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Home My WebLink About204-243MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:14 Township:10N Range:14E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:11783 ft MD Lease No.:ADL0028315 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 119 Feet Csg Cut@ na Feet Surface:13 3/8"O.D. Shoe@ 2525 Feet Csg Cut@ na Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ na Feet Production:9 5/8"O.D. Shoe@ 10103 Feet Csg Cut@ na Feet Liner1:7"O.D. Shoe@ 10213 Feet Csg Cut@ na Feet Liner2:see remarks O.D. Shoe@ 11783 Feet Csg Cut@ na Feet Tubing:5 1/2" x 4 1/2"O.D. Tail@ 9822 Feet Tbg Cut@ na Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bottom 11,500 ft 9364 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 2739 2601 2548 IA 149 157 154 OA 0 0 0 Remarks: Attachments: Rich Newman Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to PBU 13-24A to witness a cement plug tag and pressure test. Rich Newman was the Hilcorp representative on the job. They tagged top of cement @ 9,364 ft MD (9,344 ft SLD) with a tool string consisting of 2 1/8" weight bar (8ft), 1 3/4" oil jars, 1 7/8" knuckeled spangs, and a 2 1/2" sample bailer (3 ft); 210lb hanging weight. The sample bailer came back with a good bit of mostly set-up cement with some softer interface up top. Pressure test after tag. Liner2: 3 1/2" x 3 3/16" x 2 7/8" mixed string. June 11, 2024 Adam Earl Well Bore Plug & Abandonment PBU 13-24A Hilcorp North Slope LLC PTD 2042430; Sundry 324-211 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0611_Plug_Verification_PBU_13-24A_ae                Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240419 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 4/5/2024 AK E-Line Perf BRU 242-04 50283201640000 212041 3/20/2024 AK E-Line JB/PProf NCIU A-17 50883201880000 223031 3/27/2024 AK E-Line GPT/Perf PBU 05-02A 50029201440100 201241 4/6/2024 Halliburton PPROF PBU 09-35A 50029213140100 193031 4/9/2024 Halliburton RBT PBU 13-24A 50029207390100 204243 4/5/2024 Halliburton RBT PBU B-14A 50029203490100 209059 4/2/2024 Halliburton RBT PBU D-31B 50029226720200 212168 4/7/2024 Halliburton PERF SRU 222-33 50133207150000 223100 3/27/2024 AK E-Line CIBP/Perf SRU 224-10 50133101380100 222124 3/29/2024 AK E-Line CIBP/Perf SRU 241-33B 50133206960000 221053 4/2/2024 AK E-Line CIBP Please include current contact information if different from above T38718 T38719 T38720 T38721 T38722 T38723 T38724 T38725 T38726 T38727 T38728 PBU 13-24A 50029207390100 204243 4/5/2024 Halliburton RBT Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.19 14:54:13 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 13-24A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-243 50-029-20739-01-00 ADL 0028311 , 0028315 11783 Conductor Surface Production Liner Liner 9066 79 2491 10070 421 2002 11747 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9040 40 - 119 39 - 2525 38 - 10103 9792 - 10213 9781 - 11783 2363 40 - 119 39 - 2530 38 - 8772 8509 - 8861 8548 - 9066 11550 470 2670 4760 7020 11160 none 1490 5380 6870 8160 10570 11100 - 11500 5-1/2" 17# x 4-1/2" 12.6# L-80 98228934 - 8932 Structural 5-1/2" BOT 3-H No SSSV 9706 8438 Date: Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY 4/25/24 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:23 pm, Apr 10, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.04.10 13:41:27 - 08'00' Bo York (1248) MGR15APR24 DSR-4/12/24SFD 4/10/2024 10-407 * State to witness slickline tag of TOC in tubing no deeper than 10,100' MD but expected to place TOC at ~9890' MD. * State to witness MIT-T to 2500 psi. JLC 4/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.16 16:21:42 -04'00'04/16/24 RBDMS JSB 041624 RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Well Name:13-24A Permit to Drill:2042430 Current Status:PWI injector, Not Operable API Number:50-029-20739-01 Estimated Start Date:4/25/2023 Estimated Duration:6days Regulatory Contact:Carrie Janowski 907-575-7336 First Call Engineer:Jerry Lau 907-360-6233 Second Call Engineer:Oliver Sternicki 907-350-0759 Current Bottom Hole Pressure:3243 psi @ 8,800’ TVD (average BHP at DS13 since 2019) Max. Anticipated Surface Pressure:2363 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:100 psi Min ID:2.44” @ 10,989’ MD Max Angle:101 deg @ 10,478’ MD Well History: 13-24 was drilled and completed as a producer in May 1982 as a Z4 PWI/SWI injector then become a PWI/SWI/MI injector in Jan 1991. Sag perfs were added in Jan 1992 with comingled injection into Z4. In Dec 2004, all perfs were cement squeezed and a whipstock was set in preparation for a CTD ST. In Jan 2005, the 13-24A CTD ST was completed as a WAG injector with Z4 perforations. After failing an MIT-IA in June 2009, an LDL found a PKR leak, which was remediated with a packer cement squeeze in Oct 2010. High IAP post packer squeeze was managed by monthly bleeds and further mitigated by an April 2011 AA for TxIA comm that required the injector be on PWI only. PWI was stopped in 2015 to reduce water cut in offset injectors. The well was used only as a pit dewatering injector from 2017-19 then was shut in. Justification for Reservoir P&A: In 2023, 13-24A was identified as a donor candidate for a rotary sidetrack WAG injector. It will be used as injection support for the development of the southern periphery sag waterflood. The tight rock of the sag waterflood requires injection to attain an economic oil recovery from the Sag reservoir. March 2024 wellhead screening and a passing CMIT-TxIA to 4000 psi to test the integrity of the 9-5/8” production casing determined that a rotary sidetrack is mechanically feasible. A reservoir P&A is required in preparation for the Hilcorp Innovation rig to drill a rotary sidetrack. Only DPZ1 and DPZ3 are present in the subsurface. A continuous lateral cement plug is targeted from the top off the Sag River formation (top of DPZ3) to more than 100’ MD above. All parent wellbore perfs were squeezed prior to the 13-24A CTD sidetrack. The CTD liner lap passed an initial pressure test, then passed another pressure test above 4000 psi in March 2024. For further verification, a cement bond log was run in April 2024 and found TOC in CTD liner lap @ 9890’. Objectives: The intent of this program is to perform a reservoir P&A of the well per 20 AAC 25.112 and cut TBG in preparation for a rotary sidetrack with planned KOP @ ~6000’ MD. RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. Wellhead: 1. PPPOT-T to 5000 psi (complete, passed on 3/6/24) 2. PPPOT-IC to 3500 psi (complete, passed on 3/12/24) Slickline / Fullbore: 1. Set 3-1/2” XX Plug in CTD LNR X Nip @ 9801’ MD (complete, 3/8/24) 2. Perform CMIT TxIA to 4000 psi against Plug in CTD deployment sleeve to verify integrity of CTD liner lap and 9-5/8” PC.(complete, passed to 4120 psi on 3/9/24) 3. Pull 3-1/2” XX Plug from CTD LNR X Nip @ 9801’ MD (complete, 3/9/24) 4. Memory CBL to identify liner lap TOC (complete, 4/6/24, TOC @ 9890’ MD) Fullbore: 1. Pump Injectivity Test, Bullhead into reservoir. x 5 bbls MeOH x 360 bbls 1% KCL or SW x Freeze protect w/ 58 bbls diesel (only necessary if cementing is not immediately following injectivity test.) x Max pressure 2650 psi 2. Pump Reservoir Abandonment plug, TOC is planned at ~9400’ MD, above PKR squeeze. Bullhead into the reservoir as follows: x 5 bbls MeOH x 10 bbls fresh water x 22 bbls 14-15.8 class G cement (3.8 bbls excess) x 5 bbls freshwater x Foam Ball x 220 bbls warm diesel displacement (75degF). x Max pressure 2650 psi Cement Type/weight:Class G 14-15.8 ppg Bottom hole temp:209°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Cement Volumes: cap top btm vol size bpf MD'MD bbls 2-7/8"0.0058 10989 11500 2.96 3-3/16"0.0076 9840 10989 8.73 3-1/2"0.0087 9781 9840 0.51 4-1/2"0.0152 9717 9781 0.97 5-1/2"0.0232 9500 9717 5.03 Excess ---3.80 Total ---22.0 Displacement: cap top btm vol size bpf MD'MD bbls 5-1/2"0.0232 0 9500 220 Fullbore 1. WOC 3 days, MIT-T to 2500 psi target pressure–AOGCC Witnessed. Slickline 1. Drift and tag to TOC –AOGCC Witnessed. Eline: 1. Punch 5.5” tubing from ~9385-9390’ MD. Adjust depth to punch across a tubing collar. See attached tubing tally. Depths may change if TOC from cement plug comes in high. A. Use 0° phase, decentralized, oriented to low side, rated for 5.5”, 17#, L-80 tubing. B. Apply 1000 psi to 5.5” prior to perforating, record before/after pressures. C. Note any pressure changes. 2. Jet Cut 5.5” tubing @ ~9350’. Adjust depth to cut 2’ below a tubing collar. Depths may change if TOC from cement plug comes in high. A. Use cutter rated for 5.5”, 17#, L-80 tubing. B. Pressure Test TxIA to 1000 psi for 5 minutes. RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Current Wellbore Schematic RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Proposed Reservoir P&A with TBG cut, TBG punch, DPZ detail, and cement detail included RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Tubing Tally RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Halliburton Radial Bond Log CBL 04/05/24. Liner Lap TOC picked at 9,890’ MD RST Res P&A Sundry Well:13-24A PTD:204-243 API:50-029-20739-01 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Operations Manager Date Operations Engineer Date Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 2042430 PBU 13-24A SFD 4/10/2024 324211 SFD 4/10/2024 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Saturday, November 21, 2020 10:34 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; Alaska NS - PB - Field Well Integrity Subject: NOT OPERABLE: Injector 13-24A (PTD #2042430) will lapse on AOGCC MIT -IA Mr. Wallace, Injector 13-24 (PTD #2042430) operates under AA AIO 4E.037 and is due for its 2 -year AOGCC witnessed MIT -IA by the end of November. There are currently no plans to put the well on injection and it will lapse on the AOGCC MIT -IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity /Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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. ('N't 13- 24 A Pit ZM 2,430 Regg, James B (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Friday, May 31, 2019 8:14 AM ISI I (� To: Regg, James B (CED) %(y�( Cc: Brooks, Phoebe L (CED); Wallace, Chris D (CED); AK, GyVO Well Integrity Well Information; AK, GWO SUPT Well Integrity; AK, GWO Projects Well Integrity Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Attachments: MIT PBU 13-24A 05-26-19.xlsx Mr. Regg, After reviewing the well service report it appears that they shut down the pumping during the initial loading operation and bleed 2bbls off the IA. They then resumed pumping operations and pumped a total of 14.23bbls. The discrepancy between the 14bbls reported on the MIT form and 12.2 bbls reported in the previous email is the net difference in the total bbls pumped and what was bled off during the operation. I believe the intent of the bbls tracking in the MIT form is to capture how much fluid it took to reach test pressure and how much fluid was bleed off after the test. If this assumption is correct the volumes are 12.23 bbls pumped and 4.6 bbls returned. I have updated the MIT form to reflect this and it is attached for review. The MIT form will also be submitted in the monthly report in the next few days. Please let me know if you have any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: Regg, James B (CED) <jim.regg@alaska.gov> Sent: Thursday, May 30, 2019 3:47 PM To: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Cc: Brooks, Phoebe L (CED) <phoebe.brooks @alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Your email (5/28, 221 pm) indicates it took 12.2 bbl to start the MIT -7 bbls to catch pressure, and 5.2 bbl to pressure up from 2 psi to 2587 psi. The MIT Notes section indicates "Total pumped 14 bbls" for the MIT. That is the reason why our Inspector deemed the test "Inconclusive". Which volume pumped is correct -12.2 or 14 bbl? Please revise/resubmit the MIT report with the correct volume pumped for the test, change test result to "P", and include the following in the Notes: "Test result changed from Inconclusive to Pass by AOGCC Inspection Supervisor J. Regg based on information provided by BPXA in follow-up emails 5/27/19 and 5/28/19." Based on the evidence provided in your emails and the test report, BPXA may continue to use PBU 13-24A for injection 7 in accordance with AIO 4E.037. J1r— Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reee@alaska.eov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 30, 2019 3:08 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Mr. Regg, The 10-426 is attached. Please let me know if you need any additional information. