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Home My WebLink About195-066MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 8, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-34 PRUDHOE BAY UN PTM P2-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/08/2025 P2-34 50-029-22558-00-00 195-066-0 N SPT 5108 1950660 3200 671 3606 3574 3529 38 36 38 37 REQVAR P Guy Cook 7/22/2025 4 year MIT-T per AIO AA 4G.013. Maximum anticipated is 3200 psi. Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P2-34 Inspection Date: Tubing OA Packer Depth 19 28 28 28IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250722132241 BBL Pumped:3.5 BBL Returned:3.4 Monday, September 8, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, March 5, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-34 PRUDHOE BAY UN PTM P2-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/05/2024 P2-34 50-029-22558-00-00 195-066-0 W SPT 4951 1950660 3200 1767 1765 1765 1767 157 571 549 540 REQVAR P Brian Bixby 1/22/2024 MITIA as per AIO 4G.013 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 PTM P2-34 Inspection Date: Tubing OA Packer Depth 24 3528 3489 3486IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240122161227 BBL Pumped:1.8 BBL Returned:2 Tuesday, March 5, 2024 Page 1 of 1           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector P2-34 (PTD #1950660) AA for continued WAG injection Date:Thursday, February 17, 2022 8:01:04 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 16, 2022 5:47 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector P2-34 (PTD #1950660) AA for continued WAG injection Mr. Wallace, WAG Injector P2-34 (PTD #1950660) AA 4G.013 for continued WAG injection with TxIA communication has been received. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, January 25, 2022 2:44 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector P2-34 (PTD #1950660) TxIA Communication Mr. Wallace, WAG Injector P2-34 (PTD #1950660) IA liquid level was found to be near surface and IA pressure was bled on 01/24/22 with fluid and gas returns. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Packoff Test Tubing 2. Well Integrity: AOGCC MIT-IA / Evaluate AA for continued 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 Sent: Sunday, October 24, 2021 6:59 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector P2-34 (PTD #1950660) RWO Complete Mr. Wallace, Injector P2-34 (PTD #1950660) RWO is complete and the well passed MIT-T & IA to 4000 psi post rig on 10/22/21. An AOGCC MIT-IA will be performed within 5 days of stabilized injection. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, June 15, 2021 9:52 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector P2-34 (PTD #1950660) tubing patch out of hole Mr. Wallace, Injector P2-34 (PTD #1950660) had the tubing patch pulled on 06/14/21 in preparation for an upcoming RWO. The well will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg per P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, February 4, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P2-34 PRUDHOE BAY UN PTM P2-34 Src: Inspector Reviewed By: P.I. Supry f j Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-066-0 Inspection Date: 1/30/2022 Insp Num: mitLOL220130100550 Rel Insp Num: Friday, February 4, 2022 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 - Type Inj O " TVD 4951 - Tubing 3115 - 3119 - 3116. 3114 - 3113- PTD 1950660 - Type Test SPT Test psi 3200 IA 241 3925 - 3905 - 3890 - 3882 - BBL PumP ed: 6.1 BBL Returned: 6 — OA 230 837 826 814 807 Interval OTHER P/F P Notes: MIT -IA to Maximum Anticipated Injection Pressure to inform AA request. Friday, February 4, 2022 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector P2-34 (PTD #1950660) TxIA Communication Date:Tuesday, January 25, 2022 4:14:37 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 25, 2022 2:44 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector P2-34 (PTD #1950660) TxIA Communication Mr. Wallace, WAG Injector P2-34 (PTD #1950660) IA liquid level was found to be near surface and IA pressure was bled on 01/24/22 with fluid and gas returns. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Packoff Test Tubing 2. Well Integrity: AOGCC MIT-IA / Evaluate AA for continued 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 Sent: Sunday, October 24, 2021 6:59 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector P2-34 (PTD #1950660) RWO Complete Mr. Wallace, Injector P2-34 (PTD #1950660) RWO is complete and the well passed MIT-T & IA to 4000 psi post rig on 10/22/21. An AOGCC MIT-IA will be performed within 5 days of stabilized injection. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, June 15, 2021 9:52 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector P2-34 (PTD #1950660) tubing patch out of hole Mr. Wallace, Injector P2-34 (PTD #1950660) had the tubing patch pulled on 06/14/21 in preparation for an upcoming RWO. The well will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. WAG MDG WAG MDG STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry y BODE Test Report for: PRUDHOE BAY UN PTM P2-34 Comm Contractor/Rig No.: Hilcorp Thunderbird 1 PTD#: 1950660 DATE: 10/14/2021 Inspector Austin McLeod Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Bass/Knowles Rig Rep: Flores/Noel Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM211018081751 Type Test: WKLY 321-186 Rams: Annular: Valves: MASP: 250/4000 - 250/3500 250/4000 3425 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank _NA --__ NA System Pressure 3000 P - Housekeeping: P Pit Level Indicators P P Pressure After Closure 1450 P PTD On Location P Flow Indicator P P 200 PSI Attained 24 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 112 _ P Well Sign P 112S Gas Detector P P Blind Switch Covers: All stations P DO. Rig P MS Misc NA NA_ Nitgn. Bottles (avg): 6@,2250 P Hazard Sec. P ACC Misc 0 NA_ Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0 NA- Stripper 0 NA No. Valves 11 P _ Lower Kelly --_ 0 NA Annular Preventer 1 1375/8 P - Manual Chokes 1 NT Ball Type 1 FP- #1 Rams 1 ' 2-7/8 P Hydraulic Chokes I- NT v Inside BOP 1 P #2 Rams 1 ' Blinds NT CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 2-7/8x5-1/2 -----FP —v #4 Rams 0 NA #5 Rams 0 NA _ INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves l 3-1/8 P - Quantity P/F HCR Valves 1 3-1/8 P Inside Reel Valves 0 NA Kill Line Valves 3 '3-1/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 3 -/ Test Results Test Time 9 Remarks: 2-7/8 & 5-1/2 joints. TIW replaced for a pass. LPR FP on both joints. One on a high -bled & came back for a pass. Functioned/filled for pass on the other. Did not witness Blinds/chokes- Received chart of those -sent to J Regg. Test time reflects my time testing. MEMORANDUM TO: Jim Regg�� P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 13, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P2-34 PRUDHOE BAY UN PTM P2-34 Src: Inspector Reviewed By: P.I. Supry J�— Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Matt Herrera Permit Number: 195-066-0 Inspection Date: 11/28/2021 Insp Num: mitMFH211129101929 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 Type Inj G TVD 4949 Tubing 3076 3081 3087 3129 3134 3125 PTD 1950660 Type Test SPT Test psi 1500 - IA 0 2909 2886 2901 2908 2908 ' BBL Pumped: 1.6 BBL Returned: 1.6 OA 90 729 715 715 718 718- ' Interval oTF>Ex P/F 1 Notes: MIT -IA performed post RWO converted well from a Monobore completion per Sundry 321-186 Well previously limited to water injection. Inconsistent injection tubing pressures and rates casued fluctuating IA temperatures and pressures resulting in an inconclusive test. IA Pressure tested to 2900 PSI per Operations Monday, December 13, 2021 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor I c ZI7II707-1 FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 10, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P2-34 PRUDHOE BAY UN PTM P2-34 Sre: Inspector Reviewed By: P.I. Supry `_)_F� Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-2255800-00 Inspector Name: Matt Herrera Permit Number: 195-066-0 Inspection Date: 11/28/2021 , Insp Num: mitMFH211129104110 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 Type Inj G 'TVD 4949 Tubing 3127 3129. 3127, 3118- 9 50660 Type Test SPT Test psi 1500 IA 24 2904. 2877 - 2859 - BBL Pumped: 1.5 - BL Returned: 1.5 OA 84 721 , 708 - 700 Interval — INITAL - PIF P Notes: MIT -IA performed post RWO converted well from a Monobore completion per Sundry 321-186. Well previously limited to water injection. Inconsistent injection tubing pressures and rates caused fluctuating IA temperatures and pressures resulting in a previous inconclusive test. This is a retest. IA Pressure tested to 2900 PSI Per Operations Friday, December 10, 2021 Page 1 of 1 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector P2-34 (PTD #1950660) RWO Complete Date:Monday, October 25, 2021 8:58:10 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, October 24, 2021 6:59 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector P2-34 (PTD #1950660) RWO Complete Mr. Wallace, Injector P2-34 (PTD #1950660) RWO is complete and the well passed MIT-T & IA to 4000 psi post rig on 10/22/21. An AOGCC MIT-IA will be performed within 5 days of stabilized injection. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, June 15, 2021 9:52 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector P2-34 (PTD #1950660) tubing patch out of hole Mr. Wallace, Injector P2-34 (PTD #1950660) had the tubing patch pulled on 06/14/21 in preparation for an upcoming RWO. The well will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type PBU 15-48C 500292263503 211-030 6/16/2021 CBL PBU B-07A 500292028501 214-091 1/20/2021 CBL PBU C-03C 500292012403 212-058 7/10/2021 PPROF PBU C-29B 500292147202 214-049 7/10/2021 PPROF PBU C-41B 500292238502 213-104 6/26/2021 CBL PBU F-10C 500292041003 213-086 7/11/2021 CBL PBU P2-34 500292255800 195-066 6/17/2021 CBL Please include current contact information if different from above. Received By: 07/23/2021 37' (6HW By Abby Bell at 9:33 am, Jul 23, 2021 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, June 15, 2021 9:52 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; John Condio - (C); Alaska NS - PB - Field Well Integrity Subject: NOT OPERABLE: Injector P2-34 (PTD #1950660) tubing patch out of hole Mr. Wallace, Injector 132-34 (PTD #1950660) had the tubing patch pulled on 06/14/21 in preparation for an upcoming RWO. The well will now be classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.oRRPhilcoro.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:195-066 6.API Number:50-029-22558-00-00 PRUDHOE BAY, PT MCINTYRE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034624 Property Designation (Lease Number):10. 8. PTM P2-34 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13326 Effective Depth MD: NT-80 11. 7/1/2021 Commission Representative: 15. Suspended Contact Name: Kirsty Schultz Contact Email: Kirsten.Schultz@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 5-1/2" MCX I-SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9232 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 6386 , 4951 2091 , 2051 Date: Liner 6946 5-1/2"6380 - 13326 4947 - 9232 7740 6280 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 38 - 6532 38 - 5042 14. Estimated Date for Commencing Operations: BOP Sketch 39 - 119 Structural Proposal Summary 13. Well Class after proposed work: 7" Baker ZXP 12896 - 13120 8952 - 9098 5-1/2" 17# NT-80 34 - 6418 Production 12820 8901 none none 39 - 119 520 9-5/8" Contact Phone:907.564.5258 Date: 4/8/2021 80 153020"Conductor 4760 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 6494 6870 Intermediate Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3425 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 4:18 pm, Apr 09, 2021 321-186 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.09 14:54:49 -08'00' Bo York BOPE test to 4000 psi. Annular to 3500 psi. 3 ram stack and remote operated choke will be required. CDW 04/15/2021 24 hour notice for AOGCC to witness MIT-IA. 24 hour notice for AOGCC to witness MIT-IA after 5 days of stabilized injection. CBL to AOGCC for approval of packer set depth. Packer variance approved. 4 year MIT approved. MGR15APR2021 SFD 4/9/2021 SFD 4/9/2021 3425 DSR-4/12/21 10-404Yesption Required? Comm 4/19/21 dts 4/16/2021 RBDMS HEW 4/19/2021 RWO Well: P2-34 PTD: 1950660 API: 500292255800 Well Name:P2-34 API Number:500292255800 Current Status:Operable PWI only Rig:Thunderbird Estimated Start Date:3Q 2021 Estimated Duration:10 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Carrie Janowski Permit to Drill Number:1950660 First Call Engineer:Kirsten Schultz Contact:907-350-4310 (M) Second Call Engineer:David Bjork Contact:907-440-0331 (M) AFE Number:TBD Current Bottom Hole Pressure:4305 psi @ 8800’ TVD SBHP Survey 02/12/2012 Maximum Expected BHP:4305 psi @ 8800’ TVD Max. Anticipated Surface Pressure:3425 psi Gas Column Gradient (0.1 psi/ft) Equivalent Brine Weight:9.42 ppg (planning for 9.8 brine) Min ID:2.75” @ 12820’MD 5-1/2”x3-1/2” XN nipple reducer Brief Well Summary: P2-34 was originally completed in 1995 as a producer. The well was completed with a 20” conductor, 9- 5/8” production casing, and 5-1/2” tubing and liner. The completion is unique in that it does not have surface casing installed. The well was converted to a water injector in 1996 and has since been operating as one of five tubingless injection wells approved by the state. The well has a history of TxIA communication which was repaired with a cement packer in 2007. The packer squeeze remedied the TxIA, and the well continued water injection. In 2017, a sundry was approved for a trial of MI; however, when the well was placed online, rapid TxIA occurred. An acoustic LDL was run which identified a leak in the tubing. The location was patched, and the well was placed back on MI only to have the TxIA communication remain. The well remained SI until 2019 when it was approved for resumption of PWI. The well is currently online injecting produced water. Due to the wells completion, it has required MITs every two years. Recent MIT-IA and MIT-T pressure tests pass to liquid, but a RWO is required to allow the well to be placed on MI. Scope of Work: The primary objective of the RWO is to ready the well for MI by replacing the tubing and creating a monitorable OA. To achieve this, the existing tubing will be cut and pulled. 7-5/8” x 5-1/2” casing will be run with a 5-1/2” x 9-5/8” packer and 5-1/2” overshot. Then new 5-1/2” x 3-1/2” tubing will be run with a 3- 1/2” x 5-1/2” packer. o The change in well configuration will add an additional annulus to the wellbore which should negate the need for the 2-year MIT requirement set forth in the 5/2/1997 letter to Arco regarding “tubingless injection wells.” Due to the updated completion, it is requested the MIT-T and MIT-IA test frequency should revert to the typical 4-year test cycle. o Hilcorp North Slope LLC requests a variance to the packer placement requirements under 20 AAC 25.412 (b). The production packer is required to be set at ~6000’ MD in order to limit the amount of 3-1/2” tubing to allow for the required injection rates. Pre Rig Prep Work: Wellhead- SFD 4/9/202100 RWO Well: P2-34 PTD: 1950660 API: 500292255800 1) PPPOT-T to 5000 psi. Function all LDS Sline- 2) Set plug in nipple reducer at 12,820’ MD. 3) MIT-T to 4000 psi 4) MIT-IA to 4000 psi 5) Pull 5-1/2” patch from 5583’ MD. 6) Run cement log to determine TOC in IA. 7) With well offline, bleed IA pressure, so LDS can be removed and inspect casing hanger. 8) Pull plug in nipple reducer 9) Pull 5-1/2” x 3-1/2” nipple reducer at 12,820’ MD. 10) Drift for 5-1/2” patch and EL cutter Eline- 1) Set 5-1/2” patch across perfs from 13,010-13,030’ MD. 2) Bullhead 9.8 ppg brine down tubing. Sline- 3) Set 5-1/2”x3-1/2” nipple reducer at 12820’ MD 4) Set plug in nipple reducer – nipple to have fill extension and ovalled junk ports if possible Eline- 5) Run string shot 6) Tubing punch 7) Cut tubing ~6000’MD 8) Circulate 9.8 ppg with diesel FP on T and IA RWO Procedure: 1. MIRU Rig. 2. Circulate KWF as needed and bleed pressure to 0 psi. 3. Set two way check 4. Nipple down tree and tubing adaptor. Nipple up BOPE: annular, 2-7/8” x 5-1/2” VBRs, blinds, Integral/cross, 7-5/8” fixed. 5. Test BOPE to 250psi Low/ 4000psi High. Test Annular to 3500 psi. a. Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR rams on 2-7/8” and 5-1/2’’ test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 6. Pull TWC 7. Pull 5-1/2” tubing 8. Dress off 5-1/2” tubing stub 9. Run 7-5/8”x5-1/2” casing with 5-1/2” x 9-5/8” packer. 10. Space out and make up casing hanger per FMC rep. 11. Land 7-5/8” mandrel hanger, and run in lock down screws. 12. Reverse circulate well to place freeze protect in 7-5/8” x 9-5/8” annulus. 13. Run work string to set 5-1/2” x 9-5/8” packer. 14. Run work string to cleanout 5-1/2” tubing to ~7000’ MD. 15. Run 5-1/2” x 3-1/2” tubing with 3-1/2” x 5-1/2” packer. 16. Space out and make up tubing hanger per FMC rep. 17. Land the tubing hanger, and run in lock down screws. 18. Circulate in freeze protect 19. Drop ball and rod and set 3-1/2” x 5-1/2” packer. 20. Perform MIT-T to 4000 psi and MIT-IA to 2000psi. 21. Set TWC 22. ND BOPE 23. NU tree and adapter flange. (Non sealing overshot to swallow tubing stub.) Monitor well to assure dead. CBL to AOGCC. Consider BPV for MIRU. ~5500' MD Record weights. 24 hour notice for AOGCC to witness. , MU landing joint, stab tubing. Back out LDS's. Pull tubing to floor. LD landing joint. ~6,000 MD ~6000' MD (CBL log may alter depth) String shot to prep tubing for clean chemical cut. RTTS for sealing pressure to activate packer setting. RWO Well: P2-34 PTD: 1950660 API: 500292255800 24. Test both tree and tubing hanger void to 500psi low/5,000psi high. 25. Pull TWC 26. RDMO Post rig Work 1. Spot Slickline unit and RU. 2. Pull Ball and rod 3. Pull RHC profile 4. Pull plug from nipple reducer at 12820’ MD. 5. RDMO 6. Reconnect surface equipment for MI service. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 24 hour notice for AOGCC to witness after 5 days of stabilized injection. RWO Well: P2-34 PTD: 1950660 API: 500292255800 Attachment 1: Current Schematic RWO Well: P2-34 PTD: 1950660 API: 500292255800 Attachment 2: Proposed Schematic 5-1/2” x 9-5/8” packer 3-1/2” x 5-1/2” packer 3-1/2” tubing, ID = 2.992” 5-1/2” x 3-1/2” XO 5-1/2” tubing, ID = 4.892” 7-5/8” Casing 5-1/2” x-nipple, ID = 4.582” 3-1/2” x-nipple, ID = 2.813 3-1/2” x-nipple, ID = 2.813” Proposed 7-5/8” x 5-1/2” XO 5-1/2” overshot 5-1/2” patch ~6,000' MD RWO Well: P2-34 PTD: 1950660 API: 500292255800 Figure 3: BOP Drawing Choke manifold will require 1 to be operated remotely. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well P2-34 (PTD 195-0660)Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared: Kirsty Schultz 3/30/2021First Call Operations Engineer Date Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, February 17, 2021 1:38 PM To: Rixse, Melvin G (CED); Wallace, Chris D (CED) Subject: RE: [EXTERNAL] RE: P2-34 (PTD# 195-066) WAG Completion Proposal Mel, I agree with the biennial MITs, with a plug set in the deep nipple because this well is still a variance to the 25.412 requirements: ALASKA OIL AND GAS 3001 POnCUPa4E DRW CONSERVATION COMMSSION ANCHOPACE. ALASKA 995o,a192 Park: (907)xMI413 FA7c (9071 216-7542 May 2, 1997 Mike Zanghi, Drill Site Dev. Supv. ARCO Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Re: Tubingless Injection Wells Dear Mr, Zanghi: As we discussed during the meeting on Wednesday, April 30, 1997, injection wells must be completed with tubing and packer to isolate pressure to the zone and to enable MPT testing in accordance with our regulations, 20 AAC 25.412. which are consistent with 40 CFR 146.8 Mechanical lnt rite. To effectively capture the discussion and the agreements resulting from that meeting, I have prepared an addendum to the November 8, 1996 memo Consideration of Tubinaless Inioction and Disposal Well:. A copy of the original memo with the May I, 1997 addendum is attached for your records. The essence of the requirements arc that the Commimim will so league approve tubinglus injection walla: however, we will allow use of the five tubingless infection wells under our Regulatory Approval authority which requires MITs every two yeas and monthly reporting of daily tubing and cuing pxeasurm end pajeedon nice. "the MIT's must be tested against a plug set in the profile nipple which should be not more than 100' above the cop of the perforations or against an inflatable plug set not more than 100' above the top of perforations. Mike, please review the KRU tubingless injection welts to determine if they have a proper MIT, if not please plan to have one conducted. Keep us advised. If you have any questions, please call me at 279-1433. Sincerely, Blair Wondzcll Senior Petroleum Engineer Enclosure cc: D. Nims, R. Thomas A. Clark SCANNEf NOV 1 6 2004 I don't agree with the WFL requirement. The old packer squeeze will all be part of the new IA, both the old tubing side and the TOC. There can be no flow from one side of that cement to the other because its all within the same annulus now, see the green line. This packer squeeze was done back in 2007, about 10 years before 00736. The C0736 requirements don't seem to apply with this new completion because a total failure of the packer squeeze has no bearing on the integrity of the well and the IA is once again "fully' monitorable after this work. flEi • 6 311r OW 115 MMtKAU' 13'i 13' S il—k AMATOR 11A1QItC MBLV • 51T OF QLV An* - W41 Proposed P2-34 C:11 mlt3'• 1l7 5.1/2" tubing, ID = 3 842 rn 1Vp S 1/2' x7112- x0 — — 1>1TM IW MP Oi C1QOA Uy4r IT Minimum ID ■ 2.76"e 12820' 6.112' X 3-112' XN NIPPLE REDUCER illlwn OM. 0 •sir 1d/r Tubing, 10.2.nr A 3.1/r x s -Ur v+cliter ►brcw�rs pax woGo•Aurr F"WA MTM"SUM+MW 1ff LOG MAB GSM GN 01114% AMMEAT 10PFOW W Q 13Mf No lilw r RoMtten 110 Por rwnul w MAA 36M i 12M - 12321 0 M4t+lI6 ialr i 12901- iffi/ 0 064M tar x 12AU0.12M 0 064M 341 f 12!60.12!70 0 OGOM S -W i 13010.13030 0 064M 34W i 13070.13120 0 O"IM 3 SAE71 "M N<t 9to"Wi 111110111111 WALL 5.1/2' x•rupple, 10 - 4 582- 7 -SM Casing I 5.1J2' x 9.5/8" VK*ei OAi un UMM i'- q7itrOPurlDlNrT3 x 3-1/r x -nipple, 10.1813 13-1/2" x-rnpple,10 a 2.811 {cif' BAOLOOmON074 Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.SternickiP hilcorp.com From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, February 17, 202111:01 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: 132-34 (PTD# 195-066) WAG Completion Proposal Oliver, I am thinking biennial MITs and water flow logs. Should test the 9-5/8" prior to adding pipe and packers. Mel From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, February 16, 20212:00 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: 132-34 (PTD# 195-066) WAG Completion Proposal Here is Rev 2: The 5.5" overshot just above the cement top is not sealing meaning that the cement between the 5.5" and 9.625" is all part of the IA and will be tested. E - UM MMA RFV - Rcv . >. l J111p0 ..1n. Proposed P2-34 S1 1a0t7 10'0010 -�p—_ 1 a 5-1/2- tubing 11) —1.892- 5,11r x 3-1/2' x0 — 5-117' cm.,thct 1 YNImur11 ID 2.T8 -g 72828' _- 8412" X 3-112" XN NIPPLE REDUCER s1?1er.,1n.N1ao.Nacc, qtr sxmap.n•.ar 1311r tubing ID - 2 992" A I 3.1/2• x 5.1/2' packer I tBiY ATIONWA M" WLOG SMCMURON0111at0 N801E111 MPFM 4' a 11lW M6 N1P.r Y Rmrtdl W M Mac�yM a1Y as Wr fffMu 11TE 1 - 11!71 o1193 salt t ta01 - 12931 O 0101101 salt 1 11930.11930 O 060M sat' t UM - 111170 O Otasol "V t 13D10 11070 0 0110107 3-w IS 1070- 11110 0 '""" Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Oliver Sternicki Sent: Friday, February 5, 20213:03 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.aov> Cc: 'melvin.rixse@alaska.gov' <melvin.rixse@alaska.sov> Subject: P2-34 (PTD# 195-066) WAG Completion Proposal 5 1111111"D11 wilt preaw"Asm—_NOW. t %,l l -- S-1r,.. •.- 4. e. -._ _» 502' 7.5,18- Capry 7.5J8" ■ 5.1/2" x0 5•!J2-:9.5/8- pac>`u 63W -64c mEN OWATKO-44-p74/Ae) no MAMowlNoq l 3112' wn:pple, ID = 2 813 3-i/2- x -nipple, I D • 2.813' lawK—wi5i occwwatsl 11 Chris, Please see below for the proposed completion style on 132-34 (PTD#195-066) RWO such that the state would approve it for WAG service. Let me know your thoughts. TfGE• &3 OWR.S 91HLWAD= l7xl7SMFkC ----.. ACTUATOR = 8kop... M ELN - 51 T BF. afv - 5ZE fw= 1300 ARK AT* = 55- @ 6270 OMMKID= 12746 0a11an TVD = 11890 SS SO' Minimum ID = 2.75-@ 1282W 5-112" X 5-112' XN NIPPLE REDUCER Car ,L WELL REQUIRES A J9N— MOND- P2-34 0116 P 2 -3 4 I packer I IaTo 1J27C - I Sealing overshot I 7 ar 9.LOLODO®ON07R6B5 TYNE FVEV BY I COMMENTS I DATE WV BY P0F0W1TION SLSNA%M "am Rff LOO. SNSmWOROH07MM SETXXNPLUG 46D1n7 AMLEAT TOPrEFT 49' @ 12698 "MY MAP b Rocwc DB Iw Tagwcal Pert data 5ZE TIFF NTERVAL OpWSpz DATE 31W 6 12696 -11921 O 0"IM bar 6 129D1 - 12921 O ONUM 13C 6 12970 - 12950 O DMAT4 ILC 6 12950-12970 O 060MA 3�w 6 13010.17030 O 0WSM bYr 6 13070-13120 O DMIM IaTo 1J27C - I Sealing overshot I 7 ar 9.LOLODO®ON07R6B5 TYNE FVEV BY I COMMENTS I DATE WV BY I COAMEMS "am lCrAMMALCOMPLETIM I 1110intl SETXXNPLUG 46D1n7 MWO 18IPJC JIME CAD A GIMME PULMO NPLUG 7119 OIgAn?, N93fJMO SET PX PLW Wei Y17L_ _ OBIJII7 GWRO PULLEOPLUMETlPMEDi PLUG -- 09n7n7 RBULID SET PATCIMLALED PLUG 10n?A? R&W lCOMECITED PATCH DEPTH Oliver Sternicki PONT NCDaYF& Ulan VWLL P2.7z PEMW 5950660 APIW 50429-22550-00 BP EXPIM Pn UU50a) Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcoro.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby noted 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 telephoned the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, August 8, 2019 p P.I. Supervisor C�' �' 1 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. P2-34 FROM: Matt Herrera PRUDHOE BAY UN PTM P2-34 Petroleum Inspector Ste: Inspector - Reviewed B�y�:¢o � P.I. Supry Jl� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00.00 Permit Number: 195-066-0 Insp Num: mitMFH190702120704 Rel Insp Num: Inspector Name: Matt Herrera Inspection Date: 7/2/2019 - Packer Depth Pretest Initial 15 Min Well', P2-34 Typelnj� w TVD 4949 - Tubing 1118 - 1106. 109 7 PTD -- 1950660 Type Test SPT Test psi 1500 - IA 529 1995 1931 - BBL Pumped: 5 BBL Returned: 3.2 OA Interval -- -OTHER ✓ p/F P -- - - — —J Notes: 2 -yr MITAA Monobore completion on this well no OA. 1A Pressure tested to 2000 per Operator 30 Min 45 Min 60 Min 1064 1908 Thursday, August 8, 2019 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. P2-34 PRUDHOE BAY ON PTM P2-34 Src: Inspector Reviewed By: P.l. Supry Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Guy Cook Permit Number: 195-066-0 Inspection Date: 6/8/2019 Insp Num: mitGDC190608162139 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Mitt Well --T eIBBL!TVD 4949 -Tubing 328 2738 eto 2m_s �yP J PTD 9506w Type Test SPT Test psi 1500 IA 330 383 389 39i T — BBLPumped - —� Returned: 27 OA Interval OT14ER P/F PP - — Notes: Missed Test Date. Seeking AA. MIT -T required for AA approval. Job was completed with a triplex, bleed trailer and calibrated gauges. Monobore well, there was no OA. Iz4�- At zpl gj • UJdS s`r sµice at�bt � jeo„l f�Lu.GL Ir"doh ae.lF3t Z w C. tei7 Wednesday, June 12, 2019 Page 1 of I Wallace, Chris D From: Sent: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Friday, June 28, 2019 8:15 AM To: AK, OPS COA OSM; AK, OPS EOC Specialists; Ak, OPS GPMA Field PTL; AK, OPS LPC Board Operator, AK, OPS LPC DS Operator, AK, OPS LPC DS Ops Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL; Burton, Kaity; Lundgren, Carl E; Cc: Sauve, Mark A; Duong, Lea; Wallace, Chris D (CED) 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; Hibbert, Michael; Janowski, Carrie, Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: OPERABLE: Injector P2-34 (PTD #1950660) AOGCC approval for continued water injection All, Injector 132-34 (PTD #1950660) was made not operable on 11/01/2017 for having slow TxIA communication during a trial miscible gas injection cycle. The well has no history of TxIA communication while on water injection and the AOGCC has approved continued operation on water only. P2-34 is a monobore and requires 2 year AOGCC witnessed MIT -T and MIT -IA. The well passed an AOGCC witnessed MIT -T to 2,625psi on 6/8/2019. At this time the well is reclassified as Operable. An AOGCC witnessed MIT -IA will be conducted once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, March 26, 2019 9:57 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information Subject: RE: Request to return Injector P2-34 (PTD #1950660) to produced water injection Andrew, Looking over the May 2, 1997 letter that allows P2-34 to be on water injection with the tubingless completion, I see the requirement for the 2 year MITT and MITIA, and monthly reporting. Last testing looks like 5/14/2016 in our system (I do not have the 3/14/2019 testing) - and so a witnessed (or AOGCC waived witness) MITT and MITIA would be required to get this well into compliance. P2-34 is approved for resumption of produced water injection. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7" Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.waIlace@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.aov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, March 25, 2019 5:45 PM To: Wallace, Chris D (DOA) <chris.waIlace @alaska.gov> Cc: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <a kgwowel I i ntegritywe@ bp.com> Subject: Request to return Injector 132-34 (PTD #1950660) to produced water injection Mr. Wallace, P2-34 (PTD #1950660) is a monobore PWI that the AOGCC granted a trial period on MI per Sundry #316-613 in 2017. The well was put on Miscible Gas injection on 02/18/17, but shortly thereafter went Under Evaluation for IA repressurization. Slickline ran a leak detection log and found a tubing leak at 5,604'. On 09/08/17 a patch was set in accordance with Sundry #317-425, but did not mitigate the IA repressurization, so the well was made Not Operable and has been shut it and secured up until this point. It has been determined P2-34 can still provide some utility as a produced water injector so a MIT -T to 2,787 psi and CMIT-TxIA to 2,655 psi were performed on 03/14/19 to prove barrier integrity. Based on the past history of no IA repressurization on PWI and the passing MITs, BP is requesting your permission to resume produced water injection on P2-34. Once the well is on stable injection, an AOGCC witnessed MIT - IA will be scheduled since one was never performed post patch set. Please respond at your earliest convenience. Andrew Ogg Well Integrity Engineer • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, November 1, 2017 1:37 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GPMA Field O&M TL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea;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; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA); AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector P2-34 (PTD#1950660) IA Repressurization Post Tubing Patch All, Injector P2-34(PTD#1950660)was made under evaluation on 10/15/17 to evaluate the success of a tubing patch repair. The well was placed on injection for 5 days before it was shut in for having IA repressurization. The continued repressurization indicates the patch did not successfully mitigate the TxIA communication. On 10/31/17 slickline secured the well by setting a tubing tail plug and performing a passing CMIT-TxIA to 2,598psi. At this time the well is reclassified as Not Operable and will remain shut in and secured. The production engineer will evaluate the well for future utility. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED zi ; wo .•».•......,r....• From: AK, GWO Well -= ' Engineer Sent: Sunday, October 15, 2017 _ To: AK, OPS EOC Specialists; AK, OPS GP O&M TL; AK, OPS GPMA OSM; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; AK, OPS LPC DS Ops Lead; AK, O• • _ Ops Lead; AK, OPS Prod Controllers; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Op ,•r AKOpsProdEOCTL; Duong, Lea; 'chris.wallace@alaska.gov' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, G 1: . •Sects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Re., KIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Tr. • J; Munk, Corey; 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, October 15, 2017 5:07 AM To: AK, OPS EOC Specialists;AK, OPS GPMA Field O&M TL;AK, OPS GPMA OSM;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator;AK, OPS LPC DS Ops Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Duong, Lea;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; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J; Regg,James B (DOA) Subject: UNDER EVALUATION: Injector P2-34 (PTD#1950660) Evaluate patch repair on MI injection All, Injector P2-34(PTD#1950660)was made not operable on 4/26/17 for having TxIA communication when on MI. On 4/12/17 slickline ran an acoustic leak detection log and found a tubing leak at 5604'. The leak was repaired with a tubing patch on 9/8/17, but an MIT-T was not attempted due to the leak being to gas only. The well is now ready to be placed on MI injection to evaluate the success of the patch repair. At this time the well is reclassified as Under Evaluation and is permitted to inject MI for an additional 17 days per Sundry 316-613. Plan Forward: 1. Ops: Place well on MI injection 2. DHD: Monitor IA pressure 3. DHD: Perform AOGCC witnessed MIT-IA 4. E-Line: Perform RST/Borax log per Sundry 316-613 5. Production Engineer:Submit AA request for continued MI injection Please respond if in conflict with proposed plan, Matt Ross (Alternate: E�Josh Stephens) SCAM r� . ?' Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 From: AK, GW• -II Integrity Engineer Sent: Wednesday, Apri a 4:44 PM To: AK, GWO Well Integrity Engineer, ° GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS L' Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; - WO SUPT Special Projects; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; •-., James B (DOA) (jim.regg©alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, OPS FF Well Ops Comp Rep; Worthing :' Jessica; Dickerman, Eric; Sternicki, Oliver R; AK, GWO Completions Well Integrity; Burton, Kaity; AKIMS App User; ichael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Tempel,Troy; Worthington, Aras , . GWO Completions Well • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, September 26, 2017 9:04 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO Well Integrity Well Information; Loepp, Victoria L(DOA) Subject: RE: P2-34 (PTD# 1950660) Request permission to resume sundry 316-613 after patch repair. Josh, I am comfortable with continuing the trial on WAG (our records show 25 days gas so far this year)authorized by Sundry 316-613 and the completion of the commitments contained in that sundry. The Sundry 317-425 MITT commitment can be forgone—but a witnessed MITT to the maximum depth possible would be a requirement of the AA and so would need to be done eventually. I am looking at AIO 4G.005 which we recently authorized for WAG in a cemented IA well PTM P1-21 and it has many requirements to satisfy initially and ongoing. If you would prefer to assume success with the patch and gas injection, perhaps you would wish to do some of that required testing now rather than interrupt the injection in the near future. Your decision, but we are fairly accommodating on that timing. As we approach the Administrative Approval for continued gas, my concerns will be how to continue to ensure tubing integrity and gas to formation. With some fairly high corrosion numbers on that tubing and the recent leak/patch showing concerns, I am assuming a plug can be set in the tubing at 12820 ft? and that a fluid movement log(RST/Borax as mentioned in Sundry 316-613)could be run to ensure flow is to the perforations and not up past the 6835 ft casing and therefore out of zone? 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:AKGWOWeIISiteEnginee@bp.com] Sent: Monday,September 25,2017 3:15 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:AK,GWO Well Integrity Well Information<akgwowellintegritywe@bp.com> Subject: P2-34 (PTD#1950660) Request permission to resume sundry 316-613 after patch repair. Mr.Wallace P2-34(PTD# 1950660) is a monobore PWI that was injecting MI on a six week trial period under sundry 316-613 until it was shut in for TxIA communication. The well was placed on MI injection on 2/18/17 and made under evaluation on 3/9/17. Slickline ran a leak detection log on 4/12/17 and found a tubing leak at 5,604'. On 9/12/17 sundry 317-425 was approved to repair the TxIA communication,and on 9/8/2017 slickline completed setting the tubing patch. 1 Now that the tubing has been repaired BP would like permission to restart the r njection trial that was approved with sundry 316-613. We would also like to request permission to forgo the post patch MIT-T outlined in sundry 317-425, and proceed by verify the repair with an AOGCC witnessed MIT-IA. The request to omit the MIT-T is based on the wells history of passing pressure test to liquid. Please let us know if this plan is acceptable or if further information is needed to proceed forward. