistivity 97 7055 Open 11/19/2007 LIS Veri, GR, ROP, FET, RPM, RAM, DRHO, NPHI w/PDS and TIF graphics ~g 15702 Induction/Resistivity 25 Blu 100 6992 Open 11!19/2007 MD Vision Service 9-Oct- I 2007 ' og 15702 Induction/Resistivity 25 Blu 100 6992 Open 11/19/2007 TVD Vision Service 9-Oct- 2007 ED C Las _ ` 15930 ~ressure 0 6800 Case 2/12/2008 LAS, GR, CCL, Pres, Temp, in PDF and TIF I graphics ( 1,6g Temperature 25 Biu 1 0 6796 Case 2/12/2008 Temp, MPL, Pres, GR, rr ' g ~ Temperature 25 Blu 2 0 6730 Case 2/20/2008 CCL, Temp 10-Feb-2008 Temp, MPU, Pres, GR, 1 } I ~ CCL, FCAP 18-Feb-2008 !, ED C Las 15937r/femperature 0 6734 Case 2/20/2008 LAS Temp, Pres, CCL, GR wPDF and Tif graphics ~ DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070950 Well Name/No. PRUDHOE BAY UN POL S-217 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23362-00-00 MD 7049 TVD 5490 Completion Date Completion Status 1WINJ Current Status 1WINJ UIC Y Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? 1`tiQ''- Analysis ~-/-hf~ Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? N Formation Tops Y N Date: MEMORANDUM TO: JimRegg ~rC ~~a'~J~>~ P.I. Supervisor ~ t FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Apri102, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S-217 PRUDHOE BAY UN POL 5-217 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv ~! Comm Well Name: PRUDHOE BAY UN POL S-217 Insp Num: mitCS080318091027 Rel Insp Num: API Well Number: 50-029-23362-00-00 Permit Number: 207-095-0 ~ Inspector Name: Chuck scheve Inspection Date: 3~16i2oo8 Packer Well ~ s-z I7 !Type Inj. ~ w ~ TVD Depth a976 ` ~ IA , Pretest Initial ~ s6o ~ zooo 'I 15 Min. 30 Min. 45 Min. 60 Min. 197o I 1970 ~ P.T. ~ zo7o9so TypeTest !, SPT I Test psi ~ - lsoo pA ~ zzo 3so j Sao ~ 3ao i _ Interval VITAL P~F P _ Tubing , 1310 j~ 1310 I 1310 1310 ~~ i i Notes' Pretest pressures observed and found stable. Wednesday, April 02, 2008 Page l of 1 • ~~~ +L ~~. ProActive Diagnostic Services, Znc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 - (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnica{ Diata Center Attn: Joe Lastufka LR2-1 900 E. Benson Bbd Anchorage, Alaska 99508 and c>>~ ~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907] 245-8952 1) Temperature Survey 18-Feb-08 5-217 1 BL / EDE Disk 50-029-23362-00 2) ~~ ~ ~ ~ ~~~ t ~~ ~ t.' Signed : ~~ ~ ,+ r°~--'"~ Date Print Name: t ,~' ~ ! ~~ ALP , ,~~~ ~~,',~ ~,uP,..~ . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907)245-8851 FAX: (907)245-88952 E-IYIAIL : pdsanchoraaeCcr)memorvlog.com WEBSITE : www.memorVlog.com C:\Documenls and Settings\Ownet\Desktop\Trar~smit_BP.doc ~~~~ L. T~Aflf~n/1/7~AL ~~~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907} 245-8952 1) Temperature Survey 10-Feb-08 S-217 2) ~ I Signed : r Print Name: 1 BL / EDE Disk 50-029-23362-00 ~' ~ '~ ~. ~~ h t ti ~~ I~ Date a ,an;. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanchora a rnernoryloa.com WEBSITE : Nrrrw.rraerraoryloa.com D:\Niaster_Copy_W_PDSANC-20~c~Z_WordlDistabution\Tiansmittal_Sheets\Tru~smit_OUginal_New.doc Fage 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, December 06, 2007 11:18 AM To: 'Hubble, Terrie L' Cc: Tirpack, Robert B; Saltmarsh, Arthur C (DOA); West, Taylor Subject: RE: S-217 (207-095) Thanks Terrie. Yes, that is the only change. Polaris is the only western satellite pool that is restricted to WAG on approval. Call or message with any questions. Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Thursday, December 06, 2007 11:12 AM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B; Saltrriarsh, Arthur C (DOA); West, Taylor Subject: FW: S-217 (207-095) Hi Tom, As you can see I'm running a bit behind this week. Here is the confirmation of actual perfs. As for the WAG vs. WINJ... my mistake... I had been told previously that all 200 series injector wells would be WAG wells. I guess I've learned something new. Are we good on this one? The only change will be making it a WtNJ. Thanks! Terrie From: West, Taylor Sent: Monday, December 03, 2007 1:22 PM To: Hubble, Terrie L Subject: FW: 5-217 (207-095) Terrie: attached is a confirmation of the actual pert depths referenced to the USIT log if that helps you. Also, the Polaris AIO only allows a few wells to be WAG, all others must be by special request, so the wells we drilled this year: W-210., w-213, S-217, W-214 should be WIND until we get permission for WAG. (note we have an upcoming W-216i this spring) Can you tell me what the other wells were listed as on the 407? (WAG or WINJ) Thx Taylor From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] i i2i6i2oo~ ~e~~ ~ • ~ Page 2 of 2 Serrt: Monday, December 03, 2007 i 1:48 AM To: Hubble, Terrie (_; Tirpack, Robert B; West, Taylor Cc: Arthur C Saltmarsh Subject: RE: S-217 (207-095) Terrie, One other item, WAG is checked on the 407. According to AIO 25A, Rule 2, WAG is only by separate approval. This is due to concerns with the cementing in offset older wells. I will be changing WAG to WINJ. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, December 03, 2007 11:39 AM To: 'Hubble, Terrie L'; 'Robert Tirpack' Cc: `Arthur C Saltmarsh' Subject: 5-217 (207-095) Terrie and Robert, i am reviewing the 407 for this recently completed infection well. The perforation depths listed on the 407 differ (s{ightly) from those given in the operations summary (10!15). On the summary for 10/16, it is stated that the perts were confirmed on depth as reported. Could you reconcile the perforation depths? Thanks in advance. Tom Maunder, PE AOGCC 12/6/2007 11/15/07 Sc~lumherger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WeN Job>I Log Description NO. 4501 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 Field: Polaris, Borealis Date BL Color CD 5-217 11594528 CH EDIT PDC GR USIT t 10/15107 i S-217 V-117P82 40015624 40009107 OH MWDILWD EDIT OH MWDILWD EDIT 70/09107 06/21/03 2 4 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ~ t` , BP ExploraGOn (Alaska) Inc I~v» ~ ~ -- ~ Petrolechnical Data Center LR2 1 S - - ~ ( l~ ,~~ ~n ,~ -/` 900 E Benson Blvd. -. - l Anchorage AK 99508-4254 gpq ~` /~ 59 Date Delivered: N ~~ ~ ~ `•" ~ ~~~~ i"7 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503838 ATTN: Beth , Received by: 11/05/07 s Sc~iub~rger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job!! Log Description NO. 4478 Company: Alaska Oil 8: Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Aurora Borealis Date BL Color CD S-217 11594528 MDT 10112107 1 S-217 11594528 USIT - ~ 10/15107 1 5-125PB1 REVISED 40015467 OH MWDILWD EDIT ~ ~ 07107107 1 Z-102 40015187 OH MWDILWD EDIT 05112/07 2 1 Z-102P81 40015187 OH MWDILWD EDIT ~ 05107/07 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Ezploralion (Alaska)Inc. Petrotechnical Daia Center LR2-1 ----^ •~ ~ r '~' 900 E Benson Blvd. ,. " " ' Anchorage AK 99508-4254 Date Delivered: ° "a~ ~ r1 ~~ /1 ~ i t -' ~ ,I t.! tJ i Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by. S-217 Perfs ref to USIT • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Dawson, Bob S (PRA) [Bob.Dawson1@bp.com] Sent: Monday, October 29, 2007 2:40 PM To: G ANC PDC; West, Taylor; Cooney, Kurt J (SIS) Subject: S-217 Perfs ref to UStT The perforations in Well 5-217 have been identified on the USIT tog. The USIT log is the primary depth control log for Well S-217. The perforation depths are listed below. Well 5-217 interval Zone Top Pert (MD) Bottom Perf (MD) Thickness (MD) Date shot 1 OA 6513 6547 34 10/15/2007 2 OBa 6568 6586 18 10/15/2007 3 OBb 6614 6636 22 10/15/2007 4 OBc 6674 6693 19 10/15/2007 5 OBd 6734 6782 48 10/15/2007 Total: 107 Perts identified on USIT tog, run 10/15/2007. UStT log is primary depth control fog. Bob Dawson GPB WEST Operations Geologist 907-564-5264 (office) 907-345-3359 (home) 907-242-2391 (cell) 12/6/2007 2~CHANICAL INTEGRITY Rr.?ORT _:-UD u____: t~~1.;0`1 OPER ~ FIELD ~~ ~\,~~ `C~~~:a~~j - ~0 (~~- ~`"1 ;,ALL NUMBER C'j"" c~ ...G rE~S~..:.. .n ~ LL D~ T ~ TD , °1.~~~ I~_. ~`.a ~U TvD ; =ETD . ~~g`~ ?~n ~TVD s i °~ i~as i^ g : '1 Shoe : ~~~ MD ,~w`6y~ ~D ~ LV : ~ ~. ~ ~ ~ -`T~r-'?i ".~e_ . _ ~~ Shoe. '~ '~`JT ; Tir . ?-~ 'iD .uo',S ~I ~ Pzc'xC.er 1~~~\ '~D T'J7i ; Set eL ~~5~~ ole Sipe ~~ l~ and ~ PeTfs fob\~~ to ~~~- ~'~~ ~\+~~~~.i~~5 ~'~%c=..ci?~ =C~.~ Ii~TTEGR?'TY - agRT # 1 Ynnu~us Press Test: ~? ?5 IIin ; ~0 min Cor~ents '_~*'CH~NICr~, INTEGR?'T~ - PART_ # 2 t---~C S alb `~ fe,S !ah~~ i Cement Volumes : Amt. Liner ~~. CsQ'~~ SAC DV '1y ~ ~~ C.~t Jol to cover oer_s ~~ ~.~~\ ~S~:ssl~~C~~ ~`; C_C;v;aC ~~~'~~(~ -'- e~~et~aZ TOC ~`~ ~ (a~t ,, ~ ~ Cement Bond Log (Yes or No) ~~ ~ In AOGCC FiZe_ CEL Evaluation, gone above perfs ~ ~ v~~- ' ~~,,~ V~ -_~~ QCs. \ v\~ ~ ~C:~~S ~ PrOQUCt1on LOg: "?'yve ; EValuation CON~LJSIOt1S ?art r l . .. ar v T L : STATE OF ALASKA ~~ '? ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~IV~~ Nov z s zoo? WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil ~ Gas Goes. G~o 1a. Well u ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended i'~r.3 zoAACZS.,os zoAACZS.,,o ^ GINJ WINJ ^ WDSPL. Other No. of Completions One 1b. Weil CIa~90t8 ^ Development ~ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 10/18/2007 12. Permit to Drill Number 207-095 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/1/2007 13. API Number 50-029-23362-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/9/2007 14. Well Name and Number: S-2171 " 3157 FSL, 4566 FEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 311' FNL, 662' FEL, SEC. 03, T11 N, R12E, UM 8. KB (ft above MSL): 67 " Ground (ft MSL): 38.5 15. Field !Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 582' FNL, 666' FEL, SEC. 03, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 6954 5408 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 618885 y- 5979359 Zone- ASP4 10. Total Depth (MD+TVD) 7049 ~ 5490 ~ 16. Property Designation: ADL 028261 " _ TPI: x- 617568 y- 5975871 Zone- ASP4 Total Depth: x- 617569 y- 5975600 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit el ctronic and rinted informs i n er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, Gyro, GR / RES, AZI-DENS / NEU / PWD, MDT, GR / JB, USIT-CBL 22. CASING, LINER AND CEMENTING RECORD CASING SETTWG DEPTH MD" SETrING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM ' =TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A- 3 Surface 10 ' Surface 10 ' 42" 2 0 sx Ar tic S t A rox. 9-5/8" 40# L-80 28' 4340' 28' 3478' 12-1 /4" 761 sx DeepCRETE, 338 sx'G', 79 sx DuraSTONE To Job 270 sx Dee CRETE 7" 26# L-8 26' 70 8' 2 ' 5480' 8-3/4" 315 sx CI ss 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): .SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter 5 SPF 3-1/2", 9.2#, L-80 6847' 6454', 6550', , MD TVD D TVD M 6598' & 6723' ~.~ ~" 6513' - 6547 5027 - 5056' ~Vts~4 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6568' - 6586' 5074' - 5090' ~C'itS`C DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 6614' - 66 5114 - 5133' ~'~^~~ 6674' - 6693' 5166' - 5182' 2500' Freeze Protected with 88 Bbls of Diesel ~,. ~ ~ 6734'--6782' 5218' - 5260' Y'"`~~ ~,~ ~ ~ ~~3 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N!A Date Of Test: HOUI'S Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 2 071. ~ ~p~T10fi None '~~~ l;~ ~' €) 2DD7 ~~( - 3 -; Form 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested? ^ Yes ^ No Permafrost Top 28.5' 28 5' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Ugnu 4462' 3557' UG-MA 6136' 4711' MDT was ran. Attached is a summary of MDT results. UG_M61 6193' 4758' UG_MB2 6264' 4816' UG_MC 6305' 4851' SB_NA 6369' 4904' SB_N B 6390' 4922' SB_NC 6423' 4950' SB_NE 6434' 4959' SB NF 6474' 4994' SB OA 6512' 5026' SB_OBA 6566' 5073' SB_OBB 6609' 5110' SB_OBC 6669' 5162' SB_OBD 6728' 5213' SB_OBE 6798' 5273' SB_OBF 6852' 5320' Top of Colville Mudstone 6902' 5363' Formation at Total Depth (Name): Top of Colville Mudstone 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, MDT Data Summary and aLeak-Off Test Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed So dra Stewm ,~ _Title Drilling Technologist Date ~ I - ~. 5 ~ G.yV~ 7 S-2171 207-095 Prepared ey Name/lvumaer. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Brandon Peltier, 564-5912 INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digit's (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.07E IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = 4-118" WELLHEAD= FMC ACTUATOR = Lea KB.~ELEV = V ~~38.s' DRLG DRAFT BF. ELEV = 67 KOP= ~~ Max Angle = 18' ~ 4t)86' 20" CONDUCTOR ? Datum MD = 5254' Datum TV D = 5000' SS 9 5/8" Tam Port CoGar 916' 9-5/8" CSC, 40#, L-80, ~ = 8.835" 434Q' 7" BTGM, x TGp 267f, L-80, Crossover ~. 5924 Minimum ID = 2.750" 3-112" HES XN NIPPLE Phoenix Sensor Sub, ~ = 2.992" ~~ 646T to 3-112° TBG WIRA Tag ~ 6523' 7" 20' Marker jt w /RA Tag 6530' PERFORATION SUMMARY REF LOG: USIT ON 10/15/07 ANGLE AT TOP PERF: 31° @ 6513' Note: Refer to Production DB for historical pert data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-112" 5 OA 6513 - 6547 O 10/14!07 4-1/2" 5 OBa 6568 - 6586 O 10/14!07 4-112" 5 OBb 6614 - 6636 O 10/14/07 4-112" 5 OBc 6674 - 6693 O 10/14!07 4-1/2" 5 OBd 6734 - 6782 O 10/14/07 3-1 /2" TCII TBG, 9.2#, L-80, ~ = 2.992" ~ $847' PBTD 6954' 7" CSC, 261, L-80, ~ = 6.276" 7038' _~ ~ ~ ~ SAFETY NOTES: GLM'S ~ STA #1 -#6 ARE 3-1/2" X 1-112" MMGW WWC'H ARE WATERFLOOD MANDRELS. 2891... _ 3-112" HES X NE°i, ~ = 2.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6395 4926 32 MMG FS RKP 0 10/18/07 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6479 4997 31 MMG-W DMY RK 0 10118/07 5 6533 5044 31 MMG-W DMY RK 0 10!18/07 4 6576 5081 30 MMG-W DMY RK 0 10/18/07 3 6632 5130 30 MMG-W DMY RK 0 10/18!07 2 6694 5183 30 MMG-W DMY RK 0 10/18/07 1 6775 5254 30 MMG-W DMY RK 0 10/i8/07 6423' 3-i /2" HES X N~', ID = 2.813" g4j4' 7" X 3-112" HES AHR Packer, ID = 2.965" 6549' 3-1 /2" HES X NP ID = 2.813" 655$' 7" X 3-1 t2" HES AHR Packer, iD = 2.965" 3-1 J2" HES X NP, ID = 2.813" ~ 7" X 3-1/2" HES A HR Packer, ID = 2.965" 66{}6' I ~ Phoenix Sensor Sub, ID= 6723' 7" X 3-i f2" HES A HR Packer, ID = 2.965" ~ 3-1 /2" HES X Nom, ID= 2.813" ~ 68Q4' ~-13-112" HES X N~ i~ = 2,813" wt 6$24' 3-1/2" HES XN NIP, ID= 2.750" 684T 3-1x2" wLEC, ~ = 3.00" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18/07 N9ES ORIGINAL COMPLETION 10/30/07 TW/PJC PERF CORRECTIONS Orion Unit WELL: S-217i PERMIT No: 207-0950 API No: 50-029-23362-00-00 3156' FSL, 4565' FEL, Sec 35, T12N, R12E, UM BP Exploration (Alaska) BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase: Description of Operations 9/29/2007 18:00 - 19:00 1.00 RIGD P PRE PJSM. Bridle up blocks. 