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: Regg, James B (CED) <jim.regg[a)alaska.goy> Sent: Thursday, May 30, 2019 2:34 PM To: AK, GWO Well Integrity Engineer <AKGWOWelISiteEnginee@bp.com> Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Submit the MIT report. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.rege@alaska.aov. From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Tuesday, May 28, 2019 2:21 PM To: Regg, James B (CED) <iim.regg@alaska.gov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator(@bp.com>; AK, GWO Projects Well Integrity <AKDCProiectsWelllntegrityEngineer@bp.com>; AK, GWO Well Integrity Well Information <a kgwowe I I i ntegritywe @ b p.com> Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Mr. Regg, I wanted to clarify a couple of items from my previous email: 1. It took approximately 7 bbls of fluid to catch pressure which indicates there was a 7 bbl void. 2. Upon catching pressure, it took 5.2 bbls to pressure up from 2 psi to a test pressure of 2,587 psi. 3. After the passing AOGCC MIT -IA, the IA pressure was bled back to 200 psi which returned 4.6 bbls 4. After the well was shut it, it was estimated 6-8 bbls was bled from the [Awhile the pressure stabilized. Please let me know if you have any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization — Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, May 27, 2019 4:37 PM To: 'Regg, James B (DOA) (dim.regg@alaska.gov)' <iim.regg@alaska.gov> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, GWO Projects Well Integrity<AI<DCProiectsWelllntegrityEngineer@bp.com> Subject: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Mr. Regg, Injector 13-24 (PTD # 2042430) operates under AIO 4E.037 for water only injection with TxIA communication. The well i< mainly used as an injector to support field dewatering operations. It was made Not Operable on 11/11/18 for lapsing on its 2 -year AOGCC MIT -IA. On 03/20/19 in anticipation of the upcoming dewatering season, BP performed a passing MIT - IA to 1,984 psi prior to bringing the well online and scheduling an AOGCC witnessed MIT -IA. The well was reclassified Operable and put on injection for de -watering on 05/24/19. BP did not shoot a fluid level or fill the inner annulus after the well was online. BP believes the cool temperature of the water injected during dewatering operations created fluid and tubular shrinkage, which in turn created a void in the inner annulus. Before the AOGCC witnessed MIT -IA passed to 2,505 psi, it took approximately 7 bbl of fluid to reach test pressure. The inspector on location called the test inconclusive because of the fluid volume required to reach test pressure. After the test was deemed inconclusive, BP shut the well in. After the well was shut in, the tubing went on a vacuum and the tubing fluid level dropped out to approximately 1,100' MD, but the IA pressure increased as the well returned to static temperature. Over 6 bbl of fluid was bled from the IA to manage the increasing pressure, after which the IA pressure stabilized. These observations support the theory of thermal shrinkage. Based on the passing AOGCC MIT -IA, and the above observations, BP seeks your approval to continue injection on this well. Please respond at your earliest convenience. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Thursday, May 23, 2019 9:32 AM To: 'ch ris.walace @alaska.gov' <chris.waIface (ED alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead (ED bp.com>; Ak, OPS FS3 Facility PTL <AKOPSFS3FacilityPTL@bp.com>; Ak, OPS FS3 Field PTL <AKOPSFS3Field PTL@bp.com>; AK, OPS FS3 OSM <AKOPSFS30SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Brown, Don L. <browd2@BP.com>; De la Cruz, Paulina <paaulina.meixueiro@bp.com>; G GPB FS3 Drillsites <ggpbfs3drillsites2BP.com>; Vandergon, Mark A <Mark.Vandergon@bp.com>; Vohra, Prachi <Prachi.Vohra@bp.com> Cc:'Regg, James B (DOA) (iim.regg@alaska.gov)' <iim regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProiectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras 1 <Aras Worthington bp.com> Subject: OPERABLE: Injector 13-24A (PTD #2042430) is due for AOGCC MIT -IA W Injector 13-24 (PTD #2042430) operates under AID 4E.037 for water only injection. It was made Not Operable on 11/11/18 for lapsing on its AOGCC required 2 -year MIT -IA. The well is going to be used for the upcoming de -watering season and is ready for injection. It is now classified as OPERABLE. An AOGCC witnessed MIT -IA will be scheduled when the well is thermally stable. Please respond with any question. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, May 31, 2019 8:14 AM To: Regg, James B (CED) Cc: Brooks, Phoebe L (CED); Wallace, Chris D (CED); AK, GWO Well Integrity Well Information; AK, GWO SUPT Well Integrity; AK, GWO Projects Well Integrity Subject: RE: Injector 13-24A (PTD #2042430) AOGCC MIT -IA follow up Attachments: MIT PBU 13-24A 05-26-19.xlsx Mr. Regg, After reviewing the well service report it appears that they shut down the pumping during the initial loading operation and bleed 2bbls off the IA. They then resumed pumping operations and pumped a total of 14.23bbls. The discrepancy between the 14bbls reported on the MIT form and 12.2 bbls reported in the previous email is the net difference in the total bbls pumped and what was bled off during the operation. I believe the intent of the bbls tracking in the MIT form is to capture how much fluid it took to reach test pressure and how much fluid was bleed off after the test. If this assumption is correct the volumes are 12.23 bbls pumped and 4.6 bbls returned. I have updated the MIT form to reflect this and it is attached for review. The MIT form will also be submitted in the monthly report in the next few days. Please let me know if you have any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: Re James B (CED) <jim.regg@alaska.gov> Sent: Thursda ay 30, 2019 3:47 PM To: AK, GWO Well In rity Engineer <AKGWOWellSiteEnginee@bp.com> Cc: Brooks, Phoebe L (CEDE Subject: RE: Injector 13-24A Dalaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> AOGCC MIT -IA follow up Your email (5/28, 221 pm) indicates it took 1f1bbl to start the MIT— 7 bbls to catch pressure, and 5.2 bbl to pressure up from 2 psi to 2587 psi. The MIT Notes section indicates "Total pumped 14 bbls" for the MIT. That is the reason why our Inspector deemed the test "Inconclusive". Which volume -pumped is correct -12.2 or 14 bbl? Please revise/resubmit the MIT report with the correct volume pumpedfor the test, change test result to "P", and include the following in the Notes: "Test result changed from Inconclusive to Pass by AOGCC Inspection Supervisor J. Regg based on information provided by BPXA in follow-up emails 5/27/19 and 5/28/19." Based on the evidence provided in your emails and the test report, BPXA may continue to use PBtI 13-24A for injection in accordance with AIO 4E.037. Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, May 28, 2019 2:21 PM To: Regg, James B (CED) Cc: Wallace, Chris D (CED); AK, GWO SUPT Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Well Integrity Well Information Subject: RE: Injector 13-24A (PTD #20424301 AOGCC MIT -IA follow up Mr. Regg, I wanted to clarify a couple of items from my previous email: 1. It took approximately 7 bbls of fluid to catch pressure which indicates there was a 7 bbl void. 2. Upon catching pressure, it took 5.2 bbls to pressure up from 2 psi to a test pressure of 2,587 psi. 3. After the passing AOGCC MIT -IA, the IA pressure was bled back to 200 psi which returned 4.6 bbls 4. After the well was shut it, it was estimated 6-8 bbls was bled from the IA while the pressure stabilized. Please let me know if you have any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Se Monday, May 27, 2019 4:37 PM To:'Re ames B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Cc:'chris.wal alaska.gov' <chris.wallace@alaska.gov>; AK, GWO SUPT Well Integrity <AKDCWelllntegrity rdinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, GWO Projects Well Int "ty<AKDCProjectsWelllntegrityEngineer@bp.com> Subject: Injector 13-24A (PTD # 430) AOGCC MIT -IA follow up Mr. Regg, Injector 13-24 (PTD # 2042430) operates under AIO 4E.037 -kr water only injection with TxIA communication. The well is mainly used as an injector to support field dewatering operations. Jt was made Not Operable on 11/11/18 for lapsing on its 2 -year AOGCC MIT -IA. On 03/20/19 in anticipation of the upcoming dewatering season, BP performed a passing MIT - IA to 1,984 psi prior to bringing the well online and scheduling an AOGCC witnessed MIT -IA. The well was reclassified Operable and put on injection for de -watering on 05/24/19. BP did not shoot a fluid level or fill the inner annulus after the well was online. BP believes the cool temperature of the water injected during dewatering operations created fluid and tubular shrinkage, which in turn created a void in the inner annulus. Before the AOGCC witnessed MIT -IA passed to 2,505 psi, it took approximately 7 bbl of fluid to reach test pressure. Thein'spector on location called the test inconclusive because of the fluid volume required to reach test pressure. After the to was deemed inconclusive, BP shut the well in. After the well was shut in, the tubing went on a vacuum and the tubing fluid level dropped out to approximately 1,100' MD, but the IA pressure increased as the well returned to static temperature. Over 6 bbl of fluid was bled from the IA to MEMORANDUM TO: Jim Regg\1g. 51311 P.1. SupI ervisor 1 \`(y' � y FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 31, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. 