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO .raa..««r.or..e.o. 2 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, September 26, 2017 4:11 PM To: Wallace, Chris D (DOA);AK, GWO Well Integrity Engineer Cc: Loepp,Victoria T (DOA);AK, GWO Well Integrity Well Information Subject: RE: P2-34 (PTD# 19560) Request permission to resume sundry 316-613 after patch repair. Chris, Thanks for the follow up. To clarify on a couple of things the we did set a nipple reducer in the tubing tail at 12,820' so we will have the ability to pressure test the tubing with the patch in the hole. The original plan was to perform an MIT-T post setting the patch but the discussion was made to forgo the PT due to the well having a recent passing MIT-T with liquid, and given the well only shows signs of TxIA communication when on MI injection. Since you are ok with not doing the MIT-T at this time the plan forward for evaluating the repair is to perform and MIT-IA while on gas injection, and by monitoring the IA pressure trends for any repressurization. Wireless pressure transmitters have been installed on the inner annulus and are currently feeding live data into the SCADA system. If the annulus pressure starts to rise the operations team will receive an alarm and will be able to respond very quickly. This was done as a condition of BPs internal risk assessment for converting the well to MI service. Lastly, the patch will not hinder us from running an RST/borax log since the tool OD is only 1-11/16". If the well shows no signs of TxIA after being put on injection we will finish out the trial period and perform the borax log before applying for administrative approval for continued gas injection. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO From: Wallace, Chris D (DO' • ailto:chris.wallace@alaska.gov] Sent: Tuesday, September 26, 201 -.14 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO Well Integrity Well Information; Loep., ' oria T(DOA) Subject: RE: P2-34 (PTD# 1950660) Request permission t. ; me sundry 316-613 after patch repair. Josh, 1 OF T4 ,„4", 77,,s,, THE STATE Alaska Oil and Gas 7,;,-s=ds �; of Conservation Commission 'Witt 333 333 West Seventh Avenue 105Fz GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -"' Main: 907.279.1433 ALAS"- Fax: 907.276.7542 www.aogcc.alaska.gov ��,y SEp 2 5 2017 Lea DuongS ` Senior Petroleum Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Pt. McIntyre Oil Pool,PBU P2-34 Permit to Drill Number: 195-066 Sundry Number: 317-425 Dear Ms. Duong: 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, 42(0q Hollis S. French Chair DATED this k Z day of September,2017. RDDIVIS C SEfi 1 9 2017 STATE OF ALASKA OALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Tubing Patch II. 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 195-066 • Exploratory 0 Development 0 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-22558-00-00- 99519-6612 Stratigraphic 0 Service 0• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I3 PBU P2-34 • RECEIVED ECEIVE 9. Property Designation(Lease Number): 10. Field/Pools: ADL 034624• PRUDHOE BAY,PT MCINTYRE OIL• SEP 0 5 2017 11. PRESENT WELL CONDITION SUMMARY ■■/��= Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): AO^ C 13326 • 9232 • 12820 8901 • 12820 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 39-119 39-119 1530 520 Surface 6494 9-5/8" 38-6532 38-5042 6870 4760 Intermediate Production Liner 6946 5-1/2" 6380-13326 4947-9232 7740 6280 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12896-13120 8952-9098 5-1/2"17# NT-80 36-6419 Packers and SSSV Type: 7"Baker ZXP Top Packer Packers and SSSV MD(ft)and TVD(ft): 6386/4951 No SSSV No SSSV 12.Attachments: Proposal Summary Iv] Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14.Estimated Date for Commencing Operations: eptember 3,2017` 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ® • GSTOR 0 SPLUG 0 Commission Representative: C7GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will of Contact Name: Duong,Lea be deviated from without prior written approval. Contact Email: Lea.Duong@bp.com Authorized Name: Duong,Lea Contact P _,. 1-1 907 564 4840 Authorized Title: Senior Petroleum Engineer Authorized Signature: - Date: 9 i,S'/J, COMMISSION U ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Integrity 3k--/..q 2 5 Plug g ty 0 BOP Test 0 Mechanical Integrity Test I Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes No 0 1 Spacing Exception Required? Yes 0 No 17 Subsequent Form Required: /L) —4 1 4 APPROVED BYTHE Approved by: .to I COMMISSIONER COMMISSION Date: `�. Z I k 1 2 ,,� v~rt q/olll7- ,' R I 31 NA L RBDMStj4_, SEP 192017 W, .7., -,f7 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 SEP 0 5 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Approvals (10-403) September 5, 2017 To Whom it May Concern: Attached please find the Sundry Application for a Patch on Well P2-34, PTD # 195-066. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • i ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: P2-34 Well Type: WAG Injection Well API Number: 50-029-22558-00 Well Activity Conventional 4 Classification: Activity Description: Tubing Patch Cost Code/AFE: APBINJEC Field/Reservoir: PTMAC 12 Month Avg IOR, 75 bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Lea Duong Contact numbers: No Data No Data Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Mark Sauve Contact numbers: (907)564-4660 (907)748-2865 Date Created: June 6,2017 Revisions(date,who,what changed): Current Well Status Information Water Rate Gas Rate or FTP or Injection Oil Rate or Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 5/22/2017 0 0 3,123 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) None Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and 55° 8,279'MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 4° 7,270'MD Reservoir pressure(date, 2/12/2012 4,305 psi Minimum ID and Depth 4.562" 2,091'MD psig) Reservoir Temp,F 154°F Shut-in Wellhead Pressure 3,123 psi Known mech.integrity TxIA communication at 5604'MD problems(specifics) Last downhole operation(date, 4/22/2017 Leak detect log run with HAL. operation) Most recent TD tag(date,depth, 4/11/2017 13,069'MD Drift with 4.5"Cent., 3"sample bailer and tag hard btm @ toolstring OD) 13,069'SLMD. Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, P2-34 was swapped to MI for a trial 6 weeks of injection under a trial 10-403 approved 01/20/2017. It was background information, not swapped to MI until 02/2017. The well passes MITs and MITIAs to liquid,but when put on MI started etc: seeing pressure build-up in the IA at a rate requiring bleeds roughly every 1-2 days. A PPPOT was completed 03/10/2017 and the test void showed only--100psi whereas the tubing and IA pressures were 2800/1100psi respectively. The PPPOT passed indicating the TXIA communication is not through the wellhead. P2-34 has cement in the IA to—6247'from a packer squeeze executed in 2007 to mitigate a slow leak at the packer seals. At the time the packer squeeze was completed,the well also passed MITIA to liquid but showed slow repressurization. This squeeze work resulted in cementing the only GLV into place therefore limiting the ability to circulate or pump into the IA. This injector is in process of conversion to WAG and holds the greatest remaining EOR bbls of any MI pattern in Point Mac(3.4MMBO)and therefore is highly desirable to fix. In April 2017,a leak detect log ran with HAL showed a tubing leak at 5604'MD. The objective is to remediate the leak by setting a tubing patch and return the well back into service. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: TxIA communication at 5604'MD Specific Intervention or Well Objectives: 1 Set a tubing patch to isolate the leak(s). 2 3 Key risks,critical issues: Mitigation plan: Load tubing with Diesel and MIT-T to verify integrity to 1 Tubing has 44%wall loss limit downhole differential.Crude in IA from 2007 cement job 2 80%of derated burst is 3535 psi Max differential at top of cement is 3297 based on Burst Tab 3 Summary Step# Service Line Activity 1 S Pull Plug,set nipple reducer,set plug. 2 F Assist SL per pump template 3 E Set Lower WFD Widepack Packer. 4 S Set upper WeatherfordWidepack Packer. 5 F MIT-T per pump template 6 0 Put on Injection. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1.Pull X plug from 12,820'MD. 2.Set 5-1/2"x 3-1/2"Nipple reducer 1 s 3. Load tubing w/Diesel 4.Set plug in nipple reducer 5.CMIT(leave plug post CMIT) 2 F Load Tubing and CMIT per pump template 3 E Set lower 5.5"Weatherford Widepack Packer at 5,620'MD. Tie into PDS Coil Flag UMT-GR-CCL 15-Mar- 2010.Drift packer for 2.81 X-lock prior to installing. 1. Set upper 5.5"Weatherford Widepack Packer with top element at 5,590'MD. Drift for 2.81 X-Lock 4 S prior to installing. 2.Pull plug if passing MIT-T 5 F MIT-T per pump template 6 0 Place well under evaluation and begin MI gas injection. Wells Integrity will evaluate and determine operability. Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: MMSCFD: BWPD: Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Put well on injection. Observe IA pressure to confirm leak has been mitigated. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • • 6-308'CM FLS %MILNE-AD. 13'413 5M INC P2-34 SAFETY MOTE 11/61.1 REQUIRES A STSV"53 1/I ONO I BOW WU L ACTA 1014- NAST 14 c. kB /LEV- 517' BF ELD1= I HOP= 13017 Max AogIo- $5"0262/9' [ 2091' Hs-ter PICR SYJS IMP 1) 4 5E7 i D4414/0 KV- 12746' I I Mtum WIT= 111801T SS _Lif i-2---...00 N DUC1 OR. H 801 It,.tem 1 I i)TOP OF e TM/NT 7--1 6242' ititti :et*: 6310' 1436' 404.4 NT S14611410 4 4 49*10/014.101) 1 914,41/: 6.45.1 aiFat4'LET 4.4ormit :::::, ;At: ST MU WU'_IEV IYHE ' V43/ I LA ICH HUM DA TE :.:.it'Mr!!4'41%V. I 1 63224915 51 i4rsia FIMY 1 RM 0 1206.061 Minimum ID= 4.662"(.1 2091' 1,:**,i,ma,,; V , .N044. ,:•N 5-112""PARKER SWS NIPPLE ::: $ :$i ; ::::: i .... .._..... .:.,.....,„ ...,ur'Hu,I no NI 140.FOWL, I--4 6381 0.-4-: .,,,i,..., 4374*-sifiel flab iiiii4±TH(gluon] 02325 bpi I),4 813'________j 0..40 _ Al----438 i—.j1...WV' V tool ,-i 0I 61144 FIJI• VI6 ITOPOF 5 1/7 LNR €397- . ,_ ,0 . , 41114T A 41_,KR,NR-my...,,,,Oka A.1,11/4 NJ-4 875" '41 63er 1 10-5/0*X 7MR I-641C TER I CR,ID 4.? III :4 640.' H 4 641w Hr•X 5-1/7'X0..ID-4 592- ; I 9-5411"CSG,475,L-80.NENDC,ET-8 681" H 4153S' 1-4 I z 12820 I-4 5 112-PKR SWS MP EP-4 5 1 I12825' -4 4444) ,x,,c,,..00N0b28,95 j FERFORAT1CM SUMMARY REF LOG.SINS CDPI154 ON 07/14195 12820' -5-1/7 PX,LLIG(04013)17) ' ANGLE AT TOP PEET 49"Ve 12896' No* Rater to Production DB tor tostorral port data SIZE SIT INTERVAL (pniSqz DA TE I 3 316' 6 12696 12921 0 08101795 3-31/- 6 12901-17421 4) 06/09/04 3-31W 6 12930-12950 0 0E109/04 3-3.6" 6 12950-12970 0 06108104 3-319- 6 1110-13630 C) 06/05/04 3-381` 6 13010-13126 Cl towns I . . I I 143TO H 13230' •Of 1 41 11 MI !MA, ..t I47' 454 I 44 114 1 Iva 14544.1 0/9 i 4441,ii) A,„,,,.H 13326. j _- DATE REV BY cowENTs DATE 6E41 BY COMMENTS P0441'1.4ca41VRE UNIT 07/22/95 'ocattaitok L COMPLETION 04/15/14 MY PJC 1E26E00 i 34103/14) WELL P2-34 08/16/07 RLYWFVC CG5431TO0RFECTONS 04125117 MS51,114)SET PX RIJG{04110,17) PERivir Is5orzeo 011'10/01 MEWLS:'t5/T/I1All 1 01)0454 10f/24/0() Ali MT 50-029-7:41556-00 — 02,03/10 TLEITLIC 9 5/9'CSG O1104 SEC 14 1124 R14E,245'FM.&1359 MIL 03/29010 7i P/C ELM)3W5 LOGGED 40708/95) 02/24/11 M3/JM3 ADDEO SSSV SAI-ti Y NOTE - BP Explaratkm(Alaska) TREE= 6-3/8"CM/FLS • VVELLHEAD= 13"x 13"5M FMC PROPOSED P2-34 ��WELL WELL REQUIRES A SSSV M ONO- ACTUATOR= BAKER C KB.ELEV= 51.7' BF.ELEV= KOP=.�____ --. 1300' Max Angie= 55"@ 8279' Datum MD= 12746' I 2091' —5-1/2"PKR SWS MP,D=4.562" DatumTVD= 8800'SS 20"CONDUCTOR, 80' { —5600' H5-1/2"WFD PATCH,D=3.0" J _ feet . 5-6alt , ESTIMATED TOP OF CEMENT --I 6247' "•in '4" �� : .••- 6310'-6435' CEMENT SHEATH,ID=4.49"(07/24/07) .J •�• • • GAS LFT MANDRELS TVD V lY PE VLV TCH TE '• ♦.♦1► ��v 1T 632D2 4910 55111 HES LB DMY SRM 0 PORT 12/26/06 Minimum ID = 2.75 @ 12820' . • ♦♦ 4•♦ 5-1/2" X 3-1/2" XN NIPPLE REDUCER i•i• 'ii• •••. !i!i . • • < �a 1- \ S 0 / \ / \ 2 S / \ 20 0 § 7 2 Q 7 E \ 0 = _ co \ § D = a _ 2 k c_= k n S• Co § ) ® 2 % = L 2 E ƒ \ 2 E ! ° 2 e = \ — ° = - _ _cii _ ` o ƒ / k � — 0 o a 2 0 e 2 0 / o r e 0 = _ a \ = _ co _ = & » 2 k = co _i / .� a) CO . -0 in \ C ƒ » ) k = \ $ SES > \ y2E » \ k a = � 5 � _ » e 5 < � = o — e I < _ _ cn P e I < _ — e x g a, • 7) - x 7 2 * & — @ x CO 2 7 = _ « 2 = 0 2 = n o 2 a' — CO m = m — e e I e _ e u e R 2 e _ 22 e e I e e � \ E o \ _ \ ® A 2 > 0 2 ca co m c E \ I I 6 } k \ ± 173' 2 .,- Jo = 0 \ Lo ET 0 §\ '0 { 0 k CL T.) \ ƒ / / \ _ . e = j » c = _ c M = 2 § g 0 7\ G 2 E $ \ o = 0 0- = o o Z -1 \ - » ¥ ye s u ¢ e o o)k §0 o_ 2 o E . - ccoC � — \ — ._ � = H 32 e � g = I / 77 = = e > g = _ _ / E $ k M o 0 7 ° = k k / § \ t $ / ƒ j CO -I 2 2 2 o / % E 33 \ \ \ 02 c w & 2 CO Ni" LU 0 N- • • '' 7-'7: .5 - -s0-0.-ogJs -1; l11T5lal S 4,5 R .ZG ,L7, 8103 al COMPar.BP Exploration(Alaska), Inc. x1 ,3 , 2'7(41. i I t f I ;8 I S i liis ,p2s Well P2-34 2 1.( T C°-T i il i I r" itS Z i I F ield Point McIntyre It 4 '..'iL , " k— COUritY North Slope c 7 o 3 aI 3 f state Alaska.v I ici Y.2 3 To -n * o , a 0 0 , le n) S a- = 3 I - 5 0 /5 x 7., et -. 13 ' __....4%, ,- •-‹ stsi• Ti 1 rci 4 r , 3 2 , = f y •-c I r 5 ZUDW 1 0 - —I 0 C co 3 CO 1•J—,. C ',AC. C.I.,,,C a' 72, Z63rn , t i:(L3-.E;8 ' > 1-1":' '''• g x K -4 2 ' --I .13. __,X a El 6 g(•L' r- 1 K 1...., K., ..., .„. q-4 Z u, 0 Z Xi -11 2> -n 71 -< —I - K 0 rn 0 SY1 —1 0 Z K _.,11 > * g 0 Co 0 r- r81;1.q.-. 1 ma m- c. ,..- • -n . o c• rn (J) o 0 c CJ) - - 1- > 74 3 3 e5 r—Pj M ... '1. 03 01 Z Z Z•,.... . Z Z 'r E. —I -• . 4 g g of c) : 0.1 nterpretabOrtS are OprolOroS based on inlerences from electrical or other measurements and we cannot ano CIO nOt guarantee the accrsacy or correctness Wary interpretaton arrl we snail not except in Vie,ase of yross or reltrUI negligence on our part t.,e i ar.e or responsible ice an loss costs clamages or o,penses incurreo or sustaineo r,y anyone resulting Prom an,.niefpretation mac*by any of our officers agents or employees Tee interpretations are also subpect to Our general Awns aro commons set out in our ounent Pnce Sonattule Comments Log Referenced to Tubing Tally Dated: 18-Jul-95 CCL MP to EOP Distance= 12 01' CCL MP Depth at Flag Depth=6,221 00' EOP Depth at Flag Depth=620899' Flag Log was corrected +21 00' Tool Deployed Inside 22'Pump-through Carrier • 0 rrli Szels Composite Main Up Pass a.a....ate. s. Start Pass 21 18 Dataoese+=tle O'raaaor'data'cti-s -a s_• Dataset Pathrare 1 1 Presentation Format coilftap Dataset create)n. 'rue We'5 CC -La-f ' e 8 0 STD Cas charted dY Depth+n"eef scared`ate. 3 Canr^a Ray u,,Pl 0 Ccri Speed tft,'rrun) 270 ( 55CC k CCL C-arrr^'e3 Ray Cud Speed i t i , r- Set 5.5"Weatherford Patch with lower straddle packer set at 5,620' ELMD(mid-element)and upper ;. straddle packer set at 5,590'ELMD I (mid-element. MINI IIIIIIIIM i i ij • • • LDL Log ...� t 3' arm Leak @^'5605' e , I soot ..... .c ..mow I S. 55.5 C s. 010 t ,,:z, ,, > iy W. 57CC ?' t Sj. 3. � Z r 5750 > .�„;.�x„„,� 4. • •• Fullbore Pumping Design Template 1/0/1900 0 ppm H2S(date/ppm) 3450 Max Pumping Pressure(psi) Diesel Main Fluid Type 450 Main Fluid Volume(bbls) Diesel Freeze Protect Type Freeze Protect Volume(bbls) Surface Recent Tbg Fluid Level(ft) Surface Recent IA Fluid Level(ft) If Applicable Recent OA Fluid Level(ft) If Applicable Expected Tbg Fill Up Volume(bbls) If Applicable Expected IA Fill Up Volume(bbls) If Applicable Expected OA Fill Up Volume(bbls) If Applicable Wellbore Volume to Perfs(bbls) If Applicable Anticipated Bottom Hole Pressure (psi) Select Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 5.5 7740 6192 Tubing Collapse(psi) 5.5 6280 5024 Casing Burst(psi) 9.625 6870 5496 Casing Collapse(psi) 9.625 4760 3808 Select Input Depth Integrity Issues? Select Select Yes-derate Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Not Necessary Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) III • i. ae D If LL2 a _ -_n' iL ; m u U a A a W i_25-1- y ▪m _ e U Q� y elgo am '" 3 zD o v n m >E n m m 36003 1 m R Z _'' vKi C t7 a 41 IV; J�� . !vv mmmmmmmP ^ IWmmm mmmmmm `o or`' A vHiMnmmmmmm MNNmmeHM X g n G n 4' c %o F v m m m m m m m m m m ry R N N N N N N N N N N N N N N N.- S Y a g va 1.141. - • o a 3 £_ � N NNNNNN NNNNNNNNNNN rnmmmmmmnr m 9 S aft t a "E g % E Z d g G o � `o SSS 'oSSBSS ILIMM 1 - mbmeevmmmmmmmNNNNNNNNNN c 2 % 1 u= EZ , 1131P4 !I,oxg "I E. oaomoEOE000E000000000E0000EN l' iiEao a 3314 31- �? t W$N NNNNNNNNNNNNNNNNN r. a m E a C7 R YS S o - �,I NEI �M NNN NNN mmm m mens l oar m E 7N:_m � m oSo�� n� _ -E yk`e� U oa000000000000aoa0000a00000ao njo v�� otm uo�"„ wmu_ I _ apa ,,,g w NNNNmmmmmmmmmmmmmmmmmmmmmmmmm .1-.,2,2,1,,,,0 II s ''c E'ov � a v o m m mo mv�m mo m m • 8.F%,-!. '`d2, - o li'?mm,r'm EE�Z�1�i$�ic'ac�a I!'” m _ ' z2L 3 -a- a g;g3 a m'3a'a 1=mi..0 • DATA ENTRY AREA: MUST ENTER DEPTHS, FLUID DENSITIES AND SURFACE PRESSURES. ALL OTHER INFO IS CALCULATED. Depth of Fluid Tubing Conditions IA Conditions Interface Etc. Fluid Fluid (Needs Entry) Density Pressure Density Pressure Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Psi) Enter Tbg= 3450 Enter IA= 6.8 883 4 961 6.8 846 4 921 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DATA ENTRY AREA: ENTER FLUID INTERFACE DEPTHS AND FLUID 0 DENSITIES FOR ALL INTERFACES. ENTER SURFACE PRESSURES. 0 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE. ENTRY POINTS 0 ARE DESIGNATED BY RED LETTERING. 0 0 0 Pressure @ Pkr= 5179 Pkr= 1881 Max Differential at Packer= -3297 **This is Top Of Cement in the IA Differential Pressure across Tbg Calc Differential Pressure Calculated Threshold 0 2000 4000 6000 8000 10000 0 I i - --1 - j 1000 — 2000 - I 3000 — I 4000 -Z m 5000 - o 6000 - I I „ 7000 I • I 8000 9000 - I Diff Pressure — —7"\26# — 5 1/21 17# 10000 — • 4 1/21 12.6# 3 1/21 9.3# 2 7/81 6.5# • • TBG BURST REFERENCE DATA User Input Deration Tbg Size Class Pressure Value 2 718"1 6.5# Lor N-80 11165 80%= 8932 3 1/2"1 9.3# Lor N-80 10533 80%= 8426 4 112"\12.6# L or N-80 7500 80%= 6000 5 1/2"I 17# Lor N-80 4419 4419 80%= 3535.2 7"1 26# Lor N-80 5410 80%= 4328 FLUID GRADIENT REFERENCE DATA TYPE DENSITY GRADIENT (#/GAL) (PSI/FT) 15° CRUDE 8.05 0.4182 28° CRUDE 7.40 0.3841 30° CRUDE 7.31 0.3793 40° CRUDE 6.88 0.3572 DIESEL 6.80 0.3531 100% METH 6.64 0.3446 50/50 M/W 7.49 0.3888 60/40 M/W 7.32 0.3800 FRESH WATER 8.34 0.4329 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Brine Water 9.60 0.4985 Brine Water 10.00 0.5193 Brine Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 Prod Gas @ 1000 0.49 0.0254 Your Choice= 2 0.1039 EXAMPLE CASE Tnn of WPII Diesel IA Fluid Interface @ 2000'TVD. friJJ� .�\\\\ti /i/// :\\\\\ 'J.�/J// \\�t\� %7/J// •\\\\\ ti /7 Gas �.\\\ti iii .\\\\\ti Brine 10.6#/gal /i/i :\\\\\S 5//J/ ..,,\ ///// i \\�\\\` %/J/// :\\\\-\\` Tbg Fluid Interface @ 8000' ..-;',.'.7 i. ��:�� //ii.---�ti\\\\\ TVD �iJJf::.:.:.:.:.:.:.:.:.:--:.••-�4 /✓./////:. .:.;:;2 >�.\\\: ///J/r \\`\ Packer Depth © 8200'TVD. ><M;]:..>< t:..>< Crude • • DATA ENTRY AREA: MUST ENTER DEPTHS, FLUID DENSITIES AND SURFACE PRESSURES. ALL OTHER INFO IS CALCULATED. Depth of Fluid Tubing Conditions IA Conditions Interface Etc. Fluid Fluid (Needs Entry) Density Pressure Density Pressure Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Psi) Enter Tbg = Enter IA= 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DATA ENTRY AREA: ENTER FLUID INTERFACE DEPTHS AND FLUID 0 DENSITIES FOR ALL INTERFACES. ENTER SURFACE PRESSURES. 0 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE. ENTRY POINTS 0 ARE DESIGNATED BY RED LETTERING. 0 0 0 Pressure @ I Pkr= 0 Pkr= 0 Max Differential at Packer= 0 Differential Pressure across Tbg Calc Differential Pressure Calculated Threshold 0 2000 4000 6000 8000 10000 0 1000 I I 2000 3000 I tt 4000 • I ' 5000 I I 6000 I I • 7000 8000 I ' I 9000 ' Diff Pressure —7"\26# — 5 1/21 17# 10000 — • 4 1/21 12.6# 3 1121 9.3# -27/8"\6.5# • TBG COLLAPSE REFERENCE DATA User Input Deration Tbg Size Class Pressure Value 2 7/8"16.5# L or N-80 11165 80%= 8932 3 1/2"1 9.3# L or N-80 10533 80%= 8426 4 1/2"112.6# L or N-80 7500 80%= 6000 5 1/2"117# L or N-80 3672 3672 80%= 2937.6 7"126# Lor N-80 5410 80%= 4328 FLUID GRADIENT REFERENCE DATA TYPE DENSITY GRADIENT (#/GAL) (PSI/FT) 15° CRUDE 8.05 0.4182 28° CRUDE 7.40 0.3841 30° CRUDE 7.31 0.3793 40° CRUDE 6.88 0.3572 DIESEL 6.80 0.3531 100% METH 6.64 0.3446 50/50 M/W 7.49 0.3888 60/40 M/W 7.32 0.3800 FRESH WATER 8.34 0.4329 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Brine Water 9.60 0.4985 Brine Water 10.00 0.5193 Brine Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 Prod Gas @ 1000 0.49 0.0254 Your Choice= 0.1039 EXAMPLE CASE • M-= Diesel IA Fluid Interface©2000'TVD. \44 Gas Brine 10.6#/gal Tbg Fluid Interface @ 8000' TVD Packer Depth @ 8200'TVD. l�� Crude H20 Injector Minilog Techlog Protect Pt.McIntyre P2 Wells Well: P2-34 Author Laura J.Larson Scale:11000 Date 6/13/2016 -::Kcm SZ.2 ,690432 57 SPLU Date.1995-0030 00.00 00 (..wnbv.USA UmatIon dahan.KO + 599859057 Compbhcn Date 199}00-0100 00 00 Fdd.Prudhoe Bay ro w pe t 13326 .' 148.521862 St0Co Nitta Nas Coordnala System NAD27 AFT .0 .N�70 400665 OperatorBPXA Company'GPXA 1 RES MED DEN v 72-9�,�}TE�M(p p2-34.BEST.BHOB 2t TYOSS MD 0.3 OAMO T 1 �NW WEPT) MI RES_MED Q. �l f 1�2. law 3:3000 PE Info ... 0.2-34 M0 P2-34.ti1PIPSs i ogMM too 6D POO ,•., 8 szi `, 6 1 16 W RES DEP IVOSS Tw PHIA f TV" v1"7 "°I''' l Y +t p 6_.._..e2--;111 GHOi...._ .. -0.3��4HMMD 106 s0}s0m R Q?04 MY '7.A DfT ).1 LI' s 8800- I I A } " aaso T t6 0A 3.1 .812900 . ' ii I "6950' '43000+ `f K46MI in i I 113100- g--- 1a tel �.- � ;1 9000;13200 ..._......... __.__.__..__-. _...._...__._._.. _____..._-,...,_._....__».__.. __. i i ' I ,9150; . �.._... ,.13300 .____ _._ � .-_-- ....._ ....._.....___._.. .._.,...__� '9150= ! Ill RECEIVED kc\g � ocp 2 322 JUN 2$ 2017 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. June 23, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGEC Anchorage, Alaska 99501 0,12S/2°i DE RE: Leak Detect Log: P2-34 Run Date: 4/12/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 P2-34 Digital Log Image files 1 CD Rom 50-029-22558-00 Leak Detection Log 1 Color Log 50-029-22558-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. ti 1 ), ;�r.}1 Anchorage, Alaska 99518 SC NE° ' ''. Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • 0 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,April 26, 2017 4:44 PM To: AK, GWO Well Integrity Engineer;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep;Worthington,Jessica; Dickerman, Eric; Sternicki, Oliver R;AK, GWO Completions Well Integrity; Burton, Kaity; AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;Tempel,Troy;Worthington,Aras J;AK, GWO Completions Well Integrity;Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity Subject: NOT OPERABLE: Injector P2-34 (PTD#1950660) IA Repressurization All— Our diagnostic work is complete and the well has been secured with a tested mechanical plug. The well is classified as Not Operable. Plan Forward/Work Completed 1. Ops: POI—Complete 2. Slickline:Set TTP, Memory log-Complete Please respond if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) CANNE® r '- Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,April 5, 2017 3:48 PM To: AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM; AK, OPS GPMA Field O&M IL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator; AK, OPS LPC DS Operator;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep;Worthington,Jessica; Dickerman, Eric; Sternicki, Oliver R;AK, GWO Completions Well Integrity; Burton, Kaity; AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;Tempel,Troy;Worthington,Aras J;AK, GWO Completions Well Integrity;Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity Subject: UNDER EVALUATION: Injector P2-34 (PTD#1950660) Reset Clock to Evaluate IA Repressurization All— Due to operational and now weather constraints, P2-34 will require additional time as Under Evaluation to complete diagnostics. The 28 day Under Evaluation clock has been reset. Current IAP<2500 psi (MOASP). Due to MI gas being unavailable resulting from a plant upset and recent weather activity our diagnostic work has been delayed. Plan Forward/Work Completed 1. Ops: POI—Complete 04/3/17 2. Slickline:Set TTP, Memory log 3. Well Integrity Engineer:Additional diagnostics as needed Please respond if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9038 SCANNED ��'f' J( f. VVO +ewrw.•• From: AK, GWO Projects Well Integrity Sent: Thursday, March 09, 2017 7:10 PM To: AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO 1 SUPT Special Projects; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells O1ngr; AK, OPS PCC Ops Lead; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Worthington, Jessica; Dickerman, Eric; Sternicki, Oliver R; AK, GWO Completions Well Integrity; Burton, Kaity; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Tempel,Troy; Worthington, Aras J; AK, GWO Completions Well Integrity; 'chris.wallace@alaska.gov'; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Injector P2-34 (PTD #1950660) Evaluate IA Repressurization All, Injector P2-34(PTD#1950660) is a PWI that was swapped to MI injection on 2/18/17 for a six week trial period. Since the well was brought online it has required eight inner annulus bleeds to maintain pressure below the NOL(formerly MOASP). The well is now classified as Under Evaluation,and is on a 28 day clock for monitoring/diagnostics. Plan Forward: 1. Downhole Diagnostics: Monitor 2. Well Integrity Engineer:Additional Diagnostics as Required Please reply if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 WO ekww«w«w...a. 2 • • Wallace, Chris D (DOA) From: AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEngineer@bp.com> Sent: Thursday, March 09, 2017 7:10 PM To: AK, GWO SUPT Well Integrity;AK, OPS GPMA OSM;AK, OPS GPMA Field O&M TL;AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;Worthington,Jessica; Dickerman, Eric; Sternicki, Oliver R;AK, GWO Completions Well Integrity; Burton, Kaity;AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;Tempel,Troy; Worthington,Aras J;AK, GWO Completions Well Integrity;Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION:Injector P2-34 (PTD#1950660) Evaluate IA Repressurization All, Injector P2-34(PTD#1950660) is a PWI that was swapped to MI injection on 2/18/17 for a six week trial period. Since the well was brought online it has required eight inner annulus bleeds to maintain pressure below the NOL(formerly MOASP). The well is now classified as Under Evaluation, and is on a 28 day clock for monitoring/diagnostics. Plan Forward: 1. Downhole Diagnostics: Monitor 2. Well Integrity Engineer:Additional Diagnostics as Required Please reply if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-5766 SCANNED MAR 2 4 2017 Cell: 903-816-0183 #44.61 yolk orearaaabrew 1 • • VOF 7' `;wP��yy,�s� THE STATE Alaska Oil and Gas pfj\ jSJ(A Conservation Commission 333 West Seventh Avenue '11411-01*-- .r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .` Main: 907.279.1433 OFA S1iFax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton s iga MAS 1 0 2,01? Pad Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P2-34 Permit to Drill Number: 195-066 Sundry Number: 316-613 Dear Ms. Burton: 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 DATED this 41 day of January, 2017. RBDNIS LL JAN L 5 2017 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIS PPLICATION FOR SUNDRY APPROVE ' 20 AAC 25.280 • 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other�envert-to WAG-fr14,..® • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 195-066 • Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-22558-00-00 • 99519-6612 Stratigraphic 0 Service ®• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PTM P2-34" RECEI VED 9. Property Designation(Lease Number): 10. Field/Pools: DEC 0 2 Q 1 6 ADL 0034624 . PRUDHOE BAY,PT MCINTYRE OIL • r ` ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): AQPI CC 13326 9232 ' 13230 9169 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 39-119 39-119 1530 520 Surface 6494 9-5/8"47#L-80 38-6532 38-5042 6870 4760 Intermediate Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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: 7"Baker ZXP Top Packer Packers and SSSV MD(ft)and ND(ft): 6386, 4951.20 5-1/2"MCX I-SSSV 2091, 2051.20 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®• 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 Q 6 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Burton,Kaity be deviated from without prior written approval. Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signatureo ..,/�/1(1/ 66 Phone +1 907 564 5554 Date 1 z/o1/2-0K '(1/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 4. - cQSS Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test if( Location Clearance ❑ I Other: gL vi. R5 r/13d rax /o F1—r' ti w-rr!k5 MTi1-jrc3/inr, N � t 1k44 Pro V/ 4 L f'-c5v 1'l'S i-o vi CG I re r eohGvrrzrtfilyy ,fuftin'? t' 40 Lz10-40 3 alvtcl GT I/cafi 0-Y1 fv�/d !'""� /Fpj�• ova Post Initial Injection MIT Req'd? -'Yes al No 0 C 'V1✓Cr5i oYt f i' W S Spacing Exception Required? Yes 0 NoI Subsequent Form Required: /d -- .0 4 /20‘44.4_,..._ APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: /- 7 . -6,7 (/7'L 1/4/1. ` ORI GIN AL ,,Z�,(�• RODIVIS Li Ji,,, t j /VII Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate CEJ //41/7 A ( 27/4, • • C) .o 0 0 0 0 CZ N CO - CO CO 00 - fir- NNN C Ln CO C0 CO 0 N o 0 0 0 0 0 LM N- - - - v 00 N r- r- r- m — CO r r r N (A N •- N V CO CO r- O c N o N Ln V C3) 't C) I- r C)) CA CO CO 'Cr N- o') M C7) CA M C) 4-I G) NLUNCON co CO co COC co r r V 2 Q M o in co Cr Co 00 r- • N CO CO Cn ( Ca _ . 2 3 0 O co O t ' Co CO C� i J CO JJ • 0 *kJ *kZ *k ▪ N *k N C) -0\0 CV ZN CV U o I CA Ln LL') .0 4- d' r_- V' 00 C CO V' M 0) CO CA J CO CO CO CO O)O C ~ w U Ut� LLCCWZZ Z w w m m O D Z Z D D U (n J J F- I- i C) N t6 m N CO W CO 0) CO 'I' CO O N CO Lo CO p_ V' ted' CO cr8 O O fe CJ C4 O O CO 0) O CA C3) 0) CO O O O CO CO CA 0) O) 0- I- I-• co CO CO (Nd) t r LC) CO O N LC) LC) O- C7 r V V' O LO O 0 0)) 0) C3) 0) O O > 0 V' co co Cb O CA C3) 0 F- W w Z w t- 0_a ❑w d g g 5 U 0 0 co _ _ U U W CC W +_-- co O N LC) N- CO N J J J d d fn Z [Y 4'0 °- ~ C3) O) 0) O) O r < < < W O CO N N N N CO CO _0 _0 0_ J W W U -� U COrr r r �- �- Z Z Z 0 O O a Lija U U U w ❑ ❑ Z t) "Cr 22 20coUUUU M 4-11 Q N °- a ,2 °, � (3) O LC) r I� r 0 cc ctSaCU CU O 0' CAJ I IU- O co J Q 4LLL� 2 2 2 0 co co U) Cn Cn G) 0 0 U .2 N Q' LL LL LL u Owaaa _ w cna. tY000Ct. a 0 C) m r d 0 Cy E- 9 • o4 0 0 0 o rn ❑ • 0 • O O N N N N N O O O O O Z LL D WI CI Q W O `- N LL y 181-1_N W co ❑ , W J O W fY C2 I CO co co O O O < ❑ ° _ J J J d J J CO << d COI it u.. CL d E co z . . - �r •:1- co co co co co co co Cl) LL a_ co 0 LL N LL N N N N N N N pp CL C1 CL U J G 0 W [L d 0_ O 0_ 0_ 0_ Cl. < < co CLl LL LL U U LL CY TREE= 6-3/8"CIW FLS - VVELLFEAD = 13'x13'5M FMC • P2-34 SAFEIDOTE WELL REQUIRES A SSSV MONO- BORE ACTUATOR"-, BAKER C KB,FLEV= 517] BF.B_EV= I I KOP- 1300' Max Angle= 55 @ 8279' / Datum MD= 12746' I I 2091' H5-1/2 FKR SWS NP,V=4.562" Datum TVD= 8800'SS 120"CONCOCT-45n2, — 80' I ESTIMATED TOP OF CEMENT j— 6247' • -.- .•• W •• -- -- •••4 • •• 6310'-6435' —CEMENT SHEATH,ID=4.49"(07/24/07) •• At.- Ik•• GAS LIFT MANDRELS ••.. -f..• ••, •• •A' .,.... ST MD 'TVD DEV TYFE i VLV LATCH PORT' DATE - - . +••••• ':•:*- 1 632214910. 51 II-ES- LB i DMY RM 0 12/26/06 Minimum ID = 4.562 "@ 2091 •• ••• ' ••• •• •• •• 15-1/2" PARKER SWS NIPPLE I ••4• •• ••4 •• •••• •• , ••4 •• ••4• •• .••4 ••• ••4, •• .....:,,, t..t.• •••:'4 .•-• ,••• 6374' -6376' —TBG PUNCH(6/13/07d ...; 5-1)2'TBG 17#, NT-80, NSCC,.02325 bpf,ID=4,88" H 6387' .; -..., , ...... .....1, 6383' I-9-5/8"X 7"BKR ZXP LTP,ID=6.18-F1 TOP OF 5-1/-2''L-1NR -1 6397' -ft N 6387' — BKR LNR TEBACK SEAL ASSY,D=4.875" iv N 6397' 1-9-5/8"X r BKR FRC LNIR HGR.ID=? 6403' —17"BKR PBR,0=6.184" • > ) , . 6418' —7"X 5-1/2"XO,lj=4.892" A L 1 9-5/8"CSG,47#,L-80,NSCC,C)=8.68V — 6835' PERFORATION SUMMARY I I 12820' 12825' -5-1/2-PKR SWS NP,D=4,562" -EIJ..4)LOGGED ON 07/28/95 REF LOG-SWS CDR/GR ON 07/14/95 ANGLE AT TOP FEW.49 @ 12896' Note-Refer to Production DB for historical perf data SIZE SW IITERVAL Opn/Sqz DATE 3-3/8" 6 12896- 12921 0 08/01/95 3-3/8" 6 12901 - 12921 0 06/09/04 3-3/8" 6 12930- 12950 0 06/09/04 3-3/8" 6 12950-12970 0 06/08/04 3-3/8" 6 13010- 13030 0 06/08/04 3-3/8" 6 13070- 13120 0 08/01195 I 1 LT:131-=---I 13230' V 1.. 11.* A.A. 5-1/2"LNR, 17#,NT-80.NSCC, .0233 bpf,ID=4.892H 13326' • DATE REV BY COP GATE REV BY COMENTS POINT MC1N1Y RE UNIT 07122/95 ORIGINAL COMPLETION , 04/15/14 REI/PJC TREE C/0(04/03/14) WELL- P2-34 08/18/07 RLW/PJC CEMENT CORRECTIONS FERMI'1950660 08/18/07 RDB/PJC CMT/MLL Q(JCKDRILL(07/24/07) API Pb: 50-029-22558-00 — 02/03/10 IU-VPJC 9-5/8"CSG CORRECTION SEC 14,T12N,R14E,245'F111&1359'FWL. 03/29/10 9/PJC ELM)SWS LOGGED(07/28/95) 02/24/11 M3J.JMD ADDED SSSV SAFE]Y NOTE BP Exploration(Alaska) • • P2-34 10-403 WAG status request addendum: 12/06/2016 P2-34 was completed in June 1995. This well is unique in completion such that it has only tubing, • production casing, and a conductor. This well does not have surface casing. It produced briefly from August through September 1995 when it was converted to injection. The well was originally approved for injection service by the state but in 1996 a new report setting guidelines for service wells was released which specified completion and integrity regulation. The report "Consideration of Tubingless Injection and Disposal Wells" clearly stated new guidelines for service wells which P2-34 could not meet (due to the unique completion.) After some discussion the policy was revised May 1997 to allow 5 wells exempt status, and to keep them on injection. P2-34 was one of these 5 wells as clearly stated in the addendum to the report. It developed tubing to IA communication in 2007 and the leak was detected at the PBR packer. The packer was squeezed in 2007 and pressure tested to 2400psi on August 12, 2007. The packer repair brought top of cement up to approximately 6247'MD which brings the effective packer more than 200' above the perforated interval. This injector was sundried for water injection only and in 2009 the team began progressing work to convert it to WAG status. On 03/23/2010 a 10-403 sundry for conversion to MI injection was approved under the requirements that the following criteria were met: • MIT Tubing to 4000psi • MIT Inner Annulus to 4000psi • Run RST/Borax log to ensure no out of zone injection up past the packer • Put well on MI injection for 6 weeks • Run another RST/Borax log to confirm no out-of-zone injection • Evaluate the logs and submit a 10-404 sundry request for MI injection This scope of work began in 2010. An MIT-tubing passed to 3910psi on 04/11/2010 and a Combo MIT tubing x inner annulus passed to 4000psi on 04/12/2010. The RST log was run 04/18/2010 /2 showing no out of zone injection. With all this complete and the 10-403 approved the well was ready k� for In ction but unable to be put on MI injection due to operations safety concerns around the completion and monitoring ability of the inner annulus. Because of this, the scope of work was delayed until the installation of a wireless gateway and wireless pressure transmitter could be completed to better monitor the well health when on MI injection. This work was recently completed 10/05/2016. For this reason the team is now ready to progress the completion of WAG conversion of P2-34. This is a periphery 9 spot pattern surrounding injector P2-34 which has been on waterflood only depletion since produced. Due to size of pattern, remaining oil in place, and expected 10% incremental EOR benefit, as shown through other mature EOR patterns, this pattern is considered the highest value MI pattern remaining in the Point McIntyre Pool. Because the 10-403 application is more than five years old this application aims to refresh and • achieve reclassification to WAG service under similar work scope along with an application for an Administrative Approval. The planned work scope for the Sundry completion is as follows: • Put well on MI injection for 6 weeks • Run another RST/Borax log to confirm no out-of-zone injection • Evaluate the logs and submit a 10-40/sundry request for MI injection 3 If the monitoring and RST/Borax logs are satisfactory, updated pressure testing to Max Anticipated Injection Pressure and an application for an Administrative Approval j1Lfol the 10-404. C Regards, � �?