19:00 - 20:00 1.00 RIGD P PRE PJSM. Jack up pit complex remove rig mats. Move pits away 20:00 - 20:30 0.50 RIGD P 20:30 - 21:30 1.00 MOB P 21:30 - 22:30 I 1.00 MOB I P 22:30 - 23:30 1.00 MOB P 23:30 - 00:00 0.50 MOB P 9/30/2007 00:00 - 01:00 1.00 MOB P 01:00 - 01:30 0.50 MOB P 01:30 - 02:30 1.00 MOB P ', 02:30 - 03:30 1.00 MOB P ~I 03:30 - 04:00 0.50 RIGU P 04:00 - 05:00 1.00 RIGD P 05:00 - 13:00 8.00 DIVRTR P 13:00 - 16:30 3.501 RIGD P 16:30 - 17:30 1.00 RIGU P 17:30 - 18:30 1.00 RIGU P 18:30 - 19:00 0.50 RIGU P 19:00 - 21:00 2.00 RIGU P 21:00 - 22:00 I 1.001 DIVRTR I P 22:00 - 00:00 I 2.001 DIVRTR I N I HMAN I 110/1/2007 100:00 - 01:00 I 1.001 DIVRTR I N I HMAN I 01:00 - 04:30 I 3.501 DRILL I P 04:30 - 05:30 1.00 DRILL I P 05:30 - 06:30 1.00 DRILL P 06:30 - 12:00 I 5.501 DRILL I P 12:00 - 17:00 I 5.001 DRILL I P from rig. PRE PJSM. Lay derrick down and secure lines. PRE PJSM. Jack up rig complex, remove rig mats and move off of S-400A down well row. PRE Move pit complex around pad to south pad extension. Remove herculite from S-400A. PRE Move rig complex around pad to south pad extension. PRE Raise derrick. PRE Finish move around pad. PRE Place mats and herculite under rig. PRE .Spot rig complex over conductor. PRE PJSM. Spot mud complex next to rig. PRE Rig up rig floor, hook up lines at interconnect between rig and mud pits. PRE Bridle down blocks. Spot cuttings tank. *Accept rig for s-2171 operations @ 05:00 hr, 9/30/2007 PRE Nipple up diverter system. (Sim Ops) -Berm around rig, mix spud mud, prep drill pipe and BHA in pipeshed. PRE Pick up and make up drill pipe stands in derrick - 3,632'. PRE Pick up and make up HWDP stands in derrick - 735'. PRE Make up jar stand and 1 stand of 7" drill collars and stand back in derrick. PRE Hold Pre-Spud meeting with all personnel. PRE Make up BHA #1: New 12.25" HTC MXL-01X bit, 1.5 deg PDM, NM Lead DC, NM STAB, MWD, NM STAB, NM XO, UBHO sub. PRE Function test surface diverter system. Perform accumulator drawdown test. Witnessing of test waived by AOGCC rep Chuck Sheve. Test witnessed by BP WSL R. French and NAD TP R. Hunt. PRE Fill hole to check for leaks. Mud leaking profusely between drilling nipple and annular preventer. Nipple down drilling nipple, check API ring and grooves. Ring groove on drilling nipple had cement in it. PRE Nipple up diverter drilling nipple. Check for leaks - OK. Pressure test surface lines to 3,000 psi - OK. *Morning tour crew held Pre-Spud meeting during PTSM. Spud and drill 12.25" surface hole from 108' to 457'. Gyro every 100'. 560 gpm, 750 psi off, 890 psi on, 80 rpm, .6k TO off, 1.5k TO on, 25k WOB. Wipe 30ft POH to 112' to add jar stand, STAB to BHA. Run back in hole to 361'. Precautionary wash last stand from 361' to bottom @ 457'. 35 ft of fill. Directionally drill 12.25" surface hole from 457' to 1,202'. Last Gyro survey @ 1,100'. 30 ft wipe prior to connections. 600 gpm, 1,850 psi on, 1,730 psi off. 80 rpm, 4.5k TO on, 3.5k TO off. PU - 78k, SO - 74k, RWT - 72k, WOB - 25k. AST - 2.32 hrs, ART - 2.53 hrs. Directionally drill 12.25" surface hole from 1,202' to 1,871'. SURF SURF SURF SURF SURF Printed: 10/25/2007 1:28:01 PM ~ r BP EXPLORATION. Page 2 of 14 Operations Summary. Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/1/2007 12:00 - 17:00 5.00 DRILL P SURF 30 ft wipe prior to connections. 659 gpm, 2,525 psi on, 2,250 psi off. 80 rpm, 6.9k TQ on, 4.1 k TQ off. PU - 86k, SO - 80k, RWT - 82k, WOB - 30k. AST - 2.25 hrs, ART - 1.50 hrs. 17:00 - 18:00 1.00 DRILL P SURF Circulate 3 bottoms up. Good amount of sand and pea gravel on 1st two bottoms up. 704 gpm, 2,630 psi. 80 rpm, 3.9k TQ. 18:00 - 19:00 1.00 DRILL P SURF Monitor well - OK. POH from 1,871' to 1,105'. Started pulling tight 25k over. Attempt to wipe free. 19:00 - 21:30 2.50 DRILL P SURF Start pumping out @ 3 bpm without much progress. Start backreaming @ 680 gpm, 1,930 psi, 50 rpm, 4k to 14k TQ. Acted like boulder was on top of stabilizer. Backreamed from 1,105 to 800' with high torque. Pulled dry a couple of stands without problem then had to backream 4 stands. Last 4 stands to BHA pulled free without pumping or drag. 21:30 - 23:00 1.50 DRILL P SURF Run in hole from 276' to 580' without problem. Set down at 580'. Run in hole pumping @ 245 gpm, 550 psi from 580' to 828'. Run in hole dry with 2 stands to 1,011'. Unable to work past tight spot pumping as before. Ream 1 stand from 1,011' to 1,106' with torque ranging from 3.5k to 14.5k, 245 gpm, 550 psi. Large amount of sand returning to shakers. After getting stand down, increased pump rate to 672 gpm, 1,880 psi and backreamed stand back up one time with normal torque, turned pump to half rate and run stand back down without drag. 23:00 - 00:00 1.00 DRILL P SURF Run in hole from 1,106' to 1,775' with intermittent down drag. Precautionary wash from 1,775' to bottom @ 1,871' @ 550 gpm, 1,780 psi, 50 rpm, 3k TQ. 10/2/2007 00:00 - 01:30 1.50 DRILL P SURF Circulate and condition mud. Returns were bringing up sand and pea gravel and thick mud. Adjusted pump rates to minimize surface losses. Started off at 700 gpm and reduced to 475 for most of circulation. 01:30 - 12:00 10.50 DRILL P SURF Directionally drill 12.25" surface hole from 1,871' to 3,591'. 30 ft wipe prior to connections. 700 gpm, 3,530 psi on, 3,350 psi off. 80 rpm, 6.5k TQ on, 4.5k TQ off. PU - 100k, SO - 75k, RWT - 90k, WOB - 30k. AST - 2.15 hrs, ART - 4.5 hrs. 12:00 - 17:00 I 5.001 DRILL I P 17:00 - 19:30 I 2.501 DRILL I P 19:30 - 22:30 I 3.001 DRILL I P 22:30 - 23:00 I 0.501 DRILL I P SURF Directionally drill 12.25" surface hole from 3,591' to TD @ 4,360 MD, 3,491 TVD'. 30 ft wipe prior to connections. 600 gpm, 3,500 psi on, 3,035 psi off. 80 rpm, 9.2k TQ on, 4.8k TQ off. PU - 120k, SO - 84k, RWT - 100k, WOB - 35k. AST - 0.18 hrs, ART - 3.41 hrs. SURF Circulate 3 bottoms up. 634 gpm, 3,320 psi, 100 rpm, 4.9k TQ. SURF Monitor well - OK, MW - 9.8 ppg. POH (short trip) from 4,330' to 1,775' with intermittent 25k over drag, wiping same clean up to 1,775'. Started swabbing at 1,775'. SURF POH, pumping out at 3 bpm, 350 psi from 1,775' to 1,585'. Printed: 10/25/2007 1:28:01 PM • • BP EXPLORATION Page 3 of 14 .Operations. Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/2/2007 22:30 - 23:00 0.50 DRILL P SURF Tight at 1,585'. 23:00 - 23:30 0.50 DRILL P SURF Backream from 1,585' to 1,297' @ 702 gpm, 2,200 psi, 80 rpm, 3-15k TO. 23:30 - 00:00 0.50 DRILL P SURF Finish short trip out pulling last 5 stands without pumping from 1,297' to 823'. Intermittent 5-10K drag. 10/3/2007 00:00 - 00:30 0.50 DRILL P SURF Run in hole from 823' to 1,379. Set down at 1,379'. PU - 82k, SO-71 k. 00:30 - 02:00 1.50 DRILL P SURF Work and ream intermittent tight spots from 1,379 to 1,580. 200 gpm, 600 psi, 40 rpm, 4-10k TO. Shakers returning good amount of wood back. PU - 88k, SO - 75k, RWT - 80k 02:00 - 05:00 3.00 DRILL P SURF Run in hole from 1,580' to 3,960' working pipe down with intermittent drag. Filled drill pipe @ 3,300'. Set down at 3,960' 05:00 - 06:00 1.00 DRILL P SURF Wash and ream from 3,960' to bottom @ 4,360'. No fill. Start at 143 gpm, 1,170 psi, 50 rpm, 7.6k TO. Increase to 570 gpm, 3,200 psi, 80 rpm, 6.8-9k TQ. OK for appx 10 minutes before partially losing returns. Slow down to 180 gpm getting back returns. Continue washing to bottom at reduced pump rate. 220 gpm, 1,000 psi. *Lost 60 bbls. 06:00 - 10:00 4.00 DRILL P SURF Circulate and condition mud. Stage pumps up from 220 gpm, ~ 1,000 psi to 640 gpm, 3,430 psi , 80 rpm, 6.3k TO. PU - 135k, SO - 75k, RWT - 103k. *No more mud losses. 10:00 - 13:30 3.50 DRILL P SURF Monitor well for 10 minutes -static, MW - 9.5 ppg. POH from 4,360' to 1,910' with minor intermittent drag. Pulled tight at 1,910'. Attempted to work through without pumping. 13:30 - 15:30 2.00 DRILL P SURF Backream from 1,910' to 1,297'. 656 gpm, 2,315 psi, 90 rpm, 4.5-7.1k TO. 15:30 - 16:30 1.00 DRILL P SURF POH dry from 1,297' to BHA without problem. 16:30 - 18:30 2.00 DRILL P SURF Stand back jar and drill collar stand. Laydown remainder of BHA #1. Bit#1 grade:2-3-WT-G-E-1 -NO-TD. 18:30 - 19:00 0.50 DRILL P SURF Clear and clean rig floor. 19:00 - 21:00 2.00 CASE P SURF Make dummy hanger run. Rig up to run surface casing. 21:00 - 00:00 3.00 CASE P SURF PJSM. Baker Lok and make up 9 5/8" 40# L-80 BTC casing 2 joint shoe track. Check floats - OK. Run in hole with surface casing to 1,434' -end of tour. MU torque - 8,600 fUlb average to make up mark. Used BOL 2000 NM pipe dope. Filled every joint with casing fill-up tool. Ran bowspring centralizers on collars of 1st 25 joints in hole. *Lost 25 bbls of mud from noon to midnight. *Lost 85 bbls of mud for the day. 10/4/2007 00:00 - 00:30 0.50 CASE P SURF Continue running in hole with 9 5/8" 40# L-80 BTC surface casing from 1,434' to 1,782 filling every joint. Set down at 1,782' and attempted to work down without pumping, 00:30 - 15:00 14.50 CASE P SURF Work and wash casing down from 1,782' to 2,528'. 196 gpm, 350 psi. 2 joints from 1,836' to 1,920' went fairly easy. 1,929' to 2,159' hard. 204 bpm, 360 psi. 2,159' to 2,487' easy. 185 gpm, 420 psi. 2,487 to 2,528' hard. 244 gpm, 450 psi. 2,528' to 2,611' easy. 200 gpm, 400 psi 2,611' to 2,693' hard. 210 gpm, 450 psi. Printed: 10/25/2007 1:28:01 PM ~ r BP EXPLORATION ' Page 4 of 14 - Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2007 15:00 - 20:00 5.00 CASE P SURF Continue running in hole with surface casing from 2,693' to 4,315' fairly easy only pumping 6 joints down when needed @ 240 gpm, 670 psi. PU - 165k, SO - 90k. 20:00 - 21:00 1.00 CASE P SURF Make up landing joint and wash to planned casing depth of 4,347'. Continue circulating 1 bottoms up, @ 6 bpm, 800 psi ICP, 590 psi FCP. Reciprocate casing in 10' strokes. 21:00 - 21:30 0.50 CASE P SURF Laydown Frank's tool, blowdown topdrive and make up cement head. 21:30 - 00:00 2.50 CEMT P SURF Circulate and condition mud @ 8 bpm, 600 psi ICP, 510 psi @ midnight. 20 YP, 120 vis. Reciprocate casing in 15' strokes. *Lost total of 138 bbls for the day. 10/5/2007 100:00 - 03:00 I 3.001 CEMT P 03:00 - 07:00 I 4.001 CEMT I P 07:00 - 08:30 I 1.501 CEMT ( P 08:30 - 09:30 I 1.00 I CEMT I P 09:30 - 10:30 1.00 CEMT P 10:30 - 12:.00 1.50 CEMT P SURF Continue circulating, bringing down Vis & YP to 60 & 16 @ 8 bpm, 460 psi. Held PJSM on cementing job @ 01:30 hr. Cementers started batch @ 01:50 hr. SURF Switch to dowell. Pump 5 bbls water, test lines to 4,000 psi - OK. Mix and pump 67 bbls of 10.0 ppg MudPush II spacer. Drop bottom plug. Mix on the fly and pump 525 bbls of 10.7 ppg DeepCRETE cement. Batch mix and pump 70 bbls of 15.8 ppg Class "G" cement. *Reciprocated until casing stuck 6 1/2 ft ua during pumoino of "G" cement. Batch mix and pump 15 bbls of 16.3 ppg DuraSTONE cement. Drop top plug. Kick out plug with 10 bbls of fresh water. Switch to rig. Displace cement with 9.6 ppg mud @ 5 bpm, 335 psi ICP, 660 psi FCP with 164 bbls away. Lost total circulation. Stop working /attempting to free casing. Slow pump to 3 bpm, 575 ICP, 1,115 psi FCP for remainder of displacement for total of 314 bbls. Bump plug with 1,700 psi. CIP at 06:45 hr. Bleed off pressure, check floats - OK. Halliburton 9 5/8" Float Shoe -Bottom @ 4,340'. 2 Jts 9 5/8" 40# L-80 BTC Casing {#1- #2) Halliburton 9 5/8" Float Collar -Top @ 4,255'. 1 Jt 9 5/8" 40# L-80 BTC Casing (#3) 9 5/8" 40# L-80 BTC Pup Jt. 79 Jts 9 5/8" 40# L-80 BTC Casing (#4-#82) TAM Port Collar -Top @ 996'. 24 Jts 9 5/8" 40# L-80 BTC Casing (#83-#106) -Top @ 28.42' SURF Back out and laydown cement head and landing joint while nippling down diverter line downstream of knife. valve. SURF Rig down 350 ton elevators. Change out bales and clear rig floor SURF Make up TAM combo tool and run in hole on drill pipe to 996'. SURF Latch into TAM port collar and test to 1,000 psi - OK. Bleed off pressure. Shift open TAM collar and attemt to circulate. Pressured ua and broke over at 350 osi with no returns. Pump at 2 bam. 130 osi with no returns. Shift TAM collar shut. Printed: 10/25/2007 1:28:OT PM ~ • BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 9ES Date From - To I Hours I Task ) Code I NPT ',10/5/2007 110:30 - 12:00 I 1.501 CEMT I P 12:00 - 13:00 1.00 CEMT P 13:00 - 13:30 0.50 CEMT P 13:30 - 15:00 1.50 DIVRTR P 15:00 - 16:00 1.00 DIVRTR P 16:00 - 17:30 1.501 CEMT I P 17:30 - 18:00 0.50 DIVRTR P 18:00 - 18:30 0.50 CEMT P 18:30 - 21:30 3.00 CEMT P 21:30 - 22:00 0.501 CEMT I P 22:00 - 00:00 2.00 CEMT P 10/6/2007 102:00 - 06:00 4.00 CEMT N 06:00 - 07:00 I 1.001 CEMT I P 07:00 - 08:00 1.00 CEMT P 08:00 - 10:30 2.50 CEMT P 10:30 - 11:00 I 0.501 CEMT P 11:00 - 12:00 1.00 CEMT P WAIT Spud Date: 10/1/2007 Start: 9/29/2007 End: 10/19/2007 I Rig Release: 10/18/2007 Rig Number: 9ES Phase Description of Operations SURF Pressure test to 1,000 psi - OK. Bleed off pressure. Unlatch out of TAM collar. Re-test to 1,000 psi - OK. Pull up blow choke on combo tool @ 1,845 psi. SURF POH from 996 to surface. Break out and laydown combo tool. SURF Clear rig floor. Bring 1-1/4" handling tools to rig floor. SURF Nipple down diverter drilling nipple and remove from cellar. SURF lift diverter stack and spool for access to 9 5/8". Not enough room over top of 9 5/8" to remove, stump too high. SURF Pick up landing joint, run through diverter and make up to casing hanger. Pick up 185k with only 4 inches of movement. Slack back off and cut casing below hanger pup joint. SURF Remove diverter stack and equipment from cellar. SURF Rig up to run 1-1/4" flush hydril top job pipe. SURF Run in 9 5/8" annulus with top job pipe to 392'. Rig up to pump and attempt to wash down. Made 2 ft and stopped. Laydown single for top job @ 381'. SURF PJSM with Dowell. Rig up for top job cement. SURF Pump 10 bbls of fresh water. Pressure test to 2,000 psi - OK. Pump 185 bbls of 10.7 ppg DeepCRETE cement at 2 bpm, 300 psi ICP, 345 psi ICP. CIP @ 11:59 hr. *With 140 bbls away, started seeing lightly clabberd up mud. *With 170 bbls away mud was thick. *Nothing back to surface with a weight higher than 9.6 ppg or a PH greater than 8.5. SURF Blowdown and rig down circulating equipment. SURF Laydown top job pipe. Clear rig floor. SURF Wait on Dowell. Service rig. Changed out drilling line and change out 1 mud end on mud pump while waiting. *Dowell back on location at 06:00 hr. SURF Pick up 1-1/4" flush hydril top job pipe. Tag at 130'. Attempt to work through to make sure it was not hanging up on casing collar -mushy. SURF Rig up circulating equipment. Break circulation 1/4 bbl - OK. SURF PJSM with Dowell. Pump 10 bbls fresh water. Pressure test lines to 1,000 psi - OK. Pump 98 bbls of 10.7 ppg DeepCRETE cement @ 2 bpm, 130 psi. *1st 75 bbls away, returns were 9.5 ppg clabberd up mud. *Last 18 bbls away, returns were 10.5 ppg clabbered up cement. Pump 10 bbls of fresh water. *1st 7 bbls of returns were 10.5 ppg clabbered up cement. *Last 3 bbls of returns were 10.7 ppg good cement. Change over to ASL blend +-20 minutes. Pump 22 bbls of 10.7 ppg ASL cement. *Returned last 15 bbls of sidewalk cement to surface. CIP @ 10:25 hr. SURF Blow down Dowell, rig surface equipment. Rig down circulating equipment. SURF Laydown top job pipe. Rig down handling equipment. Clear Printed: 10/25/2007 1:28:01 PM ~ ~ BP EXPLORATION Page 6 of 14 Operatiolns Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task.• Code NPT Phase Description of Operations 10/6/2007 11:00 - 12:00 1.00 CEMT P SURF floor. 12:00 - 14:00 2.00 WHSUR N STUC SURF Cut and dress 9 5/8" casing stump with Wach's cutter. Place wellhead equipment in cellar. 14:00 - 18:00 4.00 WHSUR P SURF Make up FMC slip-lock casing head and tubing spool. Pressure test casing head to 900 psi - 15 minutes - OK. 18:00 - 00:00 6.00 BOPSU P SURF Nipple up BOPE, inner annulus secondary valve. Install bell nipple. Change out topdrive saver sub. 10/7/2007 00:00 - 01:00 1.00 BOPSU P SURF Rig up to test BOPE. 01:00 - 05:30 4.50 BOPSU P SURF Pressure test BOPE to 250 psi low, 4,000 psi high, annular preventer tested to 250 psi low, 3,500 psi high. Each test held 5 minutes each. Perform accumulator draw-down test. Witnessing of test waived by AOGCC rep Bob Noble. Test witnessed by BP WSL R. French and NAD TP B. Tiedemann. 05:30 - 07:00 1.50 BOPSU P SURF Slowdown and rig down BOP test equipment. Install wear bushing. 07:00 - 08:30 1.50 DRILL P PROD1 Make up BHA #2: Used 8 3/4" MX1 bit, NB STAB, XO, 2ea NM DC, saver sub, 1 jt 5" HWDP, jar, 1 jt 5" HWDP, XO 8 stands 4" HWDP. 08:30 - 09:00 0.50 DRILL P PROD1 Run in hole with BHA #2 picking up drill pipe from pipeshed from 900' to 1,200'. Put quick 1,000 psi on casing to check TAM port collar closed - OK. 09:00 - 11:30 2.50 DRILL P PROD1 Continue running in hole picking up drill pipe from 1,200' to 3, 768'. 11:30 - 13:00 1.50 DRILL P PROD1 Run in hole with drillpipe in derrick from 3,768' to 4,054'. Fill lines and break circulation. 