13-24A PRUDHOE BAY UNIT 13-24A Src: Inspector Reviewed By-�;+ P.1. Supry 71*r�r7— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-24A API Well Number 50-029-20739-01-00 Inspector Name: Bob Noble Permit Number: 204-243-0 Inspection Date: 5/26/2019 ' Insp Num: mi[RCN 190527090724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1324A . Type ep Inj W VD s+;a Tubing 1031 ' I034 1031 10" PTD 2042430 - !Type Test SPT Test psi 2587 - IA aus 2587 - 2528 2503 BBL Pumped: 1z.z BBL Returned: 4.6 - OA a 7 7 7 Interval REQVAR P/F P Notes- AA 4E.037 for Tx IA, test to 1.2 max injection pressure, will test to 2600 psi max. I'm listing it as inconclusive because of the volume pumped to begin MIT. The well was on vacuum when we arrived for the test. It took 7 bbls before the annulus began to pressure up dewatering pump was shut down and an additional 5.2 bbls to reach test pressure. Well was left shut in. Per J. Regg, changed status from Inconclusive to pass based on additional information provided by BPXA in emails dated 5/27/19 & 5/28/19. Friday, May 31, 2019 Page 1 of I Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 23, 2019 9:32 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; AK, OPS FS3 DS Ops Lead; Ak, OPS FS3 Facility PTL; Ak, OPS FS3 Field PTL; AK, OPS FS3 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Brown, Don L.; De la Cruz, Paulina; G GPB FS3 Drillsites; Vandergon, Mark A; Vohra, Prachi Cc: Regg, James B (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; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector 13-24A (PTD #2042430) is due for AOGCC MIT -IA All, Injector 13-24 (PTD #2042430) operates under AID 4E.037 for water only injection. It was made Not Operable on 11/11/18 for lapsing on its AOGCC required 2 -year MIT -IA. The well is going to be used for the upcoming de -watering season and is ready for injection. It is now classified as OPERABLE. An AOGCC witnessed MIT -IA will be scheduled when the well is thermally stable. Please respond with any question. Andrew Ogg Well Integrity Engineer 8P Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, November 11, 2018 4:09 PM To:'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead@bp.com>; Ak, OPS FS3 Facility PTL <AKOPSFS3FacilityOTL@bp.com>; Ak, OPS FS3 Field PTL <AKOPSFS3FieldOTL@bp.com>; AK, OPS FS3 OSM <AKOPSFS30SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AK, OPS Pipeline Compl Specialist<AKOPSPipelineComplSpecialist@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Brown, Don L. <browd2@BP.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Vandergon, Mark A <Mark.Vandergon@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim ReggC�' r P.I.Supervisor il bI ZG/( "7 SUBJECT: Mechanical Integrity Tests 1 BP EXPLORATION(ALASKA)INC. 13-24A FROM: Chuck Scheve PRUDHOE BAY UNIT 13-24A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-24A API Well Number 50-029-20739-01-00 Inspector Name: Chuck Scheve Permit Number: 204-243-0 Inspection Date: 6/5/2017 Insp Num: mitCS170606130104 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-24A " Type Inj W. TVD 8438 Tubing 1130 1130 - 1132 • 1130 • PTD 2042430 - Type Test SPT Test psi 2110 - IA 416 2390 , 2342 , 2328 BBL Pumped: 4.3 , BBL Returned: 4.1 - OA o - o 0 0 Interval REQVAR P/F P ,j Notes: AA 4E.037 Well being used for Pit dewatering. $CANNED E P 1 32017 Thursday,June 15,2017 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,June 6, 2017 9:55 AM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;G GPB FS3 Drillsites;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector 13-24A (PTD#2042430) Passed AOGCC MIT-IA All Injector 13-24A(PTD#2042430) passed an AOGCC witness MIT-IA 2,326psi on 06/03/17 demonstrating two competent well barriers. The well is now classified as Operable. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO SCANNED ,1 M 2a i Fro •• GWO Well Integrity Engineer Sent:Thurs•a",- - 11, 2017 7:13 AM To: AK, GWO SUPT Wel •rity; AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; •ski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists, • OPS Prod Controllers; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Pro Well Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Hibbert, Michael; Jan• i, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Worthington, Aras GWO Well Integrity Well Information Subject: UNDER EVALUATION: Injector 13-24A(PTD #2042430) Wi • •uire AOGCC MIT-IA once on stable injection All, 1 • • Injector 13-24A(PTD#2042430)was made not operable on 11/09/16 for missing its AOGCC MIT-IA anniversary date. The well is now ready to be put on injection and is reclassified as Under Evaluation. The well will require an AOGCC witnessed MIT-IA once on stable water injection. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO From: AK, GWO SUPT Well Integrity Sent: Wednesday, November 09, 2016 7:08 AM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; Odom, Kristine Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras 3 Subject: NOT OPERABLE: Injector 13-24A (PTD #2042430) Will Remain Shut In Past AOGCC MIT Test Date All, Injector 13-24A(PTD#2042430) is due for an AOGCC-witnessed MIT-IA by 11/28/16.The well is currently shut in, and will not be brought online for testing before that time.The well is reclassified as Not Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWeIIIntegrityCoordinator@BP.com 2 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 11, 2017 7:13 AM To: AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK,OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers;Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK,OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney;Sternicki, Oliver R;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Injector 13-24A (PTD#2042430)Will Require AOGCC MIT-IA once on stable injection All, Injector 13-24A(PTD#2042430)was made not operable on 11/09/16 for missing its AOGCC MIT-IA anniversary date. The well is now ready to be put on injection and is reclassified as Under Evaluation. The well will require an AOGCC witnessed MIT-IA once on stable water injection. Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 satit4E0 VIS, 1'�If WO Melba/mealo a..wrier. • From: 0 SUPT Well Integrity Sent: Wednesday, Nove .- 19 2016 7:08 AM To: AK, OPS FS3 OSM; AK, OPS F OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan; A', • S GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; Odom, r '•- Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well In . ' ; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; .5-rt, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; - • I, Troy; Worthington, Aras 3 Subject: NOT OPERABLE: Injector 13-24A (PTD #2042430)Will Remain Shut In AOGCC MIT Test Date All, \� 1 STATE OF ALASKA • Al II14 OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well 1 Plug Perforations U Perforate U Other 11 BrightWater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weil❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ 204-243-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service el 6.API Number: Anchorage,AK 99519-6612 50-029-20739-01-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: AoLC70N3151 ADL0028311 • PBU 13-24A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE O 11.Present Well Condition Summa ::t o Summary: r� �. Amy Total Depth measured 11783 feet Plugs measured None feet ID C T O 3 2013 true vertical 9065.98 feet Junk measured None feet AOGCC Effective Depth measured 9758 feet Packer measured 9706 feet true vertical 8480.64 feet true vertical 8437.69 feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 79 20"91.5#H-40 40-119 40-119 1490 470 Surface 2491 13-3/8"72#L-80 39-2530 39-2529.9 4930 2670 Intermediate None None None None None None Production 10070 9-5/8"47#L-80 38-10108 38-8772.41 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9666-9668 feet 11100-11210 feet 11240-11390 feet 11410-11500 feet True Vertical depth 8404.45-8406.12 feet 8933.64-8935.8 feet 8931.47-8930.31 feet 8930.82-8932.16 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 5-1/2"BOT 3-H Packer 9706 8437.69 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): �� t y 9666'-9668', 11100'-11210',11240'-11390',11410'-11500' (`)�` '2:i.G}`� Treatment descriptions including volumes used and final pressure: 1593 Gallons EC9360A Surfactant,7875 Gallons EC9398A Polymer,810 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4510 0 872 Subsequent to operation: 0 0 3420 0 805 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service IS • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG El_ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.CatronOBP.Corn Printed Name Garry Catron ,. 7n�-- Title PDC PE Signature ��W �-�' Phone 564-4424 Date 10/3/2013 VLF "Oflm 0,/ RE3DMS OCT 11 2Ui Form 10-404 Revised 10/2012 Submit Original Only Casing / Tubing Attachment ADL0028311 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 91.5# H-40 40 - 119 40 - 119 1490 470 LINER 59 3-1/2" 8.81#L-80 9781 - 9840 8499.55 - 8548.1 LINER 924 7"29# L-80 9792 - 10716 8508.58 - 8934.01 8160 7020 LINER 1149 3-3/16" 6.2#L-80 9840 - 10989 8548.1 - 8926.1 LINER 794 2-7/8"6.16# L-80 10989 - 11783 8926.1 - 9065.98 13450 13890 PRODUCTION 10070 9-5/8"47# L-80 38 - 10108 38 - 8772.41 6870 4760 SURFACE 2491 13-3/8" 72# L-80 39 - 2530 39 - 2529.9 4930 2670 • TUBING 9690 5-1/2" 17# L-80 41 - 9731 41 - 8458.38 7740 6280 TUBING 105 4-1/2" 12.6#L-80 9731 - 9836 8458.38 - 8544.79 8430 ; 7500 • 1 • • Daily Report of Well Operations ADL0028311 T/I/O 800/480/220 Temp= Hot (Brightwater Reservoir Sweep Mod) Move equipment in to location, spot, start rig up process ***Job continued to 9-5-13 WSR*** 9/4/2013 ***Job continued from 9-413 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 261 gal. EC9360A(Surfactant) Average of 18 gph for 14.5 hrs. Pumped a total of 261 gal. since start of project. Pumped 1260 gal. EC9398A( Polymer) Average of 90 gph for 14 hrs. Pumped a total of 1260 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 9-6-13 WSR*** 9/5/2013 ***Job continued from 9-5-13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 432 gal. EC9360A(Surfactant) Average of 18 gph for 24 hrs. Pumped a total of 693 gal. since start of project. Pumped 2160 gal. EC9398A( Polymer) Average of 90 gph for 24 hrs. Pumped a total of 3420 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 9-7-13 WSR*** 9/6/2013 ***Job continued from 9-6-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 432 gal. EC9360A(Surfactant) Average of 18 gph for 24 hrs. Pumped a total of 1125 gal. since start of project. Pumped 2160 gal. EC9398A( Polymer) Average of 90 gph for 24 hrs. Pumped a total of 5580 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 9-8-13 WSR*** 9/7/2013 ***Job continued from 9-7-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 432 gal. EC9360A(Surfactant) Average of 18 gph for 24 hrs. Pumped a total of 1557 gal. since start of project. Pumped 2160 gal. EC9398A( Polymer) Average of 90 gph for 24 hrs. Pumped a total of 7740 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 9-9-13 WSR*** 9/8/2013 • Daily Report of Well Operations ADL0028311 ***Job continued from 9-8-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 35000 bwpd. Pumped 36 gal. EC9360A(Surfactant) Average of 18 gph for 2 hrs. Pumped a total of 1593 gal. since start of project. Pumped 135 gal. EC9398A( Polymer) Average of 90 gph for 1.5 hrs. Pumped a total of 7875 gal. since start of project ***Establishing rates with proving pots*** Final valve positions upon LRS departure: SV=closed, WV, SSV, MV=open, IA/OA=OTG FWHP 800/120/60 9/9/2013 TAE= FMC • SioY NOTES:H2S READINGS AVERAGE 125 WELLHEAD= FMC 13-24A WHEN ON ON M WELL ANGLE>R OS A 109 3'***A SSSV ACTUATOR BAKER C KB.ELEV= 87 BF ELEV= KOP= _ 2800' I 2160' H5-1/2"0115 RQM SSSV NIP,ID=4.562" Max Angle= •101°@10478' 1 • Datum MD= 10244' Datum 1 V D= 8800'SS 120"CONDUCTOR ?? 