�� fn © - Kaity Burton Production Engineer Point McIntyre BP Alaska • • Loepp, Victoria T (DOA) From: Burton, Kaity <Kaity.Burton@bp.com> Sent: Tuesday,January 03,2017 9:02 AM To: Loepp,Victoria T(DOA) Subject: RE: PTM P2-34(PTD 195-066, Sundry 316-613)WAG Conversion Good Morning Victoria-yes we conducted our 2-year MIT-IA pressure testing this spring to 2459psi which passed 05/14/2016. The well has been consistently on water service since 2010. We have just been on hold progressing the WAG work due to internal funding and justification of the needed surface work for conversion. All this work is now complete though so pending state approval we are ready to move forward with the work to convert to WAG. Please let me know if you have any further questions. Thanks! Kaity Burton Point McIntyre PE Base Management AK Reservoir Development Sand Management SPOC (W) 907-564-5554 (C) 907-360-6002 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, January 03, 2017 8:50 AM To: Burton, Kaity Subject: PTM P2-34(PTD 195-066, Sundry 316-613) WAG Conversion Kaity, Have an MITT and an MITIA been conducted since April,2010? Has the well been on water injection since April, 2010? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeoo 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 09,2016 P.I.Supervisor V ti/ w/(73l 1(4. SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P2-34 FROM: Johnnie Hill PRUDHOE BAY UN PTM P2-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 664— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Johnnie Hill Permit Number: 195-066-0 Inspection Date: 5/6/2016 Insp Num: mitJWHl60508145143 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 Type Inj N TTVD 4949 Tubing 1582 - 3300 • 3241 3211 3190 - 3174 - PTD 1950660 Type Test SPT Test psi 1500 IA 243 246 - 246 - 247 - 247 - 247 � -- --_----- -- ----------------- Interval OTHER P/F P :/ OA Notes: 2-yr MIT-T for monobore injector Completion to 3000 psi....used 3bbls diesel SCANNED DEC 2 92Q16 Thursday,June 09,2016 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jjnl Reg2di C"" DATE: Thursday,May 19,2016 P.T.Supervisor I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P2-34 FROM: Jeff Jones PRUDHOE BAY UN PTM P2-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Jeff Jones Permit Number: 195-066-0 Inspection Date: 5/14/2016 Insp Num: mitJJ160515071925 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 - !Type Inj W'TVD 4949 Tubing 1432 1435 - T 1431 ' 1431 ' PTD 195°66° Type Test,SPT;Test psi 1500 IA 895 2512 2468 - 2459 r Interval REQVAR P/F P OA Notes: 2 year MIT-IA,monobore injector. I well inspected,no exceptions noted. SCANNED SEP. 2 7 2016 Thursday,May 19,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 10,2016 TO: Jim Regg 'g ed, ((v P.I.Supervisor c SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P2-34 FROM: Johnnie Hill PRUDHOE BAY UN PTM P2-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Johnnie Hill Permit Number: 195-066-0 Inspection Date: 5/6/2016 Insp Num: mitJWH160508145143 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 - 'Type Inj W TVD 4949 ' Tubing 1582 3300 - 3241 - 3211 . 3190 3174 - PTD li 1950660 - Type Test SPT Test psi 1500 - IA 243 246 • 246 • 247 247 - 247 Interval OTHER P/F P - OA Notes: 2-yr MIT-T for monobore injector Completion to 3000 psi....used 3bbls diesel ✓ SCANNED SEP 2 7 2016 Tuesday,May 10,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 29, 2012 TO: Jim Regg 'Re/ 6/6-/1 P.I. Supervisor ` SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2 -34 FROM: Matt Herrera PRUDHOE BAY UN PTM P2 -34 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2 - 34 API Well Number 50 029 - 22558 - 00 - 00 Inspector Name: Matt Herrera Permit Number: 195 - 066 - Inspection Date: 5/11/2012 Insp Num: mitMFH120513135758 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2-34 - Type Inj W TVD 4949 . IA 788 2500 - 2460 2452 - � PTD 1950660 - Type Test SPT Test psi 1500 - OA Interval OTHER P /I, P - Tubing 1324 - 1336 1337 1329 - Notes: Monobore completion no OA. 2 1r ! — a c(a_ retu4,re.I p O l,r 0 4er ' 1zz1 q-7 5 LANNEDJLIL 1 2 202 Tuesday, May 29, 2012 Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] / „ 5//61 /� Sent: Tuesday, May 15, 2012 2:46 PM Z 7 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; 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; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); King, Whitney; Wills, Shane M Subject: OPERABLE: Injector P2 -34 (PTD #1950660) Passing AOGCC MIT -IA Confirms Integrity Attachments: MIT GPMA P2 -34 5- 12- 12.xls All, Injector P2 -34 (PTD #1950660) passed an AOGCC MIT -IA to 2500 psi on 05/11/2012. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. A copy of the MIT -IA is included for review. «MIT GPMA P2 -34 5- 12- 12.xls» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator a4 JUN 1 7L£!re Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIllntegrityCoordinator(a BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, May 06, 2012 3:37 PM To: Regg, James B (DOA); 'Schwartz, Guy L (DOA)'; AK, OPS GPMA OSM; A • PS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; Cism•: i, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead K, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike 3; end, Jon (NORTHERN SOLUTIONS LLC); Walker, Greg (D &C); LeBaron, Michael J Subject: UNDER EVALUATION: Injector P2 -34 (PTD #19.1660) Resume Injection to Complete Compliance Testing All, Injector P2 -34 (PTD #1950660) passed an AO' CC MIT -T to 2500 psi on 05/02/2012. The well may now resume water injection so an MIT -IA can be performed. T• - well is reclassified as Under Evaluation and may resume water injection. Plan forward: 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (---7 DATE: Monday, May 07, 2012 P.I. Supervisor I�� S 1�'t v SUBJECT: Mechanical Integrity Tests B P EXPLORATION (ALASKA) INC P2 -34 FROM: John Crisp PRUDHOE BAY UN PTM P2 -34 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN PTM P2 - 34 API Well Number 50 029 - 22558 - 00 - 00 Inspector Name: John Crisp Permit Number: 195 - 066 - Inspection Date: 5/2/2012 Insp Num: mitJCr120503080335 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P2 -34 , Type Inj N ' TVD 4949 ' IA o 0 0 0 PTD 1950660 ' Type Test SPT Test psi 1500 ' OA 5 7 8 9 Interval OTHER P/F P ' Tubing 360 2500 ' 2440 2420 Notes: 2 year MITT for monobore completion. 2,9 bbls pumped for test. ,, astikikle JUL 1 2. 1 °11 - f-' Monday, May 07, 2012 Page 1 of 1 • 0 Pnti( Pz -34 Regg, James B (DOA) 1615.0l40 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, May 07, 2012 11:16 AM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector 13 -18 (PTD #1820350) Begin Water Injection Prior to AOGCC MIT -IA Attachments: MIT PBU P2 -34 05- 02- 12.xls; MIT PBU H -21 04- 29- 12.xls; MIT PBU 13 -18 04- 22- 12.xls Jim, Enclosed are the MIT's for the 2 injection wells that I sent over the weekend and 1 producer I referenced for passing MITs this weekend. Iect inr 1 3 R tPTD #1820350 Inector P2 -34 TD #1950660)IL�� Producer H -21 (PTD #1860710) Please let me know if you need anything else. I'll ensure that the MITs are included with the letters I send. Jerry Murphy BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.reggftalaska.gov] Sent: Monday, May 07, 2012 10:18 AM To: AK, D &C Well Integrity Coordinator; Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Catron, Garry R (Northern solutions) Cc: Walker, Greg (D &C); Clingingsmith, Mike J; LeBaron, Michael J Subject: RE: UNDER EVALUATION: Injector 13 -18 (PTD #1820350) Begin Water Injection Prior ► 'OGCC MIT -IA Please send MITs you reference when bringing well on line. You probably send them wit e batch submittal later in month; we cannot wait for that submittal. A passing MIT is important info in suppor a decision to put well back on injection and should accompany the notice. Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: AK, D &C Well Integrity Coordinator [mailto: A II CWellInte•ri Coordinator' b•.com] Sent: Saturday, May 05, 2012 8:57 AM To: Regg, James B (DOA); Schwartz, Guy L (' dA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operatic) Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Qpt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Catron, Garry R (Northern solutions) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J; LeBaron, Michael J Subject: UNDER EVALUATIO Injector 13 -18 (PTD #1820350) Begin Water Injection Prior to AOGCC MIT -IA All, 1 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regaC5alaska.gov; doa. aoacc .prudhoe.bav(o).alaska.gov; phoebe.brooksealaska.gov; tom.maunder(cbalaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD I UNIT / PAD: Prudhoe Bay / GPMA / P2 (-7\"-e 5 7/17- DATE: 05/02/12 OPERATOR REP: Gerald Murphy AOGCC REP: John Crisp Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P2 -34 - Type Inj. N • TVD ' 4,949' Tubing 360 ' 2500 ' 2440 2420' Interval ,/ 0 P.T.D. 1950660 ' Type test P Test psi_ ' 1500 Casing 0 0 0 0 PIF P Notes: 2 year MIT -T for regulatory compliance monobore ' OA 5 7 8 9 Used 2.9 bbl meth to reach test pressure. ' _ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF 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 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/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) Form 10 -426 (Revised 06/2010) MIT PBU P2 - 34 05 - 02 - 12 Pth /c1 0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 7 5171« Sent: Sunday, May 06, 2012 3:37 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; 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; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike J; Arend, Jon (NORTHERN SOLUTIONS LLC); Walker, Greg (D &C); LeBaron, Michael J Subject: UNDER EVALUATION: Injector P2 -34 (PTD #1950660) Resume Injection to Complete Compliance Testing Attachments: P2 -34 (PTD # 1950660) TIO and Injection Plot.doc All, Injector P2 -34 (PTD #1950660) passed an AOGCC MIT -T to 2500 psi on 05/02/2012. The well may now resume water injection so an MIT -IA can be performed. The well is reclassified as Under Evaluation and may resume water injection. Plan forward: 1. Fullbore: Perform AOGCC MIT -IA to 2500 psi once thermally stable. - Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (a�BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, April 11, 2012 11:18 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GPMA OSM; AK, OPS GPMA Field O&M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; 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; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS L Subject: NOT OPERABLE: Injector P2 -34 (PTD #1950660) Due for AOGCC 2 Year Monobore Complian - esting All, Injector P2 -34 (PTD #1950660) is a monobore produced water - ector currently due for it's 2 year compliance MIT on 04/12/2012. The well has been shut in since 03/02/2012. rently rig Doyon 25 is working on an adjacent well, P2 -39, which is limiting the ability to perform well work on P2 -3 he well is reclassified as Not Operable until an MIT -T can be performed for compliance. Plan forward: 1. Slickline: Set tubing plug after Doyon • finishes P2 -39 2. Fullbore: AOGCC MIT -T to 2500 p ', AOGCC MIT -IA to 2500 psi A TIO and Injection plot and wz •ore schematic have been included for reference. 1 PBU P2-34 PTD # 1950660 5/6/2012 TIO Pressures Plot Welk P2-34 4.000 3.000 Tbg -0-- IA 2900 OA 00A -AV- 000A On 1,000 Alb 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 03/31/12 04/07/12 Injection Plot Well: P2-34 - 6,500 I 6.000 1,800 - - 5,500 1,600 - 5 1 ,400 - I : 4,5 1200- j \7 4,000 7: - WHIP SW a_ - 3,500 --- PW 1 ,000 - - MI - 3,000 - n GI - o Other 1 800 - -2500 • On 600 - - 2,000 - 1500 400 - - 1,000 200 - A - 500 01 /1 4/12 01/28/12 02/11/12 02/25/12 03/10/12 03/24/12 04/07/12 Pm 15o660 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] 'q 4 /Z /z.- Sent: Wednesday, April 11, 2012 11:18 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GPMA OSM; AK, OPS GPMA Field O &M TL; AK, OPS LPC DS Ops Lead; AK, OPS LPC Board Operator; AK, OPS LPC DS Operator; 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; Gerik, Bob G Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector P2 -34 (PTD #1950660) Due for AOGCC 2 Year Monobore Compliance Testing Attachments: P2 -34 (PTD # 1950660) TIO and Injection Plot.doc; P2 -34 (PTD # 1950660) wellbore schematic.pdf All, Injector P2 -34 (PTD #1950660) is a monobore produced water injector currently due for it's 2 year compliance MIT on 04/12/2012. The well has been shut in since 03/02/2012. Currently rig Doyon 25 is working on an adjacent well, P2 -39, which is limiting the ability to perform well work on P2 -34. The well is reclassified as Not Operable until an MIT -T can be performed for compliance. Plan forward: 1. Slickline: Set tubing plug after Doyon 25 finishes P2 -39 2. Fullbore: AOGCC MIT -T to 2500 psi, AOGCC MIT -IA to 2500 psi A TIO and Injection plot and wellbore schematic have been included for reference. «P2 -34 (PTD # 1950660) TIO and Injection Plot.doc» «P2 -34 (PTD # 1950660) wellbore schematic.pdf» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 AdViarrap APR 1'22O1a • S PBU P2 -34 PTD # 1950660 4/11/2012 TIO Pressures Plot Wdt P2 -34 4.000 — 3,000 i — Tb9 —IF IA 2.000 —A— OA 00A -.- 000A On 1000 MIL 01/14/1 2 01/21/1 2 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/1 03/10/12 03/1 7/12 03/24/12 03/31/12 04/07/12 Injection Plot Welt P2 -34 2,000 '` — - 6,500 1,800 : � y - s.o00 - 5,500 1,600 - - 5,000 1,400 - 4,500 — 4,000 �° WHIP 1,200 - _ 4, o WHIP - 3,500 — MI 1,000- - - 3,000 m — GI o Other 800 - - 2,500 — On B00 - - 2,000 - 1500 400 - - - 1,000 200 - - 500 01/14/12 01/28/12 02/11/12 02/25/12 03/10/12 03/24/12 04/07/12 TREE = 7 "x6" CARBON 5M COOPER WELLHEAD = 13 "x13" 5M FMC • � SAFETY E: WELL REQUIRES A SSSV. MONO - ACTUATOR = P Z �V 4 BORE WELL. KB. ELEV = 51.7' BF. ELEV = I I KOP = 1300' Max Angle = 55 @ 8279' Datum MD = w 12746' I I 2091' H5_112" PKR SWS NIP, ID = 4.562" Datum TV D = 8800' SS 20" CONDUCTOR, I 80' I ESTIMATED TOP OF CEMENT H 6247' • ∎ . • ■ • •� 6310' - 6435' H CEMENT SHEATH, ID = 4.49" (07/24/07) I • •� •'• • GAS LIFT MANDRELS ••k • o�� • •••, �1 ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 4.562 t@ 2091' ► ♦ • • j'� `' ∎• 1 6322 4910 51 HES LB DMY RM 0 12/26/06 5 -1/2" PARKER SWS NIPPLE ••• ;� • I.i ►�i�i' iti ■ • • i�i . ±i!• w11 ∎•• 6374' - 6376' HTBG PUNCH (6/13/07) I -1/2" TBG, 17 #, NT -80, NSCC, .02325 bpf, ID = 4.88" H 6387' 1 44-: kV 4 - * - 1' 6383' H9-5/8" X 7" BKR ZXP LTP, ID = 6.184" I TOP OF 5 -1/2" LNR 6397' 4i: e, i 6387' H BKR LNR TIEBACK SEAL ASSY, ID = 4.$75" P i . 4 6397' H 9 -5 /8" X 7" BKR HMC LNR HGR, ID =? I ■i �� 6403' H7" BKR PBR, ID = 6.184" A 6418' H7" X 5-1/2" XO, ID = 4.892" I 9 -5/8" CSG, 47 #, L -80, NSCC, ID = 8.681" H 6835' I ' I 12820' H5-1/2" PKR SWS NIP, ID = 4.562" I PERFORATION SUMMARY I 12825' H ELMD LOGGED ON 07/28/95 I REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 12896 - 12921 0 08/01/95 3 -3/8" 6 12901 - 12921 0 06/09/04 3 -3/8" 6 12930 - 12950 0 06/09/04 I 3 -3/8" 6 12950 - 12970 0 06/08/04 3 -3/8" 6 13010 - 13030 0 06/08/04 I 3 -3/8" 6 13070 - 13120 0 08/01/95 I I PBTD I—I 13230' I 041 5 -1/2" LNR, 17 #, NT -80, NSCC, .0233 bpf, ID = 4.892" IH 13326' 1 # ' + AJ DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 07/22/95 ORIGINAL COMPLETION 08/18/07 RLW /PJC CEMENT CORRECTIONS WELL: P2 -34 06/09/04 MDC /KAK AD /REPERF 08/18/07 RDB /PJC CMT /MILL QUICKDRILL (07/24/07) PERMIT: 1950660 01/04/07 RCT /TLH GLV C/O (12/26/06) 02/03/10 TLH/PJC 9 -5/8" CSG CORRECTION API No: 50- 029 - 22558 -00 04/27/07 RW /PJC TIEBK ASSY CORRECTIONS 03/29/10 ?/ PJC ELMD SWS LOGGED (07/28/95) SEC 14, T12N, R14E, 245' FNL & 1359' FWL 06/23/07 RRD /PJC TBG PUNCH, BP & PERF (06/13/07) 02/24/11 MB /JMD ADDED SSSV SAFETY NOTE 08/05/07 RLW /SV MILL OUT & CEMENT SQZ (07/27/07) BP Exploration (Alaska) • • PI P z -9/► Regg, James B (DOA) 656766,0 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, March 25, 2012 4:20 PM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: MIT Due Dates for BP Jim, Thank you for your review of this matter. On P2 -34, you did not enter the next due date, however based on the 2 year frequency requirement for monobore injectors this should be due on 04/12/2012. I will update all our records accordingly. Mehreen Vazir BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, March 23, 2012 2:35 PM To: AK, D &C Well Integrity Coordinator o. '�� Cc: Brooks, Phoebe L (DOA) MAR ' Subject: RE: MIT Due Dates for BP Thank you. Phoebe will review the discrepancies listed below. Re: PBU B -1S and PBU P2 -24, we will accept the unwitnessed MITs as satisfying the AOGCC requirements. The anniversary dates for MITs are adjusted as follows: - PBU B -15: last test 10/27/2009; next due 10/27/2013 - PBU P2 -34: last test 4/12/2010; next due Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: AK, D &C Well Integrity Coordinator [mailto:AKDCWeIIInte. " Coordinator @bp.com] Sent: Thursday, March 22, 2012 10:45 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT Due Dates for BP Jim, Phoebe, BPXA has conducted a review of the list . ovided. The following two online wells are noted as past due for not having an AOGCC witnessed MIT -IA: B -15 (PTD #1790190) was due f. a 4 -year AOGCC witnessed MIT -IA on 09/03/2011. An internal MIT -IA was performed on 10/27/2009 which reset our -year test flag. The internal test was performed to evaluate TxIA communication and the test form was submitted to t► - AOGCC. 1 • ' 6PZ- 34 Regg, James B (DOA) Pm 1q5066,o To: AK, D &C Well Integrity Coordinator 3 Cc: Brooks, Phoebe L (DOA) �� 3 4 7 °' Subject: RE: MIT Due Dates for BP Thank you. Phoebe will review the discrepancies listed below. Re: PBU B -15 and PBU P2 -24, we will accept the unwitnessed MITs as satisfying the AOGCC requirements. The anniversary dates for MITs are adjusted as follows: - PBU B -15: 4yr MIT interval; last test 10/27/2009; next due 10/27/2013 PBU P2 -34: 2yr MIT interval; last test 4/12/2010; next due 4/12/2012 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 504\414a) MAR 2 8 Z D Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, March 22, 2012 10:45 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT Due Dates for BP Jim, Phoebe, BPXA has conducted a review of the list provided. The following two online wells are noted as past due for not having an AOGCC witnessed MIT -IA: B -15 (PTD #1790190) was due for a 4 -year AOGCC witnessed MIT -IA on 09/03/2011. An internal MIT -IA was performed on 10/27/2009 which reset our 4 -year test flag. The internal test was performed to evaluate TxIA communication and the test form was submitted to the AOGCC. «B- 15.pdf» «MIT PBU B -15 10- 27- 09.xls» «B -15 TIO 03- 22- 12.doc» P2 -34 (PTD #1950660) was due for a 2 -year AOGCC witnessed MIT -IA on 02/14/2011 and MIT -T on 03/30/2011. Internal MITs were performed on 04/12/2010 which reset our 2 -year test flag. The internal tests were performed in order to evaluate this well for MI service «P2- 34.pdf» «MIT PBU P2 -34 04- 12- 10.xls» «P2 -34 TIO 03- 22- 12.doc» The following wells appear to have incorrect information in the AO -CC list based on this review: - 11 -08 (PTD #1842290) - AOGCC data notes 8 yea t frequency but is online - 12 -21 (PTD #1840480) - AOGCC data notes fear test frequency instead of 4 year - 13 -32A (PTD #2012350) - AOGCC dat- stes 8 year test frequency but the well is online - 16 -03 (PTD #1810110) - AOGCC e - a notes the last test date as 04/15/2010 with a 4 year frequency but still shows a past due test date of 06/13/200• 1 . • 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. (e/j1 z 3(23jt FIELD / UNIT / PAD: Prudhoe Bay / GPMA / PM 2 DATE: 04/12/10 OPERATOR REP: Mehreen Vazir AOGCC REP: Not Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. Well P2 -34 Type Inj. N TVD ' 4,949' Tubing 2,000 2,000 2,010 2,020 Interval 0 P.T.D._1950660 ' Type test P Test psi ' 1500 Casing - 4,000 3,960 - 3,940 P/F P Notes: Monobore - MIT -IA OA Well P2 -34 - Type Inj. N TVD - 4,949' Tubing 3,970 ' 4,000 3,960 ' 3,940 Interval 0 P.T.D. 1950660 ' Type test P Test psi - 1500 Casing 2,020 2,000 2,010 2,020 P/F P Notes: Monobore - MIT -T 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 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/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 MIT Report Form BFL 11/27/07 MIT PBU P2 -34 04 -12 -10 • • PBU P2 -34 PTD #1950660 3/22/2012 TIO Pressures Plot Wet P2 -34 4,0110 — i —41— r 2.00 - geeneme■, --+— QA 00A 41147riVIVIeeeemmwed } L 000/1 On • fl 4181 04/08/11 05/09m T 06/09/11 07/10/11 08/10/1 1 09)10/11 10/11/11 11;11/11 12/12/11 01/12/12 02/12/12 03/14/12 Injection Plot W.l P234 — - 15.000 2000 • - 1,900 - 4 - 14,000 • 1101 . N ff� i s 13.000 1.700 Ivy • ) " I ' ./ L ' 12000 s00 I . 1.00 • „mo • • .toroo 9 OOD 100 - — WHIP 1.10 . ..8000 $W F Q —PW 1A00 -1001 $ 900. — Met 6.IX1 On B00' 700 - 5 000 ® a.0® I 300' - 2.000 W0 04r16n1 05J09n1 06NOn1 OJJ?Olit U3l ?lV11 U %10111 10/11;11 , , f 11/11 lvivil 01112/12 02n2n2 03714n2 1 TREE = 7 "x6" CARBON 5M COOPER • WELLHEAD = 13 "x13" 5M FMC SAFETYE: WELL REQUIRES A SSSV. MONO - ACTUATOR = P2-34 BORE WELL. KB. ELEV = 51,7' BF. ELEV = I I KOP = 1300' Max Angle = 55 @ 8279' Datum MD = 12746' 1 2091' H5-1/2" PKR SWS NIP, ID = 4.562" 1 Datum TV D = 8800' SS 120" CONDUCTOR, I 80' ESTIMATED TOP OF CEMENT I 6247' v � •�•∎ i�•� 6310' - 6435' CEMENT SHEATH, ID = 4.49" (07/24/07) • ##' GAS LIFT MANDRELS 10. V e.N. ∎ # * # ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 4.562 ' "@ • 2091' ► 4 1 , � A� 1 6322 4910 51 HES LB DMY RM 0 12/26/06 ■ 5-1/2" PARKER SWS NIPPLE .. �• "4 O.,* •►# •∎ 10 ''''. 6374' - 6376' H TBG PUNCH (6/13/07) -1/2" TBG, 17 #, NT -80, NSCC, .02325 bpf, ID = 4.88" H 6387' I *.. ■ :� it i 4'01 6383' H9-5/8" 9 -5/8" X 7" BKR ZXP LTP, ID = 6.184" I 1 TOP OF 5-1/2" LNR I--1 ) :t 6397' lo 1 6387' BKR LNR TIEBACK SEAL ASSY, ID = 4.875" �� 6397' H 9 -5/8" X 7" BKR HMC LNR HGR, ID =? 1 g 6403' Hr BKR PBR, ID = 6.184" 1 6418' H7" X 5-1/2" XO, ID = 4.892" 1 9 -5/8" CSG, 47 #, L -80, NSCC, ID = 8.681" H 6835' I I 12820' H5-1/2" PKR SWS NIP, ID = 4.562" I PERFORATION SUMMARY 12825' H ELMD LOGGED ON 07/28/95 1 REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical perf data f SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 12896 - 12921 0 08/01/95 3 -3/8" 6 12901 - 12921 0 06/09/04 3 -3/8" 6 12930 - 12950 0 06/09/04 3 -3/8" 6 12950 - 12970 0 06/08/04 3 -3/8" 6 13010 - 13030 0 06/08/04 I 3 -3/8" 6 13070 - 13120 0 08/01/95 I 1 PBTD H 13230' I ►1111 5 -1/2" LNR, 17 #, NT -80, NSCC, .0233 bpf, ID = 4.892" H 13326 i�i��i DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 07/22/95 ORIGINAL COMPLETION 08/18/07 RLW /PJC CEMENT CORRECTIONS WELL: P2 -34 06/09/04 MDC/KAK AD /REPERF 08/18/07 RDB /PJC CMT /MILL QUICKDRILL (07/24/07) PERMIT': r 1950660 01/04/07 RCT /TLH GLV C/O (12/26/06) 02/03/10 TLH/PJC 9 -5/8" CSG CORRECTION API No: 50- 029 - 22558 -00 04/27/07 RW /PJC TIEBK ASSY CORRECTIONS 03/29/10 ?/ PJC ELMD SWS LOGGED (07/28/95) SEC 14, T12N, R14E, 245' FNL & 1359' FWL I 06/23/07 RRD /PJC TBG PUNCH, BP & PERF (06/13/07) 02/24/11 MB /JMD ADDED SSSV SAFETY NOTE 08/05/07 RLW /SV MILL OUT & CEMENT SQZ (07/27/07) 1 BP Exploration (Alaska) Sc61um6er~r Alaska Data 8 Conauhing Servrces ~n1 y® 2525 <3smbeK Sheol, 3uke 400 ~ ~ V - ,~^1 ((("""111 ~') / 1 Mehorsgs, AK 99503-2838 ~ ~~ '6/./' ~`~Sy AT7N: Belh Well Job k ~g Description Oate on27no N0.5567 Company: State of Alaska Alaska Oi18 Gas Cons Comm Arin: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD P2-/6 F-03A BBBM-00027. AVKP-00096 LDL - I 07/210 1 1 V-225 BBKA•00039 SCMT ~ ~ USIT 07/22/10 1 1 S-100 2-56/S-D9 BCZ2.00014 BCZ2 00016 USIT r r L 07/01/10 07/14/10 1 / 1 1 /-15/P-25 W-19A 01-228 - AVKP-00094 BCRD-00036 A22F-00042 DL LDL - USIT ~ MCNL ~ 07/17/10 07/11/10 07/25/10 1 1 1 1 1 1 B-20 04-20 8-18 OS-32A AY1M-00042 BCRJ-00020 AVKP-00082 86K5-00040 RST RST RST RST -. ¢.- - . 05/19/10 05/07/10 05/30/10 06/02/10 05/19/10 1 1 1 1 1 1 1 1 1 H-25 P2.34 BCRD-011017 AVYO-00063 _ RST '~ ~ ~`\ RS - ' 05H0/10 1 1 1 T ~.,rO T 04/17/10 1 1 PLEASE ACKNOWLEDGE REC EIPT RV SIGNIN (: eun aeruouwr_ nue nnnv ~...~ ~..- tll' txploralion (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. / l~).~~.`~' Alaska Data 8 CortsuKing Services 2525 6ambeN Sheet, Su3e 400 Anchorage. AK 99503.2938 ~'1~'! ~,., ~~ . ~~~ ~~ • • !~, osn en o i Sc~lumherger Alaska Data b Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2938 ATTN: Beth N0.5545 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Welt Job # Log Description Date BL Color CD E-19R RRUn-nnnt S 4TenC wnTTn~~ a rc~~o m ~ovov H-30 - _ BCRD-00020 PRODUCTION PROFILE 05/10/10 1 1 P2.34 83SQ-00071 STATIC PRESSURE SURVEY 05/15/10 1 1 P2-34 8350.00073 (PROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJM00090 MEM CBL '~ 05/24/10 1 1 P2-17 16.068 BCRC-00017 BBUO.00023 PRODUCTION PRO ICE PRODUCTION PROFILE .06/01/10 06/08/10 1 1 1 1 S-21 Z-46A BBSK-00019 BAUJ-00027 PRODUCTION PROflLE MEM CBL 06/03/10 06/01N0 t 1 1 1 V-OS 01-26A BD88-00018 B14B-00106 MEM LOL SCMT 06/08/10 06/10/10 1 1 i 1 B-13A 1-27/P-20 BBUO-00019 AYKP-00085 USIT RST & FL RECOR 05/28/10 O6/06/10 / 1 1 1 1-27/P-20 AYKP-00085 PRODUCTION PROFILE 06/06/10 1 i MPF-82A BAUJ-00010 MCNL 04/06/10 1 1 Z-16A E-15D BCUE-00005 AWJI-00081 CH EDIT POC MEM CORR CATION MCNL 04/06/10 04/03/10 1 1 1 05-19 BBKA-00013 RST - 03/14/10 1 1 F-27A AYKP-00078 RST 03/17/10 1 1 J-18A BDBg-00010 MCNL 04/18/10 1 1 BP Exploration (Alaska) Inc. Pefrotechnical Data Center LR2-1 900 E. Benson Blvd. i'; Ataska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2839 ~~ ~ ~~ ,ilJf~ `~~ ~?(11,1 ~~ ~° ~~. a~x~n~~ ~n~~ !~ C~ Ross Warner Petroleum Engineer BP Exploration (Alaska), Inc. n ~_ ~ (^~ P.O. Box 196612 ~ "~ Y~ --- _ _ -- Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Point McIntyre Pool, PBU P2-34 Sundry Number: 310-079 Dear Mr. Warner: n 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 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 231 DATED this day of March, 2010. Encl. STATE OF ALASKA ~~" " ~ ~~ ~~~ ALASKA'CfIL AND GAS CONSERVATION COMMISSI~ ,~/ ~ ~~~/p APPLICATION FOR SUNDRY APPROVALS ~ ,~,~~~ MAR ~ ~ X010 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool^ Repair Well ^ ~I~~AsttuovedP Suspend ^ Plug Pertorations ^ Pertorate^ Pull Tubing ^ tension ~ 11(T < , Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ' Other: Dia nostic work/tem as in 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 195-0660 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22558-00-00 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: Spacing Exception Required? Yes ^ No ^ PBU P2-34 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-034624 ~ PRUDHOE BAY Field /POINT MCINTYRE Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13326 - 9231.65 ~ 13230 9169 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" SURFACE 80 SURFACE 80 1530 520 Surtace 6494 9-5/8" 47# L-80 SURFACE 6835 SURFACE 5235 6870 4760 Intermediate Production Liner 6943 5-1/2" 17# NT-80 6397 13326 4949 9232 7740 6280 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 17# NT-80 SURFACE 6387 Packers and SSSV Tvpe: 7" Baker ZXP Top Packer Packers and SSSV MD and ND (ftl: 6383 4949 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: ( , to 3 g Commencing Operations: 3/24/2010 WDSPL ^ Plugged ^ Oil ^ Gas ,_f ~ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ~ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Warner Printed Name Ross Warner Title P.E. Phone Date Signature - ,~ ; ~ '~-,r-s: 564-5359 3/17/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY witness Sundry Number: 3 ~ O ~ ~ Conditions of a roval: Notif Commission so that a re resentative ma , y p y pp Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Locati`~Clearance ^ MST tA. ~!-'1~~'T c~.s Q~zt~.cJ Other: Subsequent Form Required: 1..`0 ~ ~ (~ c~~ ~S~ ~~5~ 1 ~ ~ dfi E1~ ~ C-cs~~~~~~~~'~~~~ ~ ~Q~ t APPROVED BY " I J ~ 23 ~c~ Approved by: COMMISSIONER THE COMMISSION Date: //// RForm 10 403 Re~ise~9~/ .~~ G I N A L ~3~15 Submit in Duplicate ~~~~~~~ ~~. ~~~~~~ P2-34i Infector Background • This well was completed in June of 1995. It produced briefly from August through September when it was converted to an injector • P2-34 had a history of tubing to IA communication • A leak detection log was run April 23, 2007 and the results indicated the PBR was the problem • The PRB was successfully squeezed January 7, 2007 and was pressure tested to 3000 psi on August 12, 2007 • Currently there are no well integrity issues • A MIT-IA was successfully tested to 4000 psi on February 15, 2009 • A MIT-T was successfully tested to 2400 psi on March 28, 2009 Proposed diagnostic work to support long term gas infection: • MIT Tubing to 4000 psi • MIT IA to 4000 psi • Run aRST/Borax log • Put the well on MI injection for six weeks • Run another RST/Borax log • Evaluate the logs • Sublimit a request for gas injection If there are any questions please call Ross Warner at 564-5359 P2-34 195-066 PERF ,4TT~4CHMENT n U • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P2-34 8/1/95 PER 12,896. 12,921. 8,951.58 8,968.09 P2-34 8/1/95 PER 13,070. 13,120. 9,065.59 9,097.88 P2-34 6/8/04 APF 12,950. 12,970. 8,987.2 9,000.34 P2-34 6/8104 APF 13,010. 13,030. 9,026.54 9,039.59 P2-34 6/9/04 APF 12,930. 12,950. 8,974.02 8,987.2 P2-34 6/9/04 RPF 12,901. 12,921. 8,954.88 8,968.09 P2-34 6/12/07 BPS 6,435. 6,440. 4,981.48 4,984.63 P2-34 6/13/07 PER 6,374. 6,376. 4,943.16 4,944.42 P2-34 7/21/07 BPS 6,350. 6,353. 4,928.08 4,929.97 P2-34 7/24/07 BPP 6,350. 6,353. 4,928.08 4,929.97 P2-34 7/25/07 BPP 6,435. 6,440. 4,981.48 4,984.63 P2-34 7/25/07 SQZ 6,310. 6,435. 4,902.97 4,981.48 P2-34 3/22/09 BPS 12,825. 13,120. 8,904.63 9,097.88 P2-34 4/8/09 BPP 12,825. 13,120. 8,904.63 9,097.88 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 ~~ ~~ *~~. P2-34i Infector Backuround • This well was completed in June of 1995. It produced briefly from August through September when it was converted to an injector • P2-34 had a history of tubing to IA communication • A leak detection log was run April 23, 2007 and the results indicated the PBR was the problem • The PRB was successfully squeezed January 7, 2007 and was pressure tested to 3000 psi on August 12, 2007 • Currently there are no well integrity issues • A MIT-IA was successfully tested to 4000 psi on February 15, 2009 • A MIT-T was successfully tested to 2400 psi on March 28, 2009 Proposed diagnostic work to support Iona term gas infection: • MIT Tubing to 4000 psi • MIT IA to 4000 psi • Run aRST/Borax log • Put the well on MI injection for six weeks • Run another RST/Borax log • Evaluate the logs • Sublimit a request for gas injection If there are any questions please call Ross Warner at 564-5359 TREE = 7"x6" CARBON SM COOPER WELLHEAf~ = 13"x13" 5M FMC ACTUATOR = KB. ELEV = 51.7' BF. ELEV = KOP = 1300' Max Angle = 55 @ 8279' Datum MD = 12746' Datum TV D = 8800' SS 5-1/2" PKR SWS NIP, ID = 4.562" 20" CONDUCTOR, ~-j 80' ~ ESTIMATED TOP OF GEMENT 6247' 6310" - 6435' CEMENT SHEATH, ID = 4.49" {07/24/07) GAS LIFT MANDRELS _ _ ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 4.562 "~ 291' 1 6322 4911 51 HES LB DMY RM 0 12/26lOE 5-112" PARKER SWS NIPPLE 6374' - 6376' TBG PUNCH (6!13/07) -112" TBG, 17#, NT-80, NSCC, .02325 bpf, ID = 4.88" 63$T TOP OF 5-1/2" LNR 6397 ~~~~~~ 6383 9-518" X 7" BKR ZXP LTP, ID = 6.184" 63$7' BKR LNR TIEBACK SEAL ASSY, ID = 4.875" 6397 9-5/8" X 7" BKR HMC LNR HGR, ID =? 6403' 7" BKR FBR, ID = 6.184" 6418' 7" X 5-1/2" XO, iD = 4.892" 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" ~--{ 6$35 PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 12896 - 12921 O 08/01 /95 3-318" 6 12901 - 12921 O 06/09/04 3-3i8" 6 12930 - 12950 O 06/09/04 3-3i8" 6 12950 - 12970 O 06/08/04 3-3/8" 6 1301 p - 13030 O 06/08/04 3-3/8" 6 13070 - 13120 O 08/01/95 PBTD -~ 13230, 5-1/2" LNR, 17#, NT-80, NSCC, .0233 bpf, ID = 4.892" 13326' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/95 ORIGINAL COMPLETION 08!18!07 RLW/PJC CEMEM CORRECTIONS 06/09/04 MDClKA AD/REPERF RDB/PJC CMT/MILL QUICKDRILL (0712 01104!07 RCT/TLH GLV C/O (12!26106) 02!03/10 TLWPJC 9-5/8" CSG CORRECTION 04/27/07 RW/PJC TIEBK ASSY CORRECTIONS 06!23/07 RRD/PJC TBG PUNCH, BP & PERF (06113!07} 08!05/07 RLWlSV MILL OUT & CEMENT SOZ (07127/07} P 2 -34 SAFEfY NO ONO-BORE WE1L. 5-112" PKR SWS NIP, ID = 4.562" POINT MCINTYRE UNIT WELL: P2-34 PERMIT: 1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration (Alaska) • by cr,~,y • P2-34i Sundry Request Well Type: Water Injector Current Status: This well is currently performing as a produced water injector. Request: Install a new 3-1/2" completion to allow this well to become a WAG injector. Well History: Well P2-34i was completed in June 1995 as a mono-bore completion with two perforated intervals in the LC4 and the LC1 zones. The well produced briefly from August thru September when it was converted to injection. The well initially produced over 4,000 BOPD and cum production was only 134 KBO with minimal water production. Since conversion, the well has injected 47.9 MMBW. An (PROF was obtained on the well in August 2000. Splits indicated 100% entry into the LC1. A 68 hour warm-back pass confirmed distribution of injected fluids in the reservoir. The LC3 & 4 were receiving less injection than the LC1 & 2. Bottom of injection was not seen on the log. It passed a MITIA to 2000 psi in October 2002. In June 2004, new perforations were added in the LC3 (12,930-70') and LC2 (13010-30'}. Additionally 20' of the LC4 were re-perfed. In September 2004 the well was swapped from sea water injection to produced water injection and the infectivity decreased by 25-30% due to poorer water quality. An IPROF and warm-backs in June 2005 indicated the majority of the water entering the LC1. In 2007 a leak was identified across the seals in the PBR and a cement squeeze was performed a few months later. CTU milled out the cement from the tubing, leaving a cement sheath from 6310' to 6435'. A March 2009 caliper showed the liner above the SWS Nipple at 12820' to be in good to fair condition with respect to corrosive , damage, with no significant areas of cross-sectional wall loss recorded. It also showed the tubing to be in good to poor condition with respect to corrosive and mechanical damage. A maximum wall penetration of 50% was recorded in an isolated area of apparent erosion at 6385'. No significant areas of cross-sectional wall loss or ID restrictions were seen. The caliper indicated slight buckling in the 5.5" tubing from about 800' to about 6200' and moderate to sever buckling in the liner, increasing in severity from 6530' to 12900'. It also showed light deposits throughout the liner. In March 2009 SL ran 4.5" and 4.55" broaches through the cement sheath to 6600' and used a 4.56" broach to clear restrictions at 6293' and 6390' SLM. They attempted to seta 5.5" plug to perform a pressure test, but were not able to pass 6396'. They performed a brush and flush with a 5.5" brush and then drifted to 12900' with ' a 4.5" gauge ring.. When they again tried to set the 5.5" plug it could not pass 6393', and a 4.54" drift could not pass 6387'. It was then decided to have a-line set an inflatable bridge plug instead. A blue-goo treatment to protect the surface casing from corrosion was performed in June 2009. The treatment . involved pumping 11.5 gallons of blue-goo into the surface casing x conductor void (18" deep) at surface. Scope of Work: It is desired to make P2-34i a WAG injector to increase recovery from the area; however, that is not possible with amono-bore completion due to state regulations. This RWO will install a new tubing strip, ig nside the current 5-1/2" string and set a packer at approximately 12 700' MD (200' above perfsl, so the well will no longer be a mono-bore and WAG iniection can commence. P2-34i Sundry Application 1 1/5/2010 • MASP: 3245 psi Pre-Ri O rations• 1. S Run ressure surve on well to confirm reservoir re ressure. 2. W PPPOT-T to 5000 si, PPPOT-IC to 3500 i. RU service coil unit and RIH w/ 4.75" mill and a string reamer and mill out nipple f~ 2091', the cement sheath ~ 6310'-6435' (be careful not to stack too much weight that we end up milling a hole in the side of the 5-1/2" tubing) and clean- out down to SWS nip ~ 12820'. POOH. Run back into with 4-3/4" mill and 30' 3 C "stiff" BHA for drift down to 12820' and note any possible weight greater than 8- . 10K which could indicate path-forward issues/problems for running the planned 3-112" completion. This service coil work will be done under-balanced (this water injector well should flow "water") to allow all clean-out debris to be removed from the well. NOTE: See detailed ocedure f/Wells Grou . 4 S Drift well with a 4.6 GR/JB working up to a 4.75 GR/JB to 12,800' MD and repeat . until hole is clean. Bullhead the 5-1/2" tubing with 1.5-2 tubing volumes of 9.3 ppg brine (the brine weight to be finalized by the pressure survey in Step #1) at 5.5 bpm to kill the 5. F well. Shut down and flow-check the well. If the well is "dead", pump an adequate volume of diesel to freeze protect the 5-1/2" tubing to 500' MD. NOTE: Confirm brine wei hUfreeze rotect Ian w/ODE. 6. S Set 5-1/2" PX lu in the SWS ni le at 12,820' MD. ' 7 F/S Perform MIT-T to 4000 psi; IA to 2000 psi, if unable to get a good PT on tubing, run/set a WRP to 12,700' MD and re-test. 8. O Bleed all ressure to zero. Set BPV. Secure well. 9. O Remove the well house and level pad if necessary. Remove surrounding well- houses. Ria Operations• 1. Mi ! RU Do n 14 yo k 2. Bleed tubing pressure to 0 /confirm well is dead. 'i~' 3. Pull BPV w/lubricator and set TWC and test to 3500 psi from above. 