13:00 - 14:00 1.00 DRILL P PROD1 Pressure test 9 5/8" casing_ to 3,500 psi - 30 minutes -Good test! 14:00 - 14:30 0.50 DRILL P PROD1 Wash down from 4,054' to top of plugs on float collar @ 4,253'. 271 gpm, 640 psi, 50 rpm, 5k TO. 14:30 - 15:30 1.00 DRILL P PROD1 Drill out cement, shoe track and 20 ft rathole to 4,360'. 430 gpm, 1,280 psi, 80 rpm, 4.6k TO off, 5.8k TO on. PU - 120k, SO - 75k, RWT - 90k, WOB - 10-15k. Started mud displacement with bit above shoe. Float collar and float shoe on depth with tally. 15:30 - 16:00 0.50 DRILL P PROD1 Drill 20 ft of new hole from 4,360' to 4,380'. 520 gpm, 630 psi, 100 rpm, 4.3k TO off, 5.4k TO on. PU - 125k, SO - 70k, RWT - 90k, WOB - 10-15k. 16:00 - 17:00 1.00 DRILL P PROD1 Continue displacing hole from 9.5 ppg spud mud to 8.8 ppg LSND mud. 572 gpm, 700 psi, 100 rpm, 4.6k TO. 17:00 - 18:00 1.00 DRILL P PROD1 Perform LOT. MD - 4,340', TVD - 3,478' MW - 8.8 ppg, LO pressure.- 540 psi EMW - 11.79 Bleed off pressure, blowdown lines and monitor well -static.. MW 8.8 PPg• 18:00 - 20:00 2.00 DRILL P PROD1 POH from 4,340' to 900'. 20:00 - 21:00 1.00 DRILL P PROD1 Stand back HWDP, jar and DC stands. Laydown remainder of BHA #2. Bit grade: 2-2-WT-A-E-I-NO-BHA 21:00 - 21:30 0.50 DRILL P PROD1 Clear and clean rig floor. PJSM on new BHA and nuclear source. 21:30 - 00:00 2.50 DRILL P PROD1 Make up Power Drive. Test same @ 416 gpm, 470 psi - OK. Printed: 10/25/2007.1:28:01 PM r • $P EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date' From - To Hours Task Code NPT Ph 10/7/2007 21:30 - 00:00 2.50 DRILL P PRO 10/8/2007 00:00 - 01:30 1.50 DRILL P PRO 01:30 - 02:00 0.50 DRILL P PRO 02:00 - 03:00 I 1.001 DRILL I P I PRO 03:00 - 03:30 0.50 DRILL I P 03:30 - 04:00 0.50 DRILL N PROD1 HMAN PROD1 04:00 - 04:30 I 0.501 DRILL I N I HMAN I PRO 04:30 - 04:45 I .0.251 DRILL I N I HMAN I PRO 04:45 - 05:00 0.25 DRILL N 05:00 - 05:15 0.25 DRILL P 05:15 - 06:00 I 0.751 DRILL I P 06:00 - 12:00 I 6.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P I I PRO 10/9/2007 100:00 - 01:30 I 1.501 DRILL I P I PRO 01:30 - 03:00 I 1.501 DRILL I P I I PRO Spud Date: 10/1/2007 Start: 9/29/2007 End: 10/19/2007 Rig Release: 10/18/2007 Rig Number: 9ES ase Description of Operations D1 Continue making up BHA #3: 8-3/4" Hycalog MX202261 bit, Power Drive, 0 deg PDM, NM STAB, LWD/ARC, MWD, LWD/ADN, 2 NM DC, SS, 1 5" HWDP, jar, 1 5" HWDP, XO, 24 HWDP. "Had the LWD/ADN picked up at midnight. D1 Complete BHA #3 pick up and RIH on HWDP to 1,007'. D1 Shallow hole test MWD with 505 gpm, 1,125 psi - OK. Run in hole 4 stands and make up Ghost reamer. D1 Run in hole from 1,396' to 3,888'. *Drillers tally was mistakenly figured at depth of 4,270'. Service topdrive and crown. MadPass from 3,888' to 3,978 for tie-in log. "Drillers tally was mistakenly figured from 4,270' to 4,360'. 443 gpm, 1,125 psi, no rotation. D1 Circulate for ECD parameters. 580 gpm, 1,705 psi. CECD - 8.7 PP9??? D1 Wash to what was thought was bottom @ 4,380' but didn't find it there or anywhere down to 4,415'. Real depths were 3,998' to 4,033'. Driller rechecked tally and found that the 4 stands in the BHA were figured in twice. Run in hole to corrected DP tally depth of 4,270'. MadPass from 4,300' to 4,380'. 585 gpm, 1,780 psi, no rotation. Circulate for ECD parameters. 590, 1,830 psi. CECD - 9.41 ppg. Obtain SPR's. Directionally drill from 4,380' to 5,314'. 585 gpm, 2,060 psi off, 2,250 psi on. 40 rpm, 5.8k TO off, 7.1 k TO on. PU - 135k, SO - 90k, RWT - 107k, WOB - 15k. CECD - 9.56 ppg, AECD - 9.76 ppg. ART - 3.29 hr. Survey every 90 ft, backream 20 ft prior to connections. Pumped 25 bbl Hi Vis sweep @ 4,950' - no increase in cuttings back to surface. D1 Directionally drill from 5,314' to 6,844'. 585 gpm, 2,875 psi off, 3,120 psi on. 110 rpm, 8.6k TO off, 10k TO on. PU - 155k, SO - 120k, RWT - 124k, WOB - 15k. CECD - 9.70 ppg, AECD - 10.27 ppg. ART - 5.81 hr. Survey every 90 ft, backream 20 ft prior to connections. Pumped 25 bbl Hi Vis sweep @ 4,950' - no increase in cuttings back to surface. D1 Directionally drill from 6,844' to TD @ 7,049' MD, 5,492' TVD. 585 gpm, 2,950 psi off, 3,160 psi on. 120 rpm, 8.6k TO off, 10.7k TO on. PU - 165k, SO - 115k, RWT - 125k, WOB - 15k. CECD - 9.73 ppg, AECD - 10.10 ppg. ART - 0.87 hr. Survey every 90 ft, backream 20 ft prior to connections. D1 Circulate 3 times bottoms up. 590 gpm, 2,955 psi 110 rpm, 8k TO CECD - 9.73 ppg, AECD - 9.80 ppg. Printed: 10/25/2007 1:28:01 PM HMAN PROD1 PROD1 PROD1 PROD1 ~ ~ BP EXPLORATION Page 8 of 14< Operations Sumllnary Report Legal Well Name: S-217 Common Well Name: S-217 Event Name: DRILL+COMPLETE .Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To Hours Task.. Code NPT Ph 10/9/2007 01:30 - 03:00 1.50 DRILL P PRO 03:00 - 03:15 0.25 DRILL P PRO 03:15 - 08:00 4.75 DRILL P PRO 08:30 -100:00 10.501 DRILL I P PRO 10:00 - 13:00 I 3.001 DRILL I P I I PRO 13:00 - 15:30 2.501 DRILL I P I PRO 15:30 - 16:00 0.50 DRILL P PRO 16:00 - 20:00 4.00 EVAL P PRO 20:00 - 23:00 I 3.001 EVAL I P I I PRO 10/10/2007 100:00 - 010:00 1.001 EVAL I P PRO 01:00 - 03:30 I 2.501 EVAL I P I I PRO 03:30 - 04:00 0.50 EVAL I P PRO 04:00 - 20:00 16.00 EVAL P PRO 20:00 - 23:00 I 3.001 EVAL I P I I PRO 23:00 - 00:00 I 1.001 EVAL I P I I PRO 10/11/2007 103:00 - 06:00 3.001 EVAL (P PR 06:00 - 10:00 I 4.001 EVAL I P I I PR 10:00 - 13:30 I 3.501 EVAL I P I I PR 13:30 - 18:00 I 4.501 EVAL I P I I PR Spud Date: 10/1/2007 Start: 9/29/2007 End: 10/19/2007 Rig Release: 10/18/2007 Rig Number: 9ES ase' Description of Operations D1 9.0 MW. D1 Downlink rotary steerable tools to neutral. D1 Laydown single, observe well -static. MW - 9.0 ppg. Backream from 7,035' to 5,697' (Bringing Ghost reamer to shoe). 1st 3 stands were backreamed in 30 minutes with ECD's climbing up on 3rd one. Backream at moderate speed for ECD's. 550 gpm, 2,580 psi, 120 rpm, 7.8k TO, CECD 9.70 ppg, AECD - 10.43 ppg D1 CBU @ 5,697'. 550 gpm, 2475 psi. D1 POH from 5,697 - 5,448'. PU - 145k, SO - 98k. Hole started to swab. Pump out of hole 2 stands from 5,448' - 5,269' and @ 545 gpm, 2375 psi. POH dry from 5,269' - 4,263' md. D1 Monitor well - OK. MW in 9.1 ppg, MW out 9.1 ppg. Pump 12 bbl 11.1ppg dry job. Blow down topdrive & remove blower hose. POH to BHA. No overpulls or problems seen while POOH. D1 PJSM. Lay down BHA #3. Bit grade: 1-1-CT-A-O-I-NO-TD. D1 Clean and clear rig floor of all BHA handling equipment. D1 Spot E-Line unit on location. Pre job Safety meeting on picking up and running drill pipe conveyed MDT logging tools attended by SWS personnel, NAD rig crew and toolpusher, BP WSL Pick up and make up logging tools. Function test and verify tools. D1 Run in hole with MDT logging tools on drill pipe to 4,21 T. Circulate 10 minutes each at 2,000', 4 bpm, 140 psi and at 4,200', 4 bpm, 300 psi. PU - 105k, SO - 68k at shoe. Circulate down every 5 stands to avoid. solids build-up on DWCH in open hole. D1 Continue RIH w/ MDT tools on drill pipe from 4,200 - 4,750' md. D1 Continue RIH w/ MDT Logging tools on drill pipe from 4,750' to 5,900' md. D1 Make up side door entry sub. Pump down, RIH and latch up with wet connect at 44 gpm, 200 psi. Confirm latch up. D1 Continue running in hole from 5,900' to 6,222'. D1 Take MDT pressure samples from 6,556' to 7,574'. Total of 18 successful pressure readings taken @ 6,200', 6,271', 6,315', 6,395', 6,439', 6,523' 6,535', 6,573', 6,597', 6,613', 6,621', 6,674' 6,678', 6,688', 6,736', 6,744', 6,760', 6,802' D1 Move pipe, and position packers for sampling @ 6,744' md. Draw down sucessful, but unable to flow fluids from formation. D1 Reposition tool for sampling at 6,573' and and begin fluid analysis. OD1 Take MDT Fluid sample at 6,573' md. OD1 Reposition tool & successfully recover fluid sample #3 of 6 at 6,524' md. OD1 Reposition tool & successfully recover fluid sample #4 of 6 at 6,678' md. OD1 Reposition tool & successfully recover fluid sample #5 of 6 at 6,622' md. OD1 Abort fluid sample #6 and attempt to recover OBd sample Printed: 10/25/2007 1:28:01 PM • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/1.9/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hotars .Task Code NPT Phase Description of Operations 10/11/2007 13:30 - 18:00 4.50 EVAL P PROD1 again. Reposition tool at 6,739' md. After 4.5 hours still unable to recover samole. 18:00 - 21:00 3.00 EVAL P PROD1 Reposition tool to 6,760' and and attempt another OBd sample. 21:00 - 22:30 I 1.50 EVAL P 22:30 - 00:00 1.50 EVAL P 10/12/2007 100:00 - 01:30 I 1.501 EVAL I P 01:30 - 04:30 3.00 EVAL P 04:30 - 06:00 1.50 EVAL P 06:00 - 07:30 I 1.501 CLEAN I P 07:30 - 09:30 2.00 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 12:00 I 2.001 CLEAN I P 12:00 - 13:30 I 1.501 CLEAN I P 13:30 - 14:00 0.501 CLEAN I P 14:00 - 15:30 I 1.501 CLEAN I P 15:30 - 18:00 I 2.501 CLEAN I P 18:00 - 22:30 I 4.50 CLEAN I P 22:30 - 00:00 1.50 CLEAN P 10/13/2007 00:00 - 01:30 1.50 BOPSU P 01:30 - 03:30 2.00 BOPSU P 03:30 - 05:00 1.50 CASE P 05:00 - 06:00 1.00 CASE P 06:00 - 07:30 1.50 CASE P PROD1 POH to 5,945' md. PROD1 Unlatch wet-connect from downhole toolstring and recover to surface. PROD1 At surface with wireline wet-connect. RD wireline sheave wheels & side entry sub. PROD1 POH to top of wireline tools. PROD1 PJSM. Rig down Schlumberger MDT tools. clean & clear rig floor. CLEAN PJSM. Bring to rig floor and MU cleanout BHA #4 - 8.75" MX1 bit, Near-bit stabalizer, 1 jt 5" HWDP, Jars, 1 jt 5" HWDP, XO, 8 stands 4" HWDP. CLEAN RIH w/ cleanout BHA #4 to 4,183' md. CLEAN Break circulation. Stage pumps up to 450 gpm, 1000 psi & circulate 82 bbls. PU - 100k, SO - 75k, RTW - 90k. Blow down topdrive, hook up blower hose. CLEAN RIH from 4,183' and to 5,565' and and set down on obstruction. Bring pumps online and wash 1 stand down from 5,565' to 5,612' @ 210 gpm, 460 psi 50 rpm - OK. Continue RIH pumps off to 6,956' md. PU - 160k, SO - 95k, RTW - 120k. CLEAN Break circulation and precautionary wash last stand to bottom through 8' of fill to 7,049' md. CBU @ 450 gpm, 1720 psi, 80 rpm, 7.3k TQ. Increase pump rate &CBU @ 585 gpm, 2290 psi, 100 rpm, 7.3k TO. CLEAN Shut down pumps. Attempt to POH and pull tight @ 6,875' md. Run back in hole to TD @ 7,049'. CLEAN CBU @ 585 gpm, 2150 psi, 100 rpm. Pump 12 bbl 11.1ppg hi-vis weighted sweep. 10% cuttings increase once sweep back to surface. PU - 160k, SO - 95k, RTW - 120k, 7.8k TQ at 120 rpm. CLEAN Attempt to pull dry but pulled 35k over into tight spot at 6,860' md. Attempt to work through but unsuccessful. RIH to 6,954' and backream out to 6,189' md. 450 gpm, 1350 psi, 80 rpm, 7-8k TQ, PU - 100k, SO - 75k, RWT - 90k. Saw tight area @ 6,630 but able to pull past. CLEAN Pull 4 stands dry to 5,807'. Monitor well -static. Pump dry job. Blow down topdrive, POH to 102' md. CLEAN Break out and Lay down BHA #4. No obvious further wear on tools. Clean and clear rig floor RUNPRD Pull wear bushing, flush BOP stack, and install BOP test plug. RUNPRD Change out upper pipe VBR rams to 7". Test 7" rams to 250 psi and 4,000 psi for 5 minutes each. Pull test plug. RUNPRD Make dummy run with 7" hanger and landing joint - 26'. Change out bales. Rig up to run casing. RUNPRD PJSM. Pick up and make up 7" shoe track. Check floats - OK. RUNPRD Continue running in hole with 26 jts & 1 marker joint of 7" 26# L-80 BTC-M casing to TCII crossover @ 1,077'. Make up BTC-M connections to mark at -8,400 fUlbs TO, using Best-O-Life 2000 NM pipe dope. Ran in hole @ 1.5 minutes per joint. Circulated down every 20 joints for 3 minutes.. Ran Printed: 10/25/2007 1:28:01 PM • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date f=rom - To Hours Task Code NPT Phase ` Description of Operations 10/13/2007 06:00 - 07:30 1.50 CASE P RUNPRD total of 32 BTC-M casing joints and 2 BTC Marker pup joints. 07:30 - 08:00 0.50 CASE P RUNPRD Rig up TCII torque turn equipment. 08:00 - 16:30 8.50 CASE P RUNPRD Continue running in hole to surface casing shoe with 7" BTC-M x 7" 26# L-80 TCII casing from 1,077' to 4,340". Make up TCII connections to 10,100 ft/Ibs TO, using Jet Lube Seal Guard pipe dope. Ran in hole @ 1.5 minutes per joint. Circulated down every 20 joints for 3 minutes. Change out joint 12, 60, 67 for joints 156, 155, 154 due to torque anomaly on Torque Turn readout. 16:30 - 17:30 1.00 CASE P RUNPRD Circulate bottoms up @ 210 gpm, 380 psi. PU - 130k, SO - 98k. No losses. 17:30 - 00:00 6.50 CASE P RUNPRD Continue running in hole with 7" casing from 4,340' to 7,010' without problem. Displacement good. Ran in hole at 2 minutes per joint, filling every joint and circulating down every 10 joints @ 5 bpm for 3 minutes. Recorded PU and SO weights every 10 joints. PU - 205k, SO - 110k @ 7010'. 10/14/2007 00:00 - 00:30 0.50 CASE P RUNPRD Make up hanger and landing joint and land casing on depth @ 7,038'. HES Float Shoe 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float Collar @ 6,954' (PBTD) 10 Jts 7", 26#, L-80 BTC-Mod (#3-12) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA @ 6,530' 14 Jts 7", 26#, L-80 BTC-Mod (#13-26) 7", 26#,L-80 TC-II X BTC-Mod Crossover Jt. @ 5,924' 148 Jts 7", 26#, L-80 TC-I I (#1 - 148) 7" 26# L-80 TC-II Pup Jt. FMC Hanger 00:30 - 01:00 0.50 CASE P 01:00 - 03:30 2.50 CEMT P 03:30 - 04:45 I 1.251 CEMT I P 04:45 - 05:30 I 0.751 CEMT I P 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers: Jt. # 1 2 cent. locked down next to shoe. Skip Jt. # 2 BTC-M Jt. # 3 2 ea. free floating, not seperated by stop ring BTC-M Jts. # 4 thru # 26 2 ea. Per joint separated by stop ring marker and cross over pup 1 ea. floating over entire length TCII Jts. # 1 thru # 15: 2 ea. Per joint separated by stop ring 83 Total Centralizers, 41 Stop Rings RUNPRD Rig down casing fill up tool and rig up cement head. RUNPRD Break circulation and stage pump slowly to 5 bpm while reci rocatin casin 15' strokes. Lost no fluid. YP - 17, MW - 9.1 ppg. Held PJSM with Dowell while circulating. RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 70 bbls 10.5 ppg of MudPush II viscosified spacer @ 4.5 bpm, 285 psi. Drop bottom wiper plug. Pump 63 bbls of Class "G" 15.8 ppg tail cement @ 5 bpm, 100 psi. Wash cement lines to Tee on rig floor. Drop top plug. RUNPRD Switch to rig and displace cement with 267 bbls of 8.5 ppg Printed: 10/25/2007 1:28:01 PM • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2007 04:45 - 05:30 0.75 CEMT P RUNPRD seawater. 