113-3/8"CSG,72#,L-80,ID=12.347" IH 2525' Minimum ID =2.44" @ 10989' I I } 9880' H5-1/2"OTISXA SLIDING SLV,0=4.562" I 3-3/16" X 2-7/8" XO 01/11'PKR SQZ(10/25/10) I j 9565'-9668' �' � ( 8686' H5-1/2"BOT PBR ASSY TUBING PUNCH(10/07/10) H 9666'-9668' l Z 9706' H9..5/8"x5-1/2"BOT 3-H PKR w/T"MOE,ID=? I 5-1/2"TBG-PC,17#,L-80,.0232 bpf,ID=4.892'--j 9717' I- \ 1 9717' HT'X 4-12"XO,ID=3.9`•8" 0 H I 9781' H3.70"BKR DEPLOY SLV,ID=3.00" I TOP OF 7"LNR H 9792' t L 9801' H3-12"HES X NIP,ID=2.813" I I 9809' H4-1/2"OTIS XN NIP,MILLED ID=3.80" I 9821' —14-117'BOTSHEAROUTSUB I BEHIND 1 4-12"TBG-PC,12.6#,N-80,.0152 bpf,ID=3.958"H 9822' I 1 I 9822' H4-1/2"TUBING TAIL I CT LINER 9837' H ELMD TT LOGGED 12/09/85 I I3-1/2'LNR,8.81#,L-80 STL,.0087 bpf,ID=2.992' H 9840' I 9840' H3-12"X 3-3/16"X0,ID=2.79" I 19-5/8"CSG,47#,L-80,ID=8.681" H 10103' I-• :•:i ii.;,- ( 10000—/TOP OF CEMENT IT'X 4-1/2"BKR WHIPSTOCK(1221/04) H 10210' I—44,Q, 4.V MILLOUT WINDOW(13-24A) 10213'-10219' 4.4�,�.�..,4 I 10989' H3-3116"X 2-7/8"XO,ID=2.441" I 17"LNR,29#,L80, .0371 bpf,ID=6.184" H 10716' •�•�•�•�•�•■∎••, VAWAVA PERFORATION SUMMARY ` 11560' FISH-MILLED CIBP REF LOG:MEM GR/CCL CNL ON??/??/?? ANGLE AT TOP PERF: 86°r! 11100' PUSHED TO BTM Note:Refer to Production DB for historical perf data 3-3/16"LNR 6.2#,L-80 TCII, 10989' (10/26/10) SIZE SPF INTERVAL Opn/Sqz DATE .0076 bpf,ID=2.80 2" 6 11100-11210 0 01/04105 `, 2' 6 11240-11390 0 01/04/05 2" 6 11410-11500 0 01/04/05 PBTD --I 11747' I �`, 12-7/8"LNR,6.16#,L-80 STL, .0058 bpf,ID=2.441" H 11783' DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05122182 ORIGINAL COMPLETION 10/28/10 JNF/PJC TBG PUNCH,FASDRILL(10/6-7/10) WELL: 13-24A 01108183 R5/NO 11/16/10 LLVPJC MILL PLUG/CMT PKR SQZ (112/10) PERMIT No:12042430 01105105 NORDIC/ CTD SDTRCK(13-24A) 02/09/11 NB/JMD ADDED SSSV SAFETY NOTE AR No 50-029-20739-01 05/07/10 FOX/PJC TREE GO(05/07/10) 01/16/12 TMIWJMD ADDED 1-12S SAFETY NOTE SEC 14 PION R14E 5281.23 FEL 518.22 FNL 06/02/10 OOB/PJC SET PLUG(04/13/10) 10/28/10 WEGPJC PULL WRP(10!04110) BP Exploration(Alaska) • • scan ELARKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION Comm:mSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.037 Mr. Doug Cismoski, P.E. Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 • 1 8 201t BP BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: PBU 13 -24A (PTD 2042430) Request for Administrative Approval Dear Mr. Cismoski: In accordance with Rule 9 of Area Injection Order ( "AIO ") 04E.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby GRANTS BP Exploration (Alaska) Inc. ( "BPXA ")'s request for administrative approval to continue water injection in the subject well. PBU 13 -24A was reported to have TxIA communication in February, 2009 and was shut in. Diagnostics determined a leak near the packer and a packer squeeze was performed in October, 2010 to repair the communication. Subsequent mechanical integrity tests have passed, including a Commission witnessed test on November 28, 2010 and an non - witnessed test on December 09, 2010. The well still, however, exhibits pressure communication to the inner annulus. AOGCC finds that although BPXA has performed corrective action on PBU 13 -24A that the well continues to exhibit tubing x inner annulus communication. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures and wellhead pressure trend plots, PBU 13 -24A exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in PBU 13 -24A is conditioned upon the following: 1. BPXA shall record wellhead pressures, injection rate, and pressure bleeds for all annuli daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; AIO 4E.037 • • April 14, 2011 Page 2 of 2 3. BPXA shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date isNovember 28, 2010. As provided in AS 31.05.080(a), 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 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. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. 4n4 411,Vgillk DONE at Anchorage, Alaska and dated April 14, 2011. _, 4 e 4 0. Cathy '. Foerster Jo orman Ni;t`s ~- Commissioner • . mmissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 April 5, 2011 RECEIVED Mr. Dan Seamount, Chairman APR �1� Alaska Oil and Gas Conservation Commission & Sit Cabs. Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well 13 -24A (PTD# 2042430) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well 13 -24A. Well 13 -24A exhibits inner annulus repressurization where the inner annulus equalizes with the tubing pressure when on water injection. However, a mechanical integrity test on the inner annulus passed to 2500 psi on 12/09/10 after a cement packer squeeze was performed. Two barriers have been established and the well can be safely operated on water injection. Therefore, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay Well 13 -24A is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564 -4303 or Torin Roschinger / Gerald Murphy at 659 -5102. Sincerely, Douglas A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments: Technical Justification T1O Plot Injection Plot Wellbore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger Eest Onshore Site Manager Flow Station 3 Operations Team Leader Paulina Meixueiro Harry Engel Ryan Daniel • • Prudhoe Bay Oil Pool Well 13 -24A Technical Justification for Administrative Approval Request April 5, 2011 Well History and Status Prudhoe Bay Well 13 -24A (PTD # 2042430) exhibits inner annulus repressurization while on water injection indicated by wellhead pressure trends on a TIO plot. An MIT -IA to 2500 psi passed on 12/09/10 indicating competent tubing and production casing. Recent Well Events: > 06/19/09: LDL found leak @ packer - 9706' > 04/13/10: WRP set @ 9740' > 05/14/10: CMIT -TxIA Passed to 3000 psi > 05/28/10: MIT -T Failed LLR -1.9 gpm @ 3000 psi > 10/05/10: Pulled WRP from 9740' MD > 10/06/10: Set Fasdrill @ 11019' > 10/12/10: CMIT -TxIA Passed to 2000 psi > 10/27/10: Packer squeeze > 11/29/10: AOGCC MIT -IA Passed to 2460 psi > 12/07/10: OP called in high IAP > 12/09/10: MIT -IA Passed to 2500 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2500 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. The MI line will remain blinded to limit the well to water injections 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 2 -year MIT -IA to 1.2 times maximum anticipated injection pressure. 5. The well will be shut -in and the AOGCC notified if there is any change in the well's mechanical condition. • 0 Well 13-24A TIO Plot Wolk 13-24 4 630 - 603 -411- 740 2 0 , r" FAL! 00A • .=.,... On ? li jii U., i t 11 1 4 1 I 11 Ilicer g t L v. ' 4:ii a . ■ 04/01110 OVI2/10 06402410 07i43/10 63/03/10 03/03/10 1044/10 11/04/10 12/09110 01 /TV I 1 02/45/11 0050/11 Well 13-24A Injection Plot Wt 13-24 1 500 , a.1163 1630 n( \ ‘ 20200 1 1.200 1 MO 1610) 1 50 1404 16.000 . 1 310 1 263 P AIii \ 14.000 , 11 ---- WHIP , 1 100 03 . ' ! 160 124 , 900 . 10 060 i -- GI , 8113 -0th, Al) aocv ...... on , 601 563 4141111j 6.040 4633 __ .. 461 200 1 200 , 1, 2.030 100 to■ooramoso........................- - 04/01/10 1E402410 06102/10 07,43/10 08/03/10 09103410 11A342 11534/10 12/05. . 01/65111 02/4061 03/63/11 ... ' . t r • TWEE = MC SAFETY NOTES: WELL REQUIRES A SSSV I WELLFEAD= 13 24A WHENONML ACTUATOR = BAKER KB ELEV = ... 87' . BF. B-EV = KCP 2800' i 2160/ HS 1/T OTiS ROM SSSV NP. D = 4.582' I Max Angle = 101' 0 10478' rl Datum ani. 10244' Datum TV D 8800' SS 120' CONDUCTOR '--I ?? i 1 13.3/6' CSG. 72a, 1 -80, U= 12.347' H 2525' • Minimum ID = 2.44" @ 1098W I 9580' H5 1/2' OTIS XA SLUNG SLV. D = 4.562" I 3-3/16" X 2-7/8" XO KRSOZ(10/25/10 •4• 14 CMT H 9 565' -9668' �•� v."4, S686' 5 BOTPBRASSY I ITLJBNGPLNCy1(10/07 /10) H 9666'.9668' l: 9706' 049.5 /8'X51 /T HOT 3•MPKRw / =? I 1 5-1 /T 1B0- PC,17 #. L-80, .0232 bpi, D = 4.89TH 9717' 9717' H7 - x 4. tYP xo, ID = 3.958' I 9781' H170" 8KR taJLOY SLV,10 = 3,00' I ITOPOF 7" LFR 9792' I 9801' H3.1 /2 FESXMP,0 = 2.813' I 9809' H4-1 /T OTIS XN NP MILLED D = 3.80' I 9821' 4.1 /2' BOT SFEAROUT SUB I BEHIND 14.1 /2' TBG- PC.12.8 #, N-80, .0152 bpt. 0 = 3.958"H 9822' 9627 4. t/r TUBS.* TAI. CT LINER 9837' ELNAD TTIO ¶2X19 /85 3-112' LNIL 8 6. L -80 ST! .0087 bpi, D = 2.992' 9840' ■ 9840' 3.1/2' X 33/16' X0, D = 2.79' 1 95/8' CSG, 47 #, L -80. D = 8.68r H 10103' I-a 1 1•1 1 ; i111j� 10000' TOP OF CBMtiii I oo+ 1 1 1 1 1 1 1 I 7' X 4.1/2' BKR WHIPSTOCK (12/2604) 10210' 1 1,11 14 141 I MLLOUT WD=OW (13 -24A) 10213' . 10219• ., ► 1/ 1/1/ 1 , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 / 10989' 3.3I16' x 2. 7/8 ID= 2441' I 04111111 141111111 I UV. 29#:180..0371 NI, ID =6.184' 10716' / 1 1 1 1 / 1 1 1 1 1 1 1 1 1 1 ► eV6 11550' FISH -M8LED COP PERFORATION SUMMARY PUSHED TO8TM REF LOG: NEMGT8CCL CN. ON 771'/0 3.3/16' 1184, 8.2#. L -80 TCI, H 10989' I ` (10 /26110) ANGLE AT TOP FERF. 88 f,;( 1 110(7 ( . 0076 bpi. 13 = 2.80' J I Note( Refer to Product on CS for historical pert data SIZE SFF NTERVAL Opn/Sgz DATE ` ', 2' 8 11100 - 11210 0 01/04/05 2' 8 11240 -11390 0 01/04)05 2" 6 11410 -11500 0 01/04/05 R3113 11747' '�. 12.7/8' LNR. 6.16#,1.80 STL..0058 bpi, D = 2.441' H 11783' I `• DATE REV BY COMMENTS DATE REV BY OOM MENTS PRUHICE BAY 188T 05/22/82 ORIGINAL COMPLETION 06,132/10 OOB/PJC SET PLUG (04/13/10) WELL: 13.24A 01/08/83 RWO 10/28/10 WEC/PJC PILL WRP (1004/10) PERMIT No: 01 /05/05NOROICICTO SOT RCK(13.24A) 10 /28/10 JMF/PJC T8GR/NCH,FASORL.L API No: 50. 029-20739.01 12104/05 KOCITLJI ORLG DRAFT CORRECTIONS 41/16/10 LLVPJC M LL R.UG/ CMT PKR SOZ (11 /2/1 ) SEC 14 T1 ON R14E 5281.23 Fa 518.22 FNL 12107 /06 RLMNTI.k DIAGRAMCOH EC11ON 02/09/11 *43/./1 ) AWED SSSV SAFETY NOTE 05107/10 FOX/PJC TREED°(05/07 /10) J BP Exploration (Alaska) OPERABLE: 13 -24A (PTD #2042430) IA repressurization post packer squeeze Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, December 28, 2010 9:01 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R Cc: Janowski, Carrie; Meixueiro, Paulina Subject: OPERABLE: 13 -24A (PTD #2042430) IA repressurization post packer squeeze Attachments: 13 -24A TIO Plot 12- 28- 10.doc; MIT PBU 13 -24A 11- 28- 10.xls All, Injector 13 -24A (PTD #2042430) has been confirmed to have TxIA communication while on water injection post packer squeeze. However, on 11/28/10 an AOGCC witnessed MITIA passed proving two competent barriers. The well will be reclassified as Operable while further TxIA diagnostics are completed and an AA for PWI is pursued. A TIO Plot and MIT Form have been included for your reference. «13 -24A TIO Plot 12- 28- 10.doc» «MIT PBU 13 -24A 11- 28- 10.xls» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 APR 1 8 2011 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, December 08, 2010 5:59 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA; AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R Cc: King, Whitney; Meixueiro, Paulina Subject: UNDER EVALUATION: 13 -24A (PTD #2042430) IA repressurization All, WAG injector 13 -24 (PTD #2042430) is exhibiting IA repressurization. The wellhead pressures were 1880/2400/770 and the IA was bled down to 550 psi 12/07/10. The well has been reclassified as Under Evaluation and may remain on line for further diagnostics on a 28 day clock. The plan forward is as follows: 1. DHD: Monitor IA BUR 4/13/2011 OPERABLE: 13 -24A (PTD #2042430) IA repressurization post packer squeeze Page 2 of 2 2. DHD: t� A TIO plot and wellbore schematic have been included for your reference. « File: 13 -24 TIO plot.doc » « File: 13 -34A WBS.pdf » Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5102 AKDCWellIntegrityCoordinator @bp.com 4/13/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recia ialaska.00v; doa.aoacc.prudhoe.bav talaska.00v: phoebe.brooks)alaska.00v; tom.maunder(6ialaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU DATE: 12/09/10 OPERATOR REP: Jerry Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wet 13 -24 PIN Type Inj. W ND 8,438' Tubing 1840 1840 1840 1840 Interval o P.T.D. 2042430 _ Type test _ P Test psi 2109.5 Casing 960 2500 2500 2500 P/F P Notes: Injection for well integrity evaluation OA 720 730 750 750 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA . Well Type Inj. ND 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 13 10.xls M.: 1324 4,000 1 3 000 ` -.