66` 4. Nipple dawn tree 8~ tubing adapter. Nipple up new tubing spool (use this as spacer spool). Nipple up and test BOPE to 4000psi high/ 250psi low. Pull TWC. 5. With wire-line, pull PX Plug and bull-head brine (-9.3 ppg or as determined in Step #1 of the pre-rig work above) as required to stabilize the well. 6. With wire-line, run 4.75" GR/JB to 12,820' MD to confirm well is clean. 7. R/U 8~ begin running 3-1/2", 9.2#, L-80, TCII tubing completion (injection packer depth 12,700' MD). 8. Space out and make up tubing hanger per FMC Rep. 9. Land the tubing hanger, and run in lock down screws. 10. Reverse circulate the well to place clean brine, inhibited brine and freeze protect diesel on the annular side of the tubing. 11. Bull-head freeze protect diesel down the tubing and drop ball and rod. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes, bleed tubing to 1500 psi, pressure test IA to 4000 psi for 30 min. Record each test. - S~t~ irk ~ 12. Set a TWC, test from above and below. 13. Nipple down the BOPE. Nipple up the tree and adapter flange Oand test to 5,000 psi w/diesel. 14. Pull TWC w/lubricator. 15. Set BPV and secure the well. 16. RD and move off well. Post-Ria Ouerations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. P2-34i Sundry Application 2 1/5/2010 3. Modify S- Riser As Needed 4. ASRC Flowback Estimated Pre-rig Start Date: 01/15/2010 Estimated RWO Date: 03/20/2010 Drilling Engineer: Abby WarreNJohn Rose (907) 564-5720/5271 Production Engineer: Megan Kimmet (907) 564-5851 ATTACH: Current Well Schematic Post RWO Well Schematic P2-34i Sundry Application 3 1/5/2010 • • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Mr. Greg Hobbs Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~9~ Re: Prudhoe Bay Field, Point McIntyre Oil Pool, PBU P2-34 Sundry Number: 310-002 Dear Mr. Hobbs: 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 Chair DATED this ~ day of January, 2010 Encl. STATE OF ALASKA ~~ +~~ IQ ALAS~IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~''~_8 ~p ;~ `' l ` r J ~_ 1. Type of Request: h ~ ~r, rff ^ Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Re-Enter Suspended Well (d ~~~ ~,~~ ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ®Other Specify: 4 ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension Convert to WAG Injector ~ ~t -~ri h 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 195-066 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22558-00-00 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: PBU P2-34 ~ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): , ADL 034624 ~ Prudhoe Bay Field /Point McIntyre Oil 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): 13326' - 9232' - 13230' 9169' None None Casin Len th Size MD TVD Burst Colla se Structural Conductor 0' 1 2 Surface 6494' 9-5/8" 35' 5044' 6870 476 Intermediate Production Liner 6 4 ' 5-1/2" 3 3' - 1 2 ' 4949' - 9232' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12896' - 13120' 8952' - 9098' S-1/2", 17# NT-80 6421' Packers and SSSV Type: N/A Packers and SSSV N/A MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 15, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ . ®WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name Greg Hobbs Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4191 Date !~C%20la Terrie Hubble, 564-4628 Commission Use Onl Conditions of approva : otity Commission that a representative may witnessf,~ /D _ 11a~ Sundry Number: ,~/ (J ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance ~ yDoo ~s~ ~a~ ~cs'~ Other. s ~ ~n +~.... ~~cr // s f ~~~ n >~ ZSoo ~ Subse uent Form Re uired: q q APPROVED BY /~ r, ` ~ Z lJ D ate Approved By: COMMISSIONER THE C~MMISSI~N Form 10-403 Revised 0772000. I,.~ 7~ ~'~~' ~° RBDMS Submit In Duplicate JAN 13 1010 .~1_. % ~0/ / ~G by c,~, • P2-34i Sundry Request Well Type: Water Injector Current Status: This well is currently performing as a produced water injector. Request: Install a new 3-1/2" completion to allow this well to become a WAG injector. Well History: Well P2-34i was completed in June 1995 as a mono-bore completion with two perforated intervals in the LC4 and the LC1 zones. The well produced briefly from August thru September when it was converted to injection. The well initially produced over 4,000 BOPD and cum production was only 134 KBO with minimal water production. Since conversion, the well has injected 47.9 MMBW. An IPROF was obtained on the well in August 2000. Splits indicated 100% entry into the LC1. A 68 hour warm-back pass confirmed distribution of injected fluids in the reservoir. The LC3 & 4 were receiving less injection than the LC1 & 2. Bottom of injection was not seen on the log. It passed a MITIA to 2000 psi in October 2002. In June 2004, new perforations were added in the LC3 (12,930-70') and LC2 (13010-30'). Additionally 20' of the LC4 were re-perfed. In September 2004 the well was swapped from sea water injection to produced water injection and the infectivity decreased by 25-30% due to poorer water quality. An IPROF and warm-backs in June 2005 indicated the majority of the water entering the LC1. In 2007 a leak was identified across the seals in the PBR and a cement squeeze was performed a few months later. CTU .milled out the cement from the tubing, leaving a cement sheath from 6310' to 6435'. A March 2009 caliper showed the liner above the SWS Nipple at 12820' to be in good to fair condition with respect to corrosive , damage, with no significant areas of cross-sectional wall loss recorded. It also showed the tubing to be in good to poor condition with respect to corrosive and mechanical damage. A maximum wall penetration of 50% was recorded in an isolated area of apparent erosion at 6385'. No significant areas of cross-sectional wall loss or ID restrictions were seen. The caliper indicated slight buckling in the 5.5" tubing from about 800' to about 6200' and moderate to sever buckling in the liner, increasing in severity from 6530' to 12900'. It also showed light deposits throughout the liner. In March 2009 SL ran 4.5" and 4.55" broaches through the cement sheath to 6600' and used a 4.56" broach to clear restrictions at 6293' and 6390' SLM. They attempted to seta 5.5" plug to perform a pressure test, but were not able to pass 6396'. They performed a brush and flush with a 5.5" brush and then drifted to 12900' with ' a 4.5" gauge ring. When they again tried to set the 5.5" plug it could not pass 6393', and a 4.54" drift could not pass 6387'. It was then decided to have a-line set an inflatable bridge plug instead. A blue-goo treatment to protect the surface casing from corrosion was performed in June 2009. The treatment . involved pumping 11.5 gallons of blue-goo into the surface casing x conductor void (18" deep) at surface. Scope of Work: It is desired to make P2-34i a WAG injector to increase recovery from the area; however, that is not possible with amono-bore completion due to state regulations. This RWO will install a new tubing string inside the current 5-1/2" string and set a packer at approximately 12 700' MD (200' above perfs), so the well will no longer be a mono-bore and WAG injection can commence. P2-34i Sundry Application 1 1/5/2010 • , MASP: 3245 psi Pre-Ri O erations: 1. S Run ressure sunre on well to confirm reservoir ore ressure. 2. W PPPOT-T to 5000 si, PPPOT-IC to 3500 si. RU service coil unit and RIH w/ 4.75" mill and a string reamer and mill out nipple ~ 2091', the cement sheath C«3 6310'-6435' (be careful not to stack too much weight that we end up milling a hole in the side of the 5-1/2" tubing) and clean- out down to SWS nip @ 12820'. POOH. Run back into with 4-3/4" mill and 30' 3 C "stiff" BHA for drift down to 12820' and note any possible weight greater than 8- . 10K which could indicate path-forward issues/problems for running the planned 3-1/2" completion. This service coil work will be done under-balanced (this water injector well should flow "water") to allow all clean-out debris to be removed from the well. NOTE: See detailed rocedure f/Wells Grou . 4 S Drift well with a 4.6 GR/JB working up to a 4.75 GR/JB to 12,800' MD and repeat . until hole is clean. Bullhead the 5-1/2" tubing with 1.5-2 tubing volumes of 9.3 ppg brine (the brine weight to be finalized by the pressure survey in Step #1) at 5.5 bpm to kill the 5. F well. Shut down and flow-check the well. If the well is "dead", pump an adequate volume of diesel to freeze protect the 5-1/2" tubing to 500' MD. NOTE: Confirm brine wei ht/freeze rotect Ian w/ODE. 6. S Set 5-1/2" PX lu in the SWS ni le at 12,820' MD. ' 7 F/S Perform MIT-T to 4000 psi; IA to 2000 psi, if unable to get a good PT on tubing, . run/set a WRP to 12,700' MD and re-test. 8. O Bleed all ressure to zero. Set BPV. Secure well. 9 O Remove the well house and level pad if necessary. Remove surrounding well- houses. Ria Operations: 1. MI / RU Do on 14 ~ b 2. Bleed tubing pressure to 0 /confirm well is dead. 3~' ~ 3. Pull BPV w/lubricator and set TWC and test to 3500 psi from above. bar 4. Nipple down tree & tubing adapter. Nipple up new tubing spool (use this as spacer spool). Nipple up and test BOPE to 4000psi high/ 250psi low. Pull TWC. 5. With wire-line, pull PX Plug and bull-head brine (-9.3 ppg or as determined in Step #1 of the pre-rig work above) as required to stabilize the well. 6. With wire-line, run 4.75" GR/JB to 12,820' MD to confirm well is clean. 7. R/U & begin running 3-1/2", 9.2#, L-80, TCII tubing completion (injection packer depth 12,700' MD). 8. Space out and make up tubing hanger per FMC Rep. 9. Land the tubing hanger, and run in lock down screws. 10. Reverse circulate the well to place clean brine, inhibited brine and freeze protect diesel on the annular side of the tubing. 11. Bull-head freeze protect diesel down the tubing and drop ball and rod. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes, bleed tubing to 1500 psi, pressure test IA to 4000 psi for 30 min. Record each test. - S~eu Dcrk j 12. Set a TWC, test from above and below. 13. Nipple down the BOPE. Nipple up the tree and adapter flange Oand test to 5,000 psi w/diesel. 14. Pull TWC w/lubricator. 15. Set BPV and secure the well. 16. RD and move off well. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. P2-34i Sundry Application 2 1/5/2010 3. Modify S- Riser As Needed 4. ASRC Flowback Estimated Pre-rig Start Date: 01/15/2010 Estimated RWO Date: 03/20/2010 Drilling Engineer: Abby Warren/John Rose Production Engineer: Megan Kimmet ATTACH: Current Well Schematic Post RWO Well Schematic ~J (907) 564-5720/5271 (907) 564-5851 P2-34i Sundry Application 3 1/5/2010 TREE = 7"x6" CARBON 5M COOPER WELLHEAD = 13"x13" 5M FMC ACTUATOR = KB. E3EV = 51.7' BF. ELEV = KOP = 1300' Max Angle = 55 @ 8279' Datum MD = 12746' Datum Ti/ D = 8800' SS P2 X34 AO CC IS~WI~, 9 23- 8M MONO-BORE WELL98 2091' H 5-1 /2" PKR SWS NIP, ID = 4.562" ~20" CONDUCTOR, ~-~0~ ESTIMAT® TOP OF CEMENT 6247' Minimum ID = 4.562 "@ 2091' 5-1/2" PARKER SWS NIPPLE 5-1/2" TBG, 17#, NT-80, NSCC, .02325 bpf, ID = 4.88" 6387' TOP OF 5-1/2" LNR 6397' - 6435' H CEMENT SHEATH, ID = 4.49" (07/24/07) GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT DATE 4911 51 HES LB DMY RM 0 12/26/1 6374' -6376' HTBG PUNCH (6/13/07) 6383' 9-5/8" X 7" BKR ZXP LTP, ID = 6.184" 63$7' H BKR LNR TIEBACK SEAL ASSY, ID = 4.875" 6397' I "I9-5/8" X 7" BKR HMC LNR HGR ID =? 6403' 7" BKR PBR ID = 6.184" 6418' 7" X 5-1/2" XO, ID = 4.892" 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681 " PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12896 - 12921 O 08/01 /95 3-3/8" 6 12901 - 12921 O 06/09/04 3-3/8" 6 12930 - 12950 O 06/09/04 3-3/8" 6 12950 - 12970 O 06/08/04 3-3/8" 6 13010 - 13030 O 06/08/04 3-3/8" 6 13070 - 13120 O 08/01/95 12820' I-i5-1/2" PKR SWS NIP, ID = 4.562" PBTD 13230' 5-1/2" LNR, 17#, NT-80, NSCC, .0233 bpf, ID = 4.892" X3326' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/95 OE2IGINAL COMPLETION 08/18/07 RLW/PJC CETAE3YT CORRC-CTIONS 06/09/04 MDGKA AD/REPERF 08/19/07 RDB/PJC CMT/MILL QUICKDRILL (07/2 01/04/07 RCTlfLH GLV GO (12/26/06) 04/27/07 RW/PJC TIEBK ASSY CORRECTIONS 06/23/07 RRD/PJC TBG PUNCH, BP & PERF (06/13/07) 08/05/07 RLW/SV MILL OUT 8~ CEMENT SQZ (07/27/07) PDINT MCINTYRE UNff WEiL: P2-34 PE72Mff: 1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP 6cploration (Alaska) CM! WELLHEAD = FMC ACTUATOR = KB. ELEV = 51.7 BF. ELEV KOP = 1300' Max Angle = 55 @ 8279' Datum MD = 12746' Datum ND - 8800' SS ~ P2-34 Post RWO 20" CONDUCTOR, ~ $0' ESTIMATED TOP OF CEMENT ~~ 6247' Minimum ID = 2.635" HES XN Nipple @ 12760 5-1 /2" TBG, 17#, NT-80, NSCC, .02325 bpf, ~ = 4.88" TOP OF5-1/2" LNR SAFETY 2000' H 3-1 /2" HES XNIP = 2.813" 5-1/2" PKR SWS NIP, Milled-Out to 4.75" at 2091' MD 6310' -6435' H CEMENT sHEATH, to = a.7s" (prerig) ~ GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 6322 4911 51 HES LB DMY RM 0 12/26/06 6374' - 6376' f-'iTBG PUNCH (6/13/07) 6383' 9-5/8" X 7" BKR ZXP LTP, ID = 6.184" 63$7' H BKR LNR TIEBACK SEAL ASSY, ID = 4.875" 6397 ~--j 9-5/8" X 7" BKR HMC LNR HGR, ID =? 6403' 7" BKR PBR, ID = 6.184" 6418' H 7" X 5-1 /2" XO, ID = 4.892" 9-518" CSG, 47#, L-80, NSCC, ID = 8.681" 3-1/2", 9.2#, L-80, TC-II Tubing to 12,780` MD PB~f-0RATION SUVMARY REP LOG: SWS CDR/GRON 07/14/95 ANGLEAT TOP Pff2F: 49 @ 12896' Note: Refer to Roduction OB for historical perf data SQE SPF 9V1S11/AL OpNSgz DATE 3-3/8" 6 12896 - 12921 C 08/01/95 3-3/8" 6 12901-12921 C 06/09/04 3-3/8" 6 12930 -12950 C 06/09/04 3-3/8" 6 12950 -12970 C 06/08/04 3-318" 6 13010 -13030 C 06/08/04 3-3/8" 6 13070 -13120 C 08/01/95 ~~ 11 1 5-1/2" LNR, 17#, NT-80, NSCC, .0233 bpf, ID = 4.892" 12670' 3-1/2" HES X NIP, ID=2.813" 12700' 5-1/2" x 3-1/2" BKR SABL ID = 2.750 / / 12730' 3-1/2" HES X NIP, ID=2.75" ~~- 12760' 3-1/2" HES XN NIP, ID =2.635" (pogo) ~ 12780' 3-1/2" WLEG \ 12820' S-1i2" PKR SWS NIP, ~ = 4.562" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/95 ORIGINAL COMPLETION 08/18/07 RLW/PJC CEMBVT CORRECTIONS 06/09/04 MDGKA AD/REP~2F 08/19/07 RDB/PJC CMT/MILL QUICKDRILL (07/2 01/04/07 RCT/TLH GLV C!O (12/26/06) 12/09/09 AMW Proposed R-erig 04/27/07 RW/PJC T~K ASSY CORRECTIONS 06/23/07 RRD/PJC TBG PUNCH, BP & PERF (06113/07) 08/05/07 RLW/SV MILL OUT & CEMENT SQZ (07/27/07) POINT MGNTY RE UNIT WELL: P2-34 PERMIT: 1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP 6cploration (Alaska) P2-34 (PTD #1950660) Plans for injection with new completion • Regg, James B (DOA) Page 1 of 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, December 21, 2009 4:46 PM ~~ ~ I Z_ z Z~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Hubble, Terrie L; Warren, Abigail M; NSU, ADW Well Integrity Engineer Subject: RE: P2-34 (PTD #1950660) Plans for MI injection with new completion Attachments: P2-34i Post RWO.pdf Hi Jim, I had incorrectly assumed there would be a high set packer. The drilling engineer has confirmed with the attached proposed schematic that 12,700' MD is the proposed set depth for the packer in P2-34. The perforations are at 12,896' MD. I apologize for the confusion. That will teach me to send a-mails before I'm completely awake.. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator ~~ `~ GPB Wells Group .~~)`~ ~ ~~~~ Phone: (907) 659-51.02 Pager: (907) 659-51QO x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, December 21, 2009 9:51 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: RE: P2-34 (PTD #1950660) Plans for MI injection with new completion Decision about type and frequency of MIT will have to be made when we receive the sundry for RWO. Make sure to highlight the high set packer in application so we can address the alternate to what is required in 20 AAC 25.412(b) rather than writing a separate admin approval. 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: Monday, December 21, 2009 5:38 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: P2-34 (PTD #1950660) Plans for MI injection with new completion 12/22/2009 P2-34 (PTD #1950660) Plans for injection with new completion • Page 2 of 2 Hi Tom and Jim, Plans are in the works for a rig workover on P2-34 which is currently a monobore completion, with no surtace casing. The new completion will install new 3-1/2" tubing in the 5-1/2", effectively adding a new inner annulus making the old 9-5/8"x5-1/2" annulus an outer annulus. While I understand that the UIC test frequency might be affected by a high set packer, I want to confirm if the well will be approved for MI injection. A wellbore schematic has been included for reference. «P2-34.pdf» Please give me a call if you would like to discuss. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Weil Integrity Coordinator GPB Vilells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 12/22/2009 TREE _ WELLHEAD = ACTUATOR = KB. ELEV = 51.T BF. ELEV KOP = 1300' Max Angle = 55 @ 8279' Datum MD = Datum TVD = 12746' 8800' SS P 2 ~3 4 SAFETY Post RWO 2000' f-13-1/2" HES X NIP = 2.813" 20" CONDUCTOR, -{ ESTIMATED TOP OF CEMENT 80~ 6247' 6310' -6435' H CEMENT SHEATH, ID = 4.75" (prerig) Minimum ID = 2.635" HES XN ', Nipple @ 12760 5-1/2" TBG, 17#, NT-80, NSCC, .02325 bpf, ID = 4.88" 6387 TOP OF5-1/2"LNR 6397' 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" ~-~ 6835' 3 1/2" 9.2 ppf L-80 TCII ID = 2.992" 12782' PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Froduction DB for historical pert data SIZE SPF INTff2VAL Opn/Sqz QATE 3-3/8" 6 12896-12921 C 08/01/95 3-3/8" 6 12901-12921 C 06/09/04 3-3/8" 6 12930- 12950 C 06/09/04 3-3/8" 6 12950-12970 C 06/08/04 3-3/8" 6 13010-13030 C 06/08/04 3-3/8" 6 13070-13120 C 08/01/95 PBTD -1 13230, 5-1/2" LNR, 17#, NT-80, NSCC, .0233 bpf, ID = 4.892" 13326' 6374' - 6376' TBG PUNCH (6/13/07) 5/8" X 7" BKR ZXP LTP ID = 6 184" 83' 9 63 , - . 6387' BKR LNR TIEBACK SEAL ASSY, ID = 4.875" 6397' 9-5/8" X 7" BKR HMC LNR HGR, ID =? 6403' 7" BKR PBR, ID = 6.184" 6418' 7" X 5-1/2" XO, ID = 4.892" 12670' 3-1/2" HES X NIP, ID=2.813" 12700' 5-1/2" x 3-1/2" BKR SABL ID = 2.750 12730' 3-1/2" HES X NIP, ID=2.75" 12760' 3-1/2" HES XN NIP, ID =2.635" (nogo) 12780' 3-1/2" WLEG \ 12820' 5-1/2" PKR SWS NIP, ID = 4.562" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/95 ORIGINAL COMPLETION 08/18/07 RLW/PJC CEMENT CORRECTIONS 06/09/04 MDC/KA AD/REPERF 08/19/07 RDB/PJC CMT/MILL QUICKDRILL (07/2 01/04/07 RCT/TLH GLV C/O (12/26/06) 12/09/09 AMW Proposed Prerig 04/27/07 RW/PJC TIEBK ASSY CORRECTIONS 06/23/07 RRD/PJC TBG PUNCH, BP & PERF (06/13!07) 08/05/07 RLW/SV MILL OUT & CEMENT SOZ (07!27/07) POINT MCINTYRE UNff WELL: P2-34 PERMIT: 1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration (Alaska) TREE = 7"x6" CARBON 5M COOPER WELLHEAD = 13"x13" 5M FMC ACTUATOR KB. ELEV - 51.T BF. ELEV....... - -- KOP = 1300' Max Ang~P = 55 @ 8279' Datum Mu = 12746' Datum iv v - 8800' SS 120" CONDUCTOR, ~--L ESTIMATED TOP OF CEMENT Minimum ID = 4.5fi2 "@ 2091' 5-112°' PARKER SWS NIPPLE 5-1/2" TBG, 17#, NT-80, NSCC, .02325 bpf, ID = 4.88" ~ 63$7' TOP OF 5-1i2" LNR -{ 6397' 9-518°' CSC, 47#, L-80, NSCC, ID = 8.681" 2091' H 5-1/2" PKR SWS NIP, ID = 4.562" - 6435' H CEMENT SHEATH, ID = 4.49" (07124107} GAS LIFT MANDRELS ND DEV TYPE VLV LATCH PORT DATI 4911 51 HES LB DMY RM 0 i 12/26/ 6374' - 6376' HTBG PUNCH (6113107) 63$3' 9-5(8" X 7" BKR ZXP LTP, ID = 6.184" 63$7' i-i BKR LNR TIEBACK SEAL ASSY, ID = 4.875" 6$97° t --+9-5/8" X 7" BKR HtvtC LNR HGR, ID =? 6403' 7" BKR PBR, ID = 6.184" 6418' 7" X 5-1/2" XO, ID = 4.892" 5-1/2" PKR SWS NIP, iD = 4.562" PERFORATION SUMMARY REF LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical perf data SIZE SPF WTERVAL Opn/Sqz DATE 3-3/8" 6 12896 - 12921 O 08!01!95 3-318" 6 12901 - 12921 O 06/09/04 3-318" 6 12930 - 12950 O 06!09/04 3-318" 6 12950 - 12970 O 06/08!04 3-3/8" 6 13010 - 13030 O 06/08(04 3-3/8" 6 13070 - 13120 O 08(01/95 PBTD -i 13230, 5-112" LNR, 17#, NT-80, NSCC, .0233 bpf, ID = 4.892" '13326' DATE REV BY COMMENTS DATE REV BY COMMENTS 07!22/95 ORIGINAL COMPLETION 08/18/07 RLW/PJC CEMENT CORRECTIONS 06/09/04 MDGKAK AD/REPERF 08/19/07 RDB(PJC CMT/MILL QUICKDRILL (07/2 01!04/07 RCT/TLH GLV C/O (12/26106} 04/27/07 RW/PJC TIEBK ASSY CORRECTIONS 06/23/07 RRDIPJC TBG PUNCH, BP & PERF (06/13/07} 08/05!07 RLWISV MILL OUT & CEMENT SOZ (07727(07} POINT MCINTYRE UNIT WELL: P2-34 PERMIT: 1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration {Alaska} SAFETY T x IA COMMUNICATION, 9-12-98. -,~ AOGCC SUNDRY, 9-23-98. MONO-BORE WELL. UNDER EVALUATION: P2-3~PTD #1950660) Failed MIT-T • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~~1~~ Sent: Thursday, March 26, 2009 3:33 PM ~] ~ ~~~ I__~- To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr North (Gas Plants/GPMA); GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Warner, Ross L; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: P2-34 (PTD #1950660) Failed MIT-T Attachments: MIT PBU P2-34 03-25-09.x1s All, Well P2-34 is a produced water monobore injector that failed an AOGCC witnessed MIT-T on 3/25/2009 due to lack of pressure stabilization. The well is therefore reclassified Under Evaluation until it demonstrates a passing MIT-T. The plan forward for the well is as follows: 1. D: Re-MIT-T with a triplex. 2. SP: Pull the IBP and place on water injection if MIT-T passes Please see the attached MIT form for reference. Please call with any questions or concerns. Thank you, Winton Aubert Office: 659-5102 «MIT PBU P2-34 03-25-09.x1s» ~~ ,j~ ~_. ~ ,., 4..,~ .~-~ 4/8/2009 • 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: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~ ~I~ ~~~ Prudhoe Bay / PBU /Point McEntyre 1 \ 03/25/09 Andrea Hughes John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well P2-34 Type Inj. N TVD 4, 49' Tubing 280 ,400 2,350 °2,320 Interval V P.T.D. 1950660 Type test P Test psi ' 1237 Casing 0 0 0 0 P/F Notes: MIT-T to 2400 psi for regulatory compliance. OA Monobore. Well P2-34 Type Inj. N TVD 4,949' Tubing 2,300 2,400 2,400 2,380 Interval V P.T.D. 1950660 Type test P Test psi 1237 Casing 0 0 0 0 P/F Notes: MIT-T to 2400 psi for regulatory compliance. OA 0 0 0 0 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 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/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 O =Other (describe in notes) j ~~-- ~sk~:~ c~,~, Y~ G~~e.,~ 1'x.1; ec,~c~ ~~L~~ . t /lc~~,~~ ~. MIT Report Form BFL 11/27/07 2009-0325_MIT_PBU_P2-34_2testsJc.xls • • MEMORANDUM TO: Jim Regg ~ ~•~ ~ ~~(~ P.L Supervisor ~oM~ John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April O8, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2-34 PRUDHOE BAY UN PTM P2-34 Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: John Crisp Insp Num: mitJCr090331115431 Permit Number: 195-066-0 - Inspection Date 3/23/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Pz-3a Type Inj. W TVD 4949 ~ IA 0 0 0 0 0 P.T.D 1950660 TypeTest sPT Test psi 2aoo ~ pA o 0 0 0 0 IIIterVal Other (describe in P~ Pass Tubing 2300 2400 2400 2380. 2380 .,.. P~ NOteS' •2 bbl's pumped for test. This was retest & data will be reviewed for Supervisor pass -fail determination. MTT of tubing only. Pass test result determined by Jim Reg BFL 4/6/09 .~ ~~~,~~ I~PF ~ _~ 20G'~ Wednesday, Apri108, 2009 Page 1 of 1 MEMORANDUM • To: Jim Regg ~ P.I. Supervisor ~~ ( ~(~ ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Cas Conservation Commission DATE: Monday, April 06, 2009 SUBJECT: Mechanical Integrity Tests BP IsYPLORATION (r1I_ASI:r1) INC P2-.34 PRUllHOE BAY UN P'I7vi P2-i4 Src: Inspector NON-CONFiDF.NTrA r Reviewed By: P.I. S~prv J ~- Well Name: PRUDHOE BAY I1N PTM P2-34 API Well Number: 50-029-22558-00-00 Chuck Scheve Inspector Name: Insp NUm: mitCS090330143417 Permit Number: 195-066-0 3:'30+'2009 Inspection Date: - Rel Insp Num: Packer De th_ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P'~~Type_bIJ TVD I ~ IA ~ ~ u ~ o ~ ~ ~ o -~._._ ~, ;P.T~ISS(>66o..1TypeTest spr Testps>t ~_ Isno - OA ~ ~ _ ( - }- -- __l --.. _ __ _ Interval REQvAR P/F !> Tub>Ing L ai _ ~ 2-ux) J ..3xo 360 1 . z~a( L _ zsao _- - Notes• Mvnobore completion, plug set m tubing at 12820 A4D. Holes punched in tbg at 6375 MD and cement circ to 6247 est. ~~ ~.~>~.. Monday, April 06, 2009 Page 1 of 1 MEMORANDUM To: Jim Regg 4 6 0 P.I. Supervisor ~ ~Cj ~ 1 1 rxoM: John Crisp Petroleum Inspector State of Alaska • Alaska oil and Gas Conservation Commission DATE: Monday. April 06. 2009 SL113JEC'T: Merhaniw! Integrity 1'u~sts 13P 1?CP7.ORA"LION {AI,:ASF:A) I'NC` P2-34 PRUDIIOE HAY' L?N PTM I'?-34 5rc: InspecKor NON-CONFIDENTIAL Reviewed Ry: P.I. Suprv ~3~ ~- Comm Well Name: PRUDHOL I3AY UN PTM P2-34 API Well Number: 50-029-22558-0o-00 Inspector Name• John Cnsp Insp Num: mitJCr09033 1 1 14522 permit Number: 195-066-0 Inspection Date: 3!23%2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. -t5 Min. 60 Min. - _. __.. Well Y'3`~ TJPe InI T u' TVD ~ 4~4y /~ IA ~ u o ~ t' ' c~ ~ --_I 1 ~..19st,6~I~ ~SI"t ;Test 4~ f ?ar>n ~ OA I_ ~ ,~ ~- --~ P T. (.__ tTvpeTest~ p, • ~~ n n __ . , _ _ 1 ' _Interval_ o~rl->ER _ PJF 1' ..__' _ Tubing ~ zsc, _ 1 ~aLro ~ ,,o ~ ~~,n ~ zsrx, .~ _.. _.. __ --.J "--. ~__ . __ Notes: IBP set in tubing for MIT'- I'. 'l'est data submitted for Supervisor review. I allowed them to retest. 3 bbl's pumped for test. !~il'I' tubing only Pass test result determined by Jim Reg I3FI., 1 %6/()<) ~~ 0 ~~ J ~ tis,~ 5~ts>..k..y ~ f ~v i e{a Czs ~ ~Ccr- tC'4c 5 ~ ~~N `-~-~5'~ J ~{1ie.1,~, i+t~-t.~s PASS a r ~, ~ r .,, : ~f; ,.,a,. ~ ~* ~ ~ l t Monday, April 06, 2009 I'a,ge 1 of l MEMORANDUM • To: Jim Regg ~ ~ ~, , l Lf ~~ I P.I. Supervisor `yjC' t;ROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gras Conservation C:'ommission DATE: Monday, April OG, 2009 SliR.IECT: Mechanical Integrity'1'u'stis 13P G`CPLORA"IION (ALASIa1)1NC P2-3=J PRIJDHOF, I3AY' UN P'l'M P2-34 Src: Inspector NON-CONFIDENTIAL Reviewed Ry: Y.I. Suprv f'i./~ Comm Well Name: PRI,JDHOF, ]3AT LJN PTM P2-34 API Well Number 50-029-2255R-00-00 Inspector Name: Jolm Crisp Insp Num: mitJCr0903311i5431 Permit Number: J95-066-0 Inspection Date: 3'23,2009 Rel Insp Num: Packer Depth Pretest Initial 15 .Min. 30 Min. 45 Min. b0 Min. Well~~" ~n .~YPe Inj. ~ w i TVD ~ a9~9 _ '~ IA 7. (, ~ (' ~ ° ~ o ~- -.. ~~ ~ _ __ _ --- _.. _ _ ~ _195UCi6U SPT -~- ~ 1 0 t _- P T .__~ LTyPeTe~t ~ _ ,Test psi i -a(x, _ OA i „ ,, cJ t o i __._... 3(k) i 2.7iN, r . o~7CK, ~ ''38t1 ~ "'3S0 °. _Interval o1J~It _. .. _ _P/F..__.. P..._ .. __... _ -- Tubmgi._ ` _ -. 1 L__.. ~ NOtes: •2 bbl's pumped for tit. This was retest & data will be reviewed for Supervisor pass -fail. dete~rnination. MIT of tubing only. Pass test result determined by Jim Reg BFL ] 16109 ~, C~~i~v ~r~i~~,~s " P~s~~`' ,,. (. ., s f t~ Monday, Apri106, 2009 page 1 of I February MIT Forms Regg, James B (DOA) • Page 1 of 1 °~ - ~ ~ ~s-~~~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, February 27, 2009 12:49 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: February MIT Forms Attachments: MIT PBU P2-34 02-14-09.x1s; MIT PBU S-116 02-25-09.x1s; MIT PBU V-119 02-05-09.x1s; MlT PBU V-213 & V-219 02-25-09.x1s; MIT MPU B-18 02-21-09.x1s; MIT PBU 09-17 02-05-09.x1s; MIT PBU 09-20 02-14-09.x1s; MIT PBU 12-31, 12-33, 12-02 02-14-09.x1s; MIT PBU M-38A 02- 05-09.x1s; MIT PBU P1-14 02-19-09.x1s Jim, Tom and Bob, ;'~r~~~~~~t~~~' ~~ ~~ ,~ ~~~(~ Please see the attached MIT forms for the following wells: 09-17 (PTD #1770380}: MITIA for variance compliance; witnessed by John Crisp. 09-20 (PTD #1770410): MITIA for AA request; witnessed by Chuck Scheve. 12-02 (PTD #1790320): MITIA for 4-year UIC Compliance; witnessed by Chuck Scheve. 12-31 (PTD #1890010): MITIA post-initial injection; witnessed by Chuck Scheve. 12-33 (PTD #1890100): MITIA post-initial injection; witnessed by Chuck Scheve. M-38A (PTD #2011320): MITIA post-initial injection; John Crisp. MPB-18 (PTD #1852290): MITIA for 4-year UIC Compliance; witnessed by Bob Noble. P1-14 (PTD #1930160): MITIA pre-MI swap; witnessed by Chuck Scheve. J~~ 2~Z~ (Z~D~f ,% P2-34 (PTD #1950660): MITIA for no longer planned MI swap; not witnessed. S-116 (PTD #2031810): MITIA for 4-year UIC Compliance; witnessed by John Crisp. V-119 (PTD #2040410): MITIA for 4-year UIC Compliance; witnessed by John Crisp. V-213 (PTD #2041160): MITIA for 4-year UIC compliance; witnessed by John Crisp. V-219 (PTD #2081420): MITIA post-initial injection; witnessed by John Crisp. «MIT PBU P2-34 02-14-09.x1s» «MIT PBU S-116 02-25-09.x1s» «MIT PBU V-119 02-05-09.x1s» «MIT PBU V-213 & V-219 02-25-09.x1s» «MIT MPU B-18 02-21-09.x1s» «MIT PBU 09-17 02-05-09.x1s» «MIT PBU 09-20 02-14-09.x1s» «MIT PBU 12-31, 12-33, 12-02 02-14-09.x1s» «MIT PBU M-38A 02-05-09.x1s» «MIT PBU P1-14 02-19-09.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 2/27/2009 ~ a 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: DATE: OPERATOR REP: AOGCC REP: Prudhoe Bay / GPMA / PM 2 02/14/09 Anna Dube Packer Dep Pretest Initial 15 Min. 30 Min. Well P2-34 Type Inj. W TVD 4,949' Tubing 1,400 1,400 1,400 1,400 Interval O P.T.D. 1950660 / Type test P Test psi 1500 Casing 340 4,000 3,860 3,840 P/F P 4 Notes: MITIA for UIC compliance. Not allowed for MI OA due to monobore completion. AOGCC inspector declined witnessing test. 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 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 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 ~~xR c,~,~,t ~~ •- T ~~ ~~ s etc c~ ~ ~~ ~~ ~Q~ i" 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 2009-0214 MIT PBU P2-34.x1s Page 1 of 2 Regg, James B (DOA) ~ ~~S-®Co(~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, February 26, 2009 11:20 AM ~~pc ,~ I ~ ~ Q R To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Chmielowski, Jessie; NSU, ADW Well Integrity Engineer Subject: RE: P2-34 Jim, f apologize far my oversight. I have requested that the well be shut-in and a plan has been submitted to set a tubing tail plug in the nipple at 12820' MD for an AOGCC"vvitnessed MITT to 2400 psi. The last MITT was conducted on 06/12/07, but it was not AOGCC witnessed. Thank you for your patience. Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, February 26, 2009 10:42 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: P2-34 MITIA is not acceptable test for a monobore. Intent of MIT is to test as close to the perfs as possible; that is why we have the regulatory requirement that the packer in an injection well be within 200 feet {MD} of the perfs {refer to attached 20 AAC 25.412}. In case of P2-34, MITIA would only test well to 6383 feet MD; top of uppermost perforated interval is 12896 feet MD. Also, letter !referenced in previous email also requires MITT as condition to allowing well to continue injecting. Apologize for not including email exchange with first response. Copy attached. 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: Thursday, February 26, 2009 7:17 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer Subject: RE: P2-34 Jim, Is an MITIA an acceptable substitute for an MITT'? Our belief is that an MITIA is a better test because it verifies both the primary and secondary barrier. We choose to perform MITIA's rather than MiTT's when possible. 2/26/2009 Page 2 of 2 • ~J However, given your statement below, i would like to hear your opinian on the use of an MITIA instead of an MITT. ! didn't see the email exchange between you and Harry attached, so this topic may have been settled back in 2004. Thanks, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, February 17, 2009 1:02 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: P2-34 Attached is the tubingless injector letter. What is not explicit in the letter but was well understood is the fact that the approved monobore injectors (5 specifically referenced in letter) would only be allowed to inject water. I have also attached is an email exchange I had with Harry Engel back in 2004 regarding the well P2-34 -there was confusion about our requirement for monthly reporting of TIO pressures and need to perform MITT instead of MITIA every 2 years. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 2/26/2009 MEMORANDUM . TO: Jim Regg ~åí4 'P( IbiD? P.I. Supervisor { ( FROM: Jeff Jones Petroleum Inspector Well Name: PRUDHOE BAY UN PTM P2-34 Insp Num: mitJJ070812200652 Rei Insp N urn: 'I I Well I P2-34 Type Inj. I W P.T. ¡ 1950660 !TypeTest 1 spy Interval OTHER~PfF Packer TVD T est psi P State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 15,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2-34 PRUDHOE BAY UN PTM P2-34 Src: Inspector Reviewed By: P.I. Suprv .:Jr]f!-- Comm NON-CONFIDENTIAL API Well Number: 50-029-22558-00-00 Permit Number: 195-066-0 Inspector Name: Jeff Jones Inspection Date: 8/12/2007 Depth 4949 vt IA I 1500 I OA r , i ./ Tubing I Pretest Initial 800 I 2410 I ! 1680 I 1440 15 Min. 30 Min. 45 Min. 60 Min. I 2330 I 2310 I I I I ¡ ¡ ¡¡I I 'I i 1440 I 1520 I I -- -- Notes: Post coil tubing packer cement squeeze on monobore injector. 2.7 BBLS methanol pumped. I well house inspected; no exceptions noted. ..,.-/ Wednesday, August 15,2007 SCANNED AUB 232007 Page I of I TREE = 7"x6" CARBON 5M COOÆR WELLHEAD = 13"x13" 5M FMC ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = . P2-34 1300' 55 @ 8279' 12746' 8800' SS 120" CONDUCTOR, Minimum ID = 4.562 "@ 2091' 5-1/2" PARKER SWS NIPPLE I 5-1/2" TBG, 17#, NT-80, NSCC, .02325 bpf, 10 = 4.88" I TOP OF 5-1/2" LNR I I 9-5/8" CSG, 47#, L-80, NSCC, 10 = 8.681" I PERFORA TION SUMMARY REF LOG: SWS CDR/GR ON 07/14/95 ANGLEATTOPÆRF: 49 @ 12896' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 12896 - 12921 0 08/01/95 3-3/8" 6 12901 - 12921 0 06/09/04 3-3/8" 6 12930 - 12950 0 06/09/04 3-3/8" 6 12950 - 12970 0 06/08/04 3-3/8" 6 13010- 13030 0 06/08/04 3-3/8" 6 13070 - 13120 0 08/01/95 I PBTD I 13326' 13230' 15-1/2" LNR, 17#, NT-BO, NSCC, .0233 bpf, 10 = 4.892" I DATE 07/22/95 06/09/04 01/04/07 04/27/07 06/23/07 REV BY COMMENTS ORIGINAL COMPLETION MDC/KA AD/REÆRF RCT/TLH GLV C/O (12/26/06) RW/PJC TIEBK ASSY CORRECTIONS RRD/PJC TBG PUNCH, BP & ÆRF (06/13/07) DATE REV BY COMMENTS SAF~TE: T x fA COMMUNICATION, 9-12-98. AOG.UNDRV,9-23-98. MONO-BORE WELL. 2091' 5-1/2" PKR SWS NIP, 10 - 4.562" 6374' - 6376' TBG PUNCH (6/13/07) 9-5/8" X 7" BKR ZXP L TP, 10 = 6.184" 9-5/8" X 7" BKR HMC LNR HGR, 10 =? 7" BKR PBR, 10= 6.184" 7" X 5-1/2" XO, 10 = 4.892" 5-1/2" BKR QUIKDRILL CBP (06/12/07) 12820' 15-1/2" PKR SWS NIP, 10 = 4.562" I POINT MCINTYRE UNrr WELL: P2-34 ÆRMrr: "1950660 API No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration (Alaska) · . ~V~VŒ (ID~ ~~~~~~ / AT/ASJiA. OIL AND GAS / CONSERVATION COMMISSION r SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ross Warner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 sCANNED MAY 1:7 2007 Re: Prudhoe Bay Field, Point McIntyre Pool, P2-34 Sundry Number: 307-164 \qs--O!olt. Dear Mr. Warner: 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 me 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, Dan T. Seamount Commissioner DATED this [{ day of May, 2007 Encl. I~ 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate U Waiver U Other~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 PBR Squeeze Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developm ent 0 Exploratory 0 195-0660 3. Address: P.O. Box 196612 Stratigraphic 0 Service ø 6. API Number: Anchorage, AK 99519-6612 I 50-029-22558-00-00 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: P2-34 Spacing Exception Required? Yes 0 No 0 9. Property Designation: 10. KB Elevation (ft): 11. Field/PooIS(S): ADLO-034624 52.2 KB Prudhoe Bay Field / Point Mcintyre Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): I Plugs (measured): runk (measured): 13326 9232 13230 9169 None None Casing Length Size MD TVD Burst Collapse Surface 6494' 9-5/8" 47# NT80S 41 6535' 41 5235' 6870 4760 Conductor 110' 20" 94# H-40 Surface 80' Surface 80' 1530 520 Liner 6943' 5-1/2" 17# NT80S 6383' 13326' 4949' 9232' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12896 - 12921 8951.58 - 8968.09 5-1/2" 17# NT-80 Surface - 6387' 12896 - 12901 8951.58 - 8954.88 13070 - 13120 9065.59 - 9097.88 Packers and SSSV Type: 9-5/8"x7" BKR ZXP L TP Packers and SSSV MD (ft): 6383' 0 0 0 0 0 0 12. Attachments: DescriDtive Summary of Proposal ø 13. Well Class after proposed work: Detailed Operations Program B BOP Sketch 0 Exploratory 0 Developm ent 0 Service ø 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/1/2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ ø WDSPL 0 Commission Representative: Prepared by I.;:U:HY ....rt::ule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Warner Printed Name ÁlossJNarner Title Production Engineer Signature c:..~~~ -d'Ou.. Phone 564-5359 Date 5/14/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: [301''I~4 Plug Integrity 0 BOP Test '¢... Mechanical Integrity Test ~ Location Clearance 0 Other: ~500 \>s.\ M..\~\~..;}~ ~~ ~-\- \},J,\-.r..Jè- ~~ k\\~ "C\~\~ C()\¿V ~ c \- (CCZ) u...ç. \<t r- ~Q: \ \ "'Ú-~. Û-L "t~ \,,)C'~~k~Q. \ <è.'ì..-\) 'X'\ b,\ '-.) ¡ . 5"""',",", F"m R",";"do ~ ~ APPROVED BY 5 / /to (7 Approved by: COMMISSIONER THE COMMISSION Date: j/ ~5,(t"g1 .ß#:.,?, -MAY 1 . STATE OF ALASKA ~ r -~. __.,5 7007 AI~:A Oil AND GAS CONSERVATION COM 9tfðSk1i & G" APPLICATION FOR SUNDRY APPROVAL as Cons. Commission 20 AAC 25 280 51, Anchorage Form 10-403 Revised 06/28 R , G , N A L RBDMS BFL MAY 1 4 2007 Submit in Duplicate bp ,t. "',.