1st 247 bbls @ 5 bpm, 110 psi ICP, 350 psi FCP. Next 20 bbls @ 2 bpm, 350 psi ICP, 1250 psi FCP. bump. Bumped plug at calculated strokes with 95% pump efficiency to 1,750 psi. CIP @ 05:39 hr. Bleed off pressure, check for flowback - OK. No losses during cement job. 05:30 - 06:00 0.50 CEMT P 06:00 - 09:00 3.00 CASE P 09:00 - 10:00 1.00 WHSUR P 10:00 - 10:30 0.50 EVAL P 10:30 - 11:00 0.50 BOPSU P 11:00 - 14:00 3.00 BOPSU P 14:00 - 15:30 1.50 BOPSU P 15:30 - 16:00 0.50 BOPSU P 16:00 - 16:30 0.50 P 16:30 - 18:00 1.50 P 18:00 - 22:00 4.00 P 22:00 - 00:00 2.00 P 10/15/2007 1010:30 - 02:30 1.00 I P 02:30 - 03:00 I 0.50 PE 03:00 - 04:00 1.00 PE P P P P P P P P Note: Top off surface cement cement job w/ 3 bbls unsalted neat 'G' cement during plug displacement. RUNPRD Pressure test 7" casino to 4.000 osi - OK. RUNPRD Rig down remaing casing equipment and change out bales. RUNPRD Install and test 7" x 9 5/8" packoff to 5,000 psi - 10 min- OK. OTHCMP Perform 7" x 9 5/8" LOT and infectivity test: 4,340' MD / 3,478' TVD 9.2 ppg MW 1630 psi leak off pressure EMW - 12.68 ppp Injection - 2 bpm - 750 psi, pumped total of 6 bbls during leak off and infectivity test. OTHCMP Flush BOP stack. Install BOP test plug. OTHCMP Change upper rams from 7" to 3.5" x 6" VBR's. OTHCMP Rig up to test rams. Test rams to 250 psi low, 4,000 psi high, w/ 3.5" & 4" test joints - 5 min each - OK. OTHCMP Rig down test equipment. Pull test plug. Install wear busing and blow down lines. *Sim Ops - OA injection and freeze protection: 98 bbls 9.2 ppg mud @ 3 bpm, 1,000 FCP. 75 bbls 80 deg dead crude @ 1 bpm, 850 ICP, 3 bpm, 1,300 FCP, 900 SIP. OTHCMP Pick up to rig floor and rig up perforation running equipment. OTHCMP Pick up and make up DPC perforation assembly - 4.5" Power Jet Omega Guns loaded at 5 SPF, XOs, bumper sub and MWD. OTHCMP Run in hole with DPC pert assembly from 358' to 6,951'. Shallow hole tested MWD @ 2,080', 295 gpm, 475 psi - OK. Set down 5k and verify tag on top of landing collar on depth. OTHCMP Start displacement of well from 8.5 ppg seawater to 8.9 ppg brine @ 285 gpm, 915 psi. Log and correlate to formation gamma ray. OTHCMP Continue to correlate and log into position w/ top shot depth at 6,510.0' md. No depth correction needed. OTHCMP PJSM on E-fire procedure. Initiate firing sequence by pump and bleed. Wait 4:58 minutes for guns to fire. Good indication of uns firin .Well initially lost 6 bbls then went to 3 bph losses. Perf Intervals: - 6,510' - 6,544' - 6,564' - 6,582' - 6,610' - 6,632' - 6,670' - 6,689' - 6,730' - 6,778' OTHCMP POH from 6,778' to 6,500'. OTHCMP Circulate 2 bottoms up @ 240 gpm, 950 psi. Losses at about 3 Printed: toizsizoo~ t:za:ut Pnn BP EXPLORATION Page 12 of 14 . Operations Summary .Report Legal Well Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 10/15/2007 03:00 - 04:00 1.00 PERFO P OTHCMP bph. Shut down pump and observed well -losing fluid @ 3 bph. MW - 8.9 pP9• 04:00 - 09:00 5.00 PERFO P OTHCMP POH laying down drillpipe from 6,500' to 357' md. 09:00 - 12:30 3.50 PERFO P OTHCMP PJSM. Lay down pert gun assembly. All guns fired. Clear tools and clean rig floor of gun residue. *Lost 50 bbls of 8.9 ppg brine from midnight to noon. Losses reduced to -1 bph. 12:30 - 13:00 0.50 PERFO P OTHCMP Run in hole with remaining drill pipe out of derrick to 1,114'. 13:00 - 15:00 2.00 PERFO P OTHCMP Cut and slip drilling line 104'. Adjust brakes. 15:00 - 16:00 1.00 PERFO P OTHCMP POH laying down drill pipe from 1,114' to surface. 16:00 - 17:00 1.00 EVAL P OTHCMP PJSM. Rig up SLB E-line and GR/JB assembly. *Monitor well -Static. 17:00 - 18:30 1.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 1: 5.94" tool to 6,830'. No obstructions found. Did not tag TD. POH. Less than a teaspoon of debris in junk basket when back to surface. 18:30 - 20:00 1.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 2: 6.16" tool ran into obstruction @ 6,510' (top perf). Attempt to work past, but no-go. POH. Less than a teaspoon of debris in junk basket when back to surface. 20:00 - 21:30 1.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 3: 6.125" tool to 6,915'. No obstructions found. Did not tag TD. POH. Less than a teaspoon of debris in junk basket when back to surface. 21:30 - 22:30 1.00 EVAL P OTHCMP Rig up USIT-CBL Logging tools. 22:30 - 00:00 1.50 EVAL P OTHCMP RIH w/ USIT-CBL from surface to 6,900' md. *Lost 13 bbls of 8.9 ppg brine from noon to midnight. *Lost 63 bbls total for the day. 10/16/2007 00:00 - 02:00 2.00 EVAL N SFAL OTHCMP Troubleshoot wireline logging tools. Data aquisition would lock up while trying to log. Eventually switched to backup computer system and problem went away. 02:00 - 03:00 1.00 EVAL P OTHCMP Log Hi-Res USIT-CBL pass from 6,810' and to 6,470' md. Transmit USIT-CBL log to Anchorage ODE & PE Brandon Peltier & Taylor West and call to review results - OK. Good cement across entire interval. 03:00 - 05:00 2.00 EVAL P OTHCMP USIT log 7" casing from 6,810' to surface w/ primary depth control procedures. Top of cement stringer @ 4,825' a-line measured depth. Logs indicated perfs on depth as reported. PIP Tag logged at 6,525' Drillipipe depth or 6,529' E-Line md. 05:00 - 06:00 1.00 EVAL P OTHCMP Lay down USIT tools and rig down E-line. *Well static. No losses since beginning of E-Line logging. 06:00 - 09:00 3.00 RUNCO RUNCMP Drain stack, pull wear ring. Make dummy run w/ hanger. Rig up to run 3.5" Quad Packer completion with I-wire. 09:00 - 16:30 7.50 RUNCO RUNCMP PJSM. Pick up and make up 3.5" 9.2# L-80 TCII completion assembly to last HES packer @ 461'. Terminate I-wire on packers, test connections to 5,000 psi - OK. Make up assembly using Torq Turn equipment to 2,300 ft/Ibs and dope connections with JetLube Seal Gaurd. Apply Baker-Lok to all connections below 1st packer in hole. 16:30 - 00:00 7.50 RUNCO RUNCMP Continue running in hole with 3.5" completion assembly to 3,625' md. Make up assembly using Torq Turn equipment to 2,300 ft/Ibs and dope connections with JetLube Seal Gaurd. 10/17/2007 00:00 - 07:30 7.50 RUNCO RUNCMP Continue running in hole with 3.5" completion assembly to 6,841'. Make up assembly using Torq Turn equipment to 2,300 ft/Ibs and dope connections with JetLube Seal Gaurd. Space Printed: 10/25/2007 1:28:01 PM • BP EXPLORATION Page 13 of 14 Qperations Summary'Report Legal Well Name: Common Well Name: Event Name: Contractor Name: ~ Rig Name: Date I From - To 1,10/17/2007 00:00 - 07:30 7.50 RU 07:30 - 09:00 1.50 RU 09:00 - 12:30 3.50 RU 12:30 - 14:30 2.00 RU 14:30 - 15:00 ( 0.501 RU 15:00 - 17:30 I 2.50 17:30 - 18:00 I 0.50 Start: 9/29/2007 Rig Release: 10/18/2007 Rig Number: 9ES Spud Date: 10/1/2007 End: 10/19/2007 Phase Description of Operations S-217 S-217 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours I Task I Code I NPT RUNCMP out and set completion on depth in reference to pipe tally. Checked I-wire integrity every 1,000' while running in hole. RUNCMP Rig up SLB E-line. RUNCMP Run in hole with CCL/GR tools, correlate to USIT /Primary Depth Control log and and log jewelry in tubing. POH with wireline. RUNCMP POH to space out pup and add lea 5.79' tbg spaceout pup. Pick up and make up landing joint and tubing hanger. Terminate I-wire and control lines to hanger. Test same to 5,000 psi - OK. RUNCMP Land tubing. PU - 99k, SO - 71 k with blocks. 3.5" 9.2 # WLEG, 3.5" TC-II 3.5" HES'XN' Nipple: 2.75" ID 3.5" HES'X' Nipple: 2.813" ID RHC-M Plug GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 3.5" HES 'X' Nipple: 2.813" ID 3.5" x 7" HES single feedthru Packer (1 port) #1 packer GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 1 jt 3.5" 9.2# L-80 TC-I I Tubing (# 1) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 3.5" HES 'X' Nipple: 2.813" ID Phoenix Sensor sub 3.5" x 7" HES single feedthru Packer (1 port) # 2 packer GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 3.5" x 7" HES Dual feedthru Packer (2 ports) #3 packer 3.5" HES 'X' Nipple: 2.813" ID GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch Space out pups w/ RA Tag @ 6,520 E-Line MD GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch Phoenix Sensor sub 3.5" x 7" HES Dual feedthru Packer (2 ports) # 4 packer 3.5" HES'X' Nipple: 2.813" ID GLM#7 -3.5"x1.5" MMG w/DCR-1 w/RKP latch 108 jts 3.5" 9.2# L-80 TC-II Tubing (#2 - 109} 3.5" HES 'X' Nipple: 2.813" ID 87 jts 3.5" 9.2# L-80 TC-I I Tubing (# 110 -.196 ) 2 ea space out pup jts. 3.5" 9.2# L-80 TC-II 9.81 and 5.79 1 jt 3.5" 9.2# L-80 TC-I I Tubing (# 197 ) pup jt 3.5" 9.2# L-80 TC-I I 4.5" X 3.5" TC-I I Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads 15 ea half I-wire clamps 109 ea full clamps RUNCMP Run in hole with CCL/GR tools, correlate to USIT /Primary Depth Control log and and log jewelry in tubing to confirm completion string on depth - OK. POH with wireline. RD Schlumberger E-Line. RUNCMP Run in tubing head lock down screws.. Rig up lines to set and Printed: 10/25/2007 1:28:01. PM i 'BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Weil Name: S-217 Common Well Name: S-217 Spud Date: 10/1/2007 Event Name: DRILL+COMPLETE Start: 9/29/2007 End: 10/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/18/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date I ..From - To I Hours I Task Code I NPT I Phase Description of Operations 10/17/2007 17:30 - 18:00 0.50 RUNCO RUNCMP test packer. 18:00 - 19:30 1.50 RUNCO RUNCMP Drop 1 5/16 ball rod. Lay down landing joint. Pressure up tubin to to 4,000 psi. Hold 4,000 psi for 30 minute tubing test - Good test. Bleed tubing pressure down to 2,500 psi. Pressure test inner annu us to psi or minutes -Good test. Bleed annulus pressure to 0 psi. Bleed tubing pressure to 0 si. ressure up inner annu us o s ear va ve. Sheared at 2,500 psi. Confirm shear by pumping both ways through DCR valve - OK. 170 psi @ 2 bpm. 19:30 - 20:30 1.00 BOPSU P RUNCMP Install 2-way check and test same to 1.000 osi from below - OK. 20:30 - 21:00 0.50 BOPSU P RUNCMP RD Tubing and I-Wire running equipment. Clean & Clear rig floor. 21:00 - 00:00 3.00 BOPSU P RUNCMP Nipple down BOPE. 10/18/2007 00:00 - 02:00 2.00 BOPSU P RUNCMP Continue ND BOPE. 02:00 - 04:00 2.00 WHSUR P RUNCMP Install SBMS, nipple up tree adapter. Terminate I-wires and check wire integrity. Test I-wire and adapter flange to 5,000 psi - OK. 04:00 - 06:00 2.00 WHSUR P RUNCMP Nipple up production tree. Fill tree with diesel and test to 5,000 psi - OK. 06:00 - 08:00 2.00 WHSUR N WAIT RUNCMP Stand by on drill site maintenance to pull TWC. 08:00 - 09:00 1.00 WHSUR P RUNCMP Rig up lubricator and pull 2-wav check valve. 09:00 - 09:30 0.50 WHSUR P RUNCMP Rig up to reverse circulate and test lines to 3,000 psi - OK. 09:00 - 10:30 1.50 WHSUR P RUNCMP Reverse circulate 34 bbls of 8.9 ppg clean brine down IA, followed by 102 bbls of 8.9 ppg inhibited brine @ 2.5 bpm, 220 psi. 10:30 - 12:00 1.50 WHSUR P RUNCMP Rig up LRHOS. PJSM. Pressure test lines to 3,000 psi - OK. Reverse circulate 88 bbls of 70 deg diesel @ 2 bpm, 650 psi ICP, 900 psi FCP. 12:00 - 14:00 2.00 WHSUR P RUNCMP Line up to U-tube diesel. U-tube diesel from IA to tubing. Well freeze protected to 2,500 MD, 2,250 TVD. 14:00 - 15:00 1.00 WHSUR P RUNCMP Rig up lubricator and install BPV. Test BPV to 1,000 psi from below - OK. Final pressures: Tubing - 0 psi IA - 0 psi OA - 50 psi 15:00 - 18:00 3.00 WHSUR P RUNCMP Install VR plugs in IA. Remove working valves, install gauges and secure cellar. 'Release rig to S-1261 at 1800 hrs. Printed: 10/25/2007 1:28:01 PM BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: S-217 Common Name: S-217 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/7/2007 LOT 4,340.0 (ft) 3,478.3 (ft) 8.80 (ppg) 540 (psi) 2,130 (psi) 11.79 (ppg) 10/14/2007 LOT 4,340.0 (ft) 3,478.3 (ft) 9.20 (ppg) 320 (psi) 1,982 (psi) 10.97 (ppg) • Printed: 11/12/2007 4:35:54 PM by ~"'~ ~ ~. , .. ~ Schlumberger I~~f~Vfi CIieM: BP Exploration Alaska Vertical Section Azimuth: 200.410° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure 1 Slot: S-PAD / S-217 TVD Reference Datum: Rotary Table Well: 5-217 TVD Reference Elevation: 67.00 ft relative to MSL Borehole: S-217 Sea Bed 1 Ground Level Elevation: 36.000 ft relative t0 MSL UWIIAPI#: 50029233620( Magnetic Declination: 23.426° Survey Name I Date: 5-217 /October 9, 2007 Total Field Strength: 57646.754 nT Tort 1 AHD I DDI I ERD ratio: 106.032° / 4012.27 ft / 5.737 / 0.73' Magnetic Dip: 80.911 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Declination Date: October 05, 2007 Location LatlLong: N 70.35226346, W 149.0346729; Magnetic Declination Model: BGGM 2007 Location Grid NIE Y1X: N 5979359.390 ftUS, E 618885.110 ftU: North Reference: True North Grid Convergence Angle: 10.90913320° Total Corr Mag North -> True North: +23.426° Grid Scale Factor: 0.99991606 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub•SeaTVD Typ Vertical Along Hole Closure NS EW DLS Northing Easting Lathude Longitude Depth Section Departure h de de ft k ft k k k ft de 1100 k kUS kUS Klt U.UU U.UU u.UU -6/.uu u.uu u.uu u.uu U.uu u.uu u.uu u.u~ 7aros7asa 016007.1 I rv rv.o7cco.r+o vv i4y.us°wrta~ GYD CT DMS 100.00 0.47 158.18 33.00 100.00 0.30 0.41 0.41 -0.38 0.15 0.47 5979359.01 618885.27 N 70.35226241 W 149.03467169 200.00 0.69 167.74 132.99 199.99 1.11 1.42 1.42 -1.35 0.43 0.24 5979358.05 618885.56 N 70.35225977 W 149.03466941 300.00 1.89 188.82 232.97 299.97 3.24 3.65 3.58 -3.57 0.31 1.27 5979355.83 618885.47 N 70.35225371 W 149.03467043 400.00 3.66 196.81 332.85 399.85 8.04 8.48 8.30 -8.25 -0.87 1.81 5979351.12 618884.37 N 70.35224091 W 149.03467998 500.00 5.33 213.43 432.54 499.54 15.75 16.27 15.80 -15.19 -4.35 2.10 5979344.14 618881.00 N 70.35222197 W 149.03470825 600.00 6.29 211.36 532.02 599.02 25.65 26.39 25.67 -23.74 -9.76 0.98 5979335.50 618875.73 N 70.35219860 W 149.03475217 700.00 7.87 212.12 631.26 698.26 37.74 38.72 37.88 -34.22 -16.25 1.58 5979324.92 618869.40 N 70.35216998 W 149.03480487 800.00 9.71 210.54 730.08 797.08 52.74 54.00 53.10 -47.28 -24.18 1.86 5979311.74 618861.69 N 70.35213429 W 149.03486922 900.00 12.00 208.20 828.28 895.28 71.35 72.82 71.92 -63.71 -33.38 2.33 5979295.17 618852.75 N 70.35208941 W 149.03494390 1000.00 14.47 207.26 925.62 992.62 94.05 95.72 94.81 -83.98 -44.01 2.48 5979274.73 618842.44 N 70.35203404 W 149.03503025 1100.00 16.37 206.66 1022.02 1089.02 120.47 122.30 121.40 -107.68 -56.06 1.91 5979250.84 618830.77 N 70.35196928 W 149.03512 MWD+IFR+MS 1140.81 17.35 205.75 1061.07 1128.07 132.24 134.14 133.23 -118.30 -61.28 2.49 5979240.14 618825.72 N 70.35194027 W 149.03517 1236.96 18.14 204.03 1152.65 1219.65 161.46 163.44 162.51 -144.88 -73.61 0.99 5979213.37 618813.82 N 70.35186765 W 149.0352705 1332.09 20.44 204.24 1242.43 1309.43 192.81 194.87 193.90 -173.56 -86.46 2.42 5979184.50 618801.42 N 70.35178931 W 149.03537485 1427.20 22.71 203.35 1330.87 1397.87 227.73 229.84 228.84 -205.56 -100.56 2.41 5979152.28 618787.84 N 70.35170188 W 149.03548929 1523.66 23.93 203.12 1419.45 1486.45 265.86 268.02 266.98 -240.65 -115.62 1.27 5979116.96 618773.33 N 70.35160602 W 149.03561157 1619.60 25.67 201.90 1506.54 1573.54 306.08 308.26 307.17 -277.83 -131.01 1.89 5979079.54 618758.53 N 70.35150445 W 149.03573652 1714.72 29.35 202.27 1590.89 1657.89 349.99 352.19 351.04 -318.53 -147.54 3.87 5979038.59 618742.66 N 70.35139325 W 149.03587067 1810.19 33.92 202.48 1672.15 1739.15 400.02 402.25 401.06 -364.82 -166.60 4.79 5978992.00 618724.34 N 70.35126679 W 149.03602541 1904.53 38.11 203.17 1748.44 1815.44 455.43 457.71 456.50 -415.93 -188.13 4.46 5978940.56 618703.62 N 70.35112716 W 149.03620018 2000.80 38.43 202.63 1824.03 1891.03 514.99 517.34 516.11 -470.86 -211.33 0.48 5978885.28 618681.30 N 70.35097711 W 149.03638852 2095.58 40.51 203.12 1897.19 1964.19 575.18 577.58 576.34 -526.36 -234.75 2.22 5978829.41 618658.76 N 70.35082547 W 149.03657867 2191.16 41.81 203.55 1969.15 2036.15 638.01 640.49 639.24 -584.12 -259.67 1.39 5978771.27 618634.76 N 70.35066768 W 149.03678096 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-217 est 128+15\S-217\S-217\S-217 Generated 11/12/2007 9:10 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longhude Depth Section Departure ft de de ft ft ft ft ft ft ft d 1100 ft ftUS ftUS LLaa.J 1 2383.42 2478.58 2574.39 2668.94 2764.79 2860.89 2955.78 3052.59 3145.17 3243.71 3338.85 3434.93 3530.43 3625.91 3721.68 3816.39 3913.03 4008.65 4103.34 4199.82 4295.25 4369.51 4465.85 4560.11 4655.99 4751.89 4847.88 4942.47 5039.25 5133.87 5230.04 5324.16 5420.39 5515.78 5610.90 5707.47 5803.09 5898.14 5993.79 6089.65 4J.4 1 46.79 45.60 48.29 47.82 47.85 47.98 47.87 47.31 46.97 48.82 48.35 48.17 48.19 48.30 48.34 48.36 49.23 49.12 49.18 48.70 48.85 49.67 49.58 48.44 48.26 47.26 45.93 45.45 44.28 45.68 48.55 49.56 49.20 48.35 48.42 47.13 44.90 44.10 42.84 38.09 LUJ.JB 203.89 203.32 202.66 203.24 202.70 202.08 202.45 202.26 202.24 203.48 203.47 202.97 202.99 203.10 203.28 202.76 204.27 204.37 204.42 203.85 203.45 203.72 204.44 204.85 204.58 204.67 205.66 206.00 205.24 204.22 202.27 197.75 195.52 193.66 194.34 194.88 195.61 197.84 197.20 195.91 LUJ7.40 L I V0.40 I U4.7V ! V / .4.7 ~ vV.cY -V'YJ.JJ -cVV.YV J. i ~ Jai V. v.