-- T(p 2,0(00 t I0. - DA OOA --A-- OOOA 7 00 0 VII _Alillilla .....A. On 10/02/10 10/05/10 10/1610 10/23/10 10/30/10 11/06/10 11/13/10 17 /20 /10 11/27/10 12'04/10 12/11/10 12/10/10 12/25/10 0 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ( DATE: Friday, December 03, 2010 TO: Jim Regg ` et( 10-1 1+1 C) P.I. Supervisor (` SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13 -24A FROM: Jeff Jones PRUDHOE BAY UNIT 13 -24A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ;l_- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 13 -24A API Well Number 50- 029 - 20739 -01 -00 Inspector Name: Jeff Jones Insp Num: mitJJ101129065109 Permit Number: 204 -243 -0 Inspection Date: 11/28/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 13-2a4A pT I W . V T D 8438 IA 1760 2460 -� 2430 — 2420 P.T.D' 2042430 ITypeTest +PT Test psi 2109 OA 500 500 500 500 Int erval OTHER P/F P — Tu bing � 1850 1 1850 1850 1850 Notes: Post packer squeeze MIT -IA. 0.8 BBLS methanol pumped. 1 well inspected; one exception noted: a lockdown screw on the tubing hanger is leaking oil. Mr. Noren to initiate repair. AA 1c 6 Z1 Friday, December 03, 2010 Page 1 of I STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q CEMENT SQUEEZE Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ I 204 -2430 3. Address: P.O. Box 196612 Stratigraphic❑r Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20739 -01 -00 rp 8. Property Designation (Lease Number) X6 : Well Name and Number: ADLO- 028311 PBU 13 -24A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 11783 feet Plugs (measured) 9758 feet true vertical 9065.98 feet Junk (measured) 11550 feet (10/26/10) Effective Depth measured 11747 feet Packer (measured) 9706 feet true vertical 9039.66 feet (true vertical) 8438 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.5# H -40 SURFACE -79 SURFACE -79 1490 470 Surface 2525' 13 -3/8" 72# L -80 SURFACE - 2525 SURFACE - 2525 4930 2670 Production 10103' 9 -5/8" 47# L -80 SURFACE - 10103 SURFACE - 8768 6870 4760 Liner 421' 7" 29# L -80 9792 - 10213 8509 - 8861 8160 7020 Liner 2002' 3- 1/2 "X3- 3/16 "X2 -7/8" 9781 - 11783 8500 - 9066 Liner 8.81 #/6.2 #/6.16# Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# N_80 SURFACE - 9822 SURFACE - 8533 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 5 -112" BOT 3 -H PKR 970 8438 AEI 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1 � N v 2 4 2010 Treatment descriptions including volumes used and final pressure: 'n fi oas cons' 6 =4 kt.c ' S1011 Apdora 8 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: si Subsequent to operation: 3200 1793 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil GasEl WDSPL GSTOR ❑ WINJ ❑ WAGQ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -357 Contact Joe Lastufka Printed Na e J Lastl c Title Data Manager Signatu Phone 564 -4091 Date 11/24/2010 RBDAAS NOV 2-0 A- 77 � 11 Form 10-404 Revised 1012010 ` Submit Original Only 13 -24A 204 -243 PERF ATTACHMENT -. Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 13 -24A 1/4/05 PER 11,100. 11,210. 8,933.64 8,935.8 13 -24A 1/4/05 PER 11,240. 11,390. 8,931.47 8,930.31 13 -24A 1/4/05 PER 11,410. 11,500. 8,930.82 8,932.16 13 -24A 4/13/10 BPS 9,758. 11,500. 8,480.64 8,932.16 13 -24A 10/5/10 BPP 9,758. 11,500. 8,480.64 8,932.16 13 -24A 10/6/10 BPS 11,019. 11,500. 8,928.47 8,932.16 13 -24A 10/7/10 PER 9,666. 9,668. 8,404.45 8,406.12 13 -24A 10/17/10 BPS 9,758. 11,100. 8,480.64 8,933.64 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH I OPEN HOLE • 13 -24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/25/2010 CTU #8 w/ 1.75" CT: Job Scope: Cement Packer S ue MIRU CT unit. MU and RIH with 2.0" BJN cementing BHA. Lay in 11 bbls of 16.5# geo /barite pill Squeezed 15 bbls of 15.8 ppg cement into IA. <<< Continue WSR on 10/26/10 >>>* *"Job in E Progress * ** I i 10/26/2010 CTU #8 w/ 1.75" CT: Job Scope: Cement Packer Squeeze: <<< Continue WSR 1 from 10/25/10 >>> Cement is @ 800 psi compressive strength @ 05:15 preform MIT zX IA to 620 psi. Holding solid. Cleanout weighted pill down to composite plug at 11019' and chase to surface. MU and RIH with 2.30" junk mill BHA. Milled up lcomposite plug and pushed it to 11550' ** *Job in Progress * ** f i l 10/27/2010iCTU #8 w/ 1.75" CT: Job Scope: Cement Packer Squeeze: & Mill composite plug <<< Continue WSR from 10/26/10 >>> Milled composite pulg and pushed it to 11550'. Freeze protect well w / 58 bbls of 60/40 methanol. Ball has been recovered. <<< Job complete >>> � ! i i I l 10/27/2010ICTU #8 w/ 1.75" CT: Job Scope: Cement Packer Squeeze: & Mill composite plug '<<< Continue WSR from 10/26/10 >>> Milled composite pulg and pushed it to 11550'. Freeze protect well w / 58 bbls of 60/40 methanol. Ball has been recovered. <<< Job complete >>> I ' ' 1 � j l j m 11/2/201OiT/I/0= 0 /vac /200 Temp= SI MIT IA FAILED to 4000 psi- (Evaluate Squeeze Job) Pressured up IA to 4000 psi with 11.7 bbls meth. 4th test results- 1st 15 min IA lost I 180 psi, 2nd 15 min IA lost 60 psi with a total loss of 140 psi in 30 min test. Bled back j 10 bbls. Final WHP's= 0/200/200 "Valves are SV,WV,SSV= closed, MV, IA and OA open on departure" i I i a 11/13/2010 T /I /0= Vac /50/200. Temp St. MIT -IA to 3700 psi PASSED (EvahT x lA a�cker ;squeeze). T FL near surface. IA FL @ surface. Used 11.4 bbls methanol to increased IAP from 50 psi to 3700 psi in 35 minutes. IA lost 100 psi in 1st 15 minutes and 40 psi in the 2nd 15 minutes. A total lost of 140 psi in 30 minutes. Bled IAP from 3560 psi to 30 psi. 6 bbls of fluid returned. Monitored for 30 minutes, IAP increased 120 psi. Final WHPs= Vac /50/200. 1 ;Job completed. 1 ISV,WV,SSV= closed. MV =open. IA,OA =open to gauge. NOVP. FLUIDS PUMPED BBLS 15.8 PPG CEMENT 16.5 PPG WEIGHTED PILL 228 60/40 METH 13 NEAT 273.3 TOTAL TREE = FMC SAMT)&ES: WELLHEAD = FMC 'ACTUATOR = BAKER C 13-24A KB. ELEV - 87' BF. ELEV - KOP = 2800' 2160 5 -1/2" OTIS RQM SSSV NIP, ID Max Angle = 101° @ 10478' Datum MD = 10244' Datum TV D = 8800' SS 20" CONDUCTOR ?? 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2525' Minimum ID = 2.44" @ 10989' / I ' 9580' 5 -1/2" OTIS XA SLIDING SLV, ID 3- 3116" X 2 -718" XO CM PKR SQ ( 10/25110) 9565' - 66$' 9686' 5 -1/2" BOT PB RASSY TUBING PUNCH (10/07/10) 9666' - 668' 1 i 9706' 9 -5/8" X 5 -1 /2" BOT 3 -H PKR w / 5 -1/2" TBG- PC, 17 #, L-80_0232 bpf, ID = 4.892" 9717' 9717' — ( 7 X 4 -112" XO, ID = 3.958 3.70" BKR DEPLOY SLV, ID = 3.00" TOP OF 7" LNR 9792' 9$01' — 3 -112" HES X N IP, ID = 2.813" 9809' 4 -1/2" OTIS XN NIP, MILLED ID = 3.80" 9821' 4 -112" BOTSHEAROUTSUB BEHIND 4 -1/2" TBG- PC,12.6 #, N-80_0152 bpf, ID = 3.958" Q$22' 9822 4 -1/2" TUBING TAIL CT LINER 9837' ELMD TT LOGGED 12(09(85 3 -1/2" LNR, 8.81 #, L -80 STL, .0087 bpf, ID = 2.992" 9840' 9840' 3 -1/2" X 3- 3/16" XO, ID = 2.79" 9 -518" CSG, 47 #, L -80, ID = 8.681" 10103' 10000' — TOP OF CEMENT 7" X 4 -1/2" BKR WHIPSTOCK (12/21/04) 10210' MILLOUT WINDOW (13 -24A) 10213'- 10219' I 10989' 3- 3/16" X 2 -7/8" XO, ID = 2.441" 7" LNR, 29 #, L80,.0371 bpf, ID = 6.184" 10716' PERFORATION SUMMARY 11550' FISH - MILLED CIBP PUSHED TO BTM REF LOG: MEM GR/CCL CNL ON ? ? / ? ? / ?? 3- 3/16" LNR, 6.27# L 80 - TCII, 109$9' (10/26/10) ANGLE AT TOP PERF: 86@11100' 1 .0076 bpf, ID = 2.80" Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL Opn /Sqz DATE 2" 6 11100 - 11210 0 01/04/05 2" 6 11240 - 11390 0 01/04/05 2" 6 11410 - 11500 0 01/04/05 PBTD 11747' 2 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" 11783' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/22/82 ORIGINAL COM PLEI'ION 06/02/10 OOB /PJC SET PLUG (04/13/10) WELL: 13 -24A 01/08183 RWO 10/28/10 WEC /PJC PULL WRP (10/04/10) PERMITNo:2042430 01/05/05 NORDIC1 CTD SDTRCK (13 -24A) 10/28/10 JMF /PJC TBG PUNCH, FASDRILL (10/6 -7/10 ) API No: 50- 029 - 20739 -01 12/04/05 KDC/TLH DRLG DRAFT CORRECTIONS 11/16/10 LLVPJC MILL PLUG/ CMT PKR SQZ (11/2/10) SEC 14 T10N R14E 5281.23 FEL 518.22 FNL 112/07/061 RLM/TLH DIAGRAM CORRECTION 05/07/10 1 FOX/PJG TREE C/O (05/07/10) BP Exploration (Alaska) OPERABLE: Injector 13 -24A (PTD #2042430) Passing NUTIA post packer squeeze Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] Sent: Wednesday, November 17, 2010 6:51 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; 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; Engel, Harry R; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; Meixueiro, Paulina Subject: OPERABLE: Injector 13 -24A (PTD #2042430) Passing MITIA post packer squeeze All, Injector 13 -24A (PTD #2042430) passed an MITIA after service coil performed a packer squeeze. The passing test verifies two competent barriers. The well has been reclassified as Operable so that it may be placed on production for an AOGCC witnessed MITIA. Please notify Well Integrity after the well has been placed on injection so that a slope inspector can be scheduled to witness the test. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 2a� Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: ' 95U,,ADW Well Integrity Engineer Sent: Sunday, February 01, 2009 8:02 PM To: 'Regg, James B (DQ A)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GC1 /3 /FS3); G S3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia 0; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Townsend, S. Eliot; NSU, ADW Well Int 'ty Engineer Subject: NOT OPERABLE: 13 -24A (PTD #2042 Failed MIT -IA Well 13 -24A (PTD #2042430) failed an MIT -IA on 18/09 and then a repeat test with a triplex on 01/30/09. The well no longer meets the requirements of AIO 4E or S. The well has been reclassified as Not Operable and needs to remain shut -in. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659 -5102 Pager: (907) 659 -5100 x1154 11/18/2010 ~ • , - I~ }~' ~ ~ -a ~ ) P~ f ~ '~ ~ ,; ~ r ~ - i ,~ ~ ~ ~ ~~ ~ e ~~~ ~ ~ ~~ ~ ~ g~C ~~ k ~ ~~ ~ ~ < ~ ~ ~ ~ ~ ~ f ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ E-, ~ ~ a ~ ~ ~, ~ ~ ~~ ,~ t ~) b ~ , ` ~ ` ~ r t ~, Z ~ ~ z ~ '~~9~ ~ ~ ~ ~ ~ " ~ ~~ ~ ~ ~ ~ " ~ SEAN PARNELL, GOVERNOR ~e~ ~. ~ h~ . F ~ ~ ~ i~ °~ ~ ~ ~ ~ q ~ ~ ~ ~ ~~^ ~, ~~~ ~ L _. ~:-s ~ ~ ~ ~ ~ . ~. , ~ p. .,_ ,u ~ ., ..~ E` G ALA-7~~ ~ITi ~n' Vrv~.7 333 W. 7thAVENUE, SUITE 100 ~ CD~jS'~i RQATID~j CD~~IISS'I0~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Ms. Olivia Bommarito Engineer BP Exploration (Alaska), Inc. ~~~~~~~a ~~ ~ ~ ~ ~~~~ P.4. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Poo~, 13-24A ,,.,. ~ Sundry Number: 309-357 ~~~ ~ ~ Dear Ms. Bommarito: 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 feld 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 consid~red 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 D"~- DATED this Zgday of October, 2009 Encl. . ~~ ~d,~ . , `, , ~ ~,O 1 STATE OF ALASKA I~ ~v ALAS~IL AND GAS CONSERVATION COMMIS~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operationai shutdown ^ Perforate ^ Re-enter Suspen~~~ _ ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Other ^~ Specify: PACKER Change approved program ^ PuN Tubing ^ PerForate New Pool ^ Time Extension ^ SQUEEZE 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 204-2430~ 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~- 6. API Number: Anchorage, AK 99519-6612 50-029-20739-01-00 - 7. If pertorating, 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 13-24A - 9. Property Designation (Lease Number): 10. Field/Pooi(s): ADLO-028311 PRUDHOE BAY Field / PRU DHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11783 - 9065.98 . 