~". -..,~ ~....- ,..- ~.......- ...~ ~..... .'~"'.\" P'. . . May 11 , 2007 Alaska Oil & Gas Conservation Commission Attention: Mr. Thomas Maunder 333 west ih Avenue, Suite 100 Anchorage, AK 99501 RECEIVED M,A,Y 1 5 2007 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Thomas Maunder: Reference: Sundry Notice for P2-34---PBR Squeeze. BP Exploration (Alaska) Inc. proposes to perform a PBR Squeeze on well P2-34. Attached is the program for restoring this well to its full capabilities as a water injector. Summary: Step Type Summary 1 S Drift for composite BP. 2 E& Set Composite Bridge Plug. Pressure Test Plug. Punch holes in tubing. FB Test punched holes by circulating down tubing & up IA. 3 C& Coil tubing PBR squeeze. Circulate TBG X IA to 95 F dead crude FB immediately before coil work. 4 DHD Pressure test IA. State Witness needed. Determine leak rate if test fails. 5 0 Note # 16 Post Squeeze work. Currently this well is shut-in. Service work will begin when approval is received from your organization. If you have any questions please contact: . Ross Warner at 564-5359 Sincerely, ~ ~;C~~_&~__~ Ross L. Warner 1 2 Warner, Ross L From: Joel Johns [joeLjohns@tecwelinc.com] Sent: Friday, May 11, 2007 9:35 AM To: Warner, Ross L Subject: snap shot 05/1112007 11800 11900 1 2000 121 00 1 2200 12300 o 40 -3 · ,. Page 2 of 2 Joel Johns TecWellnc. - Manager, Sales and Marketing Phone (281 )822-0301 Cell (281)687-1515 05/1112007 . . õ To: Jerry Bixby / Clark Olsen GPB Wells Operation Supervisors Date: May 11 , 2007 From: Ross Warner GPMA Production Engineer Subject: P2-34i PBR Squeeze PMP02WL34-N Est. Cost: $200M lOR: 700 BOPD Please perform the attached PBR squeeze procedure: Step Type Summary 1 S Drift for composite BP. 2 E& Set Composite Bridge Plug. Pressure Test Plug. Punch holes in tubing. FB Test punched holes by circulating down tubing & up IA. 3 C& Coil tubing PBR squeeze. Circulate TBG X IA to 95 F dead crude FB immediately before coil work. 4 DHD Pressure test IA. State Witness needed. Determine leak rate if test fails. 5 0 Note # 16 Post Squeeze work. Current Status: Shut In Max Deviation: 55 degrees @ 8279' MD Hole Angle @ PBR 51 deg @ 6400' Minimum 10: 4.562"" @ 2091' Parker SWS Nipple Last TO tag: SL Tagged @ 13060' SLM with 3.52" centralizer (5/6/2005) Last Downhole Operation: Ran LDL 4/23/2007 Latest H2S value: Injector Backaround This well was completed 6/95 with two perforated intervals in the LC4 and the LC1 zones. The well produced briefly from August thru September when it was converted to injection. The well initially produced over 4,000 BOPD and cum production was only 134 KBO with minimal water production. Since conversion, the This well has injected 42 MMBW. According to the records P2-34 has experienced Tubing to IA communication since 1998. The IA has been bled down five times Page 1 of 10 . P2-34 PBR Squeeze . since 12/18/06. P2-34 has always successfully past the required IA pressure testing. Latest testing dates: 07/09/2006 12/28/2006 02/09/2007 03/16/2007 03/18/2007 04/23/ 2007 Objective Passed MIT-T with plug set SWS nipple at 12,820' Passed MIT-IA Passed PPPOT-T Leak Rate Test. See Well Service Report for detailed information. The well was on injection. The IA was bleed to zero psig and then bleed to a slop trailer. The leak rate was about 1.4 gals/minute. The well was shut in. TecWellog was run. Leak at PBR area. Leak rate: -0.79 gals/min. Baker has run a tubing movement calculation for this well to determine if any adverse stresses or forces will be detrimental for continual injection operations after the cementing the PBR in place. The results indicated that the tubing can safely withstand the changes that will take place with no Seal Assembly movement. The objective of this procedure is to repair the PBR leak. A Baker Quik Drill Bridge Plug will be set 6435' MD. Cement will be circulated into the IA through the punched tubing holes between 6374-76'. The tubing and IA will be circulated to dead crude at a temperature of 95 F immediately before the squeeze. This will provide the best conditions for reducing excessive stress on the tubing after the seal assembly is permanently cemented in place. A cement plug will be left in the tubing, and some will be squeezed behind tubing. We are hoping that the GLM at 6322 will not be cemented during this job The cement in the tubing and the bridge plug will be milled when the cement develops 500-psi compressive strength (-5 hours, will use sample in cement lab for time.) An MIT IA will then be conducted to evaluate the results of the job. By using the Unislurry cement only one coil trip to the well will be necessary. If there are any questions please contact: Ross Warner: (W) 564-5359, (H) 333-9017, (C) 250-3441 Attachments: Tubing tally, Tie-in log, and Baker Details concerning the hanger & packer. GG: Well File Amy Frankenburg GPB, LPC Lead Drill Site Operator GPB, LPG Drill Site Operator 2 P2-34 PBR Squeeze P2-34 5-112" tubing 6385 Top of Tieback Assembly All Depths refer to LDl 4/23/07 '4 (6435-6345) -I< 0232 ::: 2.1 Cement Volume in Annulus (6388-6345) * ,,0438 :: 1.9 Total Cement to Pump 4 bbls. GLM 6322 ~ TOC 6345 Tubing Punch 6374-76 . 6388 Top of Packer 6435 Casing ~ 6533' MD Liner 3 . P2-34 PBR Squeeze . SQueeze Taraet Place cement in the tubing by IA annulus to repair confirmed PBR leak. IA volume to packer is 280 bbls. Formation temperature @ packer is 95 F. Tubing volume to Quik Drill plug to be set at -6435'00 is 150 bbls Note: When looking at the enclosed tie-in log it would appear that the GLM is also leaking. TecWel has positively assured me this is not true and what you see is "road noise" when dragging the tool through the mandrel. If you look at the stationary log you will notice there isn't any signature at that depth. Compare that section of log with the PBR Seal Assembly area. NOTE: Have the Schlumberger lab run tests for cement. Rough draft of cement blend is 15.8 Unislurry with 0.2% 0046, 0.2% 0065, and 0.35% 0167. Discuss this recipe with the Lab Engineer (659-2434) 2 days prior to rig up. He will need to be available to run the sample during the job. Pre-SQueeze Work 1. Slickline: Make a drift for setting the Quik Drill composite bridge plug. 2. Rig up electric line and set a Baker Quik Drill at 6435 ft. This depth should be the top of the plug. Reference tie in log is the PDS TecWel LDL run 4/23/2007. 3. Pressure test the tubing to 2000 psig. 4. Punch holes in the tubing at 6374-76 ft. Again, use the Tie-in log depth as in step #2. Use a 1-1/16" two ft. gun with 9 punchers. Tag the Quik Drill plug so the CT operator knows the exact depth. 5. Establish circulation rate down the tubing taking returns up the IA holding 100 to 200 psi backpressure. Use dead crude. CTU PBR SQueeze 1. RU the CT and squeeze equipment. NOTE: Rig up surface equipment to allow returns from both the IA and the CTxTbg annulus. 2. Before commencing job have LRS circulate the tubing and IA to 95° F dead crude. As mentioned before, this is to commence this job with a known temperature at the PBR and to ensure the IA is filled with crude. Pump down the tubing and up IA to confirm circulation through the punched holes in the tubing by opening up returns from the lA, holding 100-200 psi backpressure. Confirm 1-for- 1 returns to a 40 bbl open-top tank. 4 . P2-34 PBR Squeeze . 3. RIH with cement nozzle (no checks). Tag Quik Drill plug. Pick-up until full string weight is observed. Correct the depth to the top of the plug (EL). PUH 10' and flag pipe. PUH & park coil at 6200 ft. 4. Batch mix 4 pumpable bbl 15.8 ppq Unislurrv cement which will give 500 psi compressive strength in 5-7 hours and -2000 psi ultimate compressive strength. Temperature at cement depth should be about 95°F. · Catch a sample of the cement for QC testing. (This needs to go to the lab to know when the blend should reach the right strength. Lab must be notified prior to the job.) Once the blend is approved, line up cementers to the coil. · There should not be any gas in the system since this well is an injector. Do not proceed with the squeeze unless the tubinQ and IA are liquid packed. · The first step will be to lay in all of the cement in the tubing and then pull the CT to safety and park. Then IA will be opened and cement will be circulated into IA as detailed in steps below. 5. RIH to flag. Line out cementers to the CT. Pump the following down the coil: · 10 bbl spacer water · ~ bbl Unislurry · One coil volume of spacer water. SI in IA and take returns up the backside (tubing x CT annulus) while pumping water spacer. Switch to Unislurry while continuing to take returns up the backside. Maintain 100-200 psi backpressure. Pump 2 bbl Unislurry out the nozzle (76' of cement above nozzle) and then lay-in 1:1 while PUH (This step is to ensure that you don't dilute cement as you pull up). Strap returns in the 40 bbl tank. · Monitor IA pressure while laying in the cement in the tubing to account for cement U-tube. · Water flush volume is critical, so use the internal 1 0 bbl tanks in the pump van to gauge flush volume. SAFETY: 4 barrels of cement would extend up the tubing to 6263' DD if no cement is placed in the annulus (Quik Drill plug is at 6435' DD). 6. With the nozzle at safety or at least at 6100', SD pumping, SI the backside (tubing x CT annulus). Compare pump volume to return volume in the 40 bbl tank. 7. Open IA for returns to the 40 bbl tank. Begin pumping at minimum rate down the CT. Circulate 2.0 bbl through the tubing punched holes and up the IA. Shut in IA and gauge volume of returns. Monitor the IA and tubing pressures at equilibrium. NOTE: With Quik Drill plug at 6435' DD, the final cement top in the tubing and annulus should be -6345' or -29' above the tubing punched holes. 8. Open the choke on the backside (tubing x CT annulus) and begin pumping biozan down the CT for clean out. Launch ball and begin jetting with biozan down to a maximum depth of 6340. 5 . P2-34 PBR Squeeze . 9. Pull out of hole ensuring voidage replacement is taking place so a balanced well bore is maintained. This step is critical to the success of this job-particularlv on this job which has very little cement in the annulus. 10. Freeze protect the top 500' of the well bore while POOH. Continue to closelv monitor the chanaes in wellhead pressure to maintain a balanced well bore. 11. Leave tubing and IA pressures so the well bore will be balanced between the tubing and casing at the packer. 12. Wait until lab sample has reached 500 psi compressive strength. (This should take about 5 to 7 hours so do not rig down). RU with mill and motor to mill through -83' of cement and Quik Drill plug. Note: Use Baker guidelines for milling plug. 13. Drift to below perfs to ensure perfs are clear of debris. POOH at 80%. 14. POOH, making sure to freeze protect the well. RDMO. Post-packer Saueeze 15.After 3 days WOC, MIT-IA to 3000 psi. Contact State inspectors to witness testing. If the MIT fails establish a leak rate. 16.lf the MIT-IA passes put the well back on injection. This is the real test of the cement repair as the well would test OK down the IA before this work was performed, but when on injection the seal assembly was leaking and the tubing and IA were in communication. 6 P2-34 Squeeze 7 . . . .. ITEM ID OD LENGTH TOP BOTTOM 6387.31 6387,65 ./.. '....... 6385.83 6387.31 xro PUP 5-1/2"nsct X ltc/mod 4.89 6.06 1.95 6383.88 6385.83 1 JT 5·112" 17# NSCC TUBING #1 4.89 6.06 41.36 6342.52 6383.88 5-1/2" 17# NSCC PUP 4.89 6.06 9.60 6332.92 6342.52 X/O PUP j-=lknscc X blc f;f!.... 4.89 6.06 2.00 6330.92 6332.92 &5iSîx~t$MHË§{,tË¡gW#Rê¡smÊ~R:B1ØtâfèTi 6321.94 6330.92 X!O pup,q".nscc X btc .>1>... 4.89 6.06 2.02 6319.92 6321.94 5·112" 17# NSCC PUP 4.89 6.06 9.63 6310.29 6319.92 102 JTS 5-112" 17# NSCC TBG #2-103 4.89 6.06 4209.45 2100.84 6310.29 5-1/2" 17# NSCC PUP 4.89 5.50 9.62 2091.22 2100.84 (@\i'5's.I:·' :ø¡'Pit.¡:. 2089.90 2091.22 5-112" 17# NSCC PUP 4.89 6.06 9.61 2080.29 2089.90 48 JTS 5·112" 17# NSCC TBG #104-151 4.89 6.06 1979.98 100.31 2080.29 5-1/2" 17# NSCC PUP 4.89 6.06 15.80 84.51 100.31 1 JT 5·1/2" 17# NSCC TUBING #152 4.89 6.06 41.43 43.08 84.51 FMC 7" HANGER xlo and 5.5" PUP 4.89 6.06 5.65 37.43 43.08 POOL 7 RKB 37.43 37.43 Spaced out 1.5' above locator sub. P2-34 PBR Squeeze . 8 . P2-34 PBR Squeeze . ITEM HOWCO F/S 2 JTS 5-1/2" CASING 1 & 2 HOWCO FIC BAKER UC 10 JTS 5-1/2" CASING 3 - 12 5-112" 17# L-80 PUP JT PARKER SWS NIPPLE 5·1/2" 17# L-SO PUP JT 155 JTS 5-1/2" CASING 13-167 BAKER xlo 7" nsee X 5.5" nsee BAKER PBR BAKER "HMC" UNER HANGER BAKER LNR TOP PKR "2XP"Wr 6'TBE 4.562 6.07 9 Ç) '* % -- ~ ~ )''-., ~ f\¡j " \J¡~ g£J¡(¡J B "Ii (.~ <:: ßSÆ¡ç }~ ~;i! (::. .., . 1,,5(¡lP '1" <: ?"ft-z"Z..ooo4- ,,"'VC>.'!, I 75"/0" ð .Sl. ~\.~ ~91 \.57 135//f..". ·ü o 3/llp 8~4.. 314. 11z. ¿ ;í3¿JcO In ~33/5- /....-;-'- ~/ ž':B / r.o 1.40 7, t>t>" "MC :.;qz; ë;3r:Jé)Z(rJ Liner Hanger ~1òÇ:zCL . P2-34 PBR Squeeze ,q I Cf 'D4- " .70 , !! i 4 DB J - --..--- ~. /90-{,O ::BE"' ,- ~ ¡-----1, 7 "/¡~ 01 <,.-- 7"//(p" 1N.$CG. t..¥/;'9 71/z" ¡ I' lCJ . , <f "¥g 0.1 W:!(:.q~~~/"'YJ,'\Z__ oz- 43Z3/:;. 0/.1 B "?:J/¡(P ú> I (" ¿~ ..Ç·('l ! 1~ 73 /9Ó-lðO /ðÁÆ"P"A"/7b~. /?-¿-~,~l!ícc. ,.~':JZ· 1'-_='š,Z</-/;).;:J .~-l:.;--.·-,:.(;::·/-; . (;. .:.) I ( .1 ¡ , L ! ~ I ! II " ( ¿ ¿, " /};'~'- J3.-' ~0 ./;¡J f;'-31- o ~2 t.)_ r '/J ) 10 Re: STATUS: P2-34 (PTD 1950660) IA Repressurization - We concur with placing the well back on injection Jim Regg AOGCC 5CANNED JAN 0 8 2007 NSU, ADW Well Integrity Engineer wrote: Hi Jim and Winton, .,.:0:....._ - f·...!Io,........~· Here is the MIT form for the MITIA recently conducted on P2-34 (PTD 1950660). «MIT GPMA P2-34 12-28-06.xls» With AOGCC approval, BP would like to put this well back on injection to see if replacing the DGL V mitigated the IA repressurization. The well will remain on the Monthly Injection Report. If after a month of monitoring pressures there is no IA repressurization, the well will be removed from the report. If IA repressurization is exhibited, a request for AA will be submitted. Please send us approval to place this well back on injection. Thank you, )fnna (j)u6e, Œ'. fE. Well Integrity Coordinator GPB Wells Group Phone: (901) 659-5102 Pager: (901) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December OS/20069:11 PM To: 'Winton Aubert (E-mail)'; 'James Regg' Cc: GPB, Wells Opt Eng; GPB, Optimization Engr; Cismoski, Doug A; Kurz, John; GPB, FS1 DS Ops Lead; NSU, ADW WI Tech; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; NSU, ADW WL & Completion Supervisor; GPB, GPMA Area Mgr; GPB, LPC DS Ops Lead; NSU, ADW Well Integrity Engineer Subject: STATUS: P2-34 (PTD 1950660) IA Repressurization Hello Jim & Winton. lof2 1/4/2007 1 :58 PM Re: STATUS: P2-34 (PTD 1950660) IA Repressurization . . Injection well P2-34 (PTO 1950660) exhibits IA repressurization when on injection. The IA pressure was observed to re-pressure from 430 to 1700 psi overnight. A subsequent MITIA passed to 2500 psi. Recent events: > 07/09/06: Set TIP, MIT-T Passed to 2500 psi, pulled TTP > 11/30/06: TIO = 1550/1760. Sled lAP to 430, repressured to 1700 overnight > 12/02106: MITIA Passed to 2500 psi Current plan is as follows: 1. WIC: Leave well on injection 2. S: Pull OGL V, circ in freeze protect, replace OGL V 3. F: MITIA to 3500 psi 4. WAY: Report results to AOGCC, eval if further action is needed The well has been added to the monthly UIC report. Attached is a well bore schematic and wellhead pressure plot, please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllnteqrityEnç¡ineer(ã¿bp.com 20f2 1/4/2007 1:58 PM · . STATE OF ALASKA "1 ALASKA OIL AND GAS CONSERVATION COMMISSION I ~L...-~/ Mechanical Integrity Test ~ 1 ~ ï vy. Email to:wintonAubert@admin.state.ak.us;BobFleckenstein@admin.state.ak.uS;JimRegg@admin.state.ak.us;ToXaunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / Pt. Mcintyre / P2 12/28/06 Joe Anders Iq6~ O\"to Packer Depth Pretest Initial 15 Min. 30 Min. We1l1P2-34 I Type Inj. I N TVD I 4,948' Tubingl 700 700 700 700 Interval I 0 p.T.D·11950660 I Typetest I P Test psil 3500 Casing 700 3,500 3,460 3,440 P/FI P Notes: MIT IA to evallA repressurization / OAI See note NOTE: Monobore Completion Weill Type Inj. I TVD I Tubingl Interval I p.T.D·I Type test I Test psil I Casing P/FI Notes: OAI Weill I Type Inj.1 TVD I I Tubingl Interval I P.T.D. Type test I Test psi I Casing P/FI Notes: OAI Weill I Type Inj.1 TVD I Tubing I Interval! p.T.D·1 I Type test I Test psil Casing P/FI Notes: OAI I Weill I Type Inj. TVO Tubing Interval I p.T.D·1 I Type test I I Test psil Casing I P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 /. 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 GPMA P2-34 12-28-06-1.xls STATUS: P2-34 (PTD 1950660) IA Repressurization . Hello Jim & Winton. Injection well P2-34 (PTD 1950660) exhibits IA repressurization when on injection. The IA pressure was observed to re-pressure from 430 to 1700 psi overnight. A subsequent MITIA passed to 2500 psi. Recent events: > 07/09/06: Set TIP, MIT-T Passed to 2500 psi, pulled TIP > 11/30/06: TIO = 1550/1760. Bled lAP to 430, repressured to 1700 overnight > 12/02/06: MITIA Passed to 2500 psi Current plan is as follows: 1. WIC: Leave well on injection 2. S: Pull DGL V, circ in freeze protect, replace DGL V 3. F: MITIA to 3500 psi 4. W A V: Report results to AOGCC, eval if further action is needed The well has been added to the monthly UtC report. Attached is a wellbore schematic and wellhead pressure plot, please call with any questions. «P2-34.pdf» «P2-34 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom - r;' r.t. (' 2nnQ ,p, ¡~'~., '-, I'le'-! ~.:;;r· ", NMC¡lJ D ,_,' M,('" " \::!.' i.-?t:v/. . !' ~~ Content-Description: P2-34.pdf P2-34.pdf Content-Type: application/octet-stream Content-Encoding: base64 P2-34 TIO Plot.jpg Content-Description: P2-34 no Plot.jpg lof2 12/6/20069: 11 AM STATUS: P2-34 (PTD 1950660) IA Repressurization . . Content-Type: image/jpeg Content-Encoding: base64 \z( b loÇc. ) Q'34:, fJ.l\ ".-- -. ~ Joe ,~s ( ß p) 1ð4- VOt c.è MeS ScLc<f tD l10w ¡ tJ Lt P L~ ~ GJ-{ ~ <?eu-1.eJ- tÀ. ~(J ~: PBíl Pz.- 34 - ~ -HM", weØ. cfo~ j acl,~ I kè A. 1-~ {~ <if <3Llspeð ..J.4 ~V - ~ ~ CA.. klt(~ pr;<ý\'~ tür- rt'pa-~r f w~Ll ~ ø~ -to C~-h 'I'M. ,- d..D t\o'- pl~ @ ~~ -h ~ ~ <)ubM.-~ ~ A-clÞu'^ /JpPnJVdJ ~ Ua}- ~Ctl.«~ ðf" rfPI'ESSLAr.~ ro..-k ~ Tf,. 7- Lto-kJ Cèlso ~ O~s Ole ~l~Y\~1l1 Q£'::'D0-..:J;A llr'le }ret'.è1~ - \l~ ~ blœJ.1:j -rœe~ rfbh::!- ftw¿J ~ >A ' ~"W,a V\.eeJ .-Jo b¿ aJøJesw c;Js.o ) J,\Vc¿{ {¿Ii(D~ 20f2 12/6/20069:11 AM lREr:= 7"x6" 0\ RBON 5M COOÆR WELLHEAD= 13"x13" 5M FMC P2-34 SAFEI"Y NOTE: T x IA COMMUNICATION, 9-12-98. AClUATOR= AOGCC SUtÐRY, 9-23-98. MONO-BORE WELL. KB. ELEV = 51.7' BF. ELEV = KOP= 1300' I'vtIx Angle = 55 @ 8279' . 5-1/2" PA RKER SWS NIp, ID = 4.562" I Datum MD = 12746' 2091' DatumWD- 8800' SS MinimUm ID = 4.562 @ 2091' GAS LIFT MANDRELS 5-1/2" PARKER SWS NIPPLE L--- I STI MD IWD DE\! TYPE IVLvLATCHI PORTI DA1E ~ I 1 16322149111 51 15.5" x 1.5" LBI I RA I I I 5-1/2" mG, 17#. NT-BO. 0.02325 bpf, ID =4.89" 6388' t--- 5âi ~ 6388' BAKERLNR TlEBACKSEALASSY I I TOP OF 5-1/2" LNR I ~ "1 6383' 9-518" BAKER LNR 10P ZXP PKR I 6397 n ~ ,6403' BAKER PBR I ----r 6418' 7" X5-1/Z' XOI I 9-5/8" CSG. 47#, L-80. ID = 8.681" 6533' ~ ... . I 12820' 5-1/Z' PARKERSWS NIP, ID-4.562" I ÆRFORA TION SUIllMARY REF LOG: SWS CDRlGR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' No1e: Refer to Production DB for historical erf data 1 SIZE SPF NTERVAL Opn/Sqz DA1E 3- 3/8" 6 12896 - 12921 0 08101/95 X 3- 3/8" 6 12901 - 12921 0 08109/04 3-3/8" 6 12930 - 12950 0 06109/04 3-3/8" 6 12950 - 12970 0 06109/04 ~ 3- 3/8" 6 13010- 13030 0 06109/04 3-3/8" 6 13070- 13120 0 08101/95 ¡ I PBTD I 13230' I ~ I 5-112" LNR, 17#. NT-80, 0.02325 bpf, ID= 4.89" I 13326' I DATE REV BY CO """,,ENTS Dð.1E REV BY COMIVENTS FOINT MCINrY RE UNIT 07/20/95 ORIGINAL COM PLETION WB.L: P2-34 09/16/00 SIS-lsl 5-112" PX R.UG PULLED PERMIT: 1950660 09/18/01 RN'TP CORRECTIONS A PI No: 50-029-22558-00 06/09/04 MDG'KAK ADIREÆRF SEC14. T12N. R14E. 245'FNL& 1359' FWL BP Exploration (Alaska) . RE: P2-34 (PTD #1950660) Confirmed TxIA communication e ( t ~I CG:. Hi Jim and Winton, Well P2-34 (PTD# 1950660) passed an MITIA on 6/11/06. I've included the MITIA form. «MIT GPMA P2-34 06-11-06.xls» Given the passing test, our plans are to leave the well on injection, replace the dummy gas lift valve, and monitor the IA repressurization. Please let us know if you have any questions. Thank you, Anna Dube From: NSU, ADW Well Integrity Engineer Sent: Saturday, June 10, 2006 5:29 AM To: Parker, R. Andrew; GPB, GPMA Area Mgr; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; 'AOGCC Jim Regg (E-mail)'; 'AOGCC Winton Aubert (E-mail)'; NSU, ADW WL & Completion Supervisor; GPB, LPC DS Ops Lead Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Winslow, Jack L. Subject: P2-34 (PTD #1950660) Confirmed TxIA communication All, Well P2-34 (PTD #1950660) has been found to have sustained casing pressure on the IA. The TI pressures were 1910/1720 on 06/09/06 after bleeding the IA on 06/08/06 to 280 psi and building 1440 overnight. An AOGCC witnessed MITIA passed to 3000 psi on 04/08/06. The well will be added to the Monthly Injection Report. The plan forward for this well is as follows: 1. DHD: Bleed lAP, monitor BUR - Confirmed TxlA communication 2. WOE: Leave well on-line for diagnostics 3. FB: MITIA to 3000 psi, LLR 4. WIE: Evaluate for change out of DGLV or secure and LDL 10f2 7/13/20062:09 PM RE: P2-34 (PTD #1950660) Confirmed TxIA communication e A wellbore schematic has been included for reference. e Please call if you have any questions. Thank you, }lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: MIT GPMA P2-34 06-11-06.xls GPMA P2-34 06-11-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 7/13/20062:09 PM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~1q 111~¡¡¡" Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / pt. Mcintyre / P2 06/11/06 Anna Dube v.\~/ olu!' Packer Depth Pretest Initial 15Min. 30 Min. We1l1P2-34 I Type Inj. I W TVD I 4,949' Tubing 1,550 1,500 1,500 1,500 Interval I 0 P.T.D. I 1950660 I Type test I P Test psi! 1500 Casing 1,550 3,000 2,980 2,980 P/FI P Notes: MITIA to evallA repressurization. OA Weill I Type Inj. I I TVD I Tubing Interval I P.T.D.I I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj.! ! TVD I Tubing Interva" P.T.D.I ! Type testl I Test psi! Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 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 0= other (describe in notes) 2006-0611_MIT_PBU _P2-34.xls P2-34 (PTD # 1950660) Confirmed TxIA communication ) ) Subject: P2-34 (PTD #1950660) Confirmed TxIA conununication '~qí (,114(0"- From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sat, 10 lun 200605:28:31 -0800 To: "Parker, R. Andrewtl <Andrew.Parker@BP.com>, "GPB, GPMA Area Mgr" <GPBGPMATL@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor',' <NSUADWWellOperationsSupervisor@BP.com>, "OPB, Wells Opt Eng" <GPBW ellsOptEng@BP .com>, "AOGCC Jim· Regg (E:"mail)" <jim ~regg@admin.state.alc us>, "AOGCCWinton Aubert (E-mail)..<winton~aubert@admin.state.ak.us>. "NSU, ADW WL & Cqmpletion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, LPC DS. Ops Le~d" <GPBLPCDSOpsLead@BP~com> C<p: "NSU, ADW Well Integrity Engineertl <NSUADWWellfutegrityEngíijeer@BP.com>,·tlNSU, AIpW WI Tech" <NSUADWWITech@BP.com>,"vyinslow, Jack L.II <Lyonsw@BP.com> All, / Well P2-34 (PTD #1950660) has been found to have sustained casing pressure on the IA. The TI pressures were 1910/1720 on 06/09/06 after bleeding the IA on 06/08/06 to 280 psi and building 1440 overnight. An AOGCC witnes~ed MITIA passed to 3000 psi on 04/08/06. The well will be added to the Monthly Injection Report. ,/" .1 w.:J¡\J::) The plan forward for this well is as follows: 1. DHD: Bleed lAP, monitor BUR - Confirmed TxlA communication 2. WOE: Leave well on-line for diagnostics 3. FB: MITIA to 3000 psi, LLR 4. WIE: Evaluate for change out of DGLV or secure and LDL SCANNE[) JUN 2 7 2006 A wellbore schematic has been included for reference. «P2-34.pdf» Please call if you have any questions. Thank you, }{nna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: P2-34.pdf P2-34.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/14/2006 5:32 PM ) ) 1REE = 7"x6" CA.RBON 5M COOÆR \NELL HEA D = 1 3"x 1 3" 5M FMC ÃCWA TOR = 'kËf Ël.él;;;m..... ..m.m.m ........... ..mS fi BF. ELEV = KOP= Max Ang Ie = Datum MD = Datum 1VÖ~' P2 -34 SAFETY NOTE: T x IA COMMUNICATION, 9-12-98. AOGCC SUtÐRY, 9-23-98. MONO-BORE WELL. 1300' 55 @ 8279' 12746' ... .. .... ... "áä6"öï"S"s I . 1 2091' H 5-1/2" PA RKER SWS NIP, 10 = 4.562" 1 Minimum ID = 4.562 @ 2091' 5-1/2" PARKER SWS NIPPLE L GAS LIFT MANDRELS I STI MO IlVOI OEV I TYPE IVLV ILATCHI PORTI DATE I 1 6322 4911 51 5.5" x 1.5" LB RA 5-1/2" TBG, 17#, NT-80, 0.02325 bpf, 10=4.89" 1-1 6388' ~ ~ 6388' H BAKERLNR llEBACKSEALASSY 1 1 TOP OF 5-1/2" LNR l-i 6397' I ~ 1--1 6383' H 9-5/8" BAKER LNR TOP ZXP PKR ~ 1 6403' H BAKER PBR 1 ~ 6418' H 7" X 5-1/2" XO 1 9-5/8" CSG, 47#, L-80,10 = 8.681" 1-1 6533' ~ .. I I I 12820' Ii 5-1/2" PARKERSWS NIP, 10=4.562" I ÆRFORA TION SUI\I1VIARY REF LOG: SWS COR/GRON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical :Jerf data SIZE SFf NTERVAL Opn/Sqz OA TE 3-3/8" 6 12896 - 12921 0 08/01/95 3-3/8" 6 12901 - 12921 0 06/09/04 3-3/8" 6 12930 - 12950 0 06/09/04 3-3/8" 6 12950 - 12970 0 06/09/04 3-3/8" 6 13010- 13030 0 06/09/04 3-3/8" 6 13070- 13120 0 08/01/95 I PBTO 1--1 13230' A 5-112" LNR, 17#, NT-80, 0.02325 bpf, 10= 4.89" 1-1 13326' DATE 07/20/95 09/16/00 09/18/01 06/09/04 REV BY COI\l1VlEJIITS ORIGINAL COM PLETION SIS-lsl 5-112" PX A.UG PULLED RN'TP CORRECTIONS WC'KAK AO/REÆRF [}/\ TE REV BY COMIlÆNTS FOINT WCINTY RE UNIT WB.L P2-34 PERMIT: 1950660 A PI No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration (Alas ka) RE: P2-34 (PTD 195-066) e (œ)/~ Hi Jim. The MITIA on 4/8/06 was for P2-34's 2-year MITIA requirement. It's last MIT-T was done 12/23/04 and we were planning to set a TTP and conduct the MIT-T in December. Please let me know if you have any questions. Thanks for watching our UIC test program! Joe 659-5102 -----Original Message----- From: James Regg [1!1_~_~_~_t::g_:j_~~~9.9~~0rn.in._§_!:~e :_~~::'::l:'§'] Sent: Friday, April 14, 2006 1:33 PM To: NSU, ADW Well Integrity Engineer Cc: Engel, Harry R Subject: P2-34 (PTD 195-066) We exchanged info about P2-34 (PTD 195-066) in Nov 2004 re: MIT requirements for monobores. I shared our policy and well file research establishing a Tubing MIT (MITT) every 2 years as the proper test for monobores. The test witnessed by the Commission on 4/8/06 was an MIT-IA to 3000 psi. Test should have been an MIT-T. Jim Regg AOGCC 3 1 of 1 4/28/2006 1 :37 PM MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg t'?VAl;û1' tr{ ¡t¡(UG P.l. Supervisor \\t", DATE: Monday, April 10, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P2-34 PRUDHOE BAY UN PTM P2-34 {-\ b.A) 1t!P FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.l. Suprv5~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM P2-34 API Well Number 50-029-22558-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060408 I 20841 Permit Number: 195-066-0 Inspection Date: 4/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. i P2-34 IT I'! I I I I I Well i ype nJ.: w ITVD 4949 I IA 1740 i 3030 3010 3000 ; I , i I i i I 1950660 ! ¡. I lOA ¡ ! I P.T. !TypeTest SPT i Test psi ! 1237.25 I I ì OTHER Tubing! 1660 I 1560 I 1520 I 1500 ! i Interval P/F P ! , I ! Notes Monobore completion, suspected Tubing by Casing leak, ít'sd- S)W..f(..~ tltc.<v,€ bee,.", ¡l'tYT' -\!X~?C,,~ c/v\. Aê0,CL ¡::vìtdj +ð,¡ ;UÇY1ö bôre I ~Iìec:fu '5 { c ltfrt r'é'-ð (,0/ -gf' ll/4-t Db _: .see u.'¿J( ~le \ >..J / :~Çé\N~\EJ) II, "": 0 .j, ci/ Monday, April 10, 2006 Page 1 of I Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth +:::.r>llii't.if;.flt::lf\ t D hj 2 n ?OOR ~\Vl~11~~n·~tç~!' 0 ~ -~ ~ ': .'-.1 ~ir ~- --. -~ Well Job# Log Description Date BL Z-01 11087166 LDL 08/05/05 1 Y-13 N/A PRODUCTION LOG 05/01/05 1 L2-14B 10670029 PROD PROFILE 08/20/04 1 Y -08A 11047356 MEMORY/SENSA LDL 10/15/05 1 X-36 11075908 MEMORY INJECTION PROFILE 08/17/05 1 X-30 10662973 GLS 12/02/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 P2-01 11072880 LDL 08/06/05 1 OS 12-08C 11087208 SBHP SURVEY 12/24/05 1 0.5. 09-28A 11094347 LDL 12/28/05 1 P2-34 ,qç - O{¡;, (p N/A INJECTION PROFILE 06/02/05 1 Q-05A 11087203 SBHP SURVEY 11/27/05 1 NK-09 11062632 PROD PROFILE W/DEFT 07/01/05 1 NK-38A 11075902 MEMORY PROD PROFILE 07/27/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 01/04/06 NO. 3642 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. Color CD '-' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~rff~ Received bepWI'R.AXJVt) $chlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well NK-20 ./ P2-34 N-14A 4-38/K-34 B-19A 15-31B MPF-89 DS 16-01 DS 16-15 DS 09-10 M-30 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889223 11072853 10991753 10933591 11058502 10942223 11132060 10980601 10980599 11058237 11072877 I 9. Log Description PPROF W/DEFT TEMPERATURE PRESSURE LOG LDL PPROF W/DEFT/GHOST RST MCNL SCMT (PDC-GR) INJECTION PROFILE PPROF W/DEFT INJECTION PROFILE INJECTION PROFILE D~~ \-- Date 03/21/05 06/05/05 01/22/05 10/29/04 05/06/05 07/16/05 10/08/05 08/15/05 08/13/05 08/16/05 08/04/05 ~CANNED NOV 0 2 2005 NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 Color 1 1 1 1 CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 995 - 8 A TTN: Beth Received by: 10/18/05 -' - tqj-- ð ~Co Fi¡~ ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / Point Mcintyre / PM2 12/23/04 Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. Well P2-34 Type Inj. S TVD 4,949' Tubing 800 2,000 1,980 1,975 P. T. D. 1950660 Type test P Test psi 2,500 Casing 180 180 180 180 Notes: 2-year UIC MIT-T on injector with monobore completion. AOGCC representative declined witnessing test. Well Type Inj. S TVD Tubing P.T.D. Type test P Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. SCANNEt) JAN 0 6 ¿DOS MIT Report Form Revised: 06/19/02 MIT GPMA P2-34 12-23-04.xls (ph \ ~iS'9; l) Interval 0 P/F P Interval P/F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) Re: Review of Wells wIFailed MITs -) Subject: Re: Review of Wells w/Failed MITs Fröm: James Regg <jim_regg@admin.state.ak.us> Date: Mon, 08 Nov 2004 10:56:41 -0900 T(*: flEngel~Hariy R" <EngeIHR@BP.com>. ) attached . fb fó"..'""',.,.'" ~tt~¡~€1" . . [..p"~'~ Engel, Harry R wrote: Jim.. . Thanks for tip on researching well histories. Can you please send me a PDF of the 5/2/1997 AOGCC letter you referenced? Thanks, Harry -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Monday, November 08, 2004 9:43 AM To: Engel, Harry R Cc: winton aubert@admin.state.ak.us Subject: Re: Revie':W"""'õ-:E'm'''Wells w/Failed MITs Harry - To facilitate your well research, go to the Commission's website and click on "Public Well & Production Data, Well File Images" - from there you can access the well file for P2-34 using PTD # 1950660. Specific to the "policy" for monobores: 1) In a letter sent to Arco dated 5/2/1997, the Commission outlined monobore requirements, the essence being that "the Commission will no longer approve tubingless injection wells; however, we will allow the use of the five tubingless injection wells under our Regulatory Approval authority which requires MITs every two years and monthly reporting of daily tubing and casing perssures and injection rate." The letter goes on to establish that the well "must be tested against a plug set in the profile nipple which should be not more than100 ft above the top of perforations.". 2) In the 10-404 canceling sundry waiver approval 398-243 dated 3/4/03, BP states -- "Well P2-34 is a mono-bore completion. No OA is present, which is why the TIO plot indicates the IA and OA pressures are the same. MITIA test frequency for monobore completions is every 2 years." o::;:J" c:;) CJ N :to ~ - -- 0 ~) 4-. While the reference to MITIA is inconsistent with the AOGCC requirements, it is noted that the "Action Plan" established by BP for P2-34 is for the well to "pass the tubing MIT every two years to 2500 psi" . (J W Z Z ~ Ü C() There are other monobore injectors at Prudhoe that were not named in the 5/2/97 letter - namely GC-2C, -2E where the packer is set more than 1000 ft above injection perfs; these wells similarly require MITT every 2 years (but have done only MITIAs to satisfy recent MIT requirements). We note that there are also a number of injection wells that function similar to a monobore - e.g., PBU R-07A (PTD 200010) has the inability to evaluate the well integrity below the packer at 8100 ft TVD (perfs at 8984 ft TVD) It appears the Commisson's monobore "policy" regarding injectors is clear. If there are questions about the Commission's requiring compliance with conditions in our past correspondence, or the Commission's policy regarding monobores, it is more appropriate for you lof3 11/8/2004 11 :02 AM Re: Review of Wells w/Failed MITs to identify BP's conceL» at one of our Wednesday mOrning)publiC hearings. Jim Regg AOGCC Engel, Harry R wrote: Jim, Winton- I'm following up to Jim's email below regarding the MIT review. Anna has addressed the first 3 wells. We need to discuss regulatory requirements for monobores. We are aware that there is an AOGCC policy related to monobores, however we do not have a copy and we are not familiar with its content or how to get copies. We have not found it on the AOGCC web page. We need to research the permit history for P2-34 and the regulatory history of 20 AAC 25.412 (packer within 200 ft of perfs) to understand the requirements. P2-34 is a normal and would not be included in the monthly injector list. Please give me a call so we can make arrangements to meet to discuss monobore regulatory requirements. Thanks, Harry -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, October 26, 2004 4:57 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Review of Wells w/Failed MITs We just completed a quarterly review of wells with MITs that failed and have identified 4 that need some clarification regarding status: 1) *PBU 13-22*; failed MIT 7/21/04; SI after MIT and well was added to monthly injector report; our database shows 3 days injection in September (26,996 bbls water); what is the status of request for administrative approval? [According to September Monthly Injector Report, tbg integrity was to be restored prior to placing on injection, and MIT was planned for 9/23/04; nor record of either] 2) *PBU 03-36*; failed MIT 8/2/04; well was added to monthly injector report; our database shows injection in August (9 days; 2,080 bbl water) and September (5,379 bbl water); what is the status of request for administrative approval? 3) *PBU NK-38*; failed MIT 7/12/04; well has not been added to monthly injector report; data provided to Commission indicates 32 bbls water injected (1 day) during September; what is status of this well and follow-up to failed MIT? 4) *PBU P2-34*; MIT 7/13/04; the Commmission carries this as an incomplete MIT (thus, requirements of 2 year testing for monobore injectors per AOGCC policy have not been satified); MIT is incomplete because only the upper 6,400 ft of the well (perfs at 13,000 ft) has been evaluated for mechanical integrity; it is 20f3 ~ c:.1 CJ c--.J ~ '1"""-"\1 ::> 0 z L:ì W z: Z ~ () en 11/8/2004 11 :02 AM Re: Review of Wells w/Failed MITs also unclear if the ~~21 carries a waiver from 20 AAC 25.412 (packer within 200 ft of perfs); this well should be added to the monthly injector list. I'd appreciate an update of the 4 wells so we can close out our review. Jim Regg AOGCC . : Content-Type: applicationlpdf . ; Tubingless Inj.pdf . . ; -. Content-EncodIng: base64 SCANNED NO\f 'l 6 200~ 30f3 11/8/2004 11 :02 AM ) ) ......~- 00-./ ~. c.hu..c.f.. - Jof.",.. - Çð'-"-; - TONY KNOWLES, GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 2, 1997 Mike Zanghi, Drill Site Dev. Supv. ARCa Alaska.. Inc. PO Box 100360 Anchorage, Alaska 995 10-0360 Re: Tubingless Injection Wells Dear Mr. Zanghi: As we discussed during the meeting on Wednesday, April 30:- 1997, injection wells must be completed with tubing and packer to isolate pressure to the zone and to enable MIT testing in accordance with our regulations, 20 AAC 25.412.. which are consistent with 40 CFR 146.8 Mechanical Integrity . To effectively capture the discussion and the agreements resulting from that meeting, I have prepared an addendum to the November 8, 1996 memo Consideration of Tubingless Injection and Disposal Wells. A copy of the original memo with the May I, 1997 addendum is attached for your records. The essellce of the requiremen~ are that the Commission win no kmger approve tubingle$s injection welts; however. we will allow use of the five tubingless injection wells under our Regulatory Approval authority which requires MITs every two years and nwnthly reporting of daily. tubing and çasing pres$Urcs and. injection rate. The MITs must be tested against a plug set in the profile nipple which should be not more than 100' above the top of the perforations or against an inflatable plug set not more than 100' above the top of perforations. Mike, please review the KRU tubingless injection wells to determine if they have a proper MIT, if not please plan to have one conducted. Keep us advised. If you have any questions, please call me at 279-1433. Sincerely, ~t..