~.t.i v ~ VvvV.av ~.. v..i.iv~....... . • .t ................... 2105.42 2172.42 773.32 776.02 774.77 -708.26 -314.04 1.47 5978646.29 618582.37 N 70.35032852 W 149.03722230 2171.29 2238.29 841.89 844.69 843.44 -771.19 -341.55 1.32 5978582.94 618555.87 N 70.35015661 W 149.03744554 2236.70 2303.70 911.82 914.69 913.43 -835.64 -368.88 2.85 5978518.08 618529.57 N 70.34998055 W 149.03766740 2299.90 2366.90 982.07 985.02 983.75 -900.40 -396.30 0.67 5978452.90 618503.18 N 70.34980363 W 149.03788996 2364.24 2431.24 1053.05 1056.06 1054.79 -965.81 -424.02 0.42 5978387.06 618476.50 N 70.34962493 W 149.03811500 2428.65 2495.65 1124.32 1127.38 1126.09 -1031.75 -451.19 0.50 5978320.70 618450.39 N 70.34944477 W 149.03833549 2492.23 2559.23 1194.72 1197.82 1196.51 -1096.93 -477.88 0.31 5978255.11 618424.74 N 70.34926669 W 149.03855209 2557.53 2624.53 1266.16 1269.29 1267.97 -1163.04 -505.06 0.60 5978188.58 618398.61 N 70.34908609 W 149.03877274 2620.50 2687.50 1333.99 1337.16 1335.82 -1225.85 -530.76 0.37 5978125.38 618373.91 N 70.34891450 W 149.03898129 2686.57 2753.57 1407.02 1410.26 1408.92 -1293.20 -559.17 2.10 5978057.59 618346.58 N 70.34873048 W 149.03921186 2749.50 2816.50 1478.27 1481.61 1480.27 -1358.65 -587.59 0.49 5977991.71 618319.20 N 70.34855169 W 149.03944 2813.47 2880.47 1549.87 1553.30 1551.96 -1424.53 -615.86 0.43 5977925.39 618291.99 N 70.34837169 W 149.0396719 2877.15 2944.15 1620.97 1624.47 1623.13 -1490.06 -643.64 0.03 5977859.44 618265.25 N 70.34819268 W 149.03989742 2940.73 3007.73 1692.12 1695.70 1694.35 -1555.60 -671.52 0.14 5977793.47 618238.41 N 70.34801362 W 149.04012370 3004.42 3071.42 1763.57 1767.23 1765.88 -1621.35 -699.69 0.15 5977727.28 618211.29 N 70.34783399 W 149.04035227 3067.36 3134.36 1834.26 1838.00 1836.65 -1686.48 -727.36 0.41 5977661.73 618184.66 N 70.34765605 W 149.04057685 3131.02 3198.02 1906.86 1910.70 1909.35 -1753.14 -756.38 1.48 5977594.62 618156.71 N 70.34747392 W 149.04081230 3193.53 3260.53 1979.05 1983.06 1981.70 -1819.08 -786.18 0.14 5977528.22 618127.96 N 70.34729378 W 149.04105411 3255.47 3322.47 2050.50 2054.68 2053.31 -1884.31 -815.76 0.07 5977462.54 618099.42 N 70.34711557 W 149.04129417 3318.84 3385.84 2123.09 2127.43 2126.05 -1950.70 -845.51 0.67 5977395.69 618070.73 N 70.34693419 W 149.04153555 3381.73 3448.73 2194.75 2199.21 2197.83 -2016.45 -874.30 0.35 5977329.50 618042.99 N 70.34675457 W 149.04176919 3430.20 3497.20 2250.93 2255.47 2254.09 -2068.01 -896.81 1.14 5977277.59 618021.30 N 70.34661369 W 149.04195186 3492.60 3559.60 2324.18 2328.87 2327.48 -2135.02 -926.76 0.58 5977210.12 617992.42 N 70.34643063 W 149.04219484 3554.43 3621.43 2395.13 2400.01 2398.62 -2199.68 -956.42 1.25 5977145.00 617963.79 N 70.34625395 W 149.04243556 3618.15 3685.15 2466.57 2471.66 2470.24 -2264.77 -986.38 0.28 5977079.46 617934.87 N 70.34607615 W 149.04267861 3682.62 3749.62 2537.38 2542.66 2541.23 -2329.31 -1015.96 1.05 5977014.46 617906.32 N 70.34589982 W 149.04291864 3748.58 3815.58 2606.87 2612.39 2610.94 -2392.42 -1045.61 1.58 5976950.88 617877.68 N 70.34572737 W 149.04315919 3814.65 3881.65 2674.25 2680.08 2678.57 -2453.35 -1075.10 0.57 5976889.50 617849.16 N 70.34556092 W 149.04339846 3883.25 3950.25 2742.24 2748.35 2746.80 -2514.90 -1104.62 1.33 5976827.49 617820.62 N 70.34539274 W 149.04363 3950.17 4017.17 2808.93 2815.23 2813.67 -2575.65 -1132.59 1.66 5976766.31 617793.62 N 70.34522677 W 149.04386 4015.62 4082.62 2879.30 2885.68 2884.12 -2640.40 -1160.37 3.33 5976701.14 617766.87 N 70.34504989 W 149.04409033 4077.32 4144.32 2950.35 2956.76 2955.03 -2707.17 -1184.67 3.78 5976634.00 617743.64 N 70.34486745 W 149.04428741 4139.97 4206.97 3023.23 3029.80 3027.54 -2777.15 -1205.58 1.80 5976563.70 617723.85 N 70.34467627 W 149.04445703 4202.84 4269.84 3094.60 3101.54 3098.44 -2846.57 -1223.66 1.72 5976494.01 617706.87 N 70.34448661 W 149.04460366 4266.01 4333.01 3165.27 3172.65 3168.64 -2915.57 -1240.86 0.54 5976424.75 617690.77 N 70.34429809 W 149.04474319 4330.91 4397.91 3236.41 3244.16 3239.39 -2984.77 -1258.89 1.40 5976355.28 617673.84 N 70.34410904 W 149.04488945 4397.31 4464.31 3304.93 3312.96 3307.59 -3051.15 -1276.98 2.40 5976288.63 617656.81 N 70.34392770 W 149.04503610 4465.10 4532.10 3371.40 3379.57 3373.85 -3114.94 -1296.14 1.85 5976224.54 617638.67 N 70.34375340 W 149.04519150 4534.52 4601.52 3437.12 3445.38 3439.40 -3177.69 -1315.95 1.40 5976161.49 617619.85 N 70.34358197 W 149.04535220 4607.43 4674.43 3499.17 3507.57 3501.26 -3237.30 -1333.70 5.03 5976101.62 617603.05 N 70.34341913 W 149.04549619 SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-217 est 128+15\S-217\S-217\S-217 Generated 11/12/2007 9:10 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section .Departure ft de de ft ft (ft ft ft ft ft de 1100 ft ftUS ftUS 6184.22 34.83 190.56 4683.50 4750.50 3554.89 3563.74 3556.72 -3291.93 -1346.66 4.81 5976046.79 6280.44 33.44 189.45 4763.14 4830.14 3607.99 3617.73 3609.50 -3345.09 -1356.05 1.58 5975993.49 6376.94 32.57 188.64 4844.07 4911.07 3659.53 3670.29 3660.74 -3397.00 -1364.31 1.01 5975941.46 6472.22 31.02 185.10 4925.06 4992.06 3708.32 3720.48 3709.23 -3446.82 -1370.35 2.54 5975891.56 6567.89 30.42 184.12 5007.30 5074.30 3755.35 3769.35 3755.98 -3495.53 -1374.28 0.82 5975842.80 6663.72 29.98 183.12 5090.12 5157.12 3801.50 3817.55 3801.89 -3543.64 -1377.33 0.70 5975794.65 6759.17 29.97 182.19 5172.81 5239.81 3846.91 3865.24 3847.12 -3591.27 -1379.54 0.49 5975746.99 6855.19 30.27 178.00 5255.87 5322.87 3892.07 3913.41 3892.14 -3639.43 -1379.61 2.21 5975698.84 Last Survey 6951.08 30.80 177.49 5338.46 5405.46 3937.03 3962.13 3937.03 -3688.11 -1377.69 0.62 5975650.20 TD (Projected) 7049.00 30.80 177.49 5422.57 5489.57 3983.21 4012.27 3983.23 -3738.20 -1375.49 0.00 5975600.16 Survey Type: Definitive Survey NOTES: GYD-CT-DMS - ( Gyrodata -cont. drillpipe mis -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correcti on is applied to enhance inclination accuracy. ) l.eaal Description: Northi ng (Y) [ftUS] Easting (X) [ftUS] Surface : 3156 FSL 4566 FEL S35 T12N R12E U M 5979359.39 618885.11 BHL : 4698 FSL 666 FEL S3 T1 1N R12E UM 5975600.16 617569.22 617590.97 N 70.34326988 W 149.04560122 617582.42 N 70.34312462 W 149.04567734 617574.98 N 70.34298281 W 149.04574435 617569.74 N 70.34284671 W 149.04579326 617566.58 N 70.34271363 W 149.04582509 617564.30 N 70.34258221 W 149.04584974 617562.84 N 70.34245207 W 149.04586759 617563.54 N 70.34232051 W 149.04586811 617566.23 N 70.34218752 W 149.04585246 617569.22 N 70.34205068 W 149.04583457 i SurveyEditor Ver SP 2.1 Bld( doc40x_100) S-217 est 128+15\S-217\S-217\S-217 Generated 11/12/2007 9:10 AM Page 3 of 3 w.a: s3m Eae. ,Enuxo°) S•217 MDT Formation Pressures %3rr MOTP~ .v w a (> 2 mdlcp mobility) a.,m Pexa ImwvM a. o. 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Tsu W!!"Mb rrmerM.__ IN.O 11YJ UN I .e~J•ri co MPSR rykpers Sri~s swrea claygg aia h.v. p~aeeue 410Ppe4 FireIN we acre haw a 8516 8028 x1015 559. n,4 B.w 1019 Opvr6 Boeburd 65ee 9oeb NeM na ISau 12W Otl. po..4wuMPSN cykslers he_ OpercA 9oMe NSeM Me4 Iwod s Jsn u MPSR ryheer: angle e t ~ ly~Mbeta Eb l e eml. el w1 + ~ s mx2 bog[ Su5]I 35]tl9 x81u.0 - iii ire ~„14 FFM ww 450 cc balb xN Otl snngk lYlu lulxl 0tlb 9aW mpro H mq ved sengk point YUMe'lrvmeL•ew ksl MPSR Vlm4er f` CI J f c ..Q SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Polaris Well .....................: 5-217 API number ...............: 50-029-23362-00 Engineer .................: Franco/Minnich/Hill COUNTY :..................: North Slope Borough STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 38.58 ft N/A (Topdrive) 67.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 200.41 degrees 9-Oct-2007 07:46:11 Page 1 of 4 Spud date ................: 30-Sep-07 Last survey date.........: 09-Oct-07 Total accepted surveys...: 75 MD of first survey.......: 0.00 ft MD of last survey........: 7049.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 30-Sep-2007 Magnetic field strength..: 57646.53 GAMA Magnetic dec (+E/W-).....: 23.44 degrees Magnetic dip .............: 80.91 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.68 meal Reference H ..............: 57646.50 GAMA Reference Dip ............: 80.91 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.52 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 9-Oct-2007 07:46:11 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 203.78 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.47 158.18 100.00 100.00 0.30 -0.38 0.15 0.41 158.18 0.47 BP _GYD_ CT_DMS 3 200.00 0.69 167.74 100.00 199.99 1.11 -1.35 0.43 1.42 162.23 0.24 BP _GYD_ CT_DMS 4 300.00 1.89 188.82 100.00 299.97 3.24 -3.57 0.31 3.58 175.07 1.27 BP _GYD_ CT_DMS 5 400.00 3.66 196.81 100.00 399.85 8.04 -8.25 -0.87 8.30 186.01 1.81 BP _GYD_ CT_DMS • 6 500.00 5.33 213.43 100.00 499.54 15.75 -15.19 -4.35 15.80 195.99 2.10 BP _GYD_ CT_DMS 7 600.00 6.29 211.36 100.00 599.02 25.65 -23.74 -9.76 25.67 202.35 0.98 BP _GYD_ CT_DMS 8 700.00 7.87 212.12 100.00 698.26 37.74 -34.22 -16.25 37.88 205.41 1.58 BP _GYD_ CT_DMS 9 800.00 9.71 210.54 100.00 797.08 52.74 -47.28 -24.18 53.10 207.08 1.86 BP _GYD_ CT_DMS 10 900.00 12.00 208.20 100.00 895.28 71.35 -63.71 -33.38 71.92 207.65 2.33 BP _GYD_ CT_DMS 11 1000.00 14.47 207.26 100.00 992.62 94.05 -83.98 -44.01 94.81 207.66 2.48 BP _GYD_ CT_DMS 12 1100.00 16.37 206.66 100.00 1089.02 120.47 -107.68 -56.06 121.40 207.50 1.91 BP _GYD_ CT_DMS 13 1140.81 17.35 205.75 40.81 1128.07 132.24 -118.30 -61.28 133.23 207.39 2.49 BP _MWD_ IFR_MS 14 1236.96 18.14 204.03 96.15 1219.65 161.46 -144.88 -73.61 162.51 206.93 0.99 BP _MWD_ IFR_MS 15 1332.09 20.44 204.24 95.13 1309.43 192.81 -173.56 -86.46 193.90 206.48 2.42 BP _MWD_ IFR_MS 16 1427.20 22.71 203.35 95.11 1397.87 227.73 -205.56 -100.56 228.84 206.07 2.41 BP _MWD_ IFR_MS 17 1523.66 23.93 203.12 96.46 1486.45 265.86 -240.65 -115.62 266.98 205.66 1.27 BP _MWD_ IFR_MS 18 19 1619.60 1714.72 25.67 29.35 201.90 202.27 95.94 95.12 1573.54 1657.89 306.08 349.99 -277.83 -318.53 -131.01 -147.54 307.17 351.04 205.25 204.85 1.89 3.87 BP BP _MWD_ _MWD_ IFR_MS IFR_MS • 20 1810.19 33.92 202.48 95.47 1739.15 400.02 -364.82 -166.60 401.06 204.54 4.79 BP _MWD_ IFR_MS 21 1904.53 38.11 203.17 94.34 1815.44 455.43 -415.93 -188.13 456.50 204.34 4.46 BP _MWD_ IFR_MS 22 2000.80 38.43 202.63 96.27 1891.03 514.99 -470.86 -211.33 516.11 204.17 0.48 BP _MWD_ IFR_MS 23 2095.58 40.51 203.12 94.78 1964.19 575.18 -526.36 -234.75 576.34 204.04 2.22 BP _MWD_ IFR_MS 24 2191.16 41.81 203.55 95.58 2036.15 638.01 -584.12 -259.67 639.24 203.97 1.39 BP _MWD_ IFR_MS 25 2288.31 45.41 203.58 97.15 2106.48 704.90 -645.53 -286.46 706.24 203.93 3.71 BP _MWD_ IFR_MS 26 2383.42 46.79 203.89 95.11 2172.42 773.32 -708.26 -314.04 774.77 203.91 1.47 BP _MWD_ IFR_MS 27 2478.58 45.60 203.32 95.16 2238.29 841.89 -771.19 -341.55 843.44 203.89 1.32 BP _MWD_ IFR_MS 28 2574.39 48.29 202.66 95.81 2303.70 911.82 -835.64 -368.88 913.43 203.82 2.85 BP_MWD_ IFR_MS 29 2668.94 47.82 203.24 94.55 2366.90 982.07 -900.40 -396.30 983.75 203.76 0.67 BP _MWD_ IFR_MS 30 2764.79 47.85 202.70 95.85 2431.24 1053.05 -965.81 -424.02 1054.79 203.70 0.42 BP_MWD_IFR_MS SCHLUMBERGER Survey Report 9-Oct-2007 07:46:11 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (f t) (deg) 100f) type (deg) 31 2860.89 47.98 202.08 96.10 2495.65 1124.32 -1031.75 -451.19 1126.09 203.62 0.50 BP _MWD_ IFR _MS 32 2955.78 47.87 202.45 94.89 2559.23 1194.72 -1096.93 -477.88 1196.51 203.54 0.31 BP _MWD_ IFR _MS 33 3052.59 47.31 202.26 96.81 2624.52 1266.16 -1163.04 -505.06 1267.97 203.47 0.60 BP _MWD_ IFR _MS 34 3145.17 46.97 202.24 92.58 2687.50 1333.99 -1225.85 -530.76 1335.82 203.41 0.37 BP _MWD_ IFR _MS 35 3243.71 48.82 203.48 98.54 2753.57 1407.02 -1293.20 -559.17 1408.92 203.38 2.10 BP _MWD_ IFR _MS 36 3338.85 48.35 203.47 95.14 2816.50 1478.27 -1358.65 -587.59 1480.27 203.39 0.49 BP _MWD_ IFR _MS 37 3434.93 48.17 202.97 96.08 2880.47 1549.87 -1424.53 -615.86 1551.96 203.38 0.43 BP _MWD_ IFR _MS 38 3530.43 48.19 202.99 95.50 2944.15 1620.97 -1490.06 -643.64 1623.13 203.36 0.03 BP _MWD_ IFR _MS 39 3625.91 48.30 203.10 95.48 3007.73 1692.12 -1555.60 -671.52 1694.35 203.35 0.14 BP _MWD_ IFR _MS 40 3721.68 48.34 203.28 95.77 3071.42 1763.57 -1621.35 -699.69 1765.88 203.34 0.15 BP _MWD_ IFR _MS 41 3816.39 48.36 202.76 94.71 3134.36 1834.26 -1686.48 -727.36 1836.65 203.33 0.41 BP _MWD_ IFR _MS 42 3913.03 49.23 204.27 96.64 3198.02 190b.86 -1753.14 -756.38 1909.35 203.34 1.48 BP _MWD_ IFR _MS 43 4008.65 49.12 204.37 95.62 3260.53 1979.05 -1819.08 -786.18 1981.70 203.37 0.14 BP _MWD_ IFR _MS 44 4103.34 49.18 204.42 94.69 3322.47 2050.50 -1884.31 -815.76 2053.31 203.41 0.07 BP _MWD_ IFR _MS 45 4199.82 48.70 203.85 96.48 3385.84 2123.09 -1950.70 -845.51 2126.05 203.43 0.67 BP _MWD_ IFR _MS 46 47 4295.25 4369.51 48.85 49.67 203.45 203.72 95.43 74.26 3448.73 3497.20 2194.75 2250.93 -2016.45 -2068.01 -874.30 -896.81 2197.83 2254.09 203.44 203.44 0.35 1.14 BP BP _MWD_ _MWD_ IFR IFR _MS _MS • 48 4465.85 49.58 204.44 96.34 3559.60 2324.18 -2135.02 -926.76 2327.48 203.46 0.58 BP _MWD_ IFR _MS 49 4560.11 48.44 204.85 94.26 3621.43 2395.13 -2199.68 -956.42 2398.62 203.50 1.25 BP _MWD_ IFR _MS 50 4655.99 48.26 204.58 95.88 3685.15 2466.57 -2264.77 -986.38 2470.24 203.53 0.28 BP _MWD_ IFR _MS 51 4751.89 47.26 204.67 95.90 3749.62 2537.38 -2329.31 -1015.96 2541.23 203.57 1.05 BP _MWD_ IFR _MS 52 4847.88 45.93 205.66 95.99 3815.58 2606.87 -2392.42 -1045.61 2610.94 203.61 1.58 BP _MWD_ IFR _MS 53 4942.47 45.45 206.00 94.59 3881.65 2674.25 -2453.35 -1075.10 2678.57 203.66 0.57 BP _MWD_ IFR _MS 54 5039.25 44.28 205.24 96.78 3950.24 2742.24 -2514.90 -1104.62 2746.80 203.71 1.33 BP _MWD_ IFR _MS 55 5133.87 45.68 204.22 94.62 4017.17 2808.93 -2575.65 -1132.59 2813.67 203.74 1.66 BP _MWD_ IFR _MS 56 5230.04 48.55 202.27 96.17 4082.62 2879.30 -2640.40 -1160.37 2884.12 203.72 3.33 BP _MWD_ IFR _MS 57 5324.16 49.56 197.75 94.12 4144.31 2950.35 -2707.17 -1184.67 2955.03 203.63 3.78 BP _MWD_ IFR _MS 58 5420.39 49.20 195.52 96.23 4206.97 3023.23 -2777.15 -1205.58 3027.54 203.47 1.80 BP _MWD_ IFR _MS 59 5515.78 48.35 193.66 95.39 4269.83 3094.60 -2846.57 -1223.66 3098.44 203.26 1.72 BP_MWD_IFR_MS 60 5610.90 48.42 194.34 95.12 4333.01 3165.27 -2915.57 -1240.86 3168.64 203.05 0.54 BP_MWD_IFR_MS SCHLUMBERGER Survey Report 9-Oct-2007 07:46:11 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Too l # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) -------- (deg) ------- 100f) ----- - type ---- (deg) ------ 61 5707.47 47.13 194.88 96.57 4397.90 3236.41 -2984.77 -1258.90 3239.39 202.87 1.40 BP _MWD_ IFR _MS 62 5803.09 44.90 195.61 95.62 4464.31 3304.93 -3051.15 -1276.98 3307.59 202.71 2.40 BP _MWD_ IFR _MS 63 5898.14 44.10 197.84 95.05 4532.10 3371.40 -3114.94 -1296.14 3373.85 202.59 1.85 BP _MWD_ IFR _MS 64 5993.79 42.84 197.20 95.65 4601.52 3437.12 -3177.69 -1315.95 3439.40 202.50 1.40 BP _MWD_ IFR _MS 65 6089.65 38.09 195.91 95.86 4674.43 3499.17 -3237.30 -1333.70 3501.27 .202.39 5.03 BP _MWD_ IFR _MS 66 6184.22 34.83 190.56 94.57 4750.50 3554.89 -3291.93 -1346.66 3556.72 202.25 4.81 BP _MWD_ IFR _MS 67 6280.44 33.44 189.45 96.22 4830.14 3607.99 -3345.09 -1356.05 3609.50 202.07 1.58 BP _MWD_ IFR _MS 68 6376.94 32.57 188.64 96.50 4911.07 3659.53 -3397.00 -1364.31 3660.74 201.88 1.01 BP _MWD_ IFR _MS 69 6472.22 31.02 185.10 95.28 4992.06 3708.32 -3446.82 -1370.35 3709.23 201.68 2.54 BP _MWD_ IFR _MS 70 6567.89 30.42 184.12 95.67 5074.30 3755.35 -3495.53 -1374.28 3755.98 201.46 0.82 BP _MWD_ IFR _MS 71 6663.72 29.98 183.12 95.83 5157.12 3801.50 -3543.64 -1377.33 3801.89 201.24 0.70 BP _MWD_ IFR _MS 72 6759.17 29.97 182.19 95.45 5239.81 3846.91 -3591.27 -1379.54 3847.13 201.01 0.49 BP _MWD_ IFR _MS 73 6855.19 30.27 178.00 96.02 5322.87 3892.07 -3639.43 -1379.61 3892.14 200.76 2.21 BP _MWD_ IFR _MS 74 6951.08 30.80 177.49 95.89 5405.46 3937.03 -3688.11 -1377.69 3937.03 200.48 0.62 BP _MWD_ IFR _MS 75 7049.00 30.80 177.49 97.92 5489.57 3983.21 -3738.20 -1375.49 3983.23 200.20 0.00 Projected to TD • [(0)2007 IDEAL ID12_OC_13] • ~ ~ ~ Drilling & Measurements MWD/lWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken (AOGCC) Well No S-217 Date Dispatched: 11-Oct-07 Installation/Rig Nabors 9ES Dispatched By: F. Medina LWD Lag Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Jonnson Received By: I BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-11 /,~ d ~~j~? 