11747 - 9039.66 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79 20' 91.5# H-40 Surtace 79 Surface 79 1490 470 Surface 2525 13-3/8" 72# L-80 Surface 2525 5urtace 2525 4930 2670 Production 10103 9-5/8" 47# L-80 Surface 10103 5urface 8768 6870 4760 Liner 421 7" 29# K-80 9792 10213 8509 8861 8160 7020 Liner 2002 3-1/2"X3-3/16"X2-7/8" 9781 11783 8500 9066 Liner 8.81 #/6.2#/6.16# Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" 12.6# L-80 9717 - 9822 see attached - - 5-1/2" 17# L-80 Surface-9717 Packers and SSSV Tv~e: Packers and SSSV MD and ND (ft1: 9-5/8"X5-1/2" BOT 3-H PKR 9706' 8438' 12. Attachments: Description Summary of Proposal ~ 13. Well Glass after proposed work: Detailed Operations Program ~ BOP Sketch ^ Expioratory ^ Development [] Service Q- 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/3/2009 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^~ - Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Olivia Bommarito Printed Name Olivia Bommarito Title Engineer Signature Phone Date 564-4096 10/20/2009 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notif Commission so that a re resentative ma witn S N b d D~~/ ~ y p y ess un um ry e r: / Plug Integrity ^ BOP Test [] Mechanica( Integrity Test ~ Location Ciearance ^ Other: ~d~;+y ~h 5~~~~1" I" C''a''t~~-SS" ~ lT~ ~1'i f Subsequent Form Required: ~ ~~~ ~O , / `1' APPROVED BY Approved by: COMMISSIONER THE COMM1SS10N D t d l Z a e: , ~ ~~ c~ ~~ ORIGINAL ~ %,Z~.°~ Form 10-403 Revised 07/2009 ~~~r~~ a l ~ ~~~iE~~~~~~ /O~ ~ OCT 2 1 2~109 n Submit in Duplicate 13-34A 204-243 PFRF OTTA~HMFNT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 13-24A 1/4/05 PER 11,100. 11,210. 8,933.64 8,935.8 13-24A 1/4/05 PER 11,240. 11,390. 8,931.47 8,930.31 13-24A 1/4/05 PER 11,410. 11,500. 8,930.82 8,932.16 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 i bp ~ To: C. Ofsen/J. Bixby GPB Well Ops Team Leaders From: Olivia Bommarito, DS 13 & 14 Engineer Whitney King, Wells Engineer Subject: 13-24A Packer Squeeze Please perform the following procedure(s): ~ Date: September 03, 2009 Code: PBD13WL24-N IOR: 100 Est. Cost: $350,000 1. S Drift. 2. C Drift. Set composite. CMIT. Lay in sand plug. Punch tubing. Establish circulation. Pump balanced plug through tubing punch. Mill cement. FCO. Mill com osite. 3. F WOC for 3 da s. MITIA. Establish LLR if fails. *SUNDRY REQUIRED* Current Status: Not Operable WAG Injection Target: 4000 BWPD Last Injection: 3200 PW, 1713 WHP (01/18/2009) Max Deviation: 100 deg @ 10478' MD Perf Deviation: 86.0 deg C~ 11100' Min. ID: 2.441" C~ 10989" C~ 3-3/16" x 2-7/8" liner XO Last TD tag: 11721' CTMD on 11/28/06 Last Downhole Ops: 06/19/09: TecWel LDL SBHPS: 04/21/09: 3258 psi, 153°F Latest H2S level: Injector Tie-in Log: SLB MCNL 03 Jan 2005 OBJECTIVE: The objective of this program is to repair the leaking seal assembly in the packer by punching the tubing and circulating cement around the backside. A composite will be set in the top of 2-7/8" section of the liner and then the well will be sanded back to just below the packer. WELL HISTORY: This well was sidetracked in January 2005. It's completed with 5-1/2" and 4-1/2" L-80 tubing and has a 3-1/2"x3-3/16"x2-7/8" L-80 liner. A TecWel LDL run on 06/19/09 shows a leak at the packer (9706'). The LDL was performed by pumping down the IA and into the formation. WELL INTEGRITY HISTORY: > 1/18/09: MIT-IA failed on pressure stabilization > 1/28/09: PPPOT-T passed, PPPOT-IC failed, IC has 3 stuck LDS > 1/30/09: MIT-IA w/ triplex to 3000 psi failed; LLR ~9.45 gpm at 20 psi > 4/29/09: IC voidage test failed > 6/6/09: MIT-IA w/ LRS to 2500 psi failed on 5 attempts due to pressure stabilization; LLR ~0.25 gpm @ 2500 psi > 06/17/09: Caliper shows tubing in overall good/fair condition > 06/19/09: LDL found leak @ packer --9706' Please contact Olivia Bommarito at 564-4096 (work), 952-4799 (cell), or 677-1879 (home) or Whitney King at 564-4840 (work) or 310-989-7674 (cell) with any questions or comments. Cc w/ att: Well File Page 1 of 9 SL Drift • ~ ` 1. RU SL. Drift well as deep as possible. Well surpasses a 70° an'gle C«~ ~10320' MD. Note: 04/21/09: SL reached 10350' SLM during a SBHPS. 2. POOH and RDMO. CT Sand Pluq/Balanced Pluq/ Mill Cement 3. RU CT. Ensure wellbore is liquid packed. Load IA with either 50/50 or 60/40 meth water only. No hydrocarbons in IA for MI injectors. 4. MU BHA with memory GR/CCL inside carrier with nozzle as drift for 2-7/8" composite plug. RIH and tag TD. 5. Log up with GR/CCL while POOH, flagging CT for composite. Download logging data. Tie into the SLB MCNL 03 Jan 2005 log. 6. MU composite setting BHA FOR 2-7/8" composite and follow service company procedure for pressure testing composite. RIH to composite flag. Depth shift and set 2-7/8" composite ~ 11050' MD (below 3-3/16" x 2-7/8" XO). POOH. 7. CMIT to 1500 psi to ensure plug is holding. 8. MU BHA for carbolite plug (CTC w/ no checks, disconnect, stingers, and 2" big hole nozzle with no side jets). RIH and tag composite for depth control. PU 60' to the 3-3/16" by 2-7/8" XO. NOTE: the following calculations are based on estimated depths from the most recent tag and the SLB MCNL 03 Jan 2005 log. Use corrected values from CT loq and taq for final volumes. 9. Begin mixing fresh batch of 8 ppg slurry. The following fluids will be pumped down the CT: • 3 bbl spear of gel •~26 bbls of 8 ppg slurry • 3 bbl spear of gel • Coil volume of spacer water 10. Mix first stage of sand slurry as follows and follow PE manual for SOP. • 6520 Ibs of 20/40 carbolite into ~26 bbl ael (8 ppg in 40# HEC gel). • Liner interval to fill: 9725' to 11050' MD (1325') + any void around liner top • Sand top window: 9705' - 9735' (Ideal TOS 9725') • Sand volume: 6.8 bbls • Fluid volume: 19.4 bbls • Total slurry volume: 19.4 + 6.8 + 6=~26 bbls (including lead/tail gel volumes) • Please note the actual volume of carbolite used in the WSR summary. 11. Lay in 100% of carbolite. Lay in 1:1 while taking returns to the surface. Make sure to stay above the top of slurry. After coil spacer of water has been pumped to displace sand/gel, shut down pump and pull up to safety. Page 2 of 9 ~ ~ 12. Pull a sample of slurry to ensure gel breaks as planned. Be sure to allow for enough time for gel to break before tagging carbolite. Wait at least 30 mins before reversing down to requested TOS (9725' MD). Sand top should be above the XO at 9736' MD but below the top of the seal assembly at 9704' MD. POOH. 13. Clean coil near surface with gel sweeps to tank. 14. Once CT is clean, MU 1-11/16" tubing puncher, RDX with GR/CCL. RIH and tag TOS for depth control. PU and shoot holes in tubing either in the middle of the pup joint above the seal assembly or the first full joint above the pup joint (depending on TOS). Requested tubing punch at 9688' - 9690' (bottom of first full joint). See attached tubing tally. 15. Establish circulation and remove any remaining gas from the wellbore by pumping inhibited sea water down the tubing and taking returns up the IA through the tubing punch. POOH. 16. Once well has been completely circulated, freeze protect the top 2500' of the tubing and IA (168 bbls) at surface using 50/50 or 60/40 meth with corrosion inhibitor. Add an additional 20 bbls freeze protect for cement to be placed in IA for a total of ~188 bbls. • IA x tbg volume is 425 bbls • Tubing volume to composite is 236 bbls • 58 bbls to freeze protect top 2500' of tbg • 110 bbls to freeze protect top 2500' of IA • Note: No hydrocarbons in IA for MI injectors. Use 50/50 or 60/40 meth water only. 17. MU CTC with no checks, disconnect, stingers, and cementing nozzle. RIH and tag TOS for depth control. PU 10' and flag pipe. Perform circulation test to ensure tubing punch holes are still open being careful not to circulate out too much of the freeze protect in the IA (max 10 bbls). 18. Batch mix 5.7 bbls pumpable bbls 15.8 Unislurrvi cement which will give 500 psi compressive strength in 4- 6 hours and ~2000 psi ultimate compressive strength. BHT should be approximately 153°F. Expected temperature at the packers is ~182 °F (taken from the temperature pass from the 06/19/09 TecWel LDL). 19. Catch a sample of the cement for QC testing. Pull sample for UCA. Once the blend is approved, line up cementers to the coil. 20. The following will be pumped down the coil: a. 5 bbls spacer water b. 5.7 bbls of cement c. 5 bbls spacer water 21. With IA SI, take returns up the backside (tbg x CT annulus) while pumping water spacer. Switch to Unislurry while continuing to take returns up the backside. Maintain 100 - 200 psi back pressure. Pump 1 bbl Unislurry out of the nozzle (~50' of cement above the nozzle) and then lay in 1:1 while PUH. PU to safety C«~ 9350'. SAFETY: 5.7 bbls of cement would leave WCTOC at 9484' if no cement is placed in the annulus (assuming the sand top is at 9730' MD). 22. With the nozzle at safety, SD pumping. SI backside (tbg x CT annulus). Compare pump volume to return volume in 40 bbl tank. Page 3 of 9 23. Open IA to return to~ 40 bbl tank. Begin pumping a minimu~te down the coil. Circulate ~3.6 bbls through the tubing punched holes and into the IA. I IA and gauge volume of returns. NOTE: With sand top at 9730' MD, the final cement top in the tubing should be ~9638 MD with ~3.6 bbls of Unislurry in the IA and -2.1 bbls in the tbg. 24. POOH while replacing voidage down backside adding freeze protect as needed. 25. MU motor and mill & jars. Wait until lab sample has reached 500 psi compressive strength (about 4 to 6 hours) before RIH and milling through ~92' of cement to sand plug top. Pump slugs of Geovis as necessary to adequately lift solids. Do not clean out sand. Once sand top is reached, pump a large sweep of Geovis or Biozan to displace cement fines to surface and then POOH. 26. MU BHA for FCO (CTC, disconnect, stingers, and JSN). RIH and clean out 1325' of sand to the composite plug. Sand top is at ~9730 MD. Begin jetting 10' above the sand top. Once composite is tagged (at 11050'), PUH a few feet and pump large Geovis or Biozan sweep followed by at least one backside volume of KCI to sweep sand to surface. POOH. 27. MU motor and mill/jars before RIH again. Mill through composite and push to bottom of well. Composite should be pushed to at least 11500' to clear all perforation intervals. Last tag was 11721' CTMD on 11/28/06. POOH. Fullbore WOC and MITIA 28. WOC for 3 days. 29. MITIA to 2500 psi. Establish LLR if fails Page4of9 r~~ €s~cc~,tx Acrxm.rc~= ,~~oFr -m.~v= et~ °~ eF_ e~~r ~ waPa anao~ t1eYAn R 104 t6[T8' Oef~mloO td2M' ~ ~hLenND$ 887QS5 6+ ~ ~11~F1 ~ ~ ~~'~ ~'~~~~~ 33118" X 2 7t8" XO rmca~~-u~ i ~t~ii0.TL3Pi .~ARY t'1~ LOEi A19f 4a'RlCL! Ol~ tk~!??1?'21?? ANC~.€ 0.T 1tJP P~: S8~ 11 tOR tbM: Rder 4n Ptrarlt~3ati ~ tar h'slatha0 pet4 dat~ ffiE $PF I~AL. D11~€ ~' S 1T100-1121Q ~'i Qtl8iiR5 2' 6 t12d0.11~0 ~ OilOOA6 2" 8 t1~E10-119~~~ O Ot1WA5 ~ ~'L ~ /"1 28Ef' 8.18A4 480 OAI~ ~l' ~Y CAAlAQ~E75 dATE ~ BY ~~S OSr1~ffi ALCA~I~L~TIfkl D1A8Jt.9 Otd08~06 1 DS~If 7Y2AA 12~#A15 !