~l,~ Blair Wo~;eíl[Ì Senior Petroleum Engineer ,! ; ¡ Enclosure cc: D. Nims. R. Thomas A. Clark SCANNED NOV 1 6 2004 RE: Review of Wells wlFailed MITs - 13-22,03-36, NK-38, P2-34 ) ) Subject: RE: Review of Wells wIFailed MITs - 13-22, 03-36, NK-38~_P2-34 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Date: Wed, 27 Oct 2004 19:51:35 -0800 To':~J ames Regg <jim _regg@admiít'state.ak.us~ . '." :' ..' , . " '" ' . '. . . , , CÇ:Wintori G Aubert <",ínton~ aubert@admin~state~ak.us>, ;"NSD, ADW:' Well .Integrity EngiÍ1ëert~.: <MSUADWW ellIntegrityEngineer@BP.com> ,:,' .,'. ' , ' , ' : -I"",Q" ,""""'~,',,,,',' "",,'.,,',~,~,', ' ,(), ",.' ""l-,'"',., "r", ! ,~t'!:::"'i"""" .' ." (9'V' Hi Jim, Here are updates to three of the wells requested. I am still looking into P2-34 but wanted to respond with the information I have at this time so that these reviews can be closed out. 13-22 failed an MITIA on 7/21/04 while the well was shut-in and on a vacuum. The plan has been to repair a gate valve, put the well on injection, and repeat the MITIA with the well on injection. The repair work has been completed and this well is on the schedule for an MITIA this week. The AOGCC inspector will be contacted to witness the test if possible. 03-36 failed an MITIA and passed a MIT-T on 8/2/04. An leak detection log confirmed a production casing leak at 8230' md on 8/11/04. Plans are to submit a request for Administrative Approval once M-38 AA has been approved to include any additional information required for the AA. NK-38 was not added to the monthly injection report given the plan is to workover the well instead of apply for Administrative Approval. The injection valve was opened on 9/19/04 to freeze protect the tubing and flowline for the winter. Please let me know if you have any additional questions. I will follow-up with P2-34 within the next few days. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, October 26, 2004 4:57 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Review of Wells w/Failed MITs We just completed a quarterly review of wells with MITs that failed and have identified 4 that need some clarification regarding status: 1) *PBU 13-22*; failed MIT 7/21/04; SI after MIT and well was added to monthly injector report; our database shows 3 days injection in September (26,996 bbls water); what is the status of request for administrative approval? [According to September Monthly Injector Report, tbg integrity was to be restored prior to placing on injection, and MIT was planned for 9/23/04; nor record of either] 2) *PBU 03-36*; failed MIT 8/2/04; well was added to monthly injector report; our database shows injection in August (9 days; 2,080 bbl water) and September (5,379 bbl water); what is the status of request for administrative approval? 3) *PBU NK-38*; failed MIT 7/12/04; well has not been added to monthly injector report; data provided to Commission indicates 32 bbls water injected (1 day) during September; what is status of this well and follow-up to failed MIT? 4) *PBU P2-34*; MIT 7/13/04; the Commmission carries this as an incomplete MIT (thus, requirements of 2 year testing for monobore injectors per AOGCC policy have not been satified); MIT is incomplete because only the upper 6,400 ft of the well (perfs at 13,000 ft) has been evaluated for mechanical integrity; it is also unclear if the well carries a waiver from 20 AAC 25.412 (packer within 200 ft of perfs); this well should be added to the monthly injector list. 10f2 10/28/20048:00 AM " RE: Review of Wells wlFailed MITs - 13-22,03-36, NK-38, P2-34 ) ) I'd appreciate an updatE: of the 4 wells so we can close oue our review. 20f2 Jim Regg AOGCC 10/28/20048:00 AM cM~ 1 'l REPORT OF SUNDRY WELL OPERATI ft,,-o~g.r.Rn!, Commtlsion 1. Operations Performed: ~I". \01" ..... - Abandon 0 RepairWellD PluQ PerforationsD Stimulate 0 _@!pO8 Alter CasingD Pull TubingO Perforate New Pool D WaiverD Time ExtensionO Change Approved Program D Operation Shutdown 0 Perforate IKJ Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 1-~ ---- 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ] 50~29-22558-00~0 7. KB Elevation (ft): 9. Well Name and Number: 52.20 P2-34 8. Property Designation: 10. Field/Pool(s): ADL~34624 pt Mcintyre Oil Field / Pt Mcintyre 011 Pool 11. Present Well Condition Summary: Total Depth measured 13326 feet true vertical 9231.7 feet Plugs (measured) None Effective Depth measured 13230 feet Junk (measured) None true vertical 9169.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-80 42 - 122 42.0 - 122.0 Liner 35 7" 26# L-80 6383 - 6418 4948.8 - 4970.8 7240 5410 Liner 6908 5-1/2" 17# L-80 6418 - 13326 4970.8 - 9231.7 7740 6280 Surface 6492 9-5/8" 47# NT80S 41 - 6533 41.0 - 5043.0 6870 4760 Perforation deDth: Measured depth: 12896 -12901,12901 -12921,12930 -12950,12950 -12970,13010 -13030,13070 -13120 True vertical depth: 8951.58 - 8954.88,8954.88 - 8968.09,8974.02 - 8987.2,8987.2 - 9000.34,9026.54 - 9039.59,9065.59 - 9097.88 Tubing ( size, grade. and measured depth): 5-1/2" 17# NT-80 @ 37 - 6388 Packers & SSSV (type & measured depth): 7" Baker ZXP Liner Top Packer @ 6383 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Daily Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasjnQ Pressure Tubing Pressure Prior to well operation: 0 0 -10394 200 1311 Subsequent to operation: 0 0 -9812 180 1229 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - X OilD GasD WAGD GINJD WINJŒ WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-177 Printed Name Garry Catron Title Production Technical Assistant Signature ~A ~ Phone 564-4657 Date 8/19/04 " ~ STATE OF ALASKA ~ RECE'VED ALASKA Oil AND GAS CONSERVATION COMMISSION 004 0 . " ("'-1 ~" I f¡ L R LJ I ¡ -'~ f\ -- BfL. Aü6 3 U LUll~ Form 1 0-404 Revised 4/2004 ,~ ~ P2-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/08/04 PERFORATE WITH 3-3/8" HSD 6 SPF 60 DEG PHASING 3406 PJ HMX. INTERVALS 13010 - 13030 FT AND 12950 - 12970 FT. 06/09/04 PERFORATE WITH 3-3/8" HSD 6 SPF 60 DEG PHASING 3406 PJ HMX. INTERVALS 12930 - 12950 FT AND 12901 -12021 FT. ALL GUNS SHOWED GOOD SIGNS OF FIRING AND WERE SPENT WHEN RETURNED TO SURFACE. FLUIDS PUMPED BBLS :TOT AL No Fluids Pumped 0 Page 1 ~ ~ lREE= 7"x6' CARBON 5M COOÆR WElL I-EA D = 13"x13" 5M FMC ACTUATOR- KB. ELBI - 51.7' BF. ELBI = KOP= 1300' MIx Angle = 55 @ 8279' Datum MD = 12746' Datum lVD - 8800' SS Minimum ID = 4.562 @ 2091' 5-1/2" PARKER SWS NIPPLE P2-34 SAFErYNOTE:T xlACOMMUNICATION, 9-12-98. AOGCC SUNDRY, 9-23-98. MONO-BORE WELL. 2091' 5-1/2" PA R<ER SWS NIP, ID = 4.562" 5-1/2" TBG, 17#, Nf-80, 0.02325 bpI, ID = 4.8g' TOP OF 5-112" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" ÆRFORA TION SUfl.tv1ARY REF LOG: SWS CDRiGR ON 07/14/95 ANGLE AT TOP PERF: 49 @ 12896' Note: Rafer to Production DB for historieal )erf data SIZE SA" NTERVAL Opn/Sqz DATE 3-3/8" 6 12896 - 12921 0 08101/95 3-3/8" 6 12901 - 12921 0 06109104 3-3/8" 6 12930 - 12950 0 06109104 3-3/8" 6 12950 - 12970 0 06109104 3-3/8" 6 13010-13030 0 06109104 3-3/8" 6 13070-13120 0 08101/95 13230' 13326' 5-112" LNR. 17#, Nf-80, 0.02325 bpI, ID = 4.8g' BAKERLNR llEBACKS611.LASSY 9-518" BAKERLNR TOPZXPPKR 12820' 5-1/2" PARKERSWS t\lP, ID=4.562" DATE REV BY OOfl.tv1ENTS C\II.TE RBI BY COMMENTS 07/20/95 ORIGINAL COM PLETION 09/16/00 SIS-Isl 5-112" ~ R...UG PLLLED 09/18/01 RN'TP OORRECTIONS 06/09/04 MDOKAK ADiREÆRF FOINf WCINfYRE UNrr W8.L: P2-34 PERMrr: 1950660 A PI No: 50-029-22558-00 SEC 14, T12N, R14E, 245' FNL & 1359' FWL BP Exploration (Alas ka) MEMORANDUM State of Alaska Alaska Oil and Gas Cons-enalion Commission 'R~c TO: Jim Regg 1) '7 )fot P.I. Supervisor DATE: \\'edne:;day. July 14. 2(104 SlIBJECT: f\lechanlcallntegmy Tests 8P EXPLOR..o\ T ION f AL AS K..o\ I TNC P~- 34 FROM: Chuck Scheve Petroleum Inspeclor PRUDHOE 8A Y UN PTM P~-34 Src: InspectOr Re\'iewed B\': .~J....,r P.I. Supr\' ~- Comm NON-CONFIDENTIAL \Vell Name: PRUDHOE SAY UN PTf\1 P2-34 API \Vell Number: 50-029-22558-0(1-(1(1 Insp Num: m1lCS040713211727 Permit Number: 195-066-0 Rellnsp Num: Inspector Name: Chuck Schew I nspection Date: 711312004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P2-34 Type Inj. P TVD 9232 I IA \00 2010 2010 2010 P.T. 1950660 TypeTest SPT Test psi 1237 lOA Inten'al .¡'t"RTST P/F Tubing 800 800 800 800 Notes: This well IS 3 monobore design wilh the packer sel 316383 and Ihe top perfat 12896. This test was on Ihe upper portion oflhe \\'ellbore only. ~ MCl ;, ý7'v+ -+0 t;,f 7 , I b ( 04 ClLW, '" "1 +ll'1- M;:r T - T ; "> reD' t /J"t', ( 0 r 5dv\e t> ~r M-(!tt¡t S (-¡ (~!t\ wC:~~t1 ft,\fCtltlf\1 Ct,J~ ;f\.fe:Jrt-h.j) ft'.! 5«?C~)'\ of- (:-.:~lt ~ k. L'~ {Xl C~Cr J Ï\ 71 71<:-!C4 Wednesday, July 14, 2004 Page I of I \Re: P2-::!3 (PTD 1940320), P~-4 7 (PTD 1951900), P2-34 (1950660)... Subject: Re: P2-23 (PTD 1940320), P2-47 (pTD 1951900), P2-34 (1950660) 4 Year MITIAs From: James Regg <jim_regg@admin.state.ak.us> Date: Fri, 16 Jul 2004 09:03:49 -0800 To: "NSU, ADW WeB Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.c~m> CC: Winton GAubert <wintoTI_aubert@admin.state.ak.us> . . . BeC: Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Anna - Couple concerns with P2-34 monobore MIT... 1) MIT-T is required every 2 years for monobore injectors according to my understanding of AOGCC policy established ln 1997; it appears that BP performed a MIT-IA which addresses only the upper 6,400 ft of wellbore (9-5/8" csg @ 6,533', perfs -13,000 ft'); absent an MIT-T to evaluate the injection tubular integrity to the perfs, some other means of mechanical integrity demonstration is required for the well section below the tieback seal assembly. 2) Monobore injector is a variance from requirements of 20 AAC 25.412; the well should be added to the monthly injection waiver monitoring list (reporting daily injection and casing pressures, and injection rates) so we can track performance. Please advise what BP's plans are to address these concerns. Thanks. Jim Regg NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MITIA forms for the 4 year required tests for wells P2-23 (PTD 1940320), P2-47 (PTD 1951900), and P2-34 (1950660). The AOGCC representative witnessed the tests on P2-23 and P2-34. «MIT GPMA P2-47 07-12-04.xls» «MIT GPMA P2-23, P2-34 07-13-04.xls» Thank you, Anna Dube Well Integrity Engineer GPB Wells Group Phone: ( 907 ) 659 - 5102 Pager: (907) 659-5100 x1154 I of I 7/23/20044:37 PM V"'un J {' '-I (.VQ1- STATE OF ALASKA r""\ 0 Îj s: j/ ¥ 1-- ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL MAY 11 2004 20 AAC 25.280 . AlilßéI oa & 6a5 CDns. Comn,iuion PerforateOO / WaiverD AttdtoÞ8gØsposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 195-0660 ,-/ / 6. API Number / Stratigraphic 0 Service ŒJ 50-029-22558-00-00 9. Well Name and Number: P2-34 / 10. Field/Pool (s): Pt Mcintyre Oil Field / Pt Mcintyre Oil Pool PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9231.7 13230 9116.8 Length Size MD TVD -- r""\ 1. Type of Request: Abandon 0 Alter CasinQ 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWeli 0 Pull Tubing 0 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.20 KB 8. Property Designation: ADL-034624 3. Address: 11. Total Depth MD (ft): 13326 Casing Conductor 80 Liner 35 Liner 6908 Surlace 6492 Perforation Depth MD (ft): I 12896 - 12921 13070 - 13120 Packers and SSSV Type: 7" Baker ZXP Liner Top Packer 20" 94# H-80 7" 26# L-80 5-1/2" 17# L-80 9-5/8" 47# NT80S Perforation Depth TVD (ft): 8952 8968.1 9066 9097.9 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program Œ BOP Sketch 0 APr~4 Date: 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Operation Shutdown D PluQ Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Exploratory 0 Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom 42 122 42.0 122.0 6383 6418 4948.8 4970.8 7240 5410 6418 13326 4970.8 9231.7 7740 6280 41 6533 41.0 5043.0 6870 4760 Tubing Size: Tubing Grade: Tubing MD (ft): 5.5 " 17 # NT-80 37 6388 Packers and SSSV MD (ft): 6383 13. Well Class after proposed work: Exploratory 0 DevelopmentD ServiceŒ 15. Well Status after proposed work: Oil 0 GasD PluggedD AbandonedD WAG D GINJD WINJŒ / WDSPLn Prepared by GarrYtatron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature .ÎJ Patrica Hill P;<:~~ Contact Patrica Hill Title Phone Petroleum Engineer 564-4346 4/8/04 Commissìon Use Only I Sundry Number30't'--1?7 Plug Integrity 0 Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 Other: Approve Form 10-403 Revised 12/2003 Mechanciallntegrity Test 0 BY ORDER OF THE COMMISSION Dare 1~ y ORIGINAL MAY ,1 4 200~ IØ)MS Bf L SUBMIT IN DUPLICATE , - .~ ~ To: Doug Cismoski/John Smart GPB Well Ops Team leaders Date: 4/6/04 From: Patty Hill GPMA Production Engineer Est. Cost: $50 M / Cost Code: PMP02WL34- C lOR: 250 bopd Subject: P2-34: Add Perf (Cap gust) / Please add a total of 60 ft of new perforations in the LC3 and LC2 zones and reperforate 20 ft in the LC4. An IPROF from August, 2000 indicates that 100% of the injection is entering at the bottom set of perfs (LC1) but warm back passes confirm distribution of injected fluids across the reservoir. The LC3 and LC4 are receiving less injection than the LC1 and LC2. If it is not necessary to pull the SSSV, skip steps 1 and 3. 2. 3. E S Add perfs Re-run SSSV Comments Pull SSSV if necessary. Use 3 3/8" Dummy gun (2 7/8" dg if 3-3/8" tags up high) Please refer to attached procedure Type 1. S Job D&T Current Status: Injecting 12000 bwpd at an injection pressure of 1300 psi / Max. Deviation: 550 @ 8,279' MD Completion: 5-1/2" NT80 monobore completion, top of 5-1/2" liner at 6397' MD Min. ID: 4.562" @ 5-1/2" Parker SWN Nipple (2091' MD) Last Tag: 13,105' SLM on 617/00 with 3.5" centrilizer Last Well Ops: 9/27/02 Hydrate/ice plug removal ~ Current Perforations: 12896 - 12921 MD 13070 - 13120 MD Re-perf: 12930 - 12970 MD (40 ft) ~ 13010 - 13030 MD (20 It) / 12901 -12921 MD (20 It) Add Perfs: H2S: SWI Well was completed 6/95 with two perforated intervals in the LC4 and the LC1 zones. The well produced briefly from August thru September when it was converted to injection. The well initially produced over 4,000 BOPD and cum production was only 134 KBO with minimal water production. Since conversion, the well has injected 30.7 MMBW. It passed an MITIA to 2000 psi in 10/02. This pattern is not piped for EOR. An 'PROF was obtained on the well in August of '00. Splits indicated 100% entry into the LC1. A 68-hour warm back pass confirmed distribution of injected fluids in the reservoir. Bottom of injection was not seen on the log. The addlreperf is necessary to support offset production, especially at P2-11. P2-11 is a horizontal producer in the LC3 that was recently brought online after being shut in for almost 3 years. During the initial test, P2-11 produced 2300 bfpd, and two days later, it produced 400 bfpd, showing a lack of pressure support. P2-34 is the only injector /' supporting P2-11. The LC3 and LC4 are taking significantly less fluid than the LC2 and LC1, as noted in the warmback passes on the 8/00 JPROF. These perfs are also a preemptive move to combat the expected reduced injection when Pt. Mac converts from SWI to PWI. If you have any questions or concerns regarding this program, please contact Patty Hill at 564-4346 (work) or 248- 6262 (home) or 350-0742 (cell), or Andy Parker at 564-5766 (work) or 694-2990 (home) or 440-8006 (cell) '. -. .~ TREE = 7"xf1' CARBON 5M COOÆR WELLI-EAD= 13"x13" 5M FMC ACruATOR= KB. ELBI = BF. ELBI = KOP= Max Angle = Datum I\,{) = DatumlVD= 51.7' 1300' 55 @ 8279' 12746' 8800' SS Minimum 10 = 4.562 @ 2091' 5-1/2" PARKER SWS NIPPLE I 5-1/2"lBG, 17#, NT-80,O.02325bpf, ID=4.8g' H 6388' ~ I TOPOF5-1/Z'LI'RH 639T ~ I 9-5/8" CSG, 47#, L-80,ID = 8.681" H 6533' ~ ÆRFORA TON SUM\1ARY REF LOG: SWS CDR'GR ON 07/14195 ANGLE AT TOP PERF: 49 @ 12896' Note: Refer to Production DB for historical perf data SIZE SFf INTERVAL Opn/Sqz DATE 3-318" 6 12896-12921 0 08/01/95 3-318" 6 13070-13120 0 08/01/95 I PBTD H 13230' 1 I 5-112"LNR,17#,NT-80,O.02325bpf,ID=4.8g' H 13326' 1 P2-34 ~ ~ SAFETY NOTE Tx IA COMMJNCA1l0N, 9-12-98, AOGOC SUf\DRY 9-23-98. MONO BORE WELL. I 2091' H 5-1/2"PARKERSWSNIP,ID=4.562" 1 GAS UFT MANDRELS ----ISTI MDllVDIDBlI TYPE IVLVILATCHIPORTI DAlE I L 11 6322 4911 51 5.5" x 1.5"LB RA ... / 6388' H ~ 6383' H 1 6403' H ~ 6418' H II. BAKERLl\RllEBACKS66.LASSY I 9-518" BAKER LI\R TOP ZXP PKR 1 BAKERPBR I 7" X5-1/Z' XCi 1 12820' H 5-112" PARKERSWS I\IP,ID=4.562" 1 ~ i~~ DATE REV BY COMIVENTS DATE RBI BY COM\1ENTS 07/20/95 ORIGINAL COWLEIlON 09/16/00 Sl5olsl 5-112" PX PLUG Pl1.LED 10/02/00 Sl5olsl CONVERTED TO CANVAS 02/21/01 SIS-MD ANAL 09/18/01 RNlTP CORREcrlONS POINT MON1YRE Uf\IT Wa.L: P2-34 ÆRMIT: 95-068 API No: 500292255800 SEC14 T12N R14E 13 363.61 Fa. 211.44 FNL BP Exploration (Alaska) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: P2-34 (PTD 1950660) Application for Sundry Cancellation Dear Mr. Maunder: Attached is the Application for Sundry Cancellation form 10-404 for well P2-34. This request is for approval to cancel the existing Sundry and continue injecting. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Engineer Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ ~lugging_ Perforate_ CANCEL 10-403 Pull tubing _ Alter casing _ Repair well_ Other_X CANCEL t0,403 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5270' FNL, 3914' FEL, Sec. 11, T12N, R14E, UM 5. Type of Well: Development _ Exploratory_ Stratigraphic__ Service_X (asp's 681601, 5998340) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Point Mclntyre 8. Well number P2-34 At top of productive interval 193' FNL, 693' FEL, Sec. 13, T12N, R14E, UM At effective depth 209' FNL, 438' FEL, Sec. 13, T12N, R14E, UM At total depth 214' FNL, 365' FEL, Sec. 13, T12N, R14E, UM ~sp~ 690104, 599860~ (asp's 690360,5998594) (asp~ 690433, 599859~ 9. Permit number / approval number 195-066 / 398-243 10. APl number 50-029-22558-00 11. Field / Pool Point Mclntyre 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 6494' Liner 6943' 13326 feet Plugs (measured) 9232 feet 13230 feet Junk (measured) 9169 feet Size Cemented 20" 250 sx ArcticSet (Aprox) 3262 c.f. PF 'E', 432 c.f. 9-5/8" Class 'G' 508 sx Econolite, 239 sx 5-1/2" Class 'G' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 12896'-12921', 13070'-13120' true vertical Open Perfs 8952'-8968', 9065'-9098' 5-1/2" 17# NT-80 TBG @ 6388'. Baker LNR Tieback Seal ASSY @ 6388'. 5-1/2" Parker SWS Nipple @ 2091' MD. Measured Depth True Vertical Depth 121' 121' 6535' 5044' 6383' - 13326' 4949' - 9232' . 9-5/8" Baker LNR TOP ZXP PKR @ 6383'. 1'3. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/17/2002 Subsequent to operation 02/16/2003 Representat ve Da y Avera.qe Product on or In ection Data OiI-Bbl Gas-Mcf Water-Bbl SHUT-IN 8629 Casing Pressure Tubing Pressure 1171 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil m Gas __ Suspended __ Service WATER INJECTOR 17t~reb~ foregoing is true and correct to the best of my knowledge. Title: Well Integrity Engineer ~/yetl Integrity Engineer SCANNED MAR ~ ? Z003 Form 10-404 Rev 06/15/88 · Questions? Call Well Integrity Engineer 659-5102 Date Prepared by DeWa~/ne R. Schnorr 564-.5174 ~viAR T SUBMIT IN DUPLICATE P2-34 Sundry Cancellation Request 03/04/03 PTD# 1950660 Sundry# 398-243 dated 09/23/98 This is a request to cancel the AOGCC Sundry dated 09/23/98. The Sundry was issued to allow continued injection with slow T x IA communication. This well exhibits no evidence ofT x IA communication. Upon cancellation, the well will return to normal water injection status with standard operating presstire limits on the IA. The MIT-IA schedule will return to the standard test frequency and the well will no longer be included in the monthly AOGCC injector report. Well P2-34 is a mono-bore completion. No OA is present, which is why the TIO plot indicates the IA and OA pressures are the same. MITIA test frequency for mono-bore completions is every 2 years. Reason for cancellation: There is no evidence of T x IA communication noted in the TIO plots. > 08/31/00: MITT to 2500 psi Passed / MITIA to 2000 psi Passed. > 01/17/02: MITIA to 2000 psi Passed. > 10/24/02: MITIA to 2000 psi Passed. TREE = 7',x6" CARBON 5M COOPER~.. ,.=~ ,~.-- SAFETY NOTE Tx IA COMMUNICATION, WELLI-EAD =. 13"x13" 5M FMC ~,~ .,.r~. 9-12-98, AOGCC SUNDRY 9-23-98. MONO ACTUATOR =~.. ~.~"I" BORE WELL. KB. ELEV = 51.7' BF: EL~ -- KOP= 1300' Max Angle = 55 @ 8279' Datum rvD = 12746' I ~ ~ 5'1/2" PA R~I~ SWS NIP' ID = 4'562" I Dat® TVD = 8800' SS Minimum ID = 4.562@ 2091' , 5-1/2" PARKER SWS NIPPLE GAS LIFT MANDRELS I. I1 m22 49111~15.5"x1.S"L~I 5-1/2" 1BG, 17#, Nr-80,0.02325 bpf, ID=4.80" ~ I ; 5-1/2" PARKERSWS D=..592" I PERFORATION S UI~IVIARY RI~: LOG: SWS CDR/GR ON 07/14/95 ANGLE AT TOP PEI~:: 49 @ 12896' Note: Refer to Production DB for historical perf data ri SIZE SPF INTERVAL Opn/Sqz DATE II 3-3/8" 6 12896-12921 O 08/01/95 , 3-3/8" 6 13070-13120 O 08/01/95 ~ DATE ~ BY COMkfENTS DATE REV' BY CObIME~ITS POINT MONTY RE UNIT 07/20/95 ORIGINAL COk, I~LErlON WELL: P2-34 09/16/00 SIS-Isl 5-1/2" PX PLUG PULLED PERMIT: 95-066 10/02/00 SIS-Isl CONVERTED TO CANVAS APl No: 500292255800 02/21/01 SIS-MD RNAL SEC14T12N R14E 13 363.61 FEL 211.44 FNL 09/18/01 RN/TP CORRECTIONS~.~,~,.~.,p. ,la, l~='i-~, i~.~"~ · ~ .~nn~ ~P Exploration (Alaska) ,, ......... ....... ) ) ) ARca Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~ ~~ October 2, 1999 ¿ /O(o(¿, \C\!J Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: 03-11 Monthly Pressure Data, Per State Sundry Approval #399-084 ~C\-i.J~,\'./ 11-29 Monthly Pressure Data, Per State Sundry Approval #398-035 ~·~-C$ ~ ~/''''' 13-15 Monthly Pressure Data, Per State Sundry Approval #399-091 ~"). -\:)\S~./ 13-17 Monthly Pressure Data, Per State Sundry Approval #298-275 '$.5:;) - ()c")..~./ 13-20 Monthly Pressure Data, Per State Sundry Approval #397-078 ~~ -<J~~~\v'" P1-01 Monthly Pressure Data, Per State Sundry Approval #398-188 ~S-(:)~~<'~l P2-34 Monthly Pressure Data, Per State Sundry Approval #398-243~(} -~QJ. ~ .? Dear Mr. Wondzell: Attached please find daily injection reports on Wells 03-11, 11-29, 13-15, 13-17,13-20, P1-01 and P2-34 for the month of September 1999. This report is submitted to comply with the State Sundry Approvals listed above. Also attached are MITIA reports conducted on injectors. If you require any additional information, please contact Jerry Dethlefs or me at (907) 659-5102. Sincerely, (Q{~ J Joe Anders Problem Well Specialist -SCANNE[;) J AN 1 1 2006 \7 ,_ ...... _' ',:> 1(:".... , \ - ",' t> \ ....);j~Q. ~ -\-~ (.)..,\Q. ~-')\-Q~c.\t '" _ <-~~ ~\~~'S.'~,,~~ ~~ ''-CJ..~ ~'t D\?~S~~~ .>.. r' ~L \. _ \o..\-~ ~ ~~s.""::;'~'\Ï:.. ~ c..'Ç£,. \ '<'-..""\~(-.....c:.....(..cj '')'/ <:>..c.:"" ~\'':> <::>" <:>;, "'-"-- -- '-N Cc \" '" <... s, L !-N.<i- \\. -"'::'0 \" "--: \ _ _ _ , .' \.-.. ~ l _. - ~s~c..,\ c\. \...), C ,<¿ ~a"\--';;' G...~ ""'~o,,,·~o~ ~ '"'"~~ \">-\ 'f'-~",\;. _ Q . '.:.. '\ 0\.:;1..'\<¿':;- '\. ~ ~\.:.~((_ W\ \-~ .i.-~c;.. d 1f'.-0 """'t)~\:.-\'" o.-Ç c..., c..y\.À..",\G.. ç- T'J C() ~'^-~<:"\\R ,¡. ,...)r\ù....-~ Ç> ,«:,_c::. ~'-)-~ \J...,l o..'II'''''~\ \...) ~ ~,~ <::. ~u \€.. L Ç.. ~~o;¿ ~ '\ ~ ,s-oa ~\ O\" \C!. ~'S. ~~'i \!\.'0~-~\\~~~" , . . . - O~"-,c. ~,,,,> <:0-<'- 'S<c- \- 0.\0'''''''. QIf'.. '- ,,'ð, :n~ 0:' \ v..\" \. \. ~~ '" ";. <0 ,Ié"" ~ ~,«-.." '\ ç \-~ '(' ~<::I.. " \- \-0 ¢-.J\ (:) 'II<\. \--0 ~ ~C) t- c<.. c..\a ~~ \ '-l . / , , ~ ) ') \~S-oCo0 ~n~obo~ ARCO Well P2-34 September 1999 Injection Data ,'/r Date of Injection Volume Injected Tubing Pressure ~'- Surface Casing (BWPD) (psi) ~ure (psi) 9/1/99 18,024 1,526 1,~ 9/2/99 18,166 1,530 1,600 9/3/99 18,302 1,530 1,600 9/4/99 18,243 1,531 1,600 9/5/99 18,103 1,534 1,650 9/6/99 17,901 1,533 1,600 9/7/99 17,841 1,531 1,600 9/8/99 17,7 48 1,526 1,600 9/9/99 17,745 1,523 1,580 9/10/99 17,606 1,520 1,580 9/11/99 4,647 800 1,580 9/12/99 4,395 673 1,580 9/13/99 18,533 1,518 1,580 9/14/99 18,373 1,546 1,580 9/15/99 18,272 1,548 1,580 9/16/99 18,236 1,553 1,600 9/17/99 18,070 1,558 1,600 9/18/99 18,030 1,553 1,600 9/19/99 17,980 1,541 1,600 9/20/99 17,275 1,517 1,600 9/21/99 17,647 1,544 1,600 9/22/99 17,533 1,543 1,600 9/23/99 16,404 1,514 1,600 9/24/99 16,206 1,511 1,600 9/25/99 5,251 881 1,600 9/26/99 8,940 1,022 1,600 9/27/99 15,715 1 ,454 1,600 9/28/99 14,578 1,418 1,600 9/29/99 14,529 1 ,427 1,600 9/30/99 14,357 1 ,422 1,600 Joe Anders/Jerry Dethlefs Problem Well Specialists ARGO Alaska, Inc. ARCO Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 May 3, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of April 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Joe Anders at (907) 659-5102. Sincerely, Anders Problem Well Specialist SCANNED DEC t ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 February 4, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P 1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages RECEIVED Oil & 6as Cons. Commission Anchorage ARCO Well P2-34 January 1999 Injection Data Date of Injection Volume Injected (BWPD) Tubing Pressure (psi) Surface Casing Pressure (psi) 1/1/99 13,224 1,330 1 350 1/2/99 13,240 1,337 1360 1/3/99 13,216 1,341 1360 1/4/99 13,163 1,342 1360 1/5/99 13,130 1,340 1,360 1/6/99 13,098 1,340 1 360 1/7/99 13,083 1,340 1,420 1/8/99 13,612 1,361 1,410 1/9/99 13,556 1,363 1,410 1/10/99 1,417 588 600 1/11/99 1,635 544 600 1/12/99 1,613 545 600 1/13/99 1/14/99 1 855 3,999 547 570 600 600 1/15/99 3,506 640 600 1/16/99 15,241 1,352 600 1/17/99 16,900 1 453 600 1/18/99 17,421 1 484 600 1/19/99 17,344 1 486 600 1/20/99 17,329 1 489 600 1/21/99 17,259 1489 600 1/22/99 17,236 1490 600 1/23/99 17,196 1495 600 1/24/99 17,208 I499 600 1/25/99 17,205 1,501 1,560 1/26/99 17,212 1 498 1,560 1/27/99 17,209 1 492 1,560 1/28/99 17,183 1,494 1,560 1/29/99 17,170 1 496 1,560 1/30/99 17,124 1 496 1,560 1/31/99 17,122 1 495 1,560 SCANNED DEC i 2002 Jerry Dethlefs Problem Well Specialist ARCO Alaska, Inc. ARCO Well P2-34 Feburary 1999 Injection Data Date of Injection Volume Injected (BWPD) Tubing Pressure (psi) Surface Casing Pressure (psi) 2/1/99 17,091 1,495 1 560 2/2/99 17,068 1,496 1 560 2/3/99 17,045 1,497 1 550 2/4/99 17,047 1,500 1 550 2/5/99 17,017 1,501 1,550 2/6/99 17,010 1,504 1,550 2/7/99 17,014 1,504 1 550 2/8/99 17,015 1,503 1,550 2/9/99 17,004 1,504 1 550 2/10/99 16,970 I 504 1 550 2/11/99 16,853 1 508 1,550 2/12/99 16,090 1,518 1,550 2/13/99 16,423 1 521 1 550 2/14/99 16,606 1 523 1 550 2/15/99 16,569 1 524 1 550 2/16/99 16,586 1 524 1 550 2/17/99 16,576 1 526 1,560 2/18/99 16,588 1 528 1,550 2/19/99 16,406 1,521 1,550 2/20/99 13,724 1349 1,550 2/21/99 17,391 1536 1 550 2/22/99 17,337 1539 1,550 2/23/99 17,088 1,531 1,550 2/24/99 17,135 1 536 1 550 2/25/99 17,120 1,537 1,550 2/26/99 17,057 1 535 1,550 2/27/99 17,009 1 535 1 520 1 538 1,520 2/28/99 17,034 SCANNED BEC i ¢ 2002 Jerry Dethlefs Problem Well Specialist ARCO Alaska, Inc. ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 March 3, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry ApproVal #397-078 P 1-01 Monthly Pressure Data / Per State Sundry ApprovaI #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages SCANNED BEC 1 9 200?_ ARCO Well P2-34 April 1999 Injection Data Volume Injected Tubing Pressure 9-5~8" Pressure Date of Injection (BWPD) (psi) (psi) 4/1/99 14,495 1,420 1,825 4/2/99 14,478 1,419 1,540 4/3/99 14,491 1,422 1,540 4/4/99 13,888 1,425 1,540 4/5/99 14,478 1,426 1,540 4/6/99 14,473 1,425 1,540 4/7/99 14,467 1,425 1,540 4/8/99 14,468 1,426 1,540 4/9/99 1,4,451 1,428 1,540 4/10/99 14,463 1,429 1,540 4/11/99 14,434 1,430 1,540 4/12/99 14,427 1,430 1,540 4/13/99 14,417 1,427 1,540 4/14/99 14,424 1,427 1,520 4/15/99 14,434 1,429 1,520 4/16/99 14,397 1,429 1,520 4/17/99 14,370 1,425 1,520 4/18/99 14,205 1,423 1,520 4/19/99 12,737 1,333 1,520 4/20/99 14,648 1,437 1,520 4/21/99 14,601 1,439 1,520 4/22/99 14,583 1,440 1,520 4/23/99 14,589 1,438 1,520 4/24/99 14,548 1,434 1,520 4/25/99 14,596 1,432 1,520 4/26/99 14,589 1,431 1,520 4/27/99 14,588 1,429 1,520 4/28/99 14,600 1,429 1,520 4/29/99 14,616 1,429 1,520 4/30/99 14,630 1,430 1,520 Joe Anders/Jerry Dethlefs Problem Well Specialists ARCO Alaska, Inc. Re: ARCO Well P2-34 Subject: Re: ARCO Well P2-34 Date: Mon, 13 Sep 1999 08:17:06 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 ~mail.aai.arco.com> Jerry, Thanks for doing the MIT. Yes, it does exhibit a minor leak that is within tolerance. We'll keep a closer watch on it. Regards, Blair Wondzell PRB Problem Wells wrote: Blair: As per our conversation yesterday (9/9/99), I had the DHD crew perform an MIT on the annulus of P2-34. This is the monobore completion at Pt. McIntyre. The MIT passed to 2500 psi, losing 20 psi in 15 minutes, and 20 more the next 15 minutes, for 40 psi total in 30 minutes. The well continues to exhibit signs of a minor leak, as reported in the Sundry Notice 398-243. The minor communication appears to be influenced by tubing pressure to some degree, but still is operating as reported in the Sundry. I will send the test form via mail. Let me know if you want additional data on this well. Jerry De thl efs ARCO Probl em Well s 1 ofl 9/13/99 8:19 AM ARCO Alaska Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 September 11, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: P2-34 Sundry Notice Dear Mr. Wondzell~ '~ O~~ hed is the Sundry Notice 10-403 for well P2-34 you requested as per our conversation September 9, 1998. Please include me on the distribution list of the signed Sundry at: AnARCO Alaska, Inc. Attention: Jerry Dethlefs PRB-24 PO Box 100360 chorage, AK 99510-0360___.~ If you require additional information or clarification, please feel free to contact either Steve Schudel or myself at (907) 659-5102. Sincerely, Je~ Dethlefs ~ Problem Well Specialist STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance X Perforate Other Name of Operator ARCO Alaska, Inc Address P.O. Box 100360 Anchorage Ak 99510-0360 Location of well at surface " 245' SNL, 1359' EWL, SEC. 14, T12N, R14E At top of productive interval 93' SNL, 693' WEL, SEC. 13, T12N, R14E At total depth 209' SNL, 366' WEL, SEC. 13, T12N, R14E Type of Well Development Exploratory Stratigraphic Service X 6. Datum of Elevation (DF OR KB) RKBE = 52.2' 7. Unit or Property Greater Point Mclntyre Area 8. Well number P2-34 9. Permit number 95-66 10. APl number 50-029-22558 11. Field/Pool Pt. Mclntyre 1 12. Present well condition Summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Surface 6535' 9-5~8" Production/Liner 6943' 5 112" 13326' feet Plugs (measured) 9232' feet 13230' feet 9169' feet Junk (measured) Cemented 250 SX Arcticset 3262 cuft PF "E"/432 cuft "G" 508 SX Econolite/239 sx "G" Measured depth 80' 6535' 13326' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12896-12921' 13070-12120' 8900-8916' 9014-9046' 5 1/2", NT-80, 6388' ORIGINAL Packer: Baker Liner Top 2XP, 9-5~8" x 5-1/2", 6383' SSSV: Parker SWS Nipple, 2090' X True veritical Depth 80' 9232' gECE -. I 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation Upon Approval of Sundry 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: OII Service Injector Gas Suspended 17. I hereby certify that .the foregoing is true and correct to the best of my knowledge. Signed ~--~---~-~ C_ ~'~~ Title Problem Well Specialist Date ?,~¢~/~ ~" FOR COMMISSION USE ONLY Condition of approval: Notify Commission so representative may witneSSplug integrity__ BOP test__Location clearance__ IAppr°val N°' ~_~ ~"~) ~- ,--~ -~_~ anical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Original Signed By Commissioner SUBMI~ IN T~PLICATE Form 10-403 Rev06/15/88 J. Dethlefs/S. Schudel - 659-5102 - PRB 24 David W. Johnston Approved Copy F~etu~'ned DS P2-34 SUNDRY NOTICE APPLICATION 09-10-98 ATTACHMENT DISCUSSION Well P2-34 is a Seawater injection well that has a slow leak from the tubing to the annulus. The annulus pressure approaches equalization with tubing injection pressure over time (approximately 3 days after bleeding). The well is a mono- bore completion with 9-5/8" production casing and a 5-1/2" liner over the producing interval and 5-1/2" tubing. The well is subject to State required MIT's on the tubing every 2 years, and is currently on monthly reporting of daily tubing and OA pressures and injection volumes. Pertinent information: · Passed a State Witnessed MIT on the tubing @ 2500 psi on 08/23/98. · Passed wellhead packofftest; no pressure leaks detected. · Passed MITOA @ 2500 psi on 09/07/98. ACTION PLAN Allow well to remain on water injection service with the following restrictions: A. The well must pass the tubing MIT every two years to 2500 psi; B. Limit the operating pressure of the annulus to no greater than 2500 psi. 6/2/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11O63 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Greater Point Mclntyre Area [Lisburne, L6-26, Pt. Mclntyre, and West Niakuk (NK-27/NK-28)] LIS Well Job # Log Description Date BL RF Sepia Tape P2-34 ~ -'/'7(~-7 97209 CDR/CDN 950714 1 P2-34 97209 CDR 950714 I 1 P2-34 97209 CDRTVD 950714 1 1 P2-34 97209 CDN 950714 1 1 P2-34 97209 CDNTVD 950714 1 I SIGNED' Please sign and return one qopy of this transmittal to Sherrie at the above address. Thank you. DATE: AOGCC ]tnd'iv'idua'l We'l J Geo'log-ica'l h'iater'~als Inven't:or'y ~-.-' E R N I T D A T.,,~,, T D ,'-.,,. T,~ ....... P 1... I t S 95--066 (3BT/,:3R ~ 300- 131i0 i 0 9/'0 2/' 9 5 9B~086 USIT r'nRROSION ~.~ 6300~.-13ia. 5 I (')9/'02/95 i 0 .... ~t07 R ,"P, kiPLETION DATE Ar"e We'1 i t he '"~ Ana'i :!s'i " descr'"ipt'ion r"ece'i',~:~d ? w e I 'i c o r" e d ? y e s .~,._ y s ,:~: ...... ('.: C) k1 I','I E N T S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAs [] SUSPEND~ [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-66 3. Address 9. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 50-029-22558 4. Location of well at surface ,: .~?..:...; :> ..... 9. Unit or Lease Name 245' SNL, 1359' EWL, SEC. 14, T12N, R14E i' rj lO. Well Number ~t Total Dopth $. Elovation in ~oot {indl~t~ KB, DF, otc.) ~. [oaso Dosi~nation and Serial ~o. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~15. Water Depth, if offshore 116. No. of Completions 6/30/95 7/14/95 8/1/95 N/A feet MSL ~ One ~. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickness of Permafrost 13326' MD/9232' ~D 13230' MD/9169' ~D ~ ~ ~ D~ 2090 feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run G~RES/NEU/DEN 23. CASING, UNER ~D CEME~ S~NG D~ MD CASING SIZE ~. PER ~. G~ T~ ~ ~ ~ C~~ RE,RD ~U~ PULED 20" 94~ H-40 Surface 80' 30" 250 sx Arcticset (Approx.) 9-5/8" 4 7~ NT-80S 41' 6535' 12-1/4" 3262 cu fi PF "E"/432 cu fl 'G" 5-1/2" 17~ NT-80S 6383' 13326' 8-1/2" 508 sx Econofite/239 sx "G" 2~. Pedorations open to Production (MD+~D of Top and Bottom and 25. ~BING RE. RD inte~al, size and number) SIZE DE~ S~(MD) PACKER S~ (MD) Gun Diameter 3-3/8" 6 spf 5-1/2", NT-80 6388' 6322' MD ~D (Su~) 12896~ 12921' 8900 ~8916' 13070~ 13120' 9014~9046' 26. ACID, F~CTURE, CEME~ SQUE~, ~C. DEPTH INTERVAL (MD) AMOU~ & KIND OF MATERIAL USED Freeze protected w/290 bbls diesel 27. PRODU~ Date First Production Method of Operation (Flowing, gas lift, etc.) 8/3/95 Flowing Date of Test Hours Tested ~P~~PERIOD ~ OIL-BBL GAS-MCF WATER-BBL C~S~ GAS-OIL RATIO Flow Tubing Casing Pressure C~CU~D~ OlL-BBL GAS-MCF WATER-BBL DIL GRAVIS-APl (corr) Press. 24-HOUR RATE ~ 28. ~RE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ORIGINAL Anchorag~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Kalubik 12860' 8876' Kuparuk River 12894' 8898' 31. LIST OF A-I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~~ ('/~ '~ _ Title ~r. Drillin(7 Enoineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: P2-34 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 06/30/95 06:00 SPUD: RELEASE: 07/20/95 04:00 OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 07/01/95 ( 1) TD: 1744'( 0) 07/02/95 (2) TD: 4388' (2644) 07/03/95 (3) TD: 6500' (2112) 07/04/95 ( 4) TD: 6550'( 50) 07/05/95 (5) TD: 6550' ( 0) 07/06/95 (6) TD: 7940' (1390) 07/07/95 ( 7) TD: 7971' ( 31) DRILLING MW: 0.0 VIS: 0 DRILL F/80 T/1744. DRILLING MW: 0.0 VIS: 0 DRILL T/3724. CBU. POOH T/210 PULLED BHA ASSY & PU STABILIZER. MU BHA 92 & RIH T/3724, DRILL T/4388. DRILLED MW: 0.0 VIS: 0 DRILLED T/5333. CBU. TRQ ARRESTER ON THE TOP DRIVE FAILED. OBTAINED 150% HOLE VOL. POOH T/210. REPAIRED EQUIPMENT. MU BHA #2. RIH T/5333. DRILLED T/6500. CEMENT THE CASING MW: 0.0 VIS: 0 DRILL T/65F50. CBU. OBTAINED 100% ANNUL. VOL. POOH T/4650. CBU. OBTAINED 200% HOLE VOL. POOH T/210. LD BHA. RUN 9-5/8" CASG T/6534. CBU & CEMENT THE CASING. REPAIR BRAKES MW: 0.0 VIS: 0 FINISH CEMT'G CASG. BUMP PLUG W/2000#. CIRC OUT 50 BBLS CMT. TOP JOB PUMP 32 BBLS CMT. ND DIVERTER. NU BOP STACK. TEST WELL CONTROL EQUIP. RAMS, LINES & VALVES T/5000. HYDRILL T/2500. REPAIRED MECHANICAL BRAKES. DRILLING MW: 0.0 VIS: 0 MU BHA #3 & RIH. CBU @6444. OBTAINED 100% HOLE VOL. TEST CASG T/3000#. DRILLED CMT T/6560. CBU. 100% HOLE VOL. RAN LOT @ 14.2 EMW. DRILLED T/7940. POOH T/5550 MW: 0.0 VIS: 0 DRILL T/7971. CBU. OBTAINED 100% ANNUL. VOL. POOH T/802. 