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~hp.com ~4?-cSq~ gy data ~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 October 5, 2007 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: S Pad, Welt #S-217 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~~~ ~ Rob Shoup Z~~ North American Regional Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation ~ • gy data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP S Pad #S-217 Prudhoe Bay, AK AK1007G_547 01 Oct 2007 Serving the Worldwide Energy Industry with Precision Survey Instrumentation odd?- ~ °~~~ A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: S-Pad Well: S-217, Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1007G 547 Run Date: 02 Oct 2007 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.352263 deg. N Longitude: 149.034673 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location n U • Horizontal Coordinates Calculated from Well Head Location BP Exploration (Alaska) Inc. Lease: S-Pad Well: S-217 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1007G S47 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE DOGLEG VERTICAL CLOSURE BEARING SEVERITY DEPTH DIST. AZIMUTH deg. min. deg./ feet feet deg. 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0 - 1100 FT. RATE GYROSCOPIC MULTISHOT SURVEY ALL SURVEY DEPTHS REFERENCED FROM NABORS #9ES ROTARY TABLE AT 67.0 FT. AMSL 100.00 0.47 158.18 S 21 49 E 200.00 0.69 167.74 S 12 1 S E 300.00 1.89 188.82 S 8 49 W 400.00 3.66 196.81 S 16 49 W 500.00 5.33 213.43 S 33 26 W 600.00 6.29 211.36 S 31 22 W 700.00. 7.87 212.12 S 32 7 W 800.00 9.71 210.54 S 30 33 W 900.00 12.00 208.20 S 28 12 W 1000.00 14.47 207.26 S 27 1 S W 1100.00 16.37 206.66 S 26 39 W Final Station Closure: Distance: 121.40 ft Az: 207.50 deg. HORIZONTAL COORDINATES feet 0.00 N 0.00 E 0.47 100.00 0.4 158.2 0.38 S O.1S E 0.24 199.99 1.4 162.2 1.35 S 0.43 E 1.27 299.97 3.6 175.0 3.57 S 0.31 E 1.80 399.85 8.3 186.0 8.25 S 0.86 W 2.10 499.54 1 S.8 196.0 15.18 S 4.34 W 0.99 599.02 25.7 202.3 23.74 S 9.75 W 1.58 698.26 37.9 205.4 34.21 S 16.25 W 1.86 797.08 53.1 207.1 47.28 S 24.17 W 2.33 895.28 71.9 207.6 63.71 S 33.37 W 2.48 992.62 94.8 207.7 83.98 S 44.01 W 1.91 1089.01 121.4 207.5 107.69 S 56.06 W • 2 BP Exploration (Alaska) Inc. Well: S-Pad S-217 Location: Nabors #9ES, Prudhoe Bay, Alaska 0 -1C -2C -3C -4C -5C z -60 O z -70 -80 -90 -100 -110 Inrun Gyrodata r AK1007G_547 DEFINITIVE BOTT LOCA MD: M HOLE ED 100.00 i -55 -50 -4 5 -4 0 -3 5 -3 0 -25 -20 -15 -~ o -s n FASTING (ft) BP Exploration (Alaska) Well: S-Pad 5-217 Location: Nabors #9ES, 10 Inc. Prudhoe Bay, Alaska Inrun Gyrodata - AK1007G_547 DEFINITIVE B L M TTOM HO CATED :1100.0 E i ~ ~ 10 0 20 0 30 0 40 0 50 0 60 0 70 0 80 0 90 0 10 00 11 00 12 00 0 • MEASURED DEPTH (ft) BP Exploration (Alaska) Inc. - Well: S-Pad 5-217 Location: Nabors #9E5. Prudhoe. Bav. Alaska 16 Inrun Gyrodata - AK1007G_547 DEFINITIVE )GATED D: 1100 00 14 12 10 z 0 Q z -., J U Z 6 CJ • 4 Z n 100 200 300 400 500 600 700 800 900 1000 1100 1200 MEASURED DEPTH (ft) MEMQRANDUM TO: Jim Regg P. L Supervisor • State of Alaska Alaska Oii and Gas Conservation Commission DATE: October 5, 2007 FROM: Lou Grimaldi SUBJECT: Top Job on Surface casing Petroleum Inspector BP Exploration Weld 5-2171 Prudhoe Bay Field PTD# 207-0950 October 5, 2007: I witnessed the running of 1 %4" CS Hydril pipe and "Top Job" cementing of the 9 5/8" surface casing on BP Exploration's well # S-2171 in the Prudhoe Bay Field. I had received a call earlier in the day from Tom Angles, Nabors 9-ES who reported they had failed to get cement retums to surface. They had opened the "Tam Port Collar" and lost aH retums. I arrived at the rig and watched them run 1 %" CS Hydril pipe to 394' RKB (KB 28.4') where it fetched up hard and could not be worked down any further. 10 Bbl's of flush was pumped followed by 148 Bbl's of 10.4 "Deep Cre#e" was pumped with full mud retums but no cement was observed to surface. The 1 !was pulled to stand-by for more cemen# to be brough# out #o location. I left with instructions to tag cement and finish filling the annulus #o surface. I spoke with Tom Angles the following afternoon who reported that they pumped another 90 Bbl's of "Deep Crete" followed by an additional 20 Bbl's of "Arctic Set Lite". Mr. Angles reported that good cement retums were observed at surface. Attachments: None Confidential Top Job PBU S-2171 ~0-05-07 LG (2).doc o ~ ~ o a SARAH PAUN, GOVERNOR taalca'~~ OIL ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSER~A~'I011T CO1rII~iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, 5-217i BP Exploration Alaska, Inc. Permit No: 207-095 Surface Location: 3156' FSL, 4565' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 578' FNL, 680' FEL, SEC. 03, T11N, R12E, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincere Dan T. Seamount Commissioner DATED this .~..~ day of July, 2007 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ h'~,~ PERMIT TO DRILL 20 AAC 25.005 :5.!~..:~ 1 2007 ~• ~ a ~~~sr~~. Commission 1 a. Type of work ®Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 a Specify if well is proposed :~" ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: S-2171 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7067 TVD 5502 12. Field /Pool(s): Prudhoe Bay Field /Polaris Pool 4a. Location of Well (Governmental Section): Surface: 3156' FSL 4565' FEL SEC 35 T12N UM (As-Staked) R12E 7. Property Designation: ADL 028261 , , . , , , Top of Productive Horizon: 4326' FNL, 744' FEL, SEC. 03, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 20, 2007 Total Depth: 578' FNL, 680' FEL, SEC. 03, T11 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,411' 4b. Location of Well (State Base Plane Coordinates): Surface: x-618885 y-5979359 Zone-ASP4 10. KB Elevation Plan (Height above GL): 66.7 feet 15. Distance to Nearest Well Within Pool: 419' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 47.55 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2489 Surface: 1939 18. asln P ram: S eifications To - Settin De th - o ttom uantit . of Cem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 108' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 4347' Surface Surface 4347' 3494' 646 sx AS Lite 472 sx Class'G' 8-3/4" 7" 26# L-80 TC-II 148' Surface Surface 6148' 4717' See Be! w 8-3/4" 7" 26# L-80 BTC-M 919' 6148' 4717' 7067' 5502' 305 sx Class 'G' 18. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVb (ft): Junk (measured): Casing Length ize Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name o Kolstad _ ,..._..,.. Si nature Contact Brandon Peltier, 564-5912 Title Drilling Engineer Scott Kolstad, 564-5347 Prepared By Name/Number: Phone 564-5347 Date 07 fo/~ Terrie Hubble, 564-4628 Commission Use 0~l Permit To Drill Number: ~~95D API Number: 50- Oo?9 0?.336a7.O~ DO Permit Approval See cover letter for Date: 7 other re uirements Conditions of Approval: ~sfcQ9tCr ~[t°'~ Ctc~fl`1E ~`~y +~SUC~CaC.E ~~ ~ Li~OP c7~AQCaS.~~SCh~C,~LI +` If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: "~~5t ~~ '~~-5~ G~ V~~jr.~~ Samples Req'd: ^ es ~No Mud Log Req'd: ^~es L'!J No M ~T~ CS~*MQ,~-~C ``~ ~..~~ `p~ HZS Measures: Yes ^ No Directional Survey Req'd: Ld Yes ^ No Other. v~~~~.A:t2 Cs~.~?6~S \^ G-CC~~ ~''~ ~ ~ ~~ ~'~~. Date APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ /~ I ~- - ! ~~T~~ubmit In Duplicate t~,.J, N A L • • Well Name: S-217i Drill and Complete Plan Summary T e of Well (service / roducer / in'ector): Injector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface As-Staked 618885 5979359 na T12N R12E 35 3156 4565 T tl: To OBa 617555 5971855 -4970 T11N R12E 3 953 744 T t2: To 617555 5975755 -5155 T11N R12E 3 4853 677 BHL 617555 5975604 -5435 T11N R12E 3 4702 680 AFE Number: PLDSM1090 API Number: TBD Estimated Start Date: July 20, 2007 Operating days: 16 Rig: Nabors 9ES TMD 7,067' TVD rkb: 5,502' RKB/GL 28.5'/38.2' RTE 66.7' Well Design: USH Grassroots Schrader Bluff Injector 3-%z",9.2#, L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Well Information: Estimated BHP: 2489 psi (8.7 p EMW) at 5502' TVD Estimated BHT: 105 de Fat 5502' TVD Formation Markers: Est. Est. Commercial Formation Formation Uncertainty Hydrocarbon Est. Pore Est. Pore Tops Tops Bearing Press. Press. Formation (MD) (TVDss) (feet) (Yes/No) (Psi) (pp8 EMW) Gl 330 +/-50' No -ice 149 8.7 SV6 1696 1545 +/-50' No -ice 695 8.7 Base Permafrost 2071 1875 +/-50' No 844 8.7 +/- 150' M.D. - see Fault Section Fault 1 2200 for details SV5 (faulted to) 2200 +/-50' Poss. H drates 990 8.7 SV4 2829 2405 +/-50' Poss. H drates 1082 8.7 SV3 2710 +/-50' Poss. H drates 1220 8.7 SV2 3490 2850 +/-50' Poss. H drates 1280 8.6 SVl 3974 3175 +/-50' Poss. H drates 1429 8.7 UG4 4465 3507 +/-50' Thin Coal 1600 8.8 Heavy Oil: 3535- UG4A 4514 3540 +/-50' 3750' SS 1610 8.7 Heavy Oil: 3855- 3975' SS; 4060- UG3 4973 3850 +/-50' 4190' SS; thin coals 1765 8.8 Heavy Oil: 4500- UGl 5765 4385 +/-50' 4620' SS 2010 8.8 S-217i Permit to Drill Page 1 • • UG_Ma 6148 4650 +/- 25' Heavy Oil: 4650- 4685' SS 2120 8.8 UG Mbl 6213 4700 +/- 25' Heavy Oil: 4700- 4735' SS 2160 8.8 UG Mb2 6277 4750 +/- 25' Heavy Oil: 4750- . 4775' SS 2180 8.8 UG Mc 6332 4795 +/- 25' No -wet 2200 8.8 SB Na 6399 4850 +/- 25' No -wet 2200 8.7 SB Nb 6419 4867 +/- 25' Yes 2190 8.7 SB Nc 6452 4895 +/- 25' Yes 2200 8.6 SB_Ne 6460 4902 +/- 25' Yes 2205 8.7 SB_OA 6538 4970 +/- 25' Yes 2170- 2210 8.4-8.6 SB_OBa 6595 5020 +/- 25' Yes 2100- 2160 8.0-8.3 5B OBb 6634 5055 +/- 25' Yes 2200- 2250 8.4-8.6 SB_OBe 6691 5105 +/- 25' Yes 2220- 2290 8.4-8.6 SB OBd 6748 5155 +/- 25' Yes 2200- 2270 8.2-8.5 SB OBe 6816 5215 +/- 25' Yes 2321 8.6 SB OBf 6873 5265 +/- 25' Yes 2343 8.6 Base SB OBf 6913 5300 +/- 25' Yes 2359 8.6 T.D. in Colville Shale 7066 5435 No -wet 8.7 Wells within a i/a mile of this infection well, scanned from the ton of the reservoir to TD Well Name Dist, Ft. Annulus Integrity Comments S-216 419' Offset injector. Bond log shows fairly good cement quality along and above ~'"~~~ ~~p,,, ~ Schrader Bluff. Top of cement found at 7680 MD (4683 TVD) in lower rv l UG1 i t a ~ ~~.,~ . n e a S-215 1221' Offset injector. Bond log shows good cement quality along and above ~S~ .~„~ ~~ ~ ^ Schrader Bluff. Top of cement calculated to be at 3413' MD (3162' TVD) i h SV2 i l l ~~ n t e ower nterva . Casing~'I'ubin~ Program: Hole Size Csg/ Tbg O.D. Wt1Ft Grade Connection Length (ft) Top MD/TVD RTE (ft) Btm MD/TVD RTE (ft) 42" Insulated 20" 21.5.5 A-53 WLD 108 GL 108/108 12-1/a" 9-5/8" 40 L-80 BTC 4347 GL 4347/3494 8?/a" 7" 26 L-80 TC-II 6148 GL 6148/4717 8?/a" 7" 26 L-80 BTC-M 919 6148/4717 7067/5502 Tubin 3-1/z" 9.2 L-80 TC-II 6845 GL 6845/5244 Note: Top roduction packer within 200' MD of to erforation S-217i Permit to Drill Page 2 • ~ Directional: Directional Plan: Schlumberger Feasibility Study P1 (Ref Elev: 67') KOP: 300' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference anti-collision re ort Survey Pro ram: GYD-GC-SS (900'), MWD (2300'), MWD + IFR + MS (7076') Maximum Hole An le: 47.55 de rees Distance to Nearest Pro ert Line: 16,411' from PBU boundar Distance to Nearest Well in Pool: 419' S-216 Mud Program: 12-1/a" Surface Hole Mud Pro erties S ud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-2071' (BPRF) 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 2071'-4346' (SV 1) 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 4346'-7067' (OBf Base) 8.8-9.0 8-14 18-24 9.0-9.5 4 - 7 < 15 Surve and Lo in Pro ram: 12-1/a" Hole Section: Surface G ro until MWD surve s are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sam le as re uired b well site Geolo ist MWD /LWD: GR/RES/ Azi-Dens/Neu/PWD real time O en Hole: Drill i e conve ed MDT Cased Hole: USIT in rimar de th control mode. Lo from PBTD to surface. Cement Calculations: Casin Size Surface Casin - 9-5/g" 401b/ft L-80 BTC -Sin le Sta e Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface. Tail: Open hole volume + 40% excess + 80' shoe track. TOC 1000' MD above shoe (3346' MD). Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: Wash None S acer 70 bbls of MudPush II wei hted to 10.3 Lead 510 bbls (646 sks) 10.71b/ al Arctic Set Lite cement - 4.44 cuft/sk Tail 84 bbls 1472 sksl 15.8 lb/eal Class G + Durastone - 1.15 cuft/sk Temp I BHST ~ 65° F from SOR S-217i Permit to Drill Page 3 • • Casin Size Intermediate Casin - 7" 26 lb/ft L-80 BTC-M x TC-II -Sin le Sta e Basis Lead: None Tail: O en hole volume + 30% excess + 80' shoe track. TOC at 5346' MD, which is 1000' below the surface shoe. Fluid Sequence and This cement job is planned for one stage. If two stages are required, 12.5 ppg Lite Crete will be Volume: used as the lead and the TOC will be at the same depth as for one stage. 15` Sta e Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 10.3-Ib/ al Lead None Tail 63 bbl (305 sks) 15.8 nae Class G cement + Latex - 1..16 cuft/sk Temp I BHST ~ 105° F from SOR Surface and Anti-Collision Issues: Surface Shut-in Wells: The closest existing surface wells are S-16 (30' away), S-126i (15' away), and S-11 (15' away). Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. S-217i Permit to Drill Page 4 i • Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. A function pressure test of the casin~ams is required after changing the casin r~ Anticipated surface pressures will not exceed 3,000psi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1,580 psi - SV 1 (8.7 ppg EMW @ 3494' TVD) 1,231 psi -Based on a full column of gas @ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Intermediate Section Kick Tolerance and Integrity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2489 psi - OBf Base (8.7 ppg EMW @ 5502' TVD) • Maximum surface pressure: 1,939 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: 4,000 psi surface pressure test • Integrity Test - 8-3/4" hole: LOT 20' - SO' from 9-5/8" shoe • .Kick Tolerance: 25.9 bbl KT with a 9.0 ppg mud and a 10.2 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. ~'' S-217i Permit to Drill Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control /Reservoir Pressures: a. The Schrader Bluff sands are expected to be pressured at 8.0-8.6 ppg EMW. 2. Hydrates and Shallow gas: a. Gas hydrates and/or free gas may be present in the SVS thru SV 1 surface hole interval below base Permafrost. Use standard operating procedures for hydrates. Set surface casing below deepest SV 1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. 3. Running Gravels: a. Unconsolidated sand, gravel, & cobbles and thawing Permafrost could impede well angle build and casing running through Permafrost. Keep moderate to low build angles until out of Permafrost section. Keep flow rates low. "Obstructions" including wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See S Pad Data Sheet for details. 4. Lost Circulation /Breathing: a. Penetration of fault in SVS surface hole interval. Wellplan penetrates fault at a moderate angle to move thru the fault and away from it. b. Pressure depletion of OA, OBa, OBb, OBc, and OBd zones produced in offset well S-213A to as low as 8.0 Ppg• c. Lost circulation potential if open 5-216 hydraulic fractures are encountered. 