~(YTLtf GOP~FT i'207~Cf8 A_htlTLH ~~.v2-ors a,x~t sssa ~ n~ asax- ~ rt*~sxaeP;~=a~~~- I ms ~wr~~, r~.s' ~ ~ a~a- t rz~~ors ~ei~wnrss ~2' Tl~ TAL (~~~~ ~D TT LiIIY~ID 12A8165 { PP 2' % 3~9116^ Xt?, D~ 2_'7'~.4' ~ 47~ G~3i~if MfLi.QUT WlX~IL)W (t9.2Y,) 1G~I T • tUYtY PRiI1b80~BAY tD~f -V~Z: T3-2fA P~II~ A6: 2fl~~#~ AP#PI~ 56-U2&24TT~dit s~ tar~~u~~al2a~a.s~esz€r~ s bcpauraaN~oajlaska~ Page 5 of 9 -._J 13-24 Packer Repair Sliding Sleeve 9600' MD Tubing Punch 9690' MD Bottom of ist Full Joint Packer 9720' MD ~ Requested TOC 9638' MD Requested TOS 9725' MD 5-1/2" x 4-1/2" XO 9736' MD TOL 9783' MD Total Cement to Pump: 5.70 bbis Cement Volume in Tubinp: ~ (9730' - 9638') x.0232 bbis/ft = 2.1 bbls Cement Volume in Annulus: (9720' - 9638') x.0438 bbls/ft = 3.6 bbls Total Volume of Proppant: -65201bs tbg: lengih (ft): Ibs/ft: Ibs: 2-7/8" tbg 58 3.58 207.64 3-3/16" tbg 1150 4.69 5393.5 3-1/2" tbg 59 5.37 316.83 4-1/2" tbg 47 9.38 440.86 5-1/2"tbg 11 14.32 157.52 6516.35 All Depths Correlate to SLB MCNL 03-JAN-OS 3-1/2" x 3-3/16" XO 9842' MD 3-3/16" x 2-7/8" XO 10992' MD Composite set @ 11050' MD . Page 6 of 9 r ~ _ _.... _ _ . _ ~ - ~ : :`': ; :. - -1 - SLB MCN L ~~ 03-JAN-05 g~ > :; ~I.IDINC~ iC '' >i>: '>; : : i : ~ , ~i.r:a:~ >i:• : : : : ::::: , ~ : ' %; ; a 650 9 ~s+ F~,:i t-~ ~~ „ I :: ?`z ' . : :. : ~ ;: . >,;,. ' : ; ti::::: , Tubing Punch ' 9688' 9690' . - ~,,~ ~"~, , 7 Q 1~ U 9 ~':;:;; ; -(o y ci:nt . ii ~iii>i r' ~,q: ~,..,~ i :~ . , I ~:%~'~2'i '~: ~ ~ ~~~ ~ ~ ' :. ~ ~. . , , ., ., ~ QAC t= E:R - To~ Requested TOS ' @ 9730 x~ s~so ~TOL Page 7 of 9 Page 8 of 9 ~ 1 ~ p LINER f CEMENTING SUMMARY a-~ , YVELL # 13,24A IIf~ER SIZE J YYTJFT / GRADE / T#~EAD t 10 2875 &16 L-B~ STL 2.441 iw 3.988 6.2U L-~1 TC II 2.8~0 in 3.50iD 8.81 L-BO STl 2.992 in 807"fOM OF LINER AT l1,783.U0 tt TOP ~ LlNER Ai 9,811.33 ft 1TEIA deaaipfwn i~cludes: SIZE, TYPE, COt~CTION NU JTEM QQ ~ L.ENGTH TUP SOTTOM Baker S4~ Bt~l Naae Flo~ Shoe STL 2.88 n 2.38 in 1.85 ft 11 781.t5 i1 783.~ 1 jt 2-7/8", 6.161~, l-8fi, STL, T~ing wJ hrbo 3.56 in Z_44 in 31 _79 R 71,749.36 11,~$1.15 Baker Fb~ CcNlar, 8TL 2.88 in 2.38 ~ 0.9k R t 1,7d8A2 11,749_36 BaFcer Latch Cdlar, STl 2.94 in i.81 in 0_93 ft 11,74T.49 ti,74B.42 25 ~ j~ 2 rixu 26 2-7/8", 6.7!6~, L-SD, STL, Tub~x~ wP tu~aa 3.50 st 2.44 m 739.06 ft 1'I,t3~8.43 71,747.49 TIW LSL ~ XO 33d1G' TC97 H x 2-TA8" STL P 3.54 n 2.44 in 19.~4 ft 10 989.09 11 00$.43 23~t pt2i~19 3-3l16", 6.2lF,1-80, TC11, T~ vd T~xb~ 3.79 ei 2.80 in 718.37 ft 10,270.72 10,98.4.U9 14 ~ jts54-67 3~3J16', fi.2it, L-SQ, TC1 t, T~ wW Twt~os 3.19 n ?.80 in 429_46 9,841.26 iU,270.72 Baker XO, 31fT STL 8wt 3-3it6° TC11 Pin 3.50 n 2~79 in 1.~ ft 9,839.76 9,841.26 '! ~t " 69 3-112', 8.8t~, L-~, STL, T~ing 3.SQ n 2.99 in 28_43 ft 9,811.33 9,839.76 3-1/2", STt, BWt x P~ Pt~ Jartt 3.SQ io 2.99 u~ 9.7{D ft 9,9t31.&3 9,8ii.33 Otis'X' t+6pple, ~2.813° prafite~, 3-1/2" Sil 3.74 in 2.8'1 in 1.05 ft 9,80~1.56 9,801.63 3-'fR', STL, 8ox x P'a~ Pup ,i~t 3.50 in 2_99 in 9_iD ft 9,7~.88 9.800.56 8sker Pup, 31/2", STL, Box x Pn 3.50 ~ 2_99 in 3.73 ft 9,787.t5 9,790.86 Baker Deplayme~rt Slee~re, 3-it1" STL Pa~ 3.70 a~ 3.4fl in 5.78 tt 9,781.37 9,787.95 9,781.37 64 ~ ~4ate: T~a6dcemenir~i~ I~eng9hs are ind an tti! ~irrOs B Total tength CEMENT SUMMARY tser TD 11783 ft ap to displace baM 2.50 ~ r CTLRT Rek.ase BaRI S~ (m) 1 Type 5/S" 5~1 C3p retum ~e m`Q Calculated GTLRT She~ Re.Fease 2,688 p~i L~ Cir 56 0_10 bpm ~~ Ac~ CTIRT Shear Re3ease 4,~D psi Type a~ Fhiid 2°~6 0.fi KCI ~`~ C7e6~ CLRT ~ reiease 1,112 psi Mted Denaity 8.65 Vo~me #o ~ar 45.51~ Type 1[~ity af fkid used 6o di~iece AAud 29i, ~a i(CL 8.65 ~~ ~ t~p ~/(~ aut 7 Losses ~pm) 2.~ bpnt 2.78 bprre -0.10 bpm °3 a CTP 1,~0 {~i W~ Vofune Pumped Z7S W~Is H o Gumments Ca~cWa~ed Cetr~ VaWme Req~red 23 bbls ~e 01/031d5 VW~ne 1 Type Fiuid ahesd 3.0 bCis fr~t~ Start Job 8_28 tMi:mm Cement Vohuru~ /[Iensity Vrough hlicro Ma~1on 23_1 bt~ 15_8U ppg CsnteM at D~aity+ 7:47 t~mn Droppmd C'F L~er W~e Faug {YeslNo} Yes F~ish~ Job 8:47 Iri:mm Volume / TypC Behind certoBnt 30 hb~ ~o W~r Rig Rep. Hoit ~' Displacerrrmt Vduane / Type dD 2%KCI 6aker Service ReP- Wa10on E R~e (8P+-~? end Press. {~7 3.~ b~n ~,70o psi os cemer~ker o~v~ Page 9 of 9 .------=~> ~ • ` + ~~~ ~~~~ -~=r- ---~:;-- •', ~~ ~ ~~~~ ~~x~~v~ ~sAyivasuic ~~¢~-rir.~sP ~~ve. ~o: AOGCC Christine Mah~ken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907~ 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT) The technicat data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 ' 3 ~~~'~~ ~l~L `3 ~Q~~ ~:`s~,~,~- _ 900 Benson 81vd. ~3 _ r9 ~ / ~~t~ Anchorage, Alaska 99508 and _~~~ U~C_ ~oG/~-c7~/3 /~s ~(3~ ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 j Leak Detection - STP 13-Jun-09 K 19AL1 Color Log / EDE 50-029-22531-60 ?j Leak Detection - WLD 19-Jun-09 13-24A Color Log / EDE 50-029-2Q739-O'I ~ ~ _ L.r-----'' /~ ! Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 730 W. INTERNATIONAL AIRPORT R~ SUITE C, ANCFtORAGE, AK 99518 PHONE: (907j245-8951 Fnx: (907)245-88952 E-PAAII : . :" ' ,: ; , . ; ; WEBSITE : . , . _ _.__.. _. __. _...-- _ _. _~ _..- --°----_ ._ ~~~ C:~DocumeNS and Se[tings\Owner~Desktop\Transmit_ BP.docx NOT OPERABLE: 13-24A (P~ #2042430) Failed MIT-IA ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 01, 2009 8:02 PM ~~~ ~ ~~ (q'I(~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 13-24A (PTD #2042430) Failed MIT-IA All, Well 13-24A (PTD #2042430) failed an MIT-IA on 01/18/09 and then a repeat test with a triplex on 01/30/09. The well no longer meets the requirements of A10 4E or WIMS. The well has been reclassified as Not Operable and needs to remain shut-in. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9. ~A From: NSU, ADW Well Integrity Engineer Sent: Sunday, January 18, 2009 7:35 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; NSU, ADW Well Operati s Supervisor; Engel, Harry R; GPB, Area Mgr Central (GCl/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarit , livia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: 13-24A (PTD #2042430) IA repressuriz~ All, Well 13-24A (PTD #2042430) is exhibiting IA pressurization. The wellhead pressures were 940/950/100 on 1/17/09 when the IA pressure was bled to psi. The IA repressured 732 psi overnight indicating possible TxIA communication. The well has been recl ified as Under Evaluation and may remain on-line for the MITIA. The plan forward includes: 1. Fullbore: MITIA 2. Well Integrity: If MITIA fits, shut-in and secure well and evaluate for LDL A TIO plot and wellb~re schematic have been included for reference. 4/14/2009 UNDER EVALUATION: 13-24A~TD #2042430) IA repressurization Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~, rI2~~Ze~~ Sent: Sunday, January 18, 2009 7:35 PM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: 13-24A (PTD #2042430) IA repressurization Attachments: 13-24A TIO Plot.doc; 13-24A.pdf ~ All, Well 13-24A (PTD #2042430) is exhibiting IA r~pt-PGS~~ri~ation. The wellhead pressures were 940/950/100 on 1/17/09 when the IA pressure was bled to 16 psi. The IA repressured 732 psi overniaht indicatina possible TxIA communication. The well has been reclassified as Under Evaluation and may remain on-line for the MITIA. The plan forward includes: 1. Fullbore: MITIA 2. Well Integrity: If MITIA fails, shut-in and secure well and evaluate for LDL A TIO plot and wellbore schematic have been included for reference. «13-24A TIO Plot.doc» «13-24A.pdf» Please let me know if there are any questions. Thank you, Anna ~Du6e, ~'. E. ~, ~ ~= ; _ , :- v~r Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x11 S4 1 /28/2009 PBU 13-24A PTD #2042430 1/18 /2009 TIO Plot ~.CiOQ nnn nnn 1,nnn -#- T bg f IA -~ OA OOA OOOA On 10118/09 10125108 11101108 11108/02 11x15108 11/22/08 11/29,'08 12/06108 12113108 12120108 12127108 01103109 01i10i09 d • • TREE = FMC GEN 12 WELLHEAD FMC ACTUATOR ~ ~~ Ah'tLStJN KB. ELEV = 8T RF. FI_FV„Rm~ l KUF' = _~-,~~,~~~-~ 2800' Max Angle = .. 101 @ 10478' . Datum MD = 10244 DatumT'/D __ 8800' SS 13-318" CSG: 72#, L-80: ID = 12.347" )°-~ 2525' SA NOTES: ® ~~: ~~ 2160' ~-j 5-112" OTIS ROM SSSV NIP, ID = 4.562" I ' 95$0' -~ 5-112" OTiS XA SLIDING SLV Inl4lCTt I®= 2.44" ~ 10989° 3-3116" 2-718" XO ~ 5-112" TBG-PC;17#; L-80; .0232 bpf, ID = 4.892"~--{ 971T TOP OF 7" LNR 0'-'I 9792' ~ 4-1t2" TBG-PC,12.6#, N-80..0152 bpf, ID = 3.958" ~-~ 9$22' ~3-112" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.992" ~ 9$40' 9-5(8" CSG, 47#, L-80, iD = 8.681" 10103' 7" X 4-112" BKR WHIPSTOCK {12121104) 10210' PBTD 10673' 7" LNR, 29#, L80, .0371 bpf, fD = 6.184" 10716' TD 10721' PERFORATION SUMMARY REF LOG: MEM GR/CCL CNL ON ' ANGLE AT TOP PERF: 86 @ 11100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11100 - 11210 O 01104!05 2" 6 11240 - 11390 O 01 /04105 2" 6 11410 - 11500 O 01104/05 96$6' 5-112" 80T PBR RSSY 9706' 9-518" X 5-1/2" BOT 3-H PKR 971T 5-112" X 4-1/2" XO 97$1' 3.70" BKR DEPLOY SLV, ID = 3.00" 9$01' 3-1 F2" HES X NIP, ID = 2.813" 9$09' 4-1t2" OTIS XN NIP, MILLED ID = 3.80" {BEHIND PIPE} 9821' 4-1l2" BOT BREAKOUT SUB {BEHIND PIPE) 9$22' 4-1!2" TUBING TAIL {BEHIND PIPE) 9$37° ELMD TT LOGGED 12/09185 {BEHIND PIPE) 9$40' 3-112" X 3-3116" XO, ID = 2.79" 10000' -{TOP OF CEMENT MILLOUT WINDOW {13-24A) 10213' - 10219' ~ 10989' 3-31`16" X 2-7(B" XO, ID = 2.441" 3-3(16" LNR, 6.2#, L-80 TCII, i 10~$J' .0076 bpf, ID = 2.80" PBTD 11747' 2-718" LNR; 6.16#, L-80 STL, .0058 bpf, iD = 2.441" 11783' DATE REV BY COMMENTS DATE REV BY COMMENTS 05122!82 ORIGINAL COMPLETION 01/08183 RWO 01/05105 NORDIC1 CTD SDTRCK (13-24A) 12104105 KDCiTLH DRLG DRAB CORRECTK7NS 12/07/06 RLPNTLH DIAGRAM CORRECTION PRUDHOE BAY UNIT WELL: 13-24A PERMIT Na: 2042430 API No: 50-029-20739-01 SEC 14 T10N 814E 5281.23 FEL 518.22 FNL BP Explcsration {Alaska) • • ~~ ~ h MICR4FtLMED 03/01 /2008 DO NQT PLACE .,_ `~ r. ~. n` ANY NEW MATERIAL UNDER THIS PAGE F:~I..aserFicheiCvrPgs_In~ertslMicrofiltn Marker.cioc l{~~ DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Ja ~~4 API No. 50-029-20739-01-00 Permit to Drill 2042430 MD 11783 __________n_ ..~_,._ Well Name/No. PRUDHOE BAY UNIT 13-24A Operator BP EXPLORATION (ALASKA) INC TVD 9066 UI~ Completion Date 1/4/2005 Completion Status WAGIN Current Status WAGIN -------_._"~-_._..,_.- --------.---.-.-.--- REQUIRED INFORMATION Samples No _.~~_._-,.- Mud log No Directional Survey cÞ ~____._._____~ .·.___.m_·_...~_____ DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / eel/ CNl Well Log Information: Log/ Data Digital :J% Med/Frmt ~:;:' J7 u, r9 (data taken from logs Portion of Master Well Data Maint Electr Dataset Number e Interval Start Stop 10200 11783 10122 11735 10122 11735 10200 11783 Log Log Scale Media Run No OH/ CH Name Directional Survey 13279 Induction/Resistivity 13279 LIS Verification Received 1/27/2005 Comments IIFR ---. ~_._-------- Open Open Open 9/26/2005 . 9/26/2005 2/22/2006 GR EWR4 ROP GR EWR4 ROP ROP NGP EWR plus Graphics Mem Injection Profile, GR, CCl, Pres, Temp, Spin 28- Nov-2006 13566 Induction/Resistivity Injection Profile 2 Blu 10972 11693 Case 1/10/2007 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? .~ Daily History Received? '(Y)N Formation Tops r0 N . Analysis Received? -~----- Comments: 'H-for"' _________,_·_'_.__M__._ -.-----.-----..".--.