2 CONES WERE GONE OFF THE BIT. MU BHA #5 & RIH T/6500. CUT DL @9-5/8" CASG SHOE. RIH T/7921. RUN GYRO. FISHED @7971 & POOH T/ 5550. WELL : P2-34 OPERATION: RIG : POOL 7 PAGE: 2 07/08/95 ( 8) TD: 9005' (1034) 07/09/95 (9) TD: 9620' ( 615) 07/10/95 (10) TD:ll310' (1690) 07/11/95 (11) TD:12340' (1030) 07/12/95 (12) TD:12725'( 385) 07/13/95 (13) TD:12905' ( 180) 07/14/95 (14) TD:13240'( 335) 07/15/95 (15) TD:13326' ( 86) 07/16/95 (16) TD:13326' ( 0) PULLED BHA MW: 0.0 VIS: 0 POOH T/474. PULLED BHA. MU BHA #6. RIH T/7873. WASH T/7973. DRILL T/9005. CBU. OBTAINED 100% ANNUL. VOL. POOH T/595. DRILL MW: 0.0 VIS: 0 MU BHA 37 & RIH T/6500. TAKE BENCHMARK SURVEY @7475. DRILL T/9620. DRILLING MW: 0.0 VIS: 0 DRILL T/10098. CBU. OBTAINED 100% ANNUL. VOL. PULL DP T/8970. HOLE OK. DRILL T/l1310. DOWNLOAD MWD MW: 0.0 VIS: 0 DRILL T/11343. CIRC WHILE RESETTING THE MWD. DRILL T/11613. CBU. 100% ANNUL VOL. DRILL T/12340. BIT QUIT. CBU. 100% ANNUL. VOL. PU T/ll0. DOWNLOAD MWD TOOL. DRILLING MW: 0.0 VIS: 0 DOWNLOAD THE MWD. TEST WELL CONTROL EQUIP. MU BHA #7. TEST. OK. RIH T/6500. FILL PIPE. SERVICE THE TOP DRIVE. RIH T/7475. TAKE A BENCHMARK SURVEY. RIH T/12340. DRILL T/ 12725. RIH T/5000 MW: 0.0 VIS: 0 DRILLED T/12905. CBU. POOH T/9153. MAD PASS F/9153 T/6534. POOH T/212. PULL BHA. TEST WELL CONTROL EQUIP. T/5000. MU BHA #8 TEST MWD & RIH T/5000. DRILLING MW: 0.0 VIS: 0 RIH TO 12905'. BENCHMARK SURVEY @ 7463' REAM LAST 2 STANDS TO BTM. DRILLED TO 13240' PULLED BHA MW: 0.0 VIS: 0 DRILLED T/13326.CBU. 100% ANNULUS VOL. OBTAINED. POOH T/11428. RIH T/13326. CBU. OBTAINED CLEAN RETURNS @200% HOLE VOL. POOH T/212'. DOWNLOAD MWD. LD BIT. PULL DP T/6000 MW: 0.0 VIS: 0 RU & RUN 5.5" CASG T/13326. PUMP 293 LEAD & 49 BBLS TAIL. DISPLACE 263 BBLS SLURRY. BUMPED PLUG W/4000PSI. REVERSE CIRC @ 6383. OBTAINED 110% HOLE VOL. PULLED DP T/6000. WELL : P2-34 OPERATION: RIG : POOL 7 PAGE: 3 07/17/95 (17) TD:13326 PB: 9233 07/18/95 (18) TD:13230' ( 07/19/95 (19) TD:13230' ( 07/20/95 (20) TD:13230' ( 07/21/95 (21) TD:13230 PB: 9230 o) o) o) RIH T/7700 MW: 0.0 PULL DP T/SURF. WORK ON TOP DRIVE. CHANGE OUT BRUSHES. SERVICE BLOCK LINE. MU BHA #9. 4-1/8" BIT. SINGLE IN DP T/6877. MU X/O & 9-5/8" SCRAPER & RIH T/7700. L/D SCRAPER MW: 0.0 VIS: 0 RIH TO 13172'. CIRCULATED. BROKE CIRCULATION. DRILLED CEMENT TO 13230' SCRAPER @ 6379' TAGGED LANDING COLLAR , CIRCULATED @ 13230'. CIRC OUT CE~NT. OBTAINED BOTTOMS UP. TESTED CASING AND LINER TOP PACKER. CIRCUALTED @ 13230'. HOLE DISPLACED WITH SEAWATER. REVERSE CIRCULATED. POH TO 6378'. LAID DOWN DRILL PIPE TO 5800'. L/D SCRAPER, X/O'S AND 2 7/8" DP. POH TO 1000' MW: 0.0 VIS: 0 LAID DOWN DRILL PIPE TO 600'. PULLED BHA. MADE UP BHA # 10. BAKER POLISH MILL ASSY. REMOVED WEAR BUSHING. RIGGED UP TOP RAM. CHANGE RAM TO 5". TESTED ALL RAMS. RIH TO 6387' WASHED TO 6387'. BREAK CIRC AND POLISH LINER TIE BACK SLEEVE. TAGGED UP LINER TOP. CIRCULATED. MIX AND PUMP HIGH VIS SWEEP. SEA WATER DIRTY. CIRC AND CLEAN PITS. REVERSE CIRCULATED @ 6387'. POH TO 1000'. WIRELINE WORK MW: 0.0 VIS: 0 POH TO 800' PULLED BHA. L/D POLISH MILL ASSY. RIGGED UP TUBING HANDLING EQUIPMENT. RAN 152 JOINTS 5 1/2" 17# NSCC TUBING. L/D LANDING JT. SET 2 WAY CHECK IN HANGER. RIGGED DOWN ALL RAMS. INSTALLED XMAS TREE. TEST. PULL 2 WAY CHECK. TESTED TUBING. TESTED CASING. BLEED PRESSURE OFF BOTH SIDES. REPRESSURE ANNULUS.. SHEAR RP VALVE. FREEZE PRTECT WELL. SIDE POCKET VALVE FAILED. CHANGE OPERATION. SURGED BACK TUBING AND REPRESSURE SAME TWICE, WITH NO RESULTS IN REMOVING OBSTRUCTION. CALLED OUT WIRE LINE UNIT. RIG RELEASED MW: 0.0 RU SLICKLINE UNIT & LUB. RIH T/FISH RP SHEAR VALVE. RECOVERED & RD WL MAST. FREEZE PROTECT W/290 BBLS OF DIESEL. INSTALL HANGER PLUG. RELEASE THE RIG @16:00 HRS ON 7/20/95. SIGNATURE: (drilling superintendent) DATE: P2-34 MD TVD INC'-'- 100,0 !00,¢0 0,44 204,.0 200,00 -0,16 .... 0 3nn,00 400,0 3??,?? 0,55 0,00 ~" '.,,w 0,00 0~00 0,00 O,/''* 0,44 .... .-,.~ ~/,,:,':. ,.':,7 ..... 67,26 0, ,_=. ~'~-0,16. 83,.56 150,82 83,5.6 ,.-,-... , -~. a. ~, {-%--':.''.ll~../ . 0,79 ;'~,5s .... 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'_.- f- ~ .~. ~27;:,:?.- -5i02,20 '.'.:',0~- ::-'.,~o,,.:... i~4,7.-% -~ ,19 84-54,5 62i0+'..;17-!,i4 =4 -'-:- 0 77 _~ o~ ~,,:, '?~ """' 55.--.:.=` 0,87' 0,79 99,i7 ,'3,83 ..... ,..,.. O0 _. r.- 0 .40 ::::-: :._-:-., .... , i,,14 ~-., :, -i ,70 '-' .... ~ ' .AA 86,83 - i, 82 : ~, i-_': - i, ~-~ -i~.. 52,'.;51 -i,20 ,.':, ,'.-,~.. . _ -87 ,.,-' :"" 1,,01 "'~: ~ "~--' -4'2,3,:-3 38,ii i,lO (:,,2,5 '" ~ 07 5.": ' '" .... -38,92 !31,84 1~'98 0,64 -42,131 a,_,O,~./ i~ _ -~ .'- . 5!,o? -!,37 -i,5! 86,28 ..... .~ -U,~O ~.-..,~u ...... -'~ '* !,73 87,81 51-07 -v,/~ ~"'7 -I , !6 86,65 50,59 -i:5'? ! -! 0,82 -31,97 137,87 -27, :;u o.:., 7=, -22,56 o4,A4, .... -20,15 I~0,47 -2J'~Ou _ ,.. iJ u / ,.,~ ! --- ,_,j.2_'..:;._- , . c.,r:=..-..,,,.? .-5.581,07 -0 ; -~.a: . , . '.-;'152,2 ,564!.-35 -0,3! ':";.:,'7 '~ ,-4.7,"':"::.'::A 0,43 / ~.-.: ,%1.-: 9344,6 6764,.72 i~07 50,6i 0,09 -0,39 50,04 -a,60. 0~14 =.-°7, I~=., 0,15 ex./:-: -n.-.--, -r.,56 84,62 -0,-.-, ...... =,Q2: -a .a-..,,._- .--r ,,a . ~r ,%:? ~ ~ .%,% _u :,-~ i,~0 0,8-.4 -'5,80 gA,nn 1,31 ;_ -. vt.. -'9,36 "- "' 0,4! n.72 -8~70 126,4! 0,56 -5,28 61,25 0,93 -i6,60 i28J2 !,30 0,38 .. FEB 15 1996 P2-34 -- -- ft ft de-:-- de-'-_'- ! RA?E AZM CHG CUMA3~ CIE--' deg/lO,:.:q t d.e.~ d. e9 TURN RATE CLOSURE TOOL_FACE DLS ._ deq/!OC~ ft deg deg/!OOft DLSRT deo/'!OOf:~2 7627~ i 67~J,2-6 -0,44 .... 0,=~ -~.~o 87,3i 51,42 -0,47 -0,74 37,24 ~ :.~ -A.~ ~7,94 -0~52 71 ~!7 l,d3 2,23 59,8: 0,66 0,40 . -3,01 32,19 1,06 i,64 89,58 !,69 -.<,zv ~/,94 -0,22 &~ ~_-_- 0,% 9n,~ 1,04 !2~75 92,7! ! .... ~ ~= 15,06 i22J5 0,20 i,12 iA:34 ~di,fl7 n o~ n.7A ....... ~.. ~,2, u*..- 10~"J9 1!o44 i,04 0,i0 10287,0 ~0:~,? 7456, ...... :0670,5 !0765J 7627~16 -0,13 !7,37 98,3.7 r0,69 0.37 i7,66 65,84 0,6.7 0,02 !7,32 25,43 0,40 0,29 i7. :i 07 ~ vo -0,01 ~.~ 2~.4! ~,;~ ~-r~ .... ~.~ 52,!:3 -0,,$? n~.~:." ~,~a ~ r;,44 52,44 -0,27 -0,64 8?,05 -0,67 21,6! 9!,74 0,!7 0,15 ~! ~,_~ ~ ... .,0-4,7-7 s..~.~,..~,:~0,08. 0,30 19,8! 1!3,~.5' 0,57 u,ur" &,., ~,-~ _.~.... '~., 52,44 ~,=.~.~-~'> -~,~o~ -n.::~.., 89,3! -0,5.7 · ~ ~ Qn~ :-: '~'::-i'? 8£: "-- ii'?02:.4 ': .... -, ¢.-~ 120,),')13 83,.-'8,17 -0,32 i2186,2 r,~or-.. ~,i -0,33 '"': '~ 0,17 .:...'..:, i! 37,01 0,~.: ']',O: ?A a/..ql · --. · ~ _.._, ~.. 2?:44 14.:.:..,77 0,38 1,!9 29,~= '~ ,ti,.,: ~-,a, ~,~: v,,,/r' q ...... ,~., :,?, ':"-' '~ i05,88 ':'i,'-.Q~. 5 &: &.;_=- ;.~t 12375,0 8,:'.07:i8 12'-:17!,6 -A.M.'a:,,"4? .... " ....... -L ,.CT 12565,4 8730,53 -i,6'.;' ~9//~ .~ a7,3~ £_C,,T:£ = ff .'; : ...' ~ z~ ~.- :': :-:: -A:52 ~:.'-:'.'-' .~0 aa · J.&, .:'-: .. ~t v~.~ ~: .~ ,.iL.: ,- ,-..-~- 5f:,., -¢'.-,' ..... (:-,14 c.,r:,r;? r, -..~ ..... £i~-Jr.' , ,,. ,~.~.. 4',a,6:;' -!,34 0,43 .0.0,45 0,45 - - e.= .-. r-. 4:..~vv -1,80 -i,,_--: 89,22 -1,3i .~'7 .~r. _A LO r'~ 0,'", '~"0~ fi,Q~ 30,:.0 _,.~ 0,58 0,!7 .... · -"'? i73.77 I /'7 ~'-'/ r:: .... 29,32 !65,78 i~38 0,32 :;'9,93 148 ad A~,)3 1,17 _. . ~%,~, ~ - 12814,0 ~8'~'7,3,5 '"' '':~' ~'"'" ~ :' A'&;.~,~h,~ 0~ 13114,8 90'74J3 0,65 48.07 0,7! i,87 9i,?? '~: ~ 0,81 0,26 92,~ '~'~ ~ fi. SA n ~,-, ~,-, o~ fi,i~ -0,75 9i,g~ 1 0,58 27,73 64,73 1,63 0,74 ..... ~z,42 0,~8 ~-29 23,1! 57,i5 :) ~' A.AA 19,7A 0~ ~ '=~ 49 _. ~. /£ . ~o ~i 132,40 r:.,?r, 0,20 ,-,g.r., ?~fi, 6 ,..,u.,-..¥ ,_,, ~LYSiS CIRCULAR ARC METHO[-~..***~ · ~' , .... _ RmTm ,~nN - ~D ~ !NC CHG CU~Nc CHG i ~ ' A~ CHG CUMA~M_C~ '~ '_RATE CLOSURE TOOL_FACE DL~ DLSRT - - - d~o/lOv,~ ft dea d~,~/lOOft den/~Oft~*9 ~ .. -.. .... ~. ~ ._ _ 13206,8 9i53,97 -0,24 ~,. ~,.. ~ -O,?A_. 2,30 94,64 4,66 i3,82 123,~.~ 0,48 n~, ~,. 11,42 i05,05 3,66 6,43 ,., y..., 87,64 0:06 ~.:.,:...; ..... ':.--"231,,~,0 0,4'-0-~,'~'*~,---'-'~ ..,,.¥n -:,', :',.nc; 94,64 0,00_ A "~ CO~;c'A.%'-:':' SHARED SERViE:ES WELL :.:Y ~E P2-34 ~AC;!:ETiC D:CL i:,.'~ATi[$:.. CF-liD "-"'"~':' '~ DATE: i4-JL!L-95 AP!*.' .. - -' t';:S: HEAD LUCA?lO.~-'. ~,.: :.w-:., .._. TiS iN :'Ol!'::T<TiP) :: i$:-'ASU~..::D iq.-' .:.kiLi! ~ ? A ~.. ~.~: _ .f!Jg~-:: iA,-' -S > O.--O0 O.--O0 0,00 ************* CiRCLP. AR ARC ~* ft fr 0,00 0~0 100,00 i00,0 200,00 100,0 :E,O,(<: 100,~ 300,00 m~:i STATION AZIMUTH .m~l:~: ..... ~, INCLN N/-S ft d~o d~ ft 0,35 0,44 67,2'6 0,i5 O,A~ 0,28 ~'~ ~ 0,08 1,87 0,79 !07,54 -O,Oi DEPARTURE DISPLACEMENT at A~Y~Jin E/-W ft ft deo 0,00 0,00 0100 0,~=,.,. 0,3.q_ A7~26. 0,83 0,83 64,24 I Afl . ,,.,,~ i ~08 1,87 1,87 ?O,3B DLS deo/ lOOft 0,00 0,44 0,4? 0,43 0,74 600,00 i00,0 5?% ?7 600~00 !00,0 79?,66 .~ -r n 0')..4~ O~°° ~.~ n,Tq ~o~Y -0~i5 3,~ 4,72 !,~ 88~55 -0,05 4,?2 4,92 ?0,60 0,5i ,~.~ w, 4,,~,~ 54,28 0.7~,,,, !5,2~. ,~.~z~ "~ 87,04 0,88 i!O0~O0 i200,00 !400,00 100,0 ??6,97 lO0,O i07B136 I00,0 i177+44 lO0,O 1276,06 100,0 13~4, i3 32,04 5,53 87~42 1,66 ~ a~ ~ aA 87,04 %.sn ~ ~ ~4i 0,67 .... ~...~ ~,~ ,~ 56,50 56,50 B'?,33 i.a.4 72,9? !0,52 94~22 -0,44 72~79 72,97 ~0~35 '2~0~ ~2,~ ~ 1i,78 -.~ =: _o i2 9o ,~ 92,45 -.- ¥~,:,.. =, .=,~u i .. i600;00 17(0,00 ! ~".::'..:, 100,0 14~1.43 iO0,O !587,58 !00,0 !6~2,73 iO0,O !777,7i lO0~O !872,42 115 ~ ii~ ~ 142,70 !42,87 ~2,73 2~51 i/z,72 I72,79 "~ ~oz,g2 oo: ,',t 2000,00 £~UU, 2300~00 2400~00 z;..-~/ iO0,O 2i52,~0 100~0 2244,?0 ?0,82 ~,4! oe '~ ~?:- .... !6 zoo', ~, ~? ~i ,zv -!6,75 ?0,86 ~7 :c, '- .... " 0,77 306,39 306,6! ~ ~ .l~ 09.9R ' .7Q 382,i! C8_,-,~ 4ox oo 4P4,55 92,26 2,46 Z:¥_.-'O, 0(:' Z/Ut; ~ 'iL~ 2800, O0 .-..-..~ r. :-. ~. ~vv,v i(~.i~0 2685~17 !00,0 2769,43 566~07 30,0! 90~77 -!6,9! 6!7,26 31,56 88.76 -i6.77 O/i~:o ~.. BB,5? -1~?fi 46?,59 469,67 566,15 566,1!0 9!~71 6i7,32 6!7,55 ?i~56 672~0i 672,17 3000,00 '3100,-"'JO -"..: ..-_: ...-... ¢... ;-.....,-, J.'3('-'(' :. :X:: 3400,0O :£i O/ , 7-2. ,.., i.-,+; v 794,34 40,45 87,0.5 -i0,76 .~..A~ ~ ~..:..'44,02 88,00 -,B,O? ?33,03 47,'''' '~ ~i ,~ -",61 !008, ~,"~... 49,96 67. ,,.~";' '~ -n.'35... 791 "'" ' "~¢' , ..,~ ,26 / ::i ,._,.:, 9i,07 794,38, ,v°4 ,-,, 45 '~0,79 . 861,~'? 86i,56 90,54 ,':"., 'i: f": ~' .... -' 7,.,,.,, ,,_.' ?33,06 ., v.....,, i0 iOOB,'~'.": 90,05 3,17 2,58 3,63 2,70 Q ~. ,'st'l, gi'- 'J700..O0 3?00 !00,0 3200,% ~ ~.~ ..... ivv,O 3P^R~4A i00~0 3325,00 lO0,O 23AA,*~ .~ ~ ,~ .~- ~no~,12 50,84 a~ =~,70 1,32 ii63,!8 5i.81 ?0,45 1,87 ....... J~,22 9!,67 0~37 !399,!1 ':~,i6 ~0,98 -4~00 lnA~,i2 in8~, ........... H...~,~A i,'"' !241,98 1241,78 89,98 1,02 !j~0,84 !320 1399,13 !399,i4 70,i6 !,05 PAG~ NO, 3 · P2-34 *~********* A?+A. DRILL ~**~******** SURVEY "CA£..uL,.~ ..................... ~l~U~t D~'TH DEPTH ft ft ft 4000~C4 I00.0 3511,70 4100,00 ICK~,O 3573.82 4200,04 100,0 3633,4? 4300,00 !¢},0 36?2.05 4400,00 100,0 375!,34 TARGET 5TATIO~ ^?*~ S_~,%ECT!ON INCLN, H/-S f~ de9 deg !476,67 50,64 92,46 -6,32 !554~96 52,~ 9i,65 -9,i2 !635,18 54,~ ~,84 -10,86 !7!6,20 54,i3 86,43 1796,64 53,!5 87,87 -4,92 DEPARt]RE D!§PLAC=~ENT at ft ft _ . _ t4/o,~ - ~47A,70 ~' ?~ 1~3~,23 1635,26 !776,67 i776,68 AZIMUTH deg ?0,25 90 ~ 90,38 90,30 90,i6 DLS deg/ !OOft !,26 2,00 !,78 !.52 4500,00 4700,00 4800,~ 4700,00 inn=~,,O 38tl,67 !00,0 3872~92 !00,0 39~,04 I00.0 ~°°',03~..: iC~,O 40¢S,60 ..... - .... . ,./ -4,Y~ 21!6,73 54.85 9t,68 -7,30 2i98,3! 54,57 9!,7i -?,7! 10¢o.40 90,I0 1 O~ ~ ~" ~ '~ ~_~0.._ =~o,/~ ?0,20 2i78 ~ 2~e~ ~ i,74 0,88 2,62 0,60 0,28 5000~00 5100,0~ 5200,00 5400,Q) i00,0 4i66,18 i00,0 4225,46 i00~0 4284,6! 100,0 4344,~? ........ ~.,.0 -1i,25 2440,~ 53,76 90,62 -ii,62 2279~57 227?,60 ?0~28 1,26 2360~27 2360,30 9^ ? . 24¢3,81 2440,83 90,27 0,62 ~ ,43 c~21,46 90,28 O, 2601,68 260i,71 90,28 1,03 5500,04 5600,00 5800,00 lCK~d) 4404,53 I00,0 4586,06 !00,0 4647,2! 2761,26 53.09 ~0.!2 2940,94 =~ ~ 8~,oa -1!,78 276i~~'~a Z7A!. ,o~"~ 90,25 0,51 2~41_ ,~°.~284i,04 90,24 0,51 297o, 33 2?20,o~"= ~n,. ~ 24 n,. 42' ............. 2?99,47 qn,24 0,42 6200 6300,00 6400,00 ;., _... ; ,1-4 0,-::3 0:?2 6430,00 6460,00 6470~00 6520,00 6550,00 ~0~0 4?78,34 30,0 4997,2i 30,0 50!6.07 30.0 5034,90 34i3,19 :~ m ': ~: -~,06 ' ~' ~= -8,63 3436,51 50,98 3459~ 51,n~ .... -, ~ -~ ~"~ 34!3,25 .... 15 q~q.4,56 qaoz,~7 90,i4 -~=o ~.~ 345? _ .. ~avo 0,55 0,84 6580,00 66!0,00 6640~00 6670,00 6700d4 30,0 5!10,27 on n 5i27.i7 30.0 5!48,13 35';":." ::'~ 5i.OA A~,°':' -' --.L.~ ~ .:--: ., . ~2'--. --/ q .-- 3553,27 51,00 ,_,. ac/,__ ~ .--.: _7,34 , ~7: ~: S0,93 89:75 -7.n7 ...,~: ,., ~ _:.: .... .- ......... ~u,'?.'4 8o,c,4 -6,74 ;~o,_'.,~,zl 50,68 ,~a ,q~ _-, , ~ ~o 3530 !2 0,74 o~ oo ~g2.-:~ 90,12 0,52 3576,:~ 357A,62 '~0,I~ 1,!t 3579~9! 3599,9i 90,ii 1.84 ..... ~ qgg~,iA ~n,!o °,29 6730,0~ 6760,00 67?0,00 6820,00 6850,00 30,0 5184,37 30,0 5205,64 30,0 5224,96 RA4g .... ~n ~q 8~,~, -5,38 366?.34 50,10 89,42 3692,o~ 49,73 88,84 -4+60 37!5~?~ 49,90 89,50 -4,27 ~z,,~ ~, 90,08 o,.,.,.,,o. ._%.4-6,3! i,30 ..... -, o~ 3667~38 ~oo7,~/ ?0,08 ....... ~' Q~ ~- . ' %499.RA a6.~,~6 90,07 3715,.3! 37i5,3! 90~07 1,67 3738 oo o7~ :~ ~'~,OA F'Ag'g-. NO, 4 P2-34 ************~ ~,ta3Ri~ ************** S~RVE¥ C3LCULATiONS ************* C!RCbL&q ARC METHOD******** MEASUF~ iNTEMJAL VERTICAL .... · " D~F'TH ft ft ft 6880,~n ~o,v .26o~ 6710~00 30,0 5282,34 6940~00 ~J,O 530i,35 ~o:o.~n 30.0 5320~37 7000,~n ~r, ~ ~c~,,,36 TARGET STATION AZi~TH LATI%ODE SECTION It~:LN, NY-S ft deg - deg ft 37A1,41 5~,,55 ~ ,o -4,3~ 3784,60 50,74 90,20 -4,42 3807,8i 50,65 q!oS? -4,78 3854,22 50,76 90,63 %,57 DEPARTURE DiSPLACeMENT at AZIMUTH E/-W ft ft deg 376i,44 3761,45 90,07 3784,64 3784,64 90,07 3807,85 3807,85 3831,04 3831,05 90,08 DLS dee/ lOOft 0,9'! 0,64 3,.93 1,,..)3 0,63 . . . 7060,00 7090/o4 7120~(Ki 30,0 5358,28 % n 5377,08 30,0 5395,72 30,0 5414,23 3877,50 5i,05 9!,13 -5,93 N, nn ~ 5i,37 °1~° -^,45 ~o~a.q7 ~.Te 9i,a9 -7,13 ~t~- ~. ~ _. 2747~% 52,02. 9t~46 -7~82 3971,65 52,34 ~2,0! -8,55 3877,54 3877~55 90,09 3900,92 3900,92 90,0? 3948,01 3948,02 90,11 3971,70 397!,7~ 90,i2 1,6! !,32 !~84 i,32 1,74 7 !6."3,00 7210..-C0 / :,_; U, VV 7300,C0 30,0 5469:17 30:0 5505,75 30,0 ~.-".o,~ iA 3995,40 52,47 92,77 -9,54 4019,i8 52-;63 92,85 -!0,70 4066~65 52,14 94,2i -13,27 4090,28 52,i9 93,80 -14,93 3995,45' 4019,244V: ..... 7" '-.= r, .s7 ,,'_', 90,15 ..... 4043:&q :.-_ 4066,7? 4066,74 90 ~ I'..:'- 4,23 ~ '...: .. %.:, ..d ',-, ~....i..i. ~-, 7330~00 7360,00 7390,00 7426,9i 75!3,62 5542,52 ...... ¥~JO L.~ ~i~/,o~ 52,~3 YZ,Z/ -i7,24 4i~!,46 52~63 9!,!5 -i7,95 4i90,94 ..... '~ i~ ~" a~Aa.A~ 53,74 0q,19 _o~ o7 41!4,04 4114,07 90~23 3,2? 4137,76 4i37,80 90,24 0,77 416!,54 4161,58 90,25 3,!'3 41~1~09 4i91,0' 4264~75 4264,80 76!!,45 7705,02 7800,86 77~9,i0 433? =~' -.,. o--- 91,?~ -24,20 ,-." JO~/J - ~; ,, 0-5 53,33 g'?-',86 -?~;,37 -'" ~5 ""O 0 O-O ,..-- 449i,/u _.,,,, ,-.. 8,,,_., 4643,30 = ..... ..... ;~-.. o~, ?0,6? 4414~96 4415,03 90,33 t,58 449i,81 449!,88 ~r;,~2 4567,42 4567,50 90,32 %43,42 4643,49 90,.33 0,21 8i79,86 8369,?i 8%64,52 ~-,~ 5991,01 95~2 6045,83 99,0 6102,20 ?4,6 62!0,97 4720~67 54,42 89,¢o~" -26,77 4798,48 55~25 90,i7 -26,47 4879,84 55,33 88,49 -25,52 4954,13 54,i3 86,83 -22,49 5030o17 52,99 87,79 -i8,'92 4720,79 4720,86 4798,59 47?8,67 90,32 4879,95 4860,02 90,30 4954,23 4954,29 90,26 5030,26 5030,30 90,22 i,35 1,i0 i !,46 8559,34 8653,23 8748,38 8845,2! ~090 ~£ ! o -..-d-' :.- i. ..... :o-aR ';'D ~ c. ,.,~.,,_-._.,.: ?6,8 : '* '~-' F, .4 ='~,7 6505,82 5105~ !5 51.'-69 86:28 -i5,04 5178..-80 51,93 86,08 -!0,12 5253,'5,4 s~ ,&3 ~'~ ~ %,i3 -.. ,,,...~, - '-,I ,u-, 5329,21 5i,07 86,65 -2,48 · - 5402~n 50, ="' 87:43: , o, -'.' ~7 : t, oJ. ..~,=~ 5!05,~, . ,i7 i,86 5178~86 5178,87 90,ii 0,30 5253~6! 5253,6! 90,07 !,43 ~ ......... ?O,nq 1,23 8?63005 ?057,87 9152,19 ?247,76 9344,64 23,2 6520,54 o~ i ^702.3A 96,9 6764,73 5420,3? 50~61 87,04 2,18 ~ao~ oo 50,04 ~7,i8 5,86 55.65,33 49,73 86,62 9,76 ~6~,su 50,!6 i~,47 57!3~33 51,23 88,50 15,94 5493,30 ~oo 30 89,°4 O,~' 5565,33 -~k= oo 89 90 n.~.~ 57!3,~' . P~ NO, 5 F'2-34 *****.**~.****~ AN~RILL SUR%~I' CALCULATIONS **~****~***.. CIRCULAR ARC M~.?~D*~**~* M~ASUSD iNTERVAL V~:TICAL DEPTH DEF%H ft ft it ?440,46 95,8 6824,52 9533,~D 9~,8 6882~05 9627,10 93,8 6940~26 972i~93 94,8 6998~89 9817~ 95,6 7056,8i TARGB? S?A?tON AZIMUTH. LA?iTUD~ ,~, N/-S ft deg deg f~ 5788~!5 51,55 87,31 i8,66 ~60,97 5!,86 ~7,% 21,67 5934,47 51,42 87,24 24,73 6008,96 52,2! 88~i? ~7,70 AO84,gA ~o pa 87,94 30,27 DEF'ARTL~:E DISPLACEME>4T at ft it 5788.;~' o _s788o !5 5&50,~ 5860,97 5934,42 5934,47 6008,?0 6008,96 6¢54,91 6084,99 AZIMUTH deg 89,79 89,76 89,74 89,71 DLS deg/ lOOft 1,03 0,66 0,78 1,!5 1,06 9914,77 10008,i6 10!00~'~ 10198,43 97,2 7!14,87 93,4 7170,51 ~,/ 7225 6!62,7~'"= 53,~7,.. 8%58 31,96 6237,98 ,~,r" ~9.. 88,!4 33,45 A390,46. .. 53,15 89,07 ~,~°~ n~ '~'~ ~= ~ ~ ?O.n~ 3~,6i 6!62,88 6162,96 89,70 !,38 6237~90 ^~o=,99.. ~, 89,69 1,2~ o~v~/ 6390,46 89,66 87,oo 1,04 ~ ~.l~ ,~,~ ..... i0386,99 10481,90 i 057' 6, !5 10765,q~ 94,5 7396,51 94,9 7456,16 94,3 75!3,01 94,~ ~=z.-. 83 · , / ~'.'? ~ 94~? 7627,i6 6540,4i ._s2~7. ,. 89 ,~, ~'' 39,08 6615,8! 52;73 8?°97 6690,99 53,07 90,17 39,50 6842,01 52~79 ._%,20 42,50 6540,32 6540,44 89,66 0,69 6615,72 66i5,83 89,66 0,67 6690,90 6691,01 89,66 0,40 6766,26 6766,38 89,66 87,04 0,3! 6o4~,v~ t086!~C0 !t048,'~ i!238~3! 95,5 7~4,''~7o 94,0 7742,23 93,9 7799,65 93,3 7856,73 %,i 79i5,15 6916,05 52,78 8~,4! 44,75 721A,96 s~.~ A, ~v6 49~26 · _ ~ ~ ~ -. , 69!7,94 Aeon n '~ 0,17 7066,60 7066,76 89,61 7140,52 7140,68 89,61 0,68 72t6,83 7217,00 89,6i 11340,02 11524,62 Ii6i8,83 11713,85 !0!,7 7977,26 89~9 8032,i5 94,7 8090,03 7368,65 52,45 88,i3 52,85 7443~6! ~o =o 90,30 ~ ~a 75i8 .o =~ ~ _. . ,: .... ~4 Ao~Ss 53,78 7593,44 =o:~._q? 69,31. 54,34. 7297,36 7297,54 89,60 0,35 7368,52 7368,7i 89,59 0,50 7443,% 7443,67 69,59 1,83 7518,04 75i8,.24 89,59 0,44 7593,30 ,:='-'~,50oro . ~..~°-:°.., 0,47 11807,94 11902,28 12000,34 zzuY~,?O 94,1 8262,80 94,4 8319,52 98,0 8378,i7 · . ~,~!/ 9i,3 8490,56 7743,66 53,38 90,53 55,94 7297,5~ .... oo 01 ~ ,~ / ,, v,~u 52,47 6Y,5o bo,~.~ 7666,00 7688,20 69,59 77.~o ~ ~,7~ 89~59 782!,96 ,~,v~°° lA. 89,~9. _ 7897,4i 78?7~6! 89,60 7020 ,",' ' fir, KO , .... ,,=o 7Y70,i~ 0,65 ! ,55 0,38 0,87 0,42 12281,80 12375,02 12471,59 12565,36 12661,35 8549,'~ 96,6 &566,82 93,8 8730,53 8!i6,62 50,'99 90,0~ D..'.,79 ~10-] r,, .. ..... zo 49~69 90,45 5A,49 8045,55 8045,75 89,60 0'~,48 8i18,67 89,60 8192,82 6i93,01 ~9,60 8263,,~""~' 8£63,6i =.°~',~1- 8334,4t 8334,61 89,6I 0,58 1,07 !,38 2,06 0,93 1Z7~=,56 12814,03 12914,87 94,2 8858,50 ,8,~~ " 8897,36 1~0,9 8964,06 !01,6 9030,76 - F ~.-. ~ ~. 98,3 Yvy~.~ 8404,26 48,07 91,99 55,80 8447,86 48,55 92,25 54,!9 8523,46 48,67 92,01 51,38 8599,97 49,23 92,60 ~,30 oo/~,/: 49,9i 9!,85 45,39 84(~,i2 6404.30 89,62 1,63 8447,72 8447,90 89,63 0,88 a~o9 ~z 0,7! .... ,~... 8600,00 89,68 84.74,65 8.574,77 89,70 0,90 pAdrE ~, 6 M£ASL~ INTE~PA£ V~TI~L DEF?H DE?TH fr ft ft 13206,84 9~,! 9153,99 139_=-.-6,i649~3 9i88,05 ~RVEY F'ROJECTE~ TO TD ***~********* ANA~RILL' ~****:******** o,,~p¥~...~. CAbCULATIONS ,~**********~ CIR~kA:~ ARC M~THOD******** TARG~ STATION AZI~%H LATITUDE SECTION I~4~ N/-S fr deg de9 f~ -~ ~ ~ ~ .. 8,~J~O= ~9..~ 92.34 42.82 8782,40 49.22 94,64 40.54 8835.25 49,22 94,64 36.25 P2-34 DEPARTURE DISPLACEMENT at AZIMUTH DLS ~/-W ft ft dm~ !OOft 8744,92 8745,03 89,72 0.48 8782,31 8782,41 89,74 3~66 8835~18~.~=~ ~ 89,76 0.06 gyro/data MILNE POINT FIELD, ALASKA Gyro Multishot Survey in 5.5" Drill pipe Survey date · 06 July, 1995 Job number' AK0795G278 SR278.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 August 8, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re: P2 Pad Well P2-34, Point MAC, Pool 7 Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #P2-34 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER' AK0795G278 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR278.DOC gyro/data 1, DISCUSSION , SURVEY CERTIFICATION SHEET SR278.DOC gyro/data DISCUSSION JOB NUMBER' AK0795G278 Tool 080 was run in P2-34 on ATLAS 5/16" Wireline inside 5.5" drill pipe. The survey was run without problems. SR278.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0795G278 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- Rob Shoup TOM STODDARD OPERATIONS ENGINEER SR278.DOC gyro/data 2. SURVEY DETAILS SR278.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0795G278 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: POINT MAC WELL: P2-34 LATITUDE: 70.401 N LONGITUDE: 149.5 W SURVEY DATE: 06-July, 1995 SURVEY TYPE : MULTISHOT IN 5.5" casing DEPTH REFERENCE: ROTARY TABLE EVELATION MAX. SURVEY DEPTH: 7390' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' 30' (7390-7000) UTM CO-ORDINATES: TARGET DIRECTION: 89.81 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR278.DOC gyro/data 3. OUTRUN SURVEY LISTING SR278.DOC A Gy r o da t a D i r e c t i o n a i Survey for B. P. EXPLORATION WELL: P2-34 Job Number: AK0795G278 Location: PAD P-2, POINT MAC FIELD,ALASKA Run Date: 6-Jul-95 09:55:57 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.401000 deg. N Sub-sea Correction from Vertical Reference: 63.4 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 0.0 0.00 0.00 0.0 0.0 0 - 7390 FT. GYRO SURVEY RUN IN DRILL PIPE. MEASURED DEPTHS ARE REFERENCED TO POOL 7 R.K.B. SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. -63.4 0.00 0.0 0.0 HEIGHT (63.4 FT.) Page 1 H O R I Z O'N T A L COORDINATES feet 0.00 N 0.00 E 100.0 .44 67.26 100.0 .1 200.0 .28 150.82 200.0 .1 300.0 .24 39.07 300.0 .0 400.0 .79 107.54 400.0 -.0 500.0 .75 83.79 500.0 -.2 600.0 1.25 88.58 600.0 -.1 700.0 3.27 85.42 699.9 .2 800.0 4.15 84.28 799.7 .8 900.0 4.78 86.85 899.4 1.4 1000.0 5.53 89.42 999.0 1.7 1100.0 7.05 92.80 1098.4 1.4 1200.0 8.51 93.41 1197.4 .7 1300.0 10.52 94.22 1296.1 -.4 1400.0 11.98 95.56 1394.1 -2.1 1500.0 14.68 95.02 1491.4 -4.2 1600.0 17.18 95.67 1587.6 -6.8 1700.0 17.92 95.25 1682.9 -9.7 1800.0 18.54 91.55 1777.9 -11.5 1900.0 19.63 89.21 1872.4 -11.7 2000.0 20.41 89.48 1966.4 -11.3 36.6 .44 .4 67.3 136.6 .49 .8 84.1 236.6 .42 1.1 88.2 336.6 .74 1.9 90.5 436.6 .32 3.2 92.7 536.6 .50 4.9 90.6 636.5 2.03 8.8 88.7 736.3 .88 15.3 87.0 836.0 .66 23.1 86.6 935.6 .78 32.1 87.0 1035.0 1.57 43.0 88.1 1134.0 1.47 56.5 89.3 1232.7 2.01 73.0 90.4 1330.7 1.48 92.4 91.3 1428.0 2.70 115.4 92.1 1524.2 2.51 142.8 92.7 1619.5 .75 173.0 93.2 1714.5 1.31 204.2 93.2 1809.0 1.33 236.9 92.8 1903.0 .79 271.1 92.4 .15 N .35 E .08 N .82 E .03 N 1.07 E .01 S 1.85 E .15 S 3.17 E .05 S 4.91 E .20 N 8.85 E .79 N 15.29 E 1.38 N 23.05 E 1.66 N 32.02 E 1.41 N 42.97 F .66 N 56.48 E .45 S 72.98 E 2.12 S 92.41 E 4.24 S 115.36 E 6.81 S 142.68 E 9.68 S 172.69 E 11.52 S 203.90 E 11.71 S 236.59 E 11.32 S 270.81 E A Gyro d a t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 21.23 91.51 2059.9 2200.0 22.04 92.58 2152.8 2300.0 23.79 93.53 2244.9 2400.0 26.07 91.20 2335.6 2500.0 27.90 89.18 2424.7 -11.6 -13.0 -15.1 -16.8 -16.9 1996.5 2089.4 2181.5 2272.2 2361.3 1.10 306.6 92.2 .90 343.4 92.2 1.78 382.4 92.3 2.48 424.5 92.3 2.05 469.9 92.1 11.64 S 306.35 E 12.96 S 343.20 E 15.05 S 382.08 r 16.76 S 424.19 E 16.88 S 469.55 E 2600.0 28.79 89.95 2512.7 2700.0 30.01 90.97 2599.8 2800.0 31.56 88.76 2685.7 2900.0 34.78 88.59 2769.4 3000.0 37.93 87.96 2850.0 -16 -16 -16 -15 -13 .5 .9 .8 .5 .7 2449.3 2536.4 2622.3 2706.0 2786.6 .97 517.3 91.8 1.32 566.4 91.7 1.92 617.5 91.6 3.22 672.2 91.3 3.17 731.3 91.1 16.52 S 517.02 E 16.92 S 566.11 E 16.78 S 617.28 E 15.51 S 671.98 E 13.72 S 731.22 E 3100.0 40.45 87.08 2927.5 3200.0 44.02 88.00 3001.5 3300.0 47.48 86.48 3071.3 3400.0 49.96 87.91 3137.2 3500.0 50.84 88.70 3201.0 -11.0 -8.1 -4.6 -1.0 1.3 2864.1 2938.1 3007.9 3073.8 3137.6 2.58 794.4 90.8 3.62 861.5 90.5 3.63 933.0 90.3 2.71 1008.1 90.1 1.07 1085.1 89.9 10.97 S 794.34 E 8.10 S 861.48 E 4.62 S 933.01 E .97 S 1008.06 E 1.31 N 1085.08 E 3600.0 51.81 90.48 3263.5 3700.0 52.22 91.67 3325.0 3800.0 51.95 91.87 3386.5 3900.0 51.16 90.99 3448.6 4000.0 50.64 92.46 3511.7 1 -2 -4 -6 .9 .4 .1 .0 .3 3200.1 1.69 1163.1 89.9 3261.6 1.03 1241.9 90.0 3323.1 .31 1320.8 90.1 3385.2 1.05 1399.1 90.2 3448.3 1.26 1476.7 90.2 1.86 N 1163.14 E .38 N 1241.94 E 2.05 S 1320.80 E 4.01 S 1399.09 E 6.34 S 1476.66 E 4100.0 52.54 91.65 3573.8 4200.0 54.20 90.84 3633.5 4300.0 54.13 86.43 3692.1 4400.0 53.15 87.87 3751.3 4500.0 52.64 89.95 3811.7 -9.1 -10.9 -9.0 -5.0 -3 .4 3510.4 2.01 1555.0 90.3 3570.1 1.78 1635.2 90.4 3628.7 3.58 1716.2 90.3 3687.9 1.53 1796.6 90.2 3748.3 1.73 1876.4 90.1 9.14 S 1554.96 E 10.89 S 1635.19 E 8.96 S 1716.21 E 4.95 S 1796.64 E 3.43 S 1876.37 E A Gy r o da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 51.82 90.37 3872.9 4700.0 54.26 91.57 3933.0 4800.0 54.85 91.68 3991.0 4900.0 54.57 91.71 4048.8 5000.0 54.08 90.28 4107.1 -3.6 -5.0 -7..3 -9.7 -11.2 3809.5 3869.6 3927.6 3985.4 4043.7 .89 1955.4 90.1 2.62 2035.3 90.1 .60 2116.7 90.2 .28 2198.3 90.3 1.26 2279.6 90.3 3.65 S 1955.42 E 5.02 S 2035.30 E 7.33 S 2116.73 9.75 S 2198.32 11.17 S 2279.54 E 5100.0 53.53 89.90 4166.2 5200.0 53.76 90.62 4225.5 5300.0 53.71 90.63 4284.6 5400.0' 53.04 89.66 4344.3 5500.0 52.85 89.56 4404.5 -11.3 -11.7 -12.5 -12.7 -12.2 4102.8 4162.1 4221.2 4280.9 4341.1 .63 2360.3 90.3 .63 2440.8 90.3 .05 2521.4 90.3 1.03 2601.7 90.3 .21 2681.5 90.3 11.30 S 2360..24 E 11.67 S 2440.77 E 12.55 S 2521.40 E 12.75 S 2601.65 E 12.21 S 2681.45 E 5600.0 53.09 90.12 4464.8 5700.0 52.60 89.94 4525.2 5800.0 52.35 90.44 4586.1 5900.0 52.25 89.92 4647.2 6000.0 51.42 89.59 4709.0 -12.0 -12.0 -12.3 -12.5 -12.2 4401.4 4461.8 4522.7 4583.8 4645.6 .51 2761.3 90.2 .52 2841.0 90.2 .47 2920.3 90.2 .42 2999.4 90.2 .88 3078.1 90.2 11.98 S 2761.28 E 12.02 S 2840.98 E 12.28 S 2920.29 E 12.54 S 2999.41 E 12.21 S 3078.04 E 6100.0 51.16 90.27 4771.5 6200.0 51.39 88.84 4834.1 6300.0 51.12 89.85 4896.7 6400.0 51.07 88.67 4959.5 6430.0 51.07 88.88 4978.4 -12 .1 -11.5 -10.6 -9.6 -9.1 4708.1 4770.7 4833.3 4896.1 4915.0 .59 3156.1 90.2 1.14 3234.1 90.2 .83 3312.1 90.2 .92 3389.9 90.2 .55 3413.2 90.2 12.11 S 3156.06 E 11.50 S 3234.07 E 10.61 S 3312.06 E 9.61 S 3389.87 E 9.11 S 3413.20 E 6460.0 50.98 89.05 4997.2 6490.0 51.04 89.47 5016.1 6520.0 51.29 89.41 5034.9 6550.0 51.21 89.53 5053.7 6580.0 51.06 89.32 5072.5 -8.7 -8.4 -8.2 -7.9 -7.7 4933.8 4952.7 4971.5 4990.3 5009.1 .52 3436.5 90.1 1.11 3459.8 90.1 .85 3483.2 90.1 .40 3506.6 90.1 .75 3530.0 90.1 8.69 S 3436.52 E 8.38 S 3459.83 E 8.16 S 3483.20 E 7.94 S 3506.59 E 7.71 S 3529.95 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL C. O O R D I N A T E S feet 6610.0 51.00 89.13 5091.4 6640 . 0 50 . 93 89 . 55 5110 . 3 6670.0 50.94 88.84 5129.2 6700.0 50.68 88.02 5148.1 6730.0 50.43 88.41 5167.2 -7 -7 -6 -6 -5 .4 .1 .8 .2 .4 5028.0 5046.9 5065.8 5084.7 5103.8 .53 3553.3 90.1 1.12 3576.6 90.1 1.85 3599.9 90.1 2.29 3623;1 90.1 1.31 3646.3 90.1 7.39 S 3553.27 E 7.12 S 3576.58 E 6.79 S 3599.87 1 6.16 S 3623.11 E 5.43 S 3646.27 E 6760.0 50.10 89.42 5186.4 6790.0 49.93 88.84 5205.7 6820.0 49.90 89.50 5225.0 6850.0 50.30 90.33 5244.2 6880.0 50.55 90.19 5263.3 -5 -4 -4 -4 -4 .0 .6 .3 .3 .4 5123.0 5142.3 5161.6 5180.8 5199.9 2.82 3669.3 90.1 1.59 3692.3 90.1 1.68 3715.3 90.1 2.50 3738.3 90.1 .89 3761.4 90.1 5.00 S 3669.33 E 4.65 S 3692.31 E 4.32 S 3715.26 E 4.28 S 3738.28 E 4.39 S 3761.40 E 6910.0 50.74 90.20 5282.4 6940.0 50.65 91.59 5301.4 6970.0 50.66 90.84 5320.4 7000.0 50.76 90.63 5339.4 7030.0 51.05 91.13 5358.3 -4 -4 -5 -5 -6 .5 .8 .3 .6 .0 5219.0 5238.0 5257.0 5276.0 5294.9 .64 3784.6 90.1 3.58 3807.8 90.1 1.92 3831.0 90.1 .66 3854.2 90.1 1.62 3877.5 90.1 4.47 S 3784.60 E 4.83 S 3807.81 E 5.32 S 3831.00 E 5.62 S 3854.22 E 5.98 S 3877.50 E 7060.0 51.37 91.43 5377.1 7090.0 51.79 91.89 5395.7 7120.0 52.02 91.48 5414.2 7150.0 52.34 92.01 5432.6 7180.0 52.47 92.77 5450.9 -6 -7 -7 -8 -9 .5 .2 .9 .6 .6 5313.7 5332.3 5350.8 5369.2 5387.5 1.32 3900.9 90.1 1.84 3924.4 90.1 1.32 3948.0 90.1 1.74 3971.7 90.1 2.05 3995.4 90.1 6.50 S 3900.88 F 7.18 S 3924.37 E 7.87 S 3947.97 E 8.60 S 3971.66 E 9.59 S 3995.41 E 7210.0 52.63 92.85 5469.2 7240.0 52.47 92.66 5487.4 7270.0 52.14 94.21 5505.8 7300.0 52.19 93.80 5524.2 7330.0 52.31 92.56 5542.5 -10.8 -11.9 -13.3 -15.0 -16.3 5405.8 5424.0 5442.4 5460.8 5479.1 .59 4019.2 90.2 .74 4043.0 90.2 4.24 4066.7 90.2 1.09 4090.3 90.2 3.30 4114.0 90.2 10.75 S 4019.19 E 11.90 S 4042.98 E 13.32 S 4066.68 E 14.97 S 4090.31 E 16.29 S 4114.00 E A Gyro da t a D i r e c t i o n a i Survey B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL SUBSEA DEPTH DEPTH SECTION DEPTH feet deg. deg. feet feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7360.0 52.33 92.27 5560.9 -17.3 5497.5 7390.0 52.63 91.04 5579.1 -18.0 5515.7 .76 4137.8 90.2 3.41 4161.5 90.2 17.29 S 4137.72 E 17.97 S 4161.50 E Final Station Closure: Distance: 4161.54 ft Az: 90.25 deg. A Gyro da t a D i r e c t i on a i Survey for B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278SS Run Date: 6-Jul-95 09:55:57 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.401000 deg. N Sub-sea Correction from Vertical Reference: 63.4 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r e d a t a D i r e c t i e n a 1 S u rve y B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. -63.4 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0 - 7390 FT. GYRO SURVEY RUN IN DRILL PIPE. MEASURED DEPTHS ARE REFERENCED TO POOL 7 R.K.B. HEIGHT (63.4 FT.) Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .34 120.24 163.4 .1 200.0 .25 79.97 263.4 .1 300.0 .59 82.48 363.4 .0 400.0 .77 92.48 463.4 -.1 500.0 1.07 86.83 563.4 -.1 600.0 2.54 86.57 663.4 .1 700.0 3.83 84.70 763.4 .6 800.0 4.55 85.93 863.4 1.2 900.0 5.26 88.51 963.4 1.6 1000.0 6.51 91.61 1063.4 1.5 1100.0 8.01 93.20 1163.4 .9 1200.0 9.86 93.95 1263.4 -.1 1300.0 11.52 95.14 1363.4 -1.6 1400.0 13.90 95.18 1463.4 -3.6 1500.0 16.55 95.51 1563.4 -6.2 1600.0 17.77 95.34 1663.4 -9.1 1700.0 18.44 92.12 1763.4 -11.2 1800.0 19.52 89.43 1863.4 -11.7 1900.0 20.38 89.47 1963.4 -11.3 2000.0 21.26 91.55 2063.4 -11.7 .47 .8 78.0 .45 1.1 86.7 .62 1.9 89.6 .47 3.2 91.9 .44 4.9 91.4 1.47 8.8 89.4 1.29 15.3 87.6 .74 23.1 86.7 .74 32.1 86.9 1.29 43.0 87.7 1.50 56.5 88.9 1.83 73.0 90.0 1.65 92.4 91.0 2.35 115.4 91.9 2.56 142.8 92.6 1.11 173.0 93.1 1.23 204.2 93.2 1.33 23'6.9 92.9 .81 271.1 92.4 1.09 343.4 92.2 .11 N .65 E .05 N .98 E .02 S 1.57 E .10 S 2.69 E .09 S 4.27 E .15 N 7.41 E .58 N 12.95 E 1.17 N 20.25 E 1.56 N 28.82 E 1.49 N 39.12 E .92 N 51.84 E .52 S 67.52 E 1.60 S 86.32 E 3.63 S 108.75 E 6.16 S 135.81 E 9.09 S 166.54 E 11.23 S 199.13 E 11.69 S 233.47 E 11.33 S 269.73 E 11.69 S 307.76 E A Gyro d a t a D i r e c t i o n a i S u r v e'y B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 22.25 92.69 2163.4 2200.0 24.25 93.06 2263.4 2300.0 26.64 90.57 2363.4 2400.0 28.29 89.51 2463.4 2500.0 29.50 90.54 2563.4 -13.2 -15.4 -16,8 -16.7 -16.8 . 1. 2. 1. 1. 00 93 34 57 17 382.4 92.2 424.5 92.3 469.9 92.2 517.3 92.0 566.4 91.8 13.20 S 347.68 E 15.40 S 390.67 E 16.80 S 438.35 E 16.72 S 490.42 E 16.76 S 545~58 E 2600.0 31.16 89.33 2663.4 2700.0 34.55 88.61 2763.4 2800.0 38.37 87.81 2863.4 2900.0 42.18 87.52 2963.4 3000.0 47.09 86.65 3063.4 -16.8 -15.6 -13.2 -9.6 -5.0 . 3. 3. 3. 3. 76 12 07 09 63 617.5 91.6 672.2 91.3 794.4 91.0 861.5 90.7 933.0 90.3 16.82 S 603.98 E 15.60 S 668.03 E 13.24 S 742.16 E 9.58 S 826.94 E 5.02 S 924.95 E 3100.0 50.32 88.24 3163.4 3200.0 51.81 90.48 3263.4 3300.0 52.05 91.79 3363.4 3400.0 51.04 91.33 3463.4 3500.0 52.22 91.79 3563.4 -.0 1.9 -1.1 -4 .6 -8.7 2.03 1.69 .58 1.10 1.88 1085.1 90.0 1163.1 89.9 1320.8 90.0 1476.7 90.2 1555.0 90.3 1.11 N 1039.68 E 1.86 N 1163.06 E 1.43 S 1291.20 E 4.55 S 1417.25 E 8.67 S 1541.82 E 3600.0 54.17 88.59 3663.4 3700.0 53.05 88.29 3763.4 3800.0 51.94 90.31 3863.4 3900.0 54.57 91.63 3963.4 4000.0 54.45 91.36 4063.4 -9.9 -4.6 -3.6 -6.2 -10.1 2.70 1.57 1.02 1.56 .52 1716.2 90.3 1876.4 90.1 1955.4 90.1 2116.7 90.2 2279.6 90.3 9.90 S 1676.57 E 4.65 S 1812.58 E 3.62 S 1943.14 E 6.23 S 2077.93 E 10.10 S 2218.65 E 4100.0 53.55 89.92 4163.4 4200.0 53.73 90.63 4263.4 4300.0 52.98 89.63 4363.4 4400.0 53.09 90.11 4463.4 4500.0 52.44 90.25 4563.4 -11.3 -12.2 -12.6 -12.0 -12.2 .66 .26 .77 .50 .49 2360.3 90.3 2521.4 90.3 2681.5 90.3 2761.3 90.2 2920.3 90.2 11.29 S 2356.45 E 12.23 S 2492.49 E 12.58 S 2626.99 E 11.99 S 2759.49 E 12.19 S 2890.78 E A Gyr oda t a D i r e c t i o n a i Survey B.P. EXPLORATI6N WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number: AK0795G278SS SUBSEA I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERT I CAL DOGLEG SECTION SEVERITY feet deg. / 100 ft. cLOSURE DIST. AZIMUTH feet deg. Page HORIZONTAL COORDINATES feet 4600.0 52.04 89.84 4663.4 4700.0 51.19 90.18 4763.4 4800.0 51.26 89.31 4863.4 4900.0 51.07 88.72 4963.4 5000.0 51.13 89.42 5063.4 -12.4 .54 -12.1 .63 -11.1 1.00 -9.5 .84 -7.8 .58 3078.1 90.2 3156.1 90.2 3312.1 90.2 3413.2 9.0.2 3530.0 90.1 12.45 S 3020.01 E 12.12 S 3145.90 E 11.08 S 3270.57 E 9.50 S 3394.69 E 7.82 S 3518.64 E 5100.0 50.48 88.33 5163.4 5200.0 50.55 90.19 5263.4 5300.0 51.14 91.21 5363.4 5400.0 52.58 92.82 5463.4 5500.0 52.37 92.10 5563.4 -5.6 1.51 -4.4 .89 -6.1 1.54 -10.4 1.05 -17.4 1.13 3646.3 90.1 3784.6 90.1 3900.9 90.1 4019.2 90.1 4161.5 90.2 5.58 S 3641.65 E 4.39 S 3761.49 E 6.12 S 3883.85 E 10.39 S 4011.66 E 17.38 S 4141.01 E 5515.7 52.63 91.04 5579.1 -18.0 3.41 4161.5 90.2 17.97 S 4161.50 E Final Station Closure: Distance: 4161.54 ft Az: 90.25 deg. gyro/data 4. QUALITY CONTROL SR278.DOC Quality Control Comparisons B.P. EXPLORATION WELL: P2-34 Location: PAD P-2, POINT MAC FIELD,ALASKA Job Number : AK0795G278 / AK0795G278 Inrun/Outrun Comparison Inrun Outrun Inrun Depth Inc Inc Delta Az 1000.0 5.51 5.53 -.014 90.67 2000.0 20.25 20.41 -.161 89.44 3000.0 37.89 37.93 -.038 87.36 4000.0 51.09 50.64 .453 92.35 5000.0 54.34 54.08 .263 90.59 6000.0 51.38 51.42 -.033 88.71 7000.0 50.72 50.76 -.046 90.20 For Inclinations Greater than 10 degrees: Average Inclination Difference = .07288 deg. Average Azimuth Difference = -.2925 deg. Outrun Az 89.42 89.48 87.96 92.46 90.28 89.59 90.63 Delta 1.244 -.041 -.601 -.108 .304 -.879 -.431 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0795G278 TOOL NUMBER: 08O MAXIMUM GYRO TEMPERATURE: 75.0c MAXIMUM AMBIENT TEMPERATURE: 37.0 c MAXIMUM INCLINATION: 54.85 AVERAGE AZIMUTH: 90.2 WIRELINE REZERO VALUE: 0.0 REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: # 1192 Dated 6~23~95 CALIBRATION USED FOR FINAL SURVEY: # 1192 Dated 6/23/95 PRE JOB MASS BALANCE OFFSET CHECK: -.13 POST JOB MASS BALANCE OFFSET CHECK: CONDITION OF SHOCK WATCHES .0 USED-.13 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 7390 52.63 91.15 5579.1 18.0S 4161.5E 7390 '52.63 91.04 5579.1 17.97S 4161.5E SR278.DOC ~:~ . gyro/data SR278.DOC gyro/data. FUNCTION TEST JOB NUMBER: AK0795G278 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 7390 52.6 52.6 52.6 AZIMUTH M.D. ft 1 2 3 4 5 7390 91.0 91.1 91.1 SR278.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR278.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0795G278 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0094 DATA SECTION A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055 A0079 A0071 BACKUP TOOL No. 136 GYRO SECTION A0099 DATA SECTION A0029 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE A0122 A0032 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: 30.5 feet MAXIMUM O.D.: 2.25INCHES TOTAL WEIGHT OF TOOL: 240Lbs SR278.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0795G278 7/O6/95 1215 1300 205O 2220 2400 TO MILNE POINT ARRIVE PAD P-2 ,MU TOOL, STANDBY FOR GLOBE BASKET TO FISH CONES RU ATLAS,PU TOOL. 7390' 40OO' 7/07/95 0120 0200 O43O LD TOOL. RD ATLAS AND BD TOOL. RTN ATLAS,CHECK TOOL, PROCESS SURVEY, FAX TO CO REP. 7/07/95 1100 RTN RIG W/SURVEY AND ASD DISK. 7/08/95 1710 CHARTER TO ANCHORAGE SR278.DOC ARCO Alaska Inc. G~ ~,ter Point McIntyre Engineering Date: Subject: From: September 1, 1995 Transmittal Number ARCO Alaska, Inc. 753 To: Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 : . The following Greater Point Mclntyre Area data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description '1 31" LPC-02 Perforation Record Safe System ~- ,8,4 SPF ,a p2-34 Cement Bond Log, CBT- GR ~ P2-34 Ultra Sonic Imager Cement & Corrosion i~ P2-50b Ultrasonic Imager Corrosion Log . Run # Date Run Company I 4/9/95 Schlumberger 7/28/95 Schlumberger 7/28/95 Schlumberger 7/24/95 Schlumberger P2-28 73-- p2-28 Ultra Sonic Imager Cement & Corrosion Cement Bond Log, CBT- GR 1 7/13/95 Schlumberger 1 7/13/95 Schlumberger '2 3/ - ~ P2-28 Perforating Record, o- ~8,6 spf, 4HJII 1 7/14/95 Schlumberger ~:.Please~!si~Tone:~ co~~-~//~-~f/ ~~-.r~etur~?~.to~ GPMA Engr Aide, ATO-462 ':~ ................ ~ ......................... ~ ....... ~CO ~aska, ~c. P.O. Box 100360 ~ch~ 9~510-0360 4tasko Oii- .:.....: . " '~, I',, ' :,~,. . Transmittal Number: 753 Page: 1 MEMOP. ANDUM TO: THRU: State of A aska Alaska Oil and Gas Conservation Commission DATE: July 13, 1995 Blair Wondzell, P. I. Supervisor FROM: Lou Gdmaldi,' ~-o,c~- SUBJECT: Petroleum Inspector FILE NO: A21JGNCD.DOC BOP test Pool dg #7 Arco well #P2-34 Point Mclntyre Field PTD # 95-66 Thursday, July 13, 1995: I witnessed the weekly test of the BOPE on Pool dg #7 which was ddiling Arco well #P2-34 in the Point Mclntyre Field. The BOP test was started shortly before midnight of the previous day and lasted approximately four hours. All BOPE functioned properly and held its pressure test. The dg appeared to be in good shape and the crew performed well dudng the test. The area surrounding the dg was clean and orderly providing good access to the dg. SUMMARY:. I witnessed the initial BOP test on Pool dg #7 ddlling Arco well #P2~34 in the Point Mclntyre Field. Test time 4 hours, no failures. Attachments:. A21JGNCD.XLS CC: Scott Sigurdson/Tom Horten STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Operator: Arco Well Name: P2-34 Casing Size: Set @ Test: Initial Weekly Rig No. 7 PTD # 95-66 Rep.' Rig Rep.: Location: Sec. X Other DATE: 7/13/95 Rig Ph.