5. Kick Tolerance /Integrity Testing: a. Production Section Kick Tolerance and Integrity Testing i. Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9-5/8" shoe ii. Kick Tolerance: 25.9 bbl KT with a 9.0 ppg mud and a 10.2 ppg LOT 6. Stuck Pipe a. There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. 7. Hydrogen Sulfide a. S Pad is not designated as an HZS site, however Standard Operating Procedures for HZS precautions should be followed at all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Well Name H25 Level Date of Readin #1 Closest SHL Well H2S Level S-17 50 m 3/20/2007 #2 Closest SHL Well H2S Level S-18 20 m 1119/200b #1 Closest BHL Well H2S Level S-213A 50 m 8/14/2006 #2 Closest BHL Well H2S Level S-213A 10 m 5/5/2006 8. Faults a. There is a low risk of losses incurred when crossing the fault Formation Where Encounter Fault MD Intersect tvdss Est. Throw Throw Direction Uncertaint Fault #1 -SVS 2529' -2200 -80' West +/-100' M.D. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION S-2171 Permit to Drill Page 6 • • 5-217i -Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-t/a" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. Conduct a short trip at the BPRF. The actual surface hole TD will be below the top of the SV1 sands. CBU, short trip to previous ST point, RIH to TD, CBS, then POOH and lay down BHA. 3. Run and cement the 9 5/8", 40.0 lb/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency. Use Durastone in the last 15 bbls of tail cement. At plug bump, test the 9 5/g" casing to 3,500 psi for 30 minutes. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to 4,000 psi / 2500 psi annular. PU 4" DP as needed. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9-5/8" shoe and perform LOT. 6. Drill ahead to Production hole Target TD (below OBf base). Circulate one BU, back-ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 7. MU Schlumberger DP conveyed MDT. Collect 5 O-Sand oil samples and up to 30 O, N, and M Sands pressure samples. POOH. Make DP clean our run if necessary. 8. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 9. PU DPC guns and RIH w/ ~ 140' of 4.5" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR/CCL for gun correlation. 10. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, OBc, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-'/z", 9.2#, L-80, TCII completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OA perfs. 14. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the tree with hydraulic valve to 5,000 psi. 16. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-~/z" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. Replace the DCR shear valve with a dummy GLV. Pull dummy valves in injection mandrels and replace with injection valves. 2. Pull VR plug. 3. Install wellhouse and flowlines. S-2171 Permit to Drill Page 7 by Schlumherger S-217 (P1) Proposal Report Date: April 26, 2007 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski CIieM: BP Exploration Alaska Vertical Section Azimuth: 200.412° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA S-PAD / S-217 ~~ Vertical Section Origin: ~y TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: Borehole: Plan 5-217 (216-15) ~~~~~~~'i~ Plan S-217 TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: 67.00 ft relative to MSL 38.50 ft relative to MSL l1WIlAPg1: 50029 Magnetic Declination: 23.679° Survey Name 1 Date: S•217 (P1) /April 26, 2007 Total Field Strength: 57653.087 nT Tort 1 AHD 1 DDI 1 ERD ratio: 73.243° 14009.06 ft 15.577 10.729 Magnetic Dip: 80.949° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: August 26, 2007 Location LaUlong: N 70.35226239, W 149.03467387 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5979359.000 RUS, E 618885.000 ftUS North Reference: True North Grid Convergence Angle: +0.90913231 ° 7ota1 Corr Mag North a True North: +23.679° Grid Scale Factor: 0.99991606 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longftude Depth Section Tool Face Difficulty R de de R R R R R de de 1100 R Index RUS RUS RIC „U.UU u.w cVa.ra -or.uu v.UV u.uu u.VV u.vu --- V.VV U.UV by/y39y.UU b725tS25~.UU N /U.39ZZtlZ3`J VV 14y.U346/3t3/ KOP Bid 1.5/100 300.00 0.00 203.78 233.00 300.00 0.00 0.00 0.00 HS 0.00 0.00 5979359.00 618885.00 N 70 .35226239 W 149.03467387 400.00 1.50 203.78 332.99 399.99 1.31 -1.20 -0.53 HS 1.50 0.29 5979357.79 618884.49 N 70 .35225912 W 149.03467816 500.00 3.00 203.78 432.91 499.91 5.23 -4.79 -2.11 H5 1.50 1.20 5979354.18 618882.97 N 70 .35224931 W 149.03469101 600.00 4.50 203.78 532.69 599.69 11.75 -10.78 -4.75 HS 1.50 1.72 5979348.15 618880.42 N 70 .35223296 W 149.03471242 Crv 2.5/100 700.00 6.00 203.78 632.27 699.27 20.89 -19.15 -8.44 H5 1.50 2.10 5979339.72 618876.87 N 70 .35221008 W 149.03474237 800.00 8.50 203.78 731.46 798.46 33.49 -30.70 -13.53 HS 2.50 2.46 5979328.10 618871.96 N 70 .35217854 W 149.03478368 900.00 11.00 203.78 830.01 897.01 50.39 -46.19 -20.35 HS 2.50 2.75 5979312.50 618865.38 N 70. 35213620 W 149.03483912 1000.00 13.50 203.78 927.73 994.73 71.57 -65.61 -28.91 HS 2.50 2.99 5979292.95 618857.14 N 70. 35208316 W 149.03490857 1100.00 16.00 203.78 1024.42 1091.42 96.98 -88.90 -39.17 HS 2.50 3.19 5979269.49 618847.24 N 70. 35201952 W 149.03499191 1200.00 18.50 203.78 1119.92 1186.92 126.58 -116.04 -51.13 HS 2.50 3.38 5979242.18 618835.72 N 70. 35194539 W 149.035088 1300.00 21.00 203.78 1214.03 1281.03 160.31 -146.96 -64.76 HS 2.50 3.53 5979211.05 618822.59 N 70. 35186092 W 149.035199 1400.00 23.50 203.78 1306.57 1373.57 198.11 -181.61 -80.02 HS 2.50 3.68 5979176.16 618807.88 N 70. 35176626 W 149.03532353 1500.00 26.00 203.78 1397.38 1464.38 239.90 -219.91 -96.90 HS 2.50 3.81 5979137.60 618791.61 N 70. 35166161 W 149.03546057 1600.00 28.50 203.78 1486.28 1553.28 285.61 -261.81 -115.36 HS 2.50 3.92 5979095.41 618773.81 N 70. 35154715 W 149.03561044 SV6 ~ 1696.40 30.91 203.78 1570.00 1637.00 333.29 -305.52 -134.62 HS 2.50 4.03 5979051.41 618755.25 N 70. 35142774 W 149.03576679 1700.00 31.00 203.78 1573.09 1640.09 335.14 -307.22 -135.37 HS 2.50 4.03 5979049.70 618754.53 N 70. 35142311 W 149.03577286 1800.00 33.50 203.78 1657.65 1724.65 388.40 -356.04 -156.89 HS 2.50 4.13 5979000.54 618733.80 N 70. 35128971 W 149.03594752 1900.00 36.00 203.78 1739.81 9806.81 445.30 -408.20 -179.87 HS 2.50 4.23 5978948.03 618711.65 N 70. 35114723 W 149.03613408 2000.00 38.50 203.78 1819.41 1886.41 505.72 -463.59 -204.27 HS 2.50 4.32 5978892.27 618688.13 N 70. 35099591 W 149.03633219 End Crv 2052.35 39.81 203.78 1860.00 1927.00 538.72 -493.83 -217.60 -- 2.50 4.36 5978861.82 618675.28 N 70. 35091328 W 149.03644039 Base Perm 2071.88 39.81 203.78 1875.00 1942.00 551.20 -505.27 -222.64 --- 0.00 4.37 5978850.30 618670.42 N 70. 35088203 W 149.03648131 WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-217\Plan S-217 (216-15)\Plan S-217\S-217 (P1) Generated 4/26/2007 2:53 PM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Deem Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS v~. c..il ~~~ xv .la.vl GvJ.lo lo~v.VV I'Jl .00 OVJ.00 -010.! 1 -LLl.00 r7J U.UV 4.30 0~l00J0./0 2100.00 40.02 203.78 1896.59 1963.59 569.18 -521.76 -229.91 HS 2.50 4.39 5978833.70 2200.00 42.52 203.78 1971.74 2038.74 635.03 -582.12 -256.51 HS 2.50 4.47 5978772.93 2300.00 45.02 203.78 2043.95 2110.95 704.09 -645.42 -284.40 HS 2.50 4.54 5978709.20 2400.00 47.52 203.79 2113.06 2180.06 776.22 -711.54 -313.55 HS 2.50 4.61 5978642.63 End Crv 2401.24 47.55 203.79 2113.90 2180.90 777.13 -712.38 -313.91 -- 2.50 4.61 5978641.79 SV5 2530.30 47.55 203.79 2201.00 2268.00 872.20 -799.53 -352.33 --- 0.00 4.67 5978554.05 SV4 2829.61 47.55 203.79 2403.00 2470.00 1092.69 -1001.63 -441.41 --- 0.00 4.78 5978350.58 SV2 3490.46 47.55 203.79 2849.00 2916.00 1579.50 -1447.86 -638.10 --- 0.00 4.95 5977901.32 SV,1 3974.98 47.55 203.79 3176.00 3243.0.0 1936.42 -1775.03 -782.31 --- 0.00 5.05 5977571.94 9-5/8" Csg Pf ~ 4346.90 47.55 203.79 3427.00 _ 3494 00? . 22-10.38 -20.26.16_ _ -893.00 -- 0.00 5.12 5977319.10 UG4 4465.44 47.b5 203.79 3507.00 3574.00 2297.70 -210620 -92828 - 0.00 5.14 5977238.52 UG4A 4514.33 47.55 203.79 3540.00 3607.00 2333.72 -2139.22 -942.83 -- 0.00 5.14 5977205.28 UG3 4973.67 47.55 203.79 3850.00 3917.00 2672.09 -2449.38 -1079.55 --- 0.00 521 5976893.02 Crv 4/100 4977.87 47.55 203.79 3852.84 3919.84 2675.18 -2452.22 -1080.80 92.19E 0.00 5.21 5976890.16 5000.00 47.53 202.59 3867.77 3934.77 2691.49 -2467.22 -1087.22 91.38E 4.00 5.22 5976875.05 5047.71 47.51 200.00 3900.00 3967.00 2726.67 -2500.00 -1100.00 91.78E 4.00 5.24 5976842.08 End Crv 5075.70 47.49 198.48 3918.91 3985.91 2747.29 -2519.48 -1106.80 --- 4.00 5.26 5976822.50 UG1 5765.41 47.49 198.48 4385.00 4452.00 3255.39 -3001.65 -1267.96 --- 0.00 5.34 5976337.87 Crv 4/100 5983.90 47.49 198.48 4532.65 4599.65 3416.35 -3154.39 -1319.02 157.23E 0.00 5.36 5976184.35 6000.00 46.89 198.14 4543.59 4610.59 3428.16 -3165.60 -1322.73 157.00E 4.00 5.37 5976173.08 6100.00 43.23 195.86 4614.22 4681.22 3498.80 -3233.26 -1343.46 155.39E 4.00 5.41 5976105.11 Ma 6148.42 41.48 194.64 4650.00 4717.00 3531.28 -3264.73 -1352.05 154.49E 4.00 5.43 5976073.51 6200.00 39.62 193.25 4689.19 4756.19 3564.60 -3297.27 -1360.13 153.43E 4.00 5.45 5976040.85 Mb1 6213.98 39.12 192.85 4700.00 4767.00 3573.40 -3305.91 _ -1362.14 153.12E 4.00 5.45 5976032.18 Mb2 6277.43 36.88 190.94 4750.00 4817.00 3612.03 -3344.13 -137020 151.61E 4.00 5.47 5975993.84 6300.00 36.08 190.21 4768.15 4835.15 3625.25 -3357.32 -1372.67 151.03E 4.00 5.48 5975980.62 Mc 6332.99 34.93 189.10 4795.00 4862.00 3644.07 -3376.20 -1375.88 150.12E 4.00 5.49 5975961.68 Na 6399.17 32.66 186.65 4850.00 4917.00 3680.01 -3412.66 -1380.95 148.09E 4.00 5.51 5975925.15 6400.00 32.63 186.62 4850.70 4917.70 3680.44 -3413.10 -1381.00 148.06E 4.00 5.51 5975924.71 Nb 641929 31.98 185.85 4867.00 4934.00 3690.44 -3423.35 -1382.12 147.41 L 4.00 5.52 5975914.44 Nc 6452.11 30.88 184.47 4895.00 4962.00 3706.95 -3440.39 -1383.66 14623E .4.00 5.53 5975897.38 Ne 646025 30.61 184.12 4902.00 4969.00 3710.95 -3444.55 -1383.97 145.93E 4.00 5.53 5975893.23 6500.00 29.31 182.30 4936.44 5003.44 3729.91 -3464.36 -1385.09 144.35E 4.00 5.54 5975873.40 End Crv 6528.28 28.40 180.91 4961.20 5028.20 3742.82 -3478.00 -1385.47 -- 4.00 5.55 597585976 S-217 Tgt 1 OA 6538.28 28.40 180.91 4970.00 5037.00 3747.30 -3482.76 -1385.55 -- 0.00 5.55 5975855.00 OA 653829 28.40 180.91 4970.01 5037.01 3747.31 -3482.76 -1385.55 -- 0.00 5.55 5975854.99 OBa 6595.11 28.40 180.91 5020.00 5087.00 3772.78 -3509.78 -1385.98 -- 0.00 5.56 5975827.97 OBb 6634.90 28.40 180.91 5055.00 5122.00 3790.62 -3528.70 -138628 --- 0.00 5.56 5975809.05 OBc 6691.74 28.40 180.91 5105.00 5172.00 3816.10 -3555.73 -1386.71 --- 0.00 5.56 5975782.03 010000..70 IV lVAOUOOU/! VV -14`J.V300LZZ3 618663.42 N 70.35083698 W 149.03654028 618637.78 N 70.35067208 W 149.03675620 618610.90 N 70.35049915 W 149.03698265 618582.81 N 70.35031851 W 149.03721922 618582.45 N 70.35031623 W 149.03722220 618545.43 N 70.35007814 W 149.03753400 618459.57 N 70.34952600 W 149.03825707 618270.01 N 70.34830690 W 149.03985340 618131.02 N 70.34741307 W 149.04102369 618024.34 N 70.34672697 W 149.041921 617990.33 N 70.34650829 W 149.042208 617976.31 N 70.34641809 W 149.0423262 617844.54 N 70.34557071 W 149.04343551 617843.34 N 70.34556295 W 149.04344566 617837.15 N 70.34552196 W 149.04349781 617824.90 N 70.34543240 W 149.04360146 617818.41 N 70.34537919 W 149.04365662 617664.93 N 70.34406188 W 149.04496395 617616.31 N 70.34364457 W 149.04537805 617612.78 N 70.34361393 W 149.04540816 617593.12 N 70.34342908 W 149.04557632 617585.04 N 70.34334311 W 149.04564594 617577.47 N 70.34325421 W 149.04571153 617575.60 N 70.34323061 W 149.04572777 617568.14 N 70.34312620 W 149.04579318 617565.89 N 70.34309017 W 149.04581315 617562.97 N 70.34303857 W 149.04583922 617558.49 N 70.34293896 W 149.045880 617558.44 N 70.34293776 W 149.045880 617557.49 N 70.34290976 W 149.04588976 61755621 N 70.34286320 W 149.04590224 617555.97 N 70.34285185 W 149.04590477 617555.17 N 70.34279772 W 149.04591379 617555.00 N 70.34276046 W 149.04591689 617555.00 N 70.34274747 W 149.04591749 617555.00 N 70.34274746 W 149.04591749 617555.00 N 70.34267364 W 149.04592093 617555.00 N 70.34262196 W 149.04592334 617555.00 N 70.34254812 W 149.04592678 WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-217\Plan S-217 (216-15)\Plan S-217\S-217 (P1) Generated 4/26/2007 2:53 PM Page 2 of 3 Comments Measured D th Inclination Azimuth Sub-Sea ND ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude ep Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS oi4r.atl Lif.4U 7tf0.91 5149.99 5216.99 3839.02 -3580.04 -1387.09 --- 0.00 5.56 5975757.71 617555.00 N 70.34248169 W 149.04592988 S-217 Tgt 2 OBd 6748.58 28.40 180.91 5155.00 5222.00 3841.58 -3582.75 -1387.14 --- 0.00 5.56 5975755.00 617555.00 N 70.34247429 W 149.04593022 OBd 6748.59 28.40 180.91 5155.01 5222.01 3841.58 -3582.76 -1387.14 --- 0.00 5.56 5975754.99 617555.00 N 70.34247428 W 149.04593022 6816.78 28.40 180.91 5215.00 5282.00 3872.15 -3615.18 -1387.65 -- 0.00 5.57 5975722.57 617555.00 N 70.34238569 W 149.04593435 OBe 6816.79 28.40 180.91 5215.01 5282.01 3872.15 -3615.19 -1387.65 --- 0.00 5.57 5975722.56 617555.00 N 70.34238568 W 149.04593435 OBf 6873.62 28.40 180.91 5265.00 5332.00 3897.63 -3642.21 -1388.08 --- 0.00 5.57 5975695.54 617555.00 N 70.34231186 W 149.04593779 OBf Base 6913.41 28.40 180.91 5300.00 5367.00 3915.46 -3661.13 -1388.38 -- 0.00 5.57 5975676.62 617555.00 N 70.34226018 W 149.04594019 TD / 7" Csg 7066.78 28.40 180.91 5434.92 5501.92 3984.22 -3734.05 -1389.54 -- 0.00 5.58 5975603.69 617555.00 N 70.34206094 W 149.04594947 • WeIlDesign Ver SP 2.1 Bld( doc40x_100) S-2171PIan S-217 (216-15)\Plan S-2171S-217 (P1) Generated 4/26/2007 2:53 PM Page 3 of 3 by ~ • Schlumberger wELI FIELD STRUCRIRE S-217 (P1) Prudhoe Bay Unit - WOA S-PAD Magnetic Paramer~r~ 4urtace La'arron NA02]Alaa4a Sla{e Plane. Zone 0< US Feer Miscailaneous AIWeI EGGr.t 2'r~ i fl09e9 Dn!e us12620f,] Lat 'C 2'5ra5 Mnq 5919]5900 nU9 Gntl Lonv -9909112]" Slor 5-2r] NO R¢r Rgary Table lF~C±~'1 nl~e~.~:+1.I~L~ h!,ag Dec. •2]6T5 FS 5>E53.r nT Lon Vta92a.926 Ea:rurq 6r68A5 JOOU9 Scvle Fac!09999t6p66a 5-2')(Prl Ervrprre APn12620Ur 0 800 1600 2400 3200 4000 0 800 1600 2400 0 0 c u °' 3200 m in D 4000 4600 5600 Vfi End'Crv Cry 2.SI100 se Perin End Crv -..-..-..___.._.._.._.._.._.._.._. .5._.._.. _.._.._.. _. _ -..-..-..-..-..-.._.._ -..-..-..-..-..-..-..-.~._..-..-..-..-..-..-.._ _.._.. _.._. ..........i ..................................i........ .......................<...................................i..................................6................................:.._ .._ ._ _.._.._.._ _.._.._.._.._.._.__.._. _.._.._ 4_ ._.._.._. _ _.._.._.._.._.._..-.._ _.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._ _.._.._.._. -..-.._.._~._.._.._.._..-..-.._..-..-i.-.._..-.._.._.._.._.._. `..~.._.._.._.._.._.._.._..~.._.._..-.._..-..-.._.._ ._.._.._..-..-..-.._.._ _.._.._..-- ..',_. -.)- -.._..-..- -..-.._.._.._.._.._..-. -..-..-..-.._..-..-..- - -.._.._.._.._.. _.._ :A ._.. _..~.. _.._.._.._ .~..~..C..~..~..~..~.._ _..:.._.._. Crv 4N 00 End Crv _.._..-.. .. _.._.._..-..-..-..-. ..-..-..-..-..-..-..-..i.. ..-..-..-..-..-.._.._ _.._ ._.._.. ._.._..-..-..-..-..-.. .._.._.._. Crv 41100 0 800 1600 2400 3200 4000 4600 5600 0 800 1600 2400 3200 4000 Vertical Section (ft) Azim = 200.41°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V b~% Schlumberger BELL S-217 (P1) FIELD Prudhoe Bay Unit - WOA STRUCT URE S-PAD Magnetic Paramelera Surface Location NA02) AlasFa Stale Planes. Zone Oa. US Feel M1llscnean enus MoUel BGGM 2006 OIP Bu ~~a9 Oale Auyus130. 100> N>0 2t 0 tab 9m9. 6919]690C nU5 Gn,] Gonv •090n132]t' Slol S-2t ] Np Rel Rdary Table (fi) 00 B alwve MSII Mey Dac •235]9` FS 6]fi531 nT Lon WIa92a 026 Easlmg fit9 0 06 00 11115 Swle Face. 0.9995t5005a Plan 5~3111PII 6nry Dala. APIN 28. 200) -2000 -1500 -1000 -500 0 500 0 -500 -1000 n n -1500 Z o` 0 c ~ -2000 m U V V V -2500 -3000 -3500 0 -500 -1000 -1500 -2000 -2500 -3000 -3500 -2000 -1500 -1000 -500 0 500 «< W Scale = 1(in):500(ft) E »> BP Alaska Anticollision Report Company:, BP Amoco Date. 4/26/2007 Tithe: 1:4`.58:17 Page: l Field: Prudhoe Bay..;... Reference Site: < PB S Pad Co=ot•dinate(NE) Reference: Well: Plan S-217 (216-15), True North Reference Wet1:- Plan S-217 (216-15) Vertical.(TVD}Refcrcnce; S-217 Plan 67.0 ' ' Reference Wellpath: P{an 5-217 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1[L~@i~L'I'ioeells in thisF$'eddlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7066.78 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing _. _ _--- _ Survey Program for Definitive Wellpath ' Date: 4/26/2007 Validated: No Version: 4 ' Planned From To Survey Toolcode Tool Name II--- ft --- ft --- __ - - ----- _ __ - _ _------- -- --- -- __- ---- ------ - -- - - - ---- 28.50 900.00 Planned: Plan #1 V1 GYD-GC-SS Gyrodata gyro single shots 900.00 2300.00 Planned: Plan #1 V1 MWD MWD -Standard 900.00 4370.00 Planned: Plan #1 V1 MWD+IFR+MS MWD +IFR + Multi Station 4370.00 7066.78 Planned: Plan #1 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 4346.90 3494.00 9.625 12.250 13-3/8" 6685.81 5166.78 7.000 8.750 7" Summary ', <~~-~______ ._._ Offset Wellpath ---- ------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area ' Deviation Warning ft ft ft ft ff PB S Pad Plan S-126 Plan S-126 V7 Plan: PI 384.68 385.00 15.79 7.26 8.53 Pass: Major Risk ' I PB S Pad S-15 S-15 V2 404.73 410.00 139.86 9.92 129.95 Pass: Major Risk PB S Pad S-16 S-16 V1 349.50 350.00 31.41 6.95 24.46 Pass: Major Risk PB S Pad S-17 S-17 V1 1030.06 1025.00 30.37 18.24 12.14 Pass: Major Risk ' PB S Pad S-17 S-17A V1 1030.06 1025.00 30.37 18.24 12.14 Pass: Major Risk ', PB S Pad S-17 S-17AL1 V1 1030.06 1025.00 30.37 18.24 12.14 Pass: Major Risk i, PB S Pad S-17 S-17AP61 V1 1030.06 1025.00 30.37 18.24 12.14 Pass: Major Risk PB S Pad S-17 S-17B V1 1030.06 1025.00 30.37 18.24 12.14 Pass: Major Risk ', PB S Pad S-17 S-17C V1 1030.06 1025.00 30.37 18.08 12.29 Pass: Major Risk ', PB S Pad S-17 S-17CP61 V2 1030.06 1025.00 30.37 18.08 12.29 Pass: Major Risk ' PB S Pad S-17 S-17CP62 V1 1030.06 1025.00 30.37 18.08 12.29 Pass: Major Risk ', PB S Pad S-18 S-18 V1 955.09 930.00 173.77 20.42 153.35 Pass: Major Risk PB S Pad S-18 S-18A V16 952.98 925.00 173.71 20.26 153.46 Pass: Major Risk ', PB S Pad S-215 S-215 V9 387.84 395.00 117.83 7.70 110.14 Pass: Major Risk ', PB S Pad S-216 S-216 V2 4861.65 6035.00 180.66 145.43 35.23 Pass: Major Risk PB S Pad S-40A S-40A V1 1144.31 1135.00 47.29 17.04 30.25 Pass: Major Risk i PB S Pad S-40 S-40 V1 1144.31 1135.00 47.29 17.04 30.25 Pass: Major Risk • • FieldPrudhoe Bay Site PB S Pad Well:Plan 5-217 (216-15) WellpathElan 5-217 373 300 200 100 0 2 100 200 300 -3 1 3 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t ~ I L'tl ^ 123 ^6 ^ 28 ^ 27 ^5 ^ 26 ^ 25 ^ 4 ^ 24 ^ 21 ^3 ^ 23 ^ 20 ^2 ^ 19 ^ 22 ^1 MODULE MODULE UI u1 NOICOn sON ~ n ~ N N41Nfn NVl fn fA to 1$ FSL Ground 3156.44 ft. FEL Ground 4565.75 ft. cV I S-PAD 27 26 ~ I25 S PAD _N_ i i 34 I 35 36 ~`~~~~ AREA i ~~ T.12N. 3 T.11N. 2 VICINITY MAP N.T.S. NOTES: LEGEND 1. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27 & PLANT. ~ AS-STAKED CONDUCTOR 2. GEODETIC COORDINATES ARE NAD-27. ^ EXISTING CONDUCTOR 3. WOA S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. 4. HORIZONTAL CONTROL IS BASED ON MONUMENTS S-3 & S-4. 5. BASIS OF VERTICAL CONTROL IS OPERATOR MONUMENTATION. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. GRAPHIC SCALE 6. REFERENCE FIELDBOOK: W007-09 PGS. 54-5$. a 100 200 7. DATE OF SURVEY: JUNE 26, 2007. ( IN FEET ) 1 inch = 200 ft. LOCATED WITHIN PROTRACTFI7 SFC. 35. T. 1~ N.. R. 1~ F . UM1AT MFRif)iAN. AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS S-217i Y=5,979,359.04 N 964.60 70'2108.145" " 70.3522625' 38 2~ 3,156' FSL ' X= 618,885.01 E 1496.00 149'0204.825 149.0346736' 4,566 FEL s"p"ans ua uw amcm"s en scs~ nnc m wa 1 "= 20(E~ by WOA S-PAD AS-STAKED CONDUCTOR WELL S-217i 400 SHEET: 1 of 1 TREE _ 41/8" CM/ FMC ~ -~ r draulic Proposed ar~rcrr ~rv~ w. rn-_- rnn~v oo~a is r~~~ iv RELEASE' BUT CAN ALSO BE RELEASED 8Y PRESSURE DO NOT IXCEEO 4300 PSI. TEST PRESSURE PKR 17ATINf~ = Gd1A PCI /d747 PCI IC AOoL AF PKR pATIIU(;-+~- 29' 4-1/2"X03-1/2",ID=2.992" i 2901' 3-1/2" HES X NIP, ID= 2.813" 7 6417 MMG DMY RK WATER INJECTION MANDRELS WELLH D= ACTUATOR= lake Hy KB. ELEV = BF. ELEV = KOP = 300' Max Angle = 47.5 deg Datum MD = Datum TVD 4-1/2"TBG, 12.6#, L-80, 29' TG11, .0152 bpf, ID = 3.958" 9-5/8" CSG, 40#, L-80, TG11, ID = 8.835" 4347' CSG, 26#, L-80, TG11, .0383 bpf, ID = 6.276" 6148' Minimum ID = 2.75" ~ xxxx' 3-1 /2" HES XN NIPPLE MARKERJOINTw/ RA TAG H OA ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6511 MMG-W RK 5 6562 M1AG-W RK 4 6605 MVIG-W RK 3 6643 M1AG-W RK 2 6702 MMG-W RK 1 6775 MMG-W RK 6465' 3-1/2" HES X NIP, ID= 2.813" ~ 6486' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920' NOTE: DO NOT EXCEED 4300 PSI 6500' PHOENDC PRES/TEMP SENSOR SUB, ID = 2.992" 6578' 3-1/2" HES X NIP, ID= 2.813" MARKER JOINT w/ RA TAG I-~ Oba REF LOG: SLB Reaftime LWD ANGLE AT TOP PERF: Note: Refer to Roduction DB for historical perf data S¢E SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 OA xxxx'-xxxx' O 4-1/2" 5 Oba xxxx'-xxxx' O 4-1/2" 5 Obb xxxx'-xxxx' O 4-1/2" 5 Obc xxxx'-xxxx' O 4-1/2" 5 Obd xxxx'-xxxx' O 3-1/2" TBG, 9.2#, L-80, TGII, .0087 bpf, ID = 2.992 8845' PBTD 8987' 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 7067' 6583' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920' 6261' 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920' 6635' PHOENDC PRF_S/TEMP SENSOR SUB, ID = 2.992" 6637' 3-1/7' HES X NIP, ID = 2.813" ~ 6731' 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920' 6755' ~3-1/2" HES X NIP, ID = 2.813-1/2" HES X NIP, ID = 2.813" 6$~' 3-1/2" HES X NIP, ID = 2.813" 6826' 3-1/2" HES XN NIP, ID= 2.75" 6845' 3-1/2" WLEG, ID=2.992" DOTE REV BY COMMENTS DATE REV BY COMMENTS ORION UNfr 06/19/07 BJP Proposed WBD WELL: S-2171 PERMff No: xxxxx API No: 50-029-xxxxx Sec, 7w p, Rge BP Exploration (Alaska) Page 1 of 1 Maunder, Thomas E (DOA) From:- Peltier, Brandon [Brandon.Peltier@bp.com~ Sent: Tuesday, July 17, 2007 2:52 PM To: Maunder, Thomas E (DOA); Kolstad, Scott R Subject: RE: Polaris S-217 Attachments: S-217i SB OA Top.doc Tom The two wells in the permit are the only wells which pass within a quarter mile. I have attached an image of the wells at the top of the OA near S-217i. The July 20 spud date is no longer accurate. The actual spud date is more likely around the 27th now. Brandon Peltier BP Exploration (Alaska}, Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier@bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, July 17, 2007 2:33 PM To: Pettier, Brandon; Kolstad, Scott R Subject: Polaris S-217 Brandon and Scott, I am reviewing the permit application for S-217. With regard to the 1/4 mile review, you have identified 2 wells in zone within the 1/4 mile distance. Do any of the "old" wells pass through the zone as well? Also, is it possible to provide adrawing/plot of the 1/4 mile area? Thanks in advance, call or message with any questions. Also, how real is the July 20 spud date? Tom Maunder, PE 7/17/2007 • • S Pad Schrader Bluff Top OA 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 ,Alaska Department of Natural esources Land Administration System • Page 1 of 4 _;; ~ ~ ° ar , ,r : ~ ~ ~=_~cor~~r's Sh~.i~t~ State Cabins ~l~'tu»1 i~~1t'~eS See Township, Range, Section and Acreage? ~` Yes ~"'`° No New Search SAS Mena ~ Case Abstract ~ Case ©etail ~ l_anci Abstract ~., I'ilc: ADL 28261 ~~''~'~~'. Search for status Fiat Updates :1 of 07 171200 Cusf~n~er.~ 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case 7 ilae: 7i~ OIL & GAS LEASE COMP DNR Unit: 780- OIL AN1) GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of RrirrtaryResponsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: S NORTH SLOPE Last Transacti on: AA-NRB ASS IGNME NT APPROVED t~Ieridiart: U l ~ntirrrshr~: 01 ~ ~! R~rn~c: 0121: ,~'ectio~t.~ 0 3 .S'crcli~~n Acres: 6=-10 Search Plats alc'Y'Ict~tan: ~ ~ ~Ull'i1S'j11~7: O ~ ~ ~ Rail,~r(': O ~ ~ E: ~SE'~ /!il{!.~ ~)~ .~~C'c'I[U71 '~C')'C'~1': 640 Meridzan: L! 7uu~ns~hy~: 0 I 1 V'~ Rcnl~re': 0 I ? I: ,S'c~clir>n.~ 09 .ti'~~clrurz : icrc.ti~: 641) 117eridian: I~ Trnt~irshij~: OIIV' P~u1~c~: 012F. ,S<<tion: l0 S'c~ctiu»:Ir~~c°5: 6=10 Lc;;al Description 0~-28-196 * * * SALE NOTICE LEGAL DESCRIPTION * ~` CI ~1- 5611N 12E UM 3, 4,9,10 2560.00 Od-01-1977 * * * UNITIZED LEGAL DESCRIPTION* PRUDHOE I3AY UNIT TRACT -~8 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28261 &... 7/17/2007 'Alaska Department of Natural esources Land Administration System. Page 2 of 4 T. 11 N, R 12 E., U.M. SECTION 3: ALL, 6~0 ACRES; SECTION ~: ALL, 6~0 ACRES; SECTION 9: ALL, 6,t 0 ACRES; SECTION 10: ALL, 640 ACRES. CONTAINING 2, ~ 60.00 ACRES, MORE OR LESS. 0-1-01-1977 * * * INITIAL OIL RIMPA ESTABLISHED LEGAL DESCRIPTION ~ INITIAL OIL RIM PA PRUDHOE BAY UNIT, TRACT ~8 T. 11 N, R. 12 E., U.M. SECTION 3: ALL, 6~0 ACRES; SECTION ~: ALL, 610 ACRES; SECTION 9::4LL, 6=10 ACRES; SECTION 10: ALL, 6=10 ACRES. CONTAINING 2, 560.00 ACRES MORE OR LESS. Od-01-1977' * * INITIAL GAS CAP PA ESTABLISHED LEGAL DESCRIPTION* INITIAL GAS C 4P PA PRUDHOE BAY UNIT, TRACT 48 T. I 1 N, R_ 12 E., U.ILI. SECTION 3: ALL, 6=10 ACRES; SECTION d: ALL, 610 ACRES; SECTION 9: ALL, 610 ACRES; SECTION 10: ALL, 6=10 ACRES. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28261 &... 7/17/2007 F ~ Alaska Department of Natural esources Land Administration System Page 3 of 4 CONTAINING 2, 560.00 ACRES, MORE OR LESS. 11-D 1- 2000 * * * INITIAL A URORA PA ESTABLISHED LEGAL DESCRIPTION* INITIAL A URORA PA PRUDHOE BAY UNIT, TRACT ~J8, (PARTIAL) T. 11 N., R. 12 E., U.M. SECTION 3: N/2, 320 ACRES. CONTAINING 320.00 ACRES, MORE OR LESS. 11-01-1999 * * * INITIAL POLARIS PA ESTABLISHED LEGAL DESCRIPTION* INITIAL POLARIS PA PRUDHOE BAP UNIT, TRACT 48, (PARTIAL) T. 11 N., R. 12 E., U.M. .SECTION 3: ALL, 6~0 ACRES. SECTION ~: E/2E/2, 160 ACRES. SECTION 9: NE/4NE/~, SE/4, S/2NE/4, 280 ACRES SECTION 10: ALL, 6~0 ACRES. CONTALNING 1, 720.00 ACRES, MORE OR LESS. 10-01-2004 * * ~` A URORA PA EXPANDED LEGAL DESCRIPTION PR UDHOE BA Y UNIT AURORA PARTICIPATING AREA TRACT 48 (PARTIAL) http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28261 &... 7/17/2007 Alaska Department of Natural esources Land Administration System. Page 4 of 4 T.11 N. , R.12E., UMIA T rL~ERIDIAN, ALASKA SECTION 3: ALL, 60.00 ACRES; SECTION 4: E2, E2SW4, NW-~, 560.00 ACRES; THIS TRACT CONTAINS 1,200.00 ACRES. MORE OR LESS. ~k**#=~******~**#*~K#*~k**~1~##=k****#**#*#*#*****=k**x*~##=k:~~k=k~~*#t*~*###*#* Last updated on 07/17/2007. Not sure who to contact? Have a question about DNR? Visit the uf~lic Information Corte. r. Report technical problems with this page to the Webmastes-. Site optimized for Netscape 7, IE 6 or above. This site also requires that all CC3~I. must be accepted. State of Alaska Natural_Resources LAS Home Copyright Privacy S_ystem_Status ___ http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28261 &... 7/17/2007 • Terri 1.. Wubble BP Exploration AK inc. PO Box ] 96612 M6 7-5 Anchorage., AK 99519 P~:4Y T,0 THE ORDER OF t1. _ ;(~ ~ "Mastercard Check" • as-s~i 252 344 DATE O ` ~' ~'~ ` -~~`~ First'National Bank Alaska Anchv~a9e, AK 99501 . ~ ... MEMO ~:L25200060~:99L46227L5S6~~' 0344 ~ • TRAiYS1d[I~'TAL I.ETTEid C'I~I~ECKLIST WELL NAivIE ~/,~L/ ,~-~/~L~ PTD# o?D~ 09,5-~ Development / Service Ex lorato _____ Yon-Conventions[ Wet! p ~` Stratigraphic Test Circle Appropriate Letter /paragraphs to be included is Transmittal Letter CHECK I ADD-ONS WHAT ( (OPT[ONS) ~ TEXT FOR APPROVAL LETTER APPLIES ~ MliLTI LATERAL ~ The permit is for a new weil6ore se gment of existing , I o j (IF last two digits in I well .Permit No. ~ API number are ; , APi No. 50- _ between 60-69) Production should continue to be reported as a function of th ~ e original API number stated above. PILOT HOLE ' to accordance with 20 AAC 25.005{f), all records, data and Iogs acquired for the pilot hole m t b i j us e clearly differentiated in both I ,oll name ( PH) and API nu b ~ ~ ( m ec I (acquired for we(1 --~ tom records, data and togs i SPACING ;EXCEPTION The permit is approved subject to full compliance with 20 25 055 A . . 1 pproval to perforate and produce 1 inject is continue t i upon issu ance of a conservation order approving a spacing I exception. ' ! liabili of an assumes the ~ t7' y protest to the spacing exception that may occur. ~ ' DRY DCTCH i ~ i SA' biPLE ~ A11 dry ditch sample sets submitted to the-Commission must be in ~ i - ~ ; no greater than 30' sample intervals from below the f n f ~ ~ rom where samples are t•irst caught and 10' sample in tervrvats j through target cones. i '' 'I We[t Conventional j Please note the following. special condition of this , I production or production testing of coal bed methane is not al owed ;for (dame of well) until after (Company Iy'ame) has designed and t j ~ implemented a water well testing program to provide baseline data on water quality and ti I ~ C quan ty. (Company Name) must contact the ~ Commission to obtain advance approval of such water wet( t i est ng pro t Rev: ('2~i06 C:' jody~transmittal checklist ~ + ^^ N ~ W C ~ - 4 c Q o, or , , m -d c: v o L' m N ,~ c ~ ~ ~~ ~ ~ ~ ~ 3 ~ ~ ~ ~~ ~ ~~ ' ~ w O~ ~ c' a~ ~ a o •- ~ N ~ ~ ~ O > o. a a ~' im u; ~ m ~ E O a O. va 0 ~ rn c t o O a ~y ~ ~, ~ ~ .~ ~ 3. co ~ ~ o ' a I ~ Q. _~ c v ~ ~ ~ , , ! j ~ cp t1 t, c. m. N 0 ~ N 2' N ~ > c. n a. 4 ~ ~ ~ i ~ . - >: ~ ~ , Z H `a v. ~ ..r N M' J~ ~ ~ , ~ O~ G tV' ~ ~ '~ _ ~ 4 N, C, N ~ 3 '~, a ~ N: _ ~ ~ ~ a ~ ~ _ ~, ~ ~ ~ Q. ~ ~ N ~ O. ~~ M• ~ R 7, O ~ 'ur t'S ~ ~ ZO, X ~, ~ a ~ y ~ ~ ~ o . m U ~ W; ~ ~ L` 3 ~ d ~ ~' c. a , , ;i ~ ;~ f/1 N, N ry} (/1 d N d fA N~ tlY tl1 d d, N, N d} f/A N N, N, N f/D N, tlJ f? tlA N d, N, q) V! 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Oi N L C ~ ~ N C• V: ~ ~ -O' f6 N' ~ O O• Q ~ p ~~ ~ 'D ~ a ~ 0; N, U. O N ~ w~ d~ ~~ .Q~ 3,~ O ~, ' >~ l0' 2k'' Y d N ~ m g ~. 0 ~, o ° ~ C~ °~ ~', •y G ~; o > a~ o' > o~ O ~ w a m ar c m ~ ~ ~ $, . ~ C, '~, m, a °' 4 `o' ••-' tW Z' f0. C °' `o' fG E, o E' ~ ~ Q. c 3' 4 tl} ~ ~ a' ar oa ~' ~ Q >` L' O. `-°' OI O ay V as ~ N •v_1 E n. Q ~ Z °~ o, r ~ C, ~~ . - ~ ~ ~ is N. a N y ' p o, ~, Y a ~ 3 - L_, 3 ~ ~ ~ 'O f6 N ~ ~ ~+, 'O. €, ~ ~, ~ O y, ~ Qy C .0 + U « p y N• a> ~, •~ m M. ly O 4 •-, a~ 0 v1. U' N, 0 ul ti' ~ N ' a a 3, O y '~' O 3 o, ; y' 3, o l0' tV' O' w ~ ~ W O (~ C ~ n a C: p C, w~ N , I y ~~ ~, > f0 O, N, a a . '¢ _, , N O (0~ ~ .. O O C ~ , , O' Uw? O~ ~O C, d R ~~ ~y , ,., '6 ~ a Q lp' , m, O~ CI G , v ~ O a L Z , tlJ, p: GT d H 8j' t' , ~' d. a O' ~ 4Y N a a ~ U, O, _ a N ~ N a c' a L' ~. ~ ~~ d. a O y' Y' -pp' t6 y' ~' d' m' ~ Of d G U :} V? ~, , 3' N, : , t? C O C ul ~, C L. Otj ~ • ° v. ~ m. 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't ~' ~' ~"~ o ~ ~~ ~ ~; ~ m w v m. ~ m a ~ ~ d, v '~ O a, a O r ~` ~ v' O' a ti ~ d :° m w ~ c d o a~ m D ~ ~, Ca ~ ~ a, , J.~,3', , ~,~m,~; o,o,a; a; , v,~',¢' a'z' , ~ v, N',v,vv, , v , ¢, '~ ¢ , , ~ o,m, , m;v, ~',-"~; , a, , g , , cncn'v W a O - M et L) c0 P 00 O ~ O ~ ~ N ~ M~ O ~ ~ .- c0 I~ ~ e- i, tp W O ~ N ~- r N N N -- M N ~ N In t0 N N I~ O Of N N N O M ('O M~ M M M__ M M ~ ~ U d O '~' C ~ ~ N ~ ~ N ~ ~ ~ N ~ U p H O d r ~ 0 _ ~ 81 C ~ _ ~ ~ I ~ ~ O N ° N a 7 •C w ~,Ir ~,~\ I T CAE //~~ ~~ .~ a ~ a O ~ U U ~L a Q Q U Q IL W Q f' ~ Q Q