# 659-4618 Tommy Johnson Jim Davidson 14 T. 12N R. 14E Meridian Umiat Test Well Sign P Drl. Rig P MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP 1 Lower Kelly / IBOP Hazard Sec. P Ball Type Inside BOP PTD On Location OK Standing Order Posted OK Pressure P/F 250/5,000 P 250/5,000 P 250/5,000 P 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/3,000 P 1 250/3,000 P 1 250/3,000 P 1 250/3,000 P I 250/3,000 P 2 250/3,000 P I 250/3,000 P N/A 250/3, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 250/5,000 P 34 250/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: SIX bottles 2400 average 3,050 ! P 1,650 P minutes 33 sec. minutes 32 sec. P Remote: P Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good tesfi Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Insp?,.c~[L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: 3NCD.XLS Louis R Grimaldi OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 7, 1995 Adrian Clark Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Pt. McIntyre P2-34 ARCO Alaska, Inc. Permit No. 95-66 Sur. Loc. 245'$NL, 1359'EWL, Sec. 14, T12N, R14E, UM Btmnhole Loc. 215'SNL, 348'WEL, Sec. 13, T12N, R14E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. : The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at David W. Jo~hns~o~t~ ~~ Cha~rma~ ...... )-7- ~ BY ORDER OFT COMMISSION dlf/Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 a. Type of work Drill r~ Redrilll-]Jl Re-Entry [] Deepen 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612. Anchorage. Alaska 99519-6612 ;4. Location of well at surface 245' SNL, 1359' EWL, SEC. 14, T12N, R14E At top of productive interval 217' SNL, 658' WEL, SEC. 13, T12N, R14E At total depth . 215' SNL, 348' WEL, SEC. 13, T12N, R14E 12. Distance to nearest 113. DistanCe to nearest well property line ADL 365548-215' feet b. Type of well. Exploratory[] Stratigraphic Test [] Service [] Development Gas [] Single Zone [] No close approach feet 6. To be completed for deviated wells '0ckoff depth 400, feet Maximum hole angle s2.s o 8. Casing program size Specifications Weight I Grade I CouplingI Length Hole Casing 5. Datum Elevation (DF or KB) KBE = 52' feet 6. Property Designation ADL 34624 7. Unit or property Name Point Mclntyre 8. Well number P2-34 30" 20" 12-1/4" 9-5/8" 8-1/2" 5-1/2" Development Oil [] Multiple Zone [] 9. Approximate spud date 7/1/95 4. Number of acres in property 256O 10. Field and Pool Point Mclntyre 11. Type Bond(see 20 AAC 25.025) Number U-630610 Amount $200,000.00 5. Proposed depth (MD and TVD) 13299' MD/9170' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig Setting Depth Top Bottom Quantity of cement MD Surface 6384 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical TVD !4961 measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner M D TVD (include stage data) 80' 6534' 13299' 80' 5052' 250 sx Arcticset (Approx.) 1542 sx PF 'E'/323 sx 'G'/235 sx PF feet feet feet feet Plugs (measured) Junk (measured) Length Size Cemented 9170' True Vertical depth 807 sx Class "G" Perforation depth: measured~ ['~A¥ -9 1995 true vertical , ,,,o ' Cons Commission , ,',~s~,,, O~I & Gas · 20. Attachments Filing fee[~ Property plat [] BOP Sketch [] Diverter Sketch []"-Drilling ~m[] IDrilling fluid program [] TimcCvs depth plot [] ,Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby~,~i~ify that~:~/lc¢~i.c~d'j~¢t~s_ true ¢~nd correct to the best of my knowledge . , I Signed ~ //~/(~ ~~._ Title Drilling En~ineer Supervisor Date :~/~/¢/_~' [ CommiSsion Use Only -- Permit Number APl number Approval date See cover letter --~'~_~"'-~'~" 50-~::~.~- ~_~"2_~-~.~'o~ ~,--- ~-- ~'~'~ for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required working pressure for B©PE [] 2M; []3M; 1~5M; I"'I10M; 1'-115M; Other: Origina! Sign~o d~- by order of / /' Approved by Rm/iri W Johnston Commissioner rna commission Date4~ Form 10-401 Rev. 12-1-85 ........ Submit ih/ti'i~li'cate Measured depth RECEIVED I Well Name: IP2-34 Well Plan Summary I Type of Well (producer or injector): I Injector (Seawater) Surface Location: 245' FNL, 1359' FWL, Sec. 14, T12N, R14E UM Target Location: 217' FNL, 658' FEL, Sec. 13, T12N, R14E UM Bottom Hole Location: 215' FNL, 348' FEL, Sec. 13, T12N, R14E UM [AFE Number: [2C0075 [ Estimated Start Date: [ 7/1/95 [Rig: [Pool#7 Operating days to complete: [ 18 [MD: 113299' [ [TVD: 19170'rkb I [KBE: 152' Well Design (conventional, slimhole, etc.): [ ultra slimhole monobore [ Objective: [ To allow water injection on eastern flank of reservoir. Formation Markers: Formation Tops MD TVD(BKB) Base Permafrost 1813 1787 K-15 6765 5192 West Sak 9771 7022 Minimum required MW 9.5 ppg K-10 12646 8772 K-5 12662 8782 HRZ 12826 8882 Kalubik 12876 8912 Kuparuk 12909 8932 Minimum required MW 10 ppg Base Kuparuk 13245 9137 Evaluation Program: SURFACE Anadrill directional MWD only PRODUCTION Anadrill MWD/GR/CDN/CDR from 150' above top Kuparuk to TD (GR from West Sak to Kuparuk). Contingent Atlas triple combo. CASED HOLE Cement Bond Log (after rig release) LOGS Well Plan Summary " Page 1 Mud Program: ISpecial design considerations LSND system will include addition of Xanvis for rheological properties. Lubricant may be added if torque increases. Add Soltex for fluid loss control. Surface Mud Properties: [ SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: [ LSND DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.8 8-15 25-30 5-15 10-20 9-10 4-12 10.4 8-15 25-30 8-12 <30 9-9.5 +/- 5 < 15 HTHP Directional'. ]KOP: 14o0' MD Maximum Hole Angle: Close Approach Well: 52.5° , hold angle to TD, azimuth = 89.81° None Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 30" 20" 94# H-40 WLD 80' GL 80/80 12-1/4" 9-5/8" 47# NvI'-80 BTC- 6493' 41'/41' 6534'/5052' MOD Liner 8-1/2" 5-1/2" 17# NT-80S NSCC 6915' 6384'/4961' 13299'/9170' TBG 5-1/2" 17# NT-80S NSC 6343' 41'/41' 6384'/4961' C Disposal'. All fluids and cuttings to be hauled to C22A. Annular Injection (apart from freeze protection) is not allowed on P2 pad. K~as~ Oil & Gas Cons. G0mmis~on Anch0r~" Well Plan Summary Page 2 Drilling Hazards/Risks Tight hole has been experienced in the lower Sagavanirktok formation, in wells where surface casing was set above the SV4 sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. It is also likely to be a problem in this 12-1/4" surface hole. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. On well P2-07 the pipe stuck at a connection 4873' and a $380,000 BHA was lost, possibly due to insufficient hole cleaning. This will be the first well to use the 'Monobore' well design. The drilling program is essentially the same as that for our slimhole longstring wells, with the exceptions that a) the surface casing is set at 5000' TVDSS instead of 3650' TVDSS, and b) the production casing is run as a liner and tieback instead of a longstring. The main difference for this monobore well design is the proposed well completion, which is a string of 5-1/2" tubing used to tie back the 5-1/2" liner to surface. This tubing will have a seal mandrel at the bottom which will sting into a PBR at the liner top. Pressure integrity of this string will be verified. A risk analysis has been performed on this new type of well which has been designed to meet BPX Drilling and Casing Design Policies. As this well is intended to be a water injector it complies with the current AOGCC regulations and only imposes one area of additional risk. The risks and concerns expressed by corrosion problems have been mitigated by the well design and the design has been approved by the field owners. Corrosion issues were addressed separately by detailed study work and have been discussed with the AOGCC Commisioners. They were summarized in a letter sent from Mr. G. Phillips to Mr. B. Wondzell, dated April, 13, 1995. Well Plan Summary Page 3 Cement supplier HALLIBURTON P2-34 Cement volumes Surface String Spacer Casing depth 6534 ft Casing size 9.625 in Casing ID 8.681 in Casing weight 47 Ib/ft Bit diameter 12.25 in Excess factor 1.8 Shoe track 80 ft CIRCTEMP 50 Deg F 75 bbs FRESH WATER LEAD (TYPE Length Yield Density TOC # sacks Mix water Thickening time 'E' PERMAFROST) 5934 ft 2.17 12 51 1542 (3345 cu ft) 11.55 gal/sk 50.0 - 65.0 Fresh 4 hrs TAIL (CLASS Length Yield Density TOC # sacks Mix water Thickening time TOP JOB(TYPE Yield Density # sacks Mix water G' + 2% CaCI2 accelerator ) 600 ft 1.15 15.8 ppg 5934 ft 323 (371 cuft) 5 gal/sk Fresh 3.5 hrs 'E' PERMAFROST) 0.94 15.6 250 (235 cu ft) 3.7 gal/sk Fresh Production String Preflush 20 Spacer 70 Casing depth 13299 Casing size 5.5 Casing ID 4.892 Casing weight 17 Proposed TOC 8292 Bit diameter 8.5 Excess factor 1.9 Shoe track 80 Left in batch mixer 30 CIRC TEMP 135 Compress. strength 1500 250 Note: TOC design to cover the bbls Fresh water bbls NSCI SPACER ft in in Ib/ft ft in TAIL (CLASS Length Yield Density TOO # sacks ft cu.ft Deg F psi @ 180°F psi @ 80°F cretaceous interval. Thickening time G' Premium) 5007 ft 2.75 12.25 ppg 8292 ft 807 (2220 4-5 hrs @ 140°F Lab test cement/spacer/mud program to ensure compatibility before job. Ensure thickening times are adequate relative to pumping job requirement. Displace at maximum rate without inducing losses (12-15 bbl/min) cu ft) RECEIVED NIAY - 9 1995 A,!aska Oil & Gas Cons. Commission Anchors Well Plan Summary Page 4 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED ~vIAY _ 9 I99S A!~.ska 0il & Gas Cons. Commission Anchor, · Well Plan Summary Page 5 P2-34 Operations Summary 1. MIRU drilling rig. NU and function test diverter. , Spud well and drill 12-1/4" hole to 400' md. Kick off and build angle to 52.5° on 89.81° azimuth by 3555' md (3228' TVD). Hold angle to 6534' md (5052' TVD) surface hole TD. o Set 9-5/8" casing and cement same. Test casing to 3000 psi for 10 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. . P/U 8 -1/2" BHA, drill 10' new hole and perform LOT. Drill ahead and hold 52.5° to TD at _+13299', (9170' TVD) 125' md below base reservoir. Increase mud wt to 10 ppg before top of Kuparuk. If LWD logs were not obtained while drilling run wireline open hole logs. , POH and stand back drill pipe. Run 5-1/2" NT-80S liner and cement same, set liner top packer. Test casing to 4000 psi for 30 minutes. o RIH and clean out liner/displace to seawater. POH, GIH with PBR polishing mills and polish liner tieback sleeve, POH 7. Run 5-1/2" tie-back string/completion assembly. o Displace tubing to diesel, freeze protect the annulus. Sting liner tieback seals into liner top. Test tubing and annulus to 4000 psi. 9. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. 10. Secure well, release rig. POST RIG WORK 1. Run cased hole logs: cement bond log. RECEIVED fvlAY --9 1995 A~asl<a Oil & Gas Cons. Commission Anchor~ Well Plan Summary Page 6 Pt. Mcintyre P2-34 Casing Design Specifications Surface Casing 9-5/8" 47 #/ft NT80 BTC Casing BURST NT-80 687O COLLAPSE PBYS (#) TJYS (#) 4750 1,086,000 1,161,000 Burst pressure calculation Burst rating is based on shutting the well in on a gas kick equivalent to the LOT (13.5 ppg) at the surface casing shoe. LOT (ppg) TVD (ft) PRESSURE @SURFACE @ SHOE 13.5 5052 3041 Burst design factor 2.26 Minimum burst design factor 1.94 Collapse calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe. Mud weight behind the surface casing is 9.5 ppg. 3547 1.94 Mud wt (ppg) TVD (ft) Collapse press 9.5 5052 2496 Collapse design factor Tension Calculation Based on full string weight in mud 1.90 Csg wt (#/ft) MD(fi) Mud Wt (ppg) String Wt (#) 47 6530 9.5 262,396 Tension design factor PBYS TJYS 4.14 4.42 RECEIVED I'vlAY - 9 1995 Gas Cons. Commission Anch0r~ Well Plan Summary Page 7 Pt. Mclntyre P2-34 Casing Design Specifications Production Casing 5-1/2" 17 #/ft, NT80S, NSCC casing BURST COLLAPSE NT-80S 7740 6280 PBYS (#) 496,000 TJYS (#) 446,000 Burst pressure calculation Burst rating is based on a tubing leak on top of a full column of fluid. Worst case will be at TD since the internal fluid is heavier. SlTP TVD (ft) Int fluid Ext fluid Net bst. press 3480.3 9177 10.4 8.60 4339 Burst design factor 1.78 Collapse calculation Collapse rating based on completely evacuated pipe. Mud wt behind the casing is 10.4 ppg. Mud wt (ppg) TVD (ft) Collapse press 10.4 9230 4992 Collapse design factor 1.26 Tension Calculation Based on full string weight in mud Csg wt (#/ft) Length Mud Wt (ppg) String Wt (#) 17 7021 10.4 100,406 Tension design factor PBYS TJYS 4.94 4.44 R[C£1¥1ED tvl~'f - 9 1995 Gas Cons. Commission Anch0rr '" Well Plan Summary Page 8 P2-34 MW vs PP : PM2-34 E x p e c t_e_d.._?_r e__s~ _s_u_r_e__, _p_r__o_f i_l. e__ ........ !. ....................... ............................. _F..r._a_c..._.P. ~r_ .e,.s_s_u_r~_ ........ p ep.t h....( 8.65 0 ............... ~3.5 ........ _~_s.¢.p ......................... PM2-34 Expected Pressure Profile 13.5 0740 13.5 13299 13.5 13299 ......................................................................................................... ........................................................................ - .... Pore 8.55Pressure Depth0 (MD) 2000 .............................. ~_.~ ..................... z._o..~._o ...................... 9.2 9740 .................... 9.3 ..... q~-'~'~'9 ............................ 4000 ......... .............. 9.3 ...... ~'~"k"~-~ ........................... ...................................... - i_-..-'~'~__~_'~ ...... ,,_9.:_3~ .......... _1_3_2...9.9_ .................... ~ 6 0 0 0 ' ' ,ooo .- ........................................................... ~ '"~'"' ..........~ ~ ~---~ ~. ~ -.--r ~ ~ ~.-~ -.-..- ~-~-..-.-....~-. ,-~1.....~...-~ .-~-. ,-.~.~ ........ ................. ........ ?~s 9.5 9j_4fi 1 oo0o - _ 10. 0 ___ _1._2__5_.0_.0_ ................ 10.4 13299 ..... 10.4 13299 ............................................... 12000 -,-- 14000 - % ~--4'-~ ....... ,, __, ~ ........ Equivalent Mud Weight (ppg) _. ~o, ~ '~ ~ ~ "[rac Pressure" '- "Pore Pressure - Mud Weight ....... Page 1 TREE: 7"X 6" Carbon - 5M CIW WELLHEAD: 13"X 13" - 5M FMC BP Slimhole Type 2250' KOP: 400' MAX ANGLE: 52.5° @ 3080' MD 5-1/2"x 9-5/8" LINER I 6384'1 HANGER, LINER TOP PACKER 9-5/8", 47#/ft, N-80 I 6534'1 BTC - MOD PERFORATION SUMMARY: Ref Log: Size Interval SPF Open/Sqzd 13219' I PBTD 5 1/2", 17#/ft, NT-80 [ 13299'J ~ - NSCC P2-34 RT-G L = 4O' GL-SL = 12' __ 5-1/2" TRDP I 2224' 5-1/2" x 1-1/2" GLM 6334' 5.75"1D 12'Seal I 6384' I Bore Extension GAS LIFT MANDRELS (HES 5-1/2" x 1-1/2" LBRA w/dummy) N-° MD(BKB) TVDss 1 6334' 4878' NOTE: WELL IS NOT TO BE GAS LIFTED AS THE SURFACE CASING IS NOT QUALIFIED FOR THIS SERVICE IN MONOBORE WELLS ~5-1/2" 'X' NIPPLE 4.562" ID I 12809' DATE REV. BY COMMENTS 4/15/95 LF Perforated by wireline after rig release Point Mclntyre WELL-P2-34 APl NO' XX-XXX-XXXXX Prudhoe Bay Drilling VERTICAL VIEW SCALE 1000 ft. / DIVISION TVD REF: RKB VERTICAL SECTION REF: WEll,HEAD 0-- 400-- 800 -- lO00-- ii31-- 1520 3000 -- 3888 -- 4000 -- 5000 -- 5192-- 6000 -- ~000 082 =: 8000 -- 0 0 14 52 BPX-Shared Services Drilling Alaska State Plane' Zone4 ooo. oMD Structure · Pt Mac · PM2 0,00' ~a 400 MD KDP / START DF BUILD 8 1.00'/100 t$1ot ' P2-34 Wellpath ' P2 34 2,00' ~ 600 MD 4,00' ~ 800 MD START DF BUILD 8 1,50'/100 Fi; 9,00' ~ 1133 MD START DF BUILD ~ 2,00'/100 Fi; 52,50' ~ 9771 MD West Sak __J't~_ [ 13,00' e 1333 MD 17,00' 8 1533 MD END DF BUILD ~3:=~ ~ 17,00' ~ [813 MD B~se Perm~Frosi; ~ 17,00' ~ 1833 MD 229 l~ 17,00'. ~ 2119 MD START DF CURVE ~ 2,50'/[00 313 ~ 22.00 ~ 2319 MD '~ 27.00' ~ 2519 MD 2. 32,00' ~ 2719 MD [ 3~19 M5 ~ 5~,50' ~ 3539 H~ END DF CURVE 1109 3669 g 5/8 in OD, @ 6534 MD, 5052 TVD 52.50' ~ 6765 MD UG4A (K-15) 6054 oooo [ I I I -1000 0 1000 8000 VERTICAl, SECTION..PI,~NE: 89.8l -- -- ~ ~ ~ -- ~ -- ---- --U~L~-8~788517~-~-~ ................ 8810~3~~~~ '--5 1/2 in OD, @ 15299 ~, 9170 TVD 3000 4000 5000 6000 7000 8000 i · f~ 9000 Wp4 HALL IBURTDN 4/5/95 12,15 pm ee (K-lO / CH3> CRITICAL POINT DATA MD Irc IE IN O O. 00' KFIP / START 400 0.00' DF BUILD 8 t. O0'/lO0 Ft START DF BUILD 800 4,00' ~ 1,50'/100 ~t START DF BUILD 1133 9,00' 8 2.00'/100 END OF BUILD 1533 17.00' Base 1813 17,00' PermaFrost START DF 2119 17,00' CURVE 8 2.50'/100 ?t END DF CURVE 3539 52.50' UG4A <K-IS) 6765 52,50' Wes~ Sak 977l 52,50' ~eabee (K-lO / 12646 52.50' CM3> K-5 12662 52.50' HRZ 18886 58.50' Kalublk 12876 52.50' P8-34 Target 12909 52,50' 250' / Top Kuparuk ., Base Kuparuk 13245 52.50' Azl. TVD N/S E/W 89.81' 0 0 N 0 E 89,81' 400 0 N 0 E 89,81' 800 0 N 14 E 89.8l' 1131 O N' 52 89.81' 1520 89.8l' 1787 89.81' 2080 142 E 223 E t N 313 E 89.81' 3228 4 N ti09 E 89,81' 5198 12 N 3669 E 89,81' . 7082 20 N 6054 E 89.8l' 8772 28 N 8334 E 89.8l' 8782 88 N 8347 E 89.81' 8882 28 N 8478 E 89.81' 8918 28 N 8517 E 89.81' 8932 28 N 8543 E 89.81' 9137 29 N 8810 E CASING PDINT DATA OD MD Irc Azt TVD N/S E/w 9 5/8 in 6534 52 50' 89,81' 5052 12 N 3486 E 5 l/2 {n 13299 52 50' 89,8l' 9170 29 N 8853 E Tan§et N:me TVD N~ EW Gri~ X G~t~ ~ P2-34 Tange~ 250' 8932 88 N 8543 E 690140 5998580 PROPOSED BHL TVI) 9170.00 ED 13299.24 VS 8852.78 N/s 2~.~8 N E/W 8852.71E lubi !-34kT~'~-get 250' / Top Kup~r'uk tO000 SURFACE LOCATION ASP - X, 681601.06 ¥, 5998339.88 RKB Ft., 58.2' Dote . Designed by ' $.,~Yolm~ ~>~N Verified By ' 'Cerfified By ' WELL PERMIT CHECKLIST COMPANY ~NI~ cn~ss UNIT# PROGRAM: exp [] dev [] redrll [] serv~ ADMINISTRATION 1. Permit fee attached .................. - N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ....... ~ ...... N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... Y~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . .~ N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~-' N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ............... .~ ..... [~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H25 gas probable ............ ~Y~ N GEOLOGY APPR D TE Permit can be issued w/o hydrogen sulfide measures .... Y 3O. 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y// N 33. Seabed condition survey (if off-shore) /Y N 34. Contact name/phone for weekly progress reports .... ,:'~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: _ TAB~' Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ~7 7 ~ * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAM~ : P2-34 FIELD NAME : POINT MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API iVUM~ER : 50-029-22558-00 REFERENCE NO : 97209 LIS Tape ~.erification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC REEL NA~E : 97209 CONTINUATION # : PREVIOUS REEL : COI~VT : ARCO ALASKA, INC., POINT MCINTYRE P2-34, API# 50-029-22558-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC TAPE NAME : 97209 CONTINUATION # '. 1 PREVIOUS TAPE : COI~4~NT : ARCO ALASKA, INC., POINT MCINTYRE P2-34, API# 50-029-22558-00 TAPE HEADER POINT MCINTYRE MWDIMAD LOGS WELL NA~E : API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: P2-34 500292255800 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 28-MAY-97 WELL CASING RECORD 1ST STRING 2ND STRING BIT RUN 1 BIT RUN 2 BIT RUN 3 97209 97209 97209 PERRY PERRY R UM I NER JOHNSON JOHNSON JOHNSON 14 12N 14E 245 1359 52. O0 52. O0 11.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 6534.0 LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 3RD STRING PRODUCTION STRING Well drilled 8-JUL through 14-JUL-95 with CDR and CDN. Ail data was collected in three bit runs. MAD data was collected while pulling out after bit run 2. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED~!ERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUM~zARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (I4EAS~ DEPTH) START DEPTH STOP DEPTH 6502.0 13326.0 BASELINE DEPTH $ M~gGED DATA SOURCE LDWG TOOL CODE $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 2 6502.0 9007.0 1 9007.0 12341.0 2 12341.0 12906.0 3 12906.0 13326.0 NO depth adjustments were made to this data. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The CDN density data for bit run 3 (12906' - 13326') is suspect due to a stabilizer that slipped down the tool during drilling. The neutron data is ok. $ LiS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548223 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~4~548223 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~4~548223 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0P~4~548223 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD 0H~548223 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OHMM548223 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 548223 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 548223 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 548223 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 548223 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 548223 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD 548223 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 548223 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 548223 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: DEPT. 13326.000 RA.MWD ' -999.250 RP.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD CALN.MWD -999.250 NPHI.MWD -999.250 DEPT. 13000.000 RA.MWD VRP.MWD 37.120 DER.MWD GR.MWD 37.716 RHOB.MWD CALN.MWD 8.912 NPHI.MWD DEPT. 12000.000 RA.MWD VRP.MWD 4.502 DER.MWD GR.MWD 101.902 RHOB.MWD CALN. MWD 8.957 NPHI.MWD DEPT. 11000.000 RA.MWD VRP.MWD 3.018 DER.MWD GR.MWD 95.466 RHOB.MWD CALN. MWD 8.958 NPHI.MWD DEPT. 10000.000 RA.MWD VRP.MWD 3.969 DER.MWD GR.MWD 87.624 RHOB.MWD CALN.MWD 9.150 NPHI.MWD DEPT. 9000.000 RA.MWD VRP.MWD 3.174 DER.MWD GR.MWD 62.517 RHOB.MWD CALN.MWD 9.352 NPHI.MWD 39.396 RP.MWD 36.664 ROP.MWD 2.638 DRHO.MWD 20.100 4.680 RP.MWD 4.556 ROP.MWD 2.547 DRHO.MWD 26.100 3.200 RP.MWD 3.067 ROP.MWD 2.588 DRHO.MWD 29.700 4.204 RP.MWD 4.059 ROP.MWD 2.507 DRHO.MWD 32.100 -999.250 13.093 -999.250 36.296 26.412 0.504 4. 502 116.144 0.119 3.003 185.442 0.144 3. 995 50. 561 O. 149 2.876 RP.MWD 3.027 2.969 ROP.MWD -999.250 2.370 DRHO.MWD 0.079 31.300 DEPT. 8000.000 RA.MWD 1.707 RP.MWD 2.026 VRP.MWD 1.978 DER.MWD 1.875 ROP.MWD -999.250 GR.MWD 60.157 RHOB.MWD -999.250 DRHO.MWD -999.250 CALN. MWD -999.250 NPHI.MWD -999.250 DEPT. 7000.000 RA.MWD VRP.MWD 3.184 DER.MWD GR.MWD 96.502 RHOB.MWD CALN. MWD -999.250 NPHI.MWD 3.734 RP.MWD 3.224 3.366 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 -999.250 RP.MWD -999.250 -999.250 ROP.MWD -999.250 -999.250 DRHO.MWD -999.250 -999.250 DEPT. 6502.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 41.617 RHOB.MWD CALN. MWD -999.250 NPHI.MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF.MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET. MWD PEF.MWD VRA . MWD FET. MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF.MWD VRA . MWD FET.MWD PEF. MWD -999.250 -999.250 -999.250 40.097 0.000 1.457 4. 636 O. 000 3.248 3.095 0.000 3.606 4.136 0.000 3.989 3.112 -999.250 3.535 1.739 -999.250 -999.250 3.613 -999.250 -999.250 -999.250 -999.250 -999.250 ** F_ArD OF DATA ** LIS Tape ~erification Listing Schlumberger Alaska Computing Center 28-MAY-1997 PAGE: **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUI4~ER: 2 EDITED I4ERGEDMAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SU~4MARY LDWG TOOL CODE $ I4ERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: This is the merged, clipped MADpass data acquired after bit run 2. $ START DEPTH STOP DEP~W 9150.0 6502.0 MAD RUNNO. MAD PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548223 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OHlV1~548223 O0 000 O0 0 2 1 RP MAD 0HN~548223 O0 000 O0 0 2 1 VRA MAD 0F24~548223 O0 000 O0 0 2 1 VRP MAD 0H~4~I548223 O0 000 O0 0 2 1 DER MAD 0F24~548223 O0 000 O0 0 2 1 ROP MAD FPHR 548223 O0 000 O0 0 2 1 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 GR MAD GAPI 548223 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9150.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 126.712 GR.MAD -999.250 DEPT. 9000.000 RA.MAD VRP.MAD 3.174 DER.MAD 2.834 RP.MAD 3.457 VRA.MAD 3.178 ROP.MAD 1183.718 GR.MAD 3.112 74.249 DEPT. 8000.000 RA.MAD 1.707 RP.MAD 2.026 VRA.MAD VRP.MAD 1.978 DER.MAD 1.875 ROP.MAD 674.865 GR.MAD 1.739 60.157 DEPT. 7000.000 RA.MAD 3.734 RP.MAD 3.224 VRA.MAD 3.613 VRP.MAD 3.184 DER.MAD 3.366 ROP.MAD 1152.352 GR.MAD 96.502 LIS Tape ~erification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: DEPT. 6502.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 GR.MAD 41.617 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE . 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJM~ER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y LDWG TOOL CODE START DEPTH ......................... MAD 9150.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH .......... 6502.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD This is the merged, clipped MAD pass data acquired after bit run 2. $ LIS Tape verification Listing Schlumberger Alaska Computing Center 28-1~*Y-1997 10:44 PAGE: 8 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 32 66 1 0.5 FT 32 0 FT 68 1 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 548223 O0 000 O0 0 3 1 1 4 68 0000000000 RA MAD 0H~I548223 O0 000 O0 0 3 1 1 4 68 0000000000 RP MAD 0H~I548223 O0 000 O0 0 3 1 1 4 68 0000000000 VRA MAD 0H~548223 O0 000 O0 0 3 1 1 4 68 0000000000 VRP MAD 0H~I548223 O0 000 O0 0 3 1 1 4 68 0000000000 DER MAD 0P~4~548223 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAD FPHR 548223 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAD GAPI 548223 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9150.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 126.712 GR.MAD -999.250 DEPT. 9000.000 RA.MAD 2.834 RP.MAD 3.457 VRA.MAD 3.112 VRP.MAD 3.174 DER.MAD 3.178 ROP.MAD 1183.718 GR.MAD 74.249 LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: DEPT. 8000.000 RA.MAD 1.707 RP.MAD 2.026 VRP.MAD 1.978 DER.MAD 1.875 ROP.MAD 674.865 DEPT. 7000.000 RA.MAD VRP.MAD 3.184 DER.MAD 3.734 RP.MAD 3.224 3.366 ROP.MAD 1152.352 DEPT. 6502.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 GR.MAD 1.739 60.157 3. 613 96. 502 -999.250 41. 617 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA24~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE ~ER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUFiBER: 1 DEPTH INCRE~E1TT: 0.5000 FILE SUMPIARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8892.0 12341 . 0 $ LOG HEADER DATA DATE LOGGED: 14 -JUL- 95 SOFTWARE: SURFACE SOFTWARE VERSION: FAST2.5 DOWNHOLE SOFTWARE VERSION: 4. OC LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 10 DATA TYPE (I~MORY or REAL-TI~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: MEMORY 13326.0 6502.0 13326.0 70 49.7 53.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ TOOL NUMBER RGS022 NDS055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : 8.500 6534.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT f4~ASURED TEMPERATURE (MT): 2.195 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. O10 MUD CAKE AT (MT): 72.0 72.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: **** RUN1 DRILLED 9007' - 12341'**** RES TO BIT: 55.47'; GR TO BIT: 65.89' NEUT TO BIT: 115.52'; DENS TO BIT: 108.36' **** RUN2 DRILLED 12341' - 12906'**** MAD PASS DATA (CDR ONLY) 9007'- 6534' TO BIT:RES 55.17';GR 65.59';DEN 109.24';NEU 116.4' **** RUN3 DRILLED 12906' - 13226'**** TO BIT:RES 43.19';GR 53.61';DEN 97.26';NEU 104.42' $ LIS FORMAT DATA LIS Tape verification Listing Schlumberger Alaska Computing Center 28-N~Y-1997 10:44 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEPI CODE (HEX) DEPT FT 548223 O0 000 O0 0 4 1 1 4 68 0000000000 RA LW1 0I{~I548223 O0 000 O0 0 4 1 1 4 68 0000000000 RP LW1 0~548223 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW1 0PI~4l~548223 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 FPHR 548223 O0 000 O0 0 4 1 1 4 68 0000000000 FET LW1 HR 548223 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 548223 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW1 G/C3 548223 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LWl G/C3 548223 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LWl 548223 O0 000 O0 0 4 1 1 4 68 0000000000 CALNLW1 IN 548223 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 548223 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12340. 500 RA. LW1 ROP. LW1 31. 803 FET. LW1 DRHO . LW1 - 999.250 PEF. LW1 -999. 250 RP. LW1 - 999. 250 GR. LW1 -999. 250 CALN. LW1 - 999. 250 DER. LW1 -999. 250 -999. 250 RHOB. LW1 -999. 250 - 999. 250 NPHI. LW1 -999. 250 LES Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 12 DEPT. 12000. 000 RA. LWl ROP. LW1 116.144 FET. LW1 DRHO . LWl O . 119 PEF. LW1 DEPT. 11000. 000 RA. LW1 ROP. LW1 185. 442 FET. LW1 DRHO. LW1 O . 144 PEF. LW1 DEPT. 10000. 000 RA. LW1 ROP. LW1 50. 561 FET. LW1 DRHO . LW1 O . 149 PEF. LW1 DEPT. 9000. 000 RA. LW1 ROP. LW1 -999. 250 FET. LW1 DRHO. LW1 0. 079 PEF. LW1 4. 680 RP. LW1 O. 469 GR. LW1 3.248 CALN. LW1 3. 200 RP. LW1 O. 447 GR. LW1 3.606 CALN. LW1 4.204 RP. LW1 1. 028 GR. LW1 3. 989 CALN. LW1 2. 876 RP. LW1 -999. 250 GR. LW1 3. 535 CALN. LW1 DEPT. 8892. 000 RA. LW1 -999. 250 RP. LW1 ROP . LW1 -999. 250 FET. LW1 -999. 250 GR. LW1 DRHO. LW1 -999. 250 PEF. LW1 -999. 250 CALN. LW1 4.502 DER.LW1 1 O1 . 902RHOB. LW1 8. 957 NPHI. LW1 3. 003 DER. LW1 95.466 RHOB. LW1 8. 958 NPHI. LW1 3. 995 DER. LW1 87. 624 RHOB. LW1 9.150 NPHI.LW1 3.027 DER.LW1 62.517 RHOB. LW1 9.352 NPHI.LW1 - 999. 250 DER. LW1 - 999. 250 RHOB. LWl - 999. 250 NPHI. LW1 4. 556 2.547 26.100 3. 067 2.588 29. 700 4. 059 2.507 32.100 2. 969 2.370 31.300 -999.250 -999.250 30.600 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCRE~iENT: O. 5000 FILE SOFflV~tRY LiS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 13 VENDOR TOOL CODE START DEPTH LOG HEADER DATA 12168.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (FiE~ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): STOP DEPTH 12906.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OP~4~) AT TEMPERATURE (DEGF): MUD AT M~ASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 14-JUL-95 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): FAST2.5 4.0C MEMORY 13326.0 6502.0 13326.0 70 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 47.4 52.5 TOOL NUMBER ........... RGS059 NDS055 8.500 6534.0 LSND 10.00 500 2.195 72.0 2. O10 72.0 **** RUN1 DRILLED 9007' - 12341'**** RES TO BIT: 55.47'; GR TO BIT: 65.89' NEUT TO BIT: 115.52'; DENS TO BIT: 108.36' **** RUN2 DRILLED 12341' - 12906'**** 1.0 20000 SANDSTONE 2.65 LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 14 MAD PASS DATA (CDR ONLY) 9007 ' - 6534 ' TO BIT:RES 55.17';GR 65.59';DEN 109.24';NEU 116.4' **** RUN 3 DRILLED 12906' - 13226'**** TO BIT:RES 43.19';GR 53.61';DEN 97.26' ;NEU 104.42' $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548223 O0 000 O0 0 5 1 1 4 68 0000000000 RA LW2 0H~4548223 O0 000 O0 0 5 1 1 4 68 0000000000 RP LW2 OHPE4548223 O0 000 O0 0 5 1 1 4 68 0000000000 DER LW2 0P~414548223 O0 000 O0 0 5 1 1 4 68 0000000000 ROP LW2 FPHR 548223 O0 000 O0 0 5 1 1 4 68 0000000000 FET LW2 HR 548223 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW2 GAPI 548223 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB LW2 G/C3 548223 O0 000 O0 0 5 1 1 4 68 0000000000 DRHO LW2 G/C3 548223 O0 000 O0 0 5 1 1 4 68 0000000000 PEF LW2 548223 O0 000 O0 0 5 1 1 4 68 0000000000 CALNLW2 IN 548223 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI LW2 PU-S 548223 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape verification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 15 * * DATA * * DEPT. 12906. 000 RA. LW2 -999. 250 RP. LW2 ROP. LW2 12. 228 FET. LW2 -999. 250 GR. LW2 DRHO. LW2 -999. 250 PEF. LW2 - 999. 250 CALN. LW2 DEPT. 12167. 500 RA. LW2 -999. 250 RP. LW2 RO P . LW2 -999. 250 FET. LW2 - 999. 250 GR. LW2 DRHO.LW2 -999.250 PEF.LW2 -999.250 CALN. LW2 -999.250 DER.LW2 -999.250 RHOB.LW2 -999.250 NPHI.LW2 -999.250 DER.LW2 -999.250 RHOB.LW2 -999.250 NPHI.LW2 -999.250 -999.250 -999.250 -999.250 -999.250 27.100 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NANiE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUNiBER: 3 DEPTH INCREMEa~T: 0.5000 FILE SUF24ARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 12777.0 13326.0 $ LOG HEADER DATA DATE LOGGED: 14-JUL-95 SOFTWARE: SURFACE SOFTWARE VERSION: FAST2.5 DOWNHOLE SOFTWARE VERSION: 4. OC LIS Tape vwrification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 16 DATA TYPE (MEMORY or REAL-TIM~) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: MEMORY 13326.0 6502.0 13326.0 70 48.7 49.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ TOOL NUMBER ........... RGS059 NDS055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 6534.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT M~ASURED TEMPERATURE (MT): 2. 195 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. O10 MUD CAKE AT (MT): 72.0 72.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: **** RUN 1 DRILLED 9007' - 12341'**** RES TO BIT: 55.47'; GR TO BIT: 65.89' NEUT TO BIT: 115.52'; DENS TO BIT: 108.36' **** RUN 2 DRILLED 12341' - 12906'**** MAD PASS DATA (CDR ONLY) 9007 ' - 6534 ' TO BIT:RES 55.17';GR 65.59';DEN 109.24';NEU 116.4' **** RUN 3 DRILLED 12906' - 13226'**** TO BIT:RES 43.19';GR 53.61 ';DEN 97.26' ;NEU 104.42' DENSITY DATA FROM RUN 3 SUSPECT DUE TO SLIPPED STAB. $ LIS FORMAT DATA LiS Tape ~ ~rification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548223 O0 000 O0 0 6 1 1 4 68 0000000000 RA LW3 0H2~I548223 O0 000 O0 0 6 1 1 4 68 0000000000 RP LW3 0t~4548223 O0 000 O0 0 6 1 1 4 68 0000000000 DER LW3 OH2~q548223 O0 000 O0 0 6 1 1 4 68 0000000000 ROP LW3 FPHR 548223 O0 000 O0 0 6 1 1 4 68 0000000000 FET LW3 HR 548223 O0 000 O0 0 6 1 1 4 68 0000000000 GR LW3 GAPI 548223 O0 000 O0 0 6 1 1 4 68 0000000000 RHOB LW3 G/C3 548223 O0 000 O0 0 6 1 1 4 68 0000000000 DRHO LW3 G/C3 548223 O0 000 O0 0 6 1 1 4 68 0000000000 PEF LW3 548223 O0 000 O0 0 6 1 1 4 68 0000000000 CALNLW3 IN 548223 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI LW3 PU-S 548223 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13326. 000 RA. LW3 -999. 250 RP. LW3 -999. 250 DER. LW3 ROP.LW3 13.093 FET. LW3 -999.250 GR.LW3 -999.250 RHOB.LW3 DRHO.LW3 -999.250 PEF. LW3 -999.250 CALN. LW3 -999.250 NPHI.LW3 -999.250 -999.250 -999.250 LZS Tape ~rification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 18 DEPT. 13000. 000 RA. LW3 ROP. LW3 26. 412 FET. LW3 DRHO . LW3 0.504 PEF. LW3 39. 396 RP. LW3 1. 476 GR. LW3 1. 457 CALN. LW3 DEPT. 12776. 500 RA. LW3 -999. 250 RP. LW3 ROP. LW3 -999. 250 FET. LW3 -999. 250 GR. LW3 DRHO. LW3 -999. 250 PEF. LW3 -999 . 250 CALN. LW3 36. 296 DER. LW3 37. 716 RHOB.LW3 8.912 NPHI.LW3 -999. 250 DER. LW3 -999. 250 RHOB. LW3 -999. 250 NPHI. LW3 36. 664 2. 638 20.100 -999.250 -999.250 49.100 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUP~IARY VENDOR TOOL CODE START DEPTH MAD 9150.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (FiEMORY or REAL-TIME): STOP DEPTH 6502.0 14-JUL-95 FAST2.5 4. OC MEMORY LIS Tape .~rification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 19 TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 13326.0 6502.0 13326.0 49.9 54.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ TOOL NUMBER RGS059 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 6534.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT M~ASURED TEMPERATURE (MT): 2. 195 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. O10 MUD CAKE AT (MT): 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: **** RUN 1 DRILLED 9007' - 12341'**** RES TO BIT: 55.47'; GR TO BIT: 65.89' NEUT TO BIT: 115.52'; DENS TO BIT: 108.36' **** RUN2 DRILLED 12341' - 12906'**** MAD PASS DATA (CDR ONLY) 9007'- 6534' TO BIT:RES 55.17';GR 65.59';DEN 109.24';NEU 116.4' **** RUN3 DRILLED 12906' - 13226'**** TO BIT:RES 43.19';GR 53.61';DEN 97.26';NEU 104.42' $ LIS FORMAT DATA LIS Tape . =rification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548223 O0 000 O0 0 7 1 1 4 68 0000000000 ATR MAi 0Pk4~548223 O0 000 O0 0 7 1 1 4 68 0000000000 PSR MAi OPIM~548223 O0 000 O0 0 7 1 1 4 68 0000000000 DER MAi 0Pi~548223 O0 000 O0 0 7 1 1 4 68 0000000000 ROPE MA1 F/HR 548223 O0 000 O0 0 7 1 1 4 68 0000000000 GR MAi GAPI 548223 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. ROPE. MAi 9150. 000 ATR.MA1 -999. 250 PSR.MA1 126. 712 GR .MAI -999. 250 DEPT. 9000.000 ATR~MA1 2.834 PSR.MA1 ROPE.MAi 1183.718 GR.MA1 74.249 DEPT. 8000.000 ATR.MA1 1.707 PSR.MA1 ROPE.MAi 674.865 GR.MA1 60.157 DEPT. 7000.000 ATR.MA1 3.734 PSR.MA1 ROPE.MAi 1152.352 GR.MA1 96.502 -999.250 DER.MAi -999.250 3. 457 DER.MAi 3. 178 2.026 DER.MAI 1.875 3.224 DER.MA1 3.366 LrS Tape v~rification Listing Schlumberger Alaska Computing Center 28-MAY-1997 10:44 PAGE: 21 DEPT. 6502. 000 ATR .MAi -999. 250 ROPE. MAi -999. 250 GR. MAI 41.617 PSR . MAI -999. 250 DER .MAI -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 97/05/28 ORIGIN : FLIC TAPE NAME : 97209 CONTINUATION # : 1 PREVIOUS TAPE : COA94~NT : ARCO ALASKA, INC., POINT MCINTYRE P2-34, API# 50-029-22558-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/05/28 ORIGIN : FLIC REEL NAME : 97209 CONTINUATION # : PREVIOUS REEL : COFk4~al~f : ARCO ALASKA, INC., POINT MCINTYRE P2-34, API# 50-029-22558-00