- ~ Date: ~~ ~& J.',J:l~-7----- Compliance Reviewed By: Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well 17-20 N-22A R-04 17-12 B-01 J-12 13-24A L2-06 DS 04-15 P-25L 1 W-29 P2-50B 03-08 M-15 S-31A Job# 11536189 11538587 11536188 N/A N/A 11513655 11522675 11487579 11477943 11513656 11549353 11513652 11536186 11486170 11478134 u 'c... 8DL(-Ð¿ß Log Description PRODUCTION PROFILE LDL LDL PRODUCTION PROFILE LDL PRODUCTION PROFILE MEMORY INJECTION PROFILE LDL INJECTION PROFILE LDL USIT SCMT SCMT USIT USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: o zorr¡ Date 12/13/06 12/10/06 12/12/06 11/27/06 11/28/06 11/29/06 11/28/06 11/29/06 12/01/06 12/05/06 12/18/06 11/26/06 12/10/06 12/02/06 11/27/06 NO. 4101 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: 01/05/2007 . . · . WELL LOG TRANSMITTAL gO+ -;(4- '3 / ~5lo0 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 13-24A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 13-24A: LAS Data & Digital Log Images: 50-029-20739-01 1 CD Rom 1\/ÍÍ0Q. () øQ Clrh aU; C/ :''': \,;) IJ r 9'/ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 18, 2005 RE: MWD Formation Evaluation Logs: 13-24A, AK.-MW-3465349 1 LDWG formatted Disc with verification listing. API#: 50-029-20739-01 fl }),Y\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Å~ J.¡t ~ c Signed: 1LJ&iJ ;Àò'1-- ~~J> TO: Jim Reggke-dt¡ P.I. Supervisor r l . Zfz410c; State of Alaska Alaska Oil and Gas Conservation commis. DATE: Wednesday, February 09, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-24A PRUDHOE BAY UNIT 13-24A MEMORANDUM FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Supr~'~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-24A Insp Num: mitCS050206163004 Rei Insp Num: API Well Number: 50-029-20739-01-00 Permit Number: 204-243-0 Inspector Name: Chuck Scheve Inspection Date: 2/5/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 13-24A Type Inj. I P i TVD 8438 IA 940 2520 2520 2520 P.T. I 2042430 TypeTest I SPT I Test psi 2109.5 lOA I 250 370 370 370 Interval INITAL PIF P Tubing I 1500 1500 1500 1500 Notes: The pretest pressures were observed and found stable. The well demonstrated good mechanical integrity. Wednesday, February 09, 2005 Page 1 of 1 " RE _ STATE OF ALASKA . ALAS~ILAND GAS CONSERVATION CO I iSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC25.105 20AAC25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2342' NSL, 1584' WEL, SEC. 14, T10N, R14E, UM Top of Productive Horizon: 5237' NSL, 5233' WEL, SEC. 14, T10N, R14E, UM Total Depth: 338' NSL, 4733' WEL, SEC. 11, nON, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685622 y- 5932370 Zone- ASP4 TPI: x- 681901 y- 5935175 Zone- ASP4 Total Depth: x- 682390 y- 5935568 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD GR / EWR, MGR / CCL / CNL 22. One Other 5. Date Comp., Susp., or Aband. 1/4/2005 6. Date Spudded 12/30/2004 7. Date ToO. Reached 1/2/2005 8. KB Elevation (ft): 87' 9. Plug Back Depth (MD+ TVD) 11747 + 9040 10. Total Depth (MD+TVD) 11783 + 9066 11. Depth where SSSV set (Nipple) 2160' MD 19. Water depth, if offshore NIA MSL 20" 13-3/8" 9-5/8" PER FT. 91.5# 72# 47# 29# CASING, LINER AND CEMENTING RECORD $ETTINéDEBTH MD SETTING DEPTHTVD BOTTOM Top BOT1tOM 79' Surface 79' 2525' Surface 2525' 10103' Surface 8768' 10213' 8509' 8861' 11783' 8500' 9066' 7" 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2#/6.16# H-40 Surface L-80 Surface L-80 / SOO-95 Surface K-80 9792' L-80 9781' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 11100' - 11210' 8934' - 8936' 11240' - 11390' 8931' - 8930' 11410' - 11500' 8931' - 8932' 26. Date First Production: January 21, 2005 Date of Test Hours Tested 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 204-243 13. API Number 50- 029-20739-01-00 14. Well Name and Number: PBU 13-24A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028311 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 30" 490 sx Arcticset II 17-1/2" 2555 sx Fondu, 400 sx Permafrost 'C' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 8-1/2" 327 sx Class 'G' 4-1/8" x 3-3/4" 112 sx Class 'G' 24. PACKER SET (MD) 9706' SIZE DEPTH SET (MD) 5-1/2",17#, L-80 9717' 4-1/2",12.6#, L-80 9717' - 9822' FRActURE, DEPTH INTERVAL (MD) 2100' AMOUNT & KIND OF MATERIAL USED Freeze Protect MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF WATER-BsL PRODUCTION FOR TEST PERIOD .. CALCULATED .. 24-HoUR RATE OIL-BSL Flow Tubing Casing Pressure Press. GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Sub~Jt core if none, state "none". fJRIGI!\~f\t CONTINUED ON REVERSE SIDE RBDMS BFl JAN 31 2005 r ..~ í", L ",f 28. GEOLOGIC MARK. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit / 46P 10241' 8883' None 45N 10294' 8918' 45P 10304' 8923' (Fault) 45N 45P 11076' 8932' 11089' 8933' 11215' 8935' 11227' 8933' 11562' 8943' 11575' 8947' 11684' 8998' 11692' 9003' 11730' 9028' 11735' 9031' 45P (Invert) 45N (Invert) 45N (Revert) 45P (Revert) 44N (Revert) 44P (Revert) 43N (Revert) 43P (Revert) 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I ~erebY certify that the f/Oi~9 is true and correct to the best of my knowledge. Signed Terrie HUbblif'îV'Nki fi~ Title Technical Assistant Date 0 I·:A. 7 r OS PBU 13-24A 204-243 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4387 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 12/27/2004 18:00 - 00:00 6.00 MOB P PRE PJSM Lay down wind walls, Scope and lay down derrick. Prep location for move. Rig down camp, etc. 12/28/2004 00:00 - 03:30 3.50 MOB PRE Traveled to DS 1 03:30 - 08:20 4.83 MOB PRE Raised derrick and windwalls, wind picking up 08:20 - 12:30 4.17 MOB PRE Move rig to DS13-24 12:30 - 16:45 4.25 MOB N WAIT PRE Wait for DSM to install platform Pump open SSSV 16:45 - 20:00 3.25 MOB N PRE Check pressures on wellhead: o psi lA, 0 psi OA. ND tree cap. Move rig over well. RIG ACCEPT 19:30 HRS. 20:00 - 21 :00 1.00 MOB N PRE Stab BOP. NU BOP. 21 :00 - 00:00 3.00 MOB N PRE PU lubricator and injector and stab into well. 12/29/2004 00:00 - 02:30 2.50 MOB P PRE Pull coil tubing to injector. 02:30 - 03:00 0.50 BOPSUP P PRE Test BOP. AOGCC notified but didn't respond. Jim Regg with AOGCC waived witness. 03:00 - 05:30 2.50 BOPSUP N WAIT PRE Wait on grease crew. 05:30 - 17:30 12.00 BOPSUP P PRE Continue Testing BOPE. At 10:00 hrs, found swab valve leaking again. Call out grease crew while continuing on with test. Grease crew on location at 10:30. Continue testing BOPE. 17:30 - 19:50 2.33 WHIP P WEXIT Dart catcher - Pull test to 25k - Test Hard Line to 800 psi OK. PT 4000 psi OK. - Launch dart with 165 psi. Pump Dart 58.9 bbl calculated vol 2.62 bpm at 176 psi. Pump at 57.1 bbl. 19:50 - 21 :00 1.17 WHIP P WEXIT MU BHA #1 window mill 21 :00 - 22:45 1.75 STWHIP P WEXIT RIH to 9810 XN nipple. 22:45 - 23:30 0.75 STWHIP P WEXIT Mill XN nipple 23:30 - 23:45 0.25 STWHIP P WEXIT Continue to RIH. Tag WS correct depth +4'. 23:45 - 00:00 0.25 STWHIP P WEXIT Mill window. 12/30/2004 00:00 - 01 :15 1.25 STWHIP WEXIT Attempt to mill window. NO GO Not acting right. Instant stall always at 10198.5'. 01:15 - 03:00 1.75 STWHIP N DPRB WEXIT POH 03:00 - 04:15 1.25 STWHIP N DPRB WEXIT Mill and string mill both under gage. String mill 3.77 no go I 3.78 go. Speed mill 3.73 no go 13.74 go. String mill has a crack around the circumference of the matrix sleeve 15.5 " back from wear on speedmill's leading edge. Gauge of speed mill worn but no wear on the face of the mill. Mill not showing normal pinch point contact. We did see indications that the tailpipe was still in position. But cannot explain what we are seeing. Decided to PU new motor, speed mill and 3.79 string milll. 04:15 - 06:00 1.75 STWHIP N DPRB WEXIT RIH. Tag pinch point at flag at 10,196' MD. - Went right through XN nipple, no bobble. Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 12/30/2004 06:00 - 07:15 1.25 STWHIP P WEXIT 07:15 - 12:00 4.75 STWHIP P WEXIT 12:00 - 12:45 0.75 STWHIP P WEXIT 12:45 - 14:15 1.50 STWHIP P WEXIT 14:15 - 14:45 0.50 STWHIP P WEXIT 14:45 - 15:15 0.50 DRILL P PROD1 15:15 - 16:45 1.50 DRILL P PROD1 16:45 - 19:00 2.25 DRILL P PROD1 19:00 - 19:45 0.75 DRILL P PROD1 19:45 - 20:00 0.25 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 12/31/2004 00:00 - 01:15 1.25 DRILL P PROD1 01:15 - 03:00 1.75 DRILL P PROD1 03:00 - 04:15 1.25 DRILL P PROD1 04:15 - 06:30 2.25 DRILL P PROD1 06:30 - 08:00 1.50 DRILL P PROD1 08:00 - 09:45 1.75 DRILL N DPRB PROD1 Begin window milling. Suspect milling cement, milling at 0.1' I 1-2 min, drilling off. Cement coming across shakers at bottoms up. - 1550 psi free spin - 2.55 I 2.66 bpm - Milling at 1700 - 1900 psi. Begin milling window at 10,198.8' MD, break out of window at 10,203.0' MD. Drill formation to 10,215' MD. - Seeing metal shavings on magnets. - 1550 psi free spin - 2.55/2.66 bpm - Milling at 1700 psi, never exceding 400 psi working pressure or 1-3k WOB. - Milling formation to 10,215' MD. Samples indicate formation. - Dress window. - Dry run, no motor work. - Begin displacing well to Flo Pro. Continue swapping well bore fluid to reconditioned Flo Pro. POOH, swapping to reconditioned flo pro. Lay down BHA #2. - Mill 2.8 go (barely), string reamer 2.78 go (barely) - Mill shows good indication of window milling. Pre Spud meeting PJSM for PU build drilling BHA #3. PU build drilling BHA #3. MU and test CTC. RIH. SHT at 2800' MD. Continue to RIH 10170'. Tie - in Sag River correction + 15' RIH tag 10231'. Orient HS. Directionally drill 2.76/2.74 bpm at 3600 psi ,FS 3450 psi., Up wt Dn wt 21 K, ROP 35. Directionally drill to 10380 end of build. POH LD building assembly and PU lateral assembly. RIH to 1 0198'MD, tag up. Orient TF. Exit window at 44 deg ROHS. - Pit volume 255 bbls. Tie in to RA tag. Correct -6' MD. Orient TF to 20L. RIH to bottom. Tagging up 'early' at 10,355' MD. Orient to try and get by. No-go. Survey's up. Surveys indicate we are on bottom. Re-tie in to GR and RA tag to confirm depths. - Found +27' discrepancy in depths. The sequence of events and the depths at which they occurred were in line with a typical tie in; however, when all indications showed we were actually on bottom despite the depth of 10,355', we opted to re-tie in to the GR and RA marker. - CONCLUSION:The tag at the 'window' correlates to a TF change in the directional. The RA we corrected to correlates to a very hot shale stringer in the GR. In short, the correction of -6' was not correct. The +27' correction puts us in line. Tag bottom as expected, 10,380' MD. Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 12/31/2004 08:00 - 09:45 1.75 DRILL N DPRB PROD1 WINDOW DATA: TOW: 10,213' MD BOW: 10,218' MD RA: 10,219' MD 09:45 -11:15 1.50 DRILL P PROD1 Drill ahead to 10,502' MD - 2950 free spin - 2.58 / 2.60 at 3400 psi. - ROP at approximately 120 fph. - Pit volume at 229 bbls. - Looks like we are losing fluid at approximately 6 bbls an hour. 11 :15 - 12:45 1.50 DRILL N DFAL PROD1 POOH for larger bend on motor. - Angle built from 92 deg to 101 deg in 78 feet due to an error in the internal offset (orienter read 135R, actually drilling at 35R). Could not get back down and still make turn before fault. - Pit volume 216 bbls prior to POOH, losses still at 6 bph. 12:45 - 13:15 0.50 DRILL N DFAL PROD1 Change motor bend to 2 deg. 13:15 - 15:40 2.42 DRILL N DFAL PROD1 RIH with BHA #5. SHT. Continue to RIH. Orient LOHS for exiting window. Tag bottom at 10,483', correct +19' to 10,502' MD. 15:40 - 16:00 0.33 DRILL N DFAL PROD1 Orient to 140 ROHS. 16:00 - 17:00 1.00 DRILL P PROD1 Drill ahead to 10,545' MD. - 3000 psi free spin - 2.6 / 2.6 bpm at 3500 psi - ROP at 80 fph - PU 32k; SO 21k - Pit volume at 200 bbls. Losses at 10 bph for last hour. 17:00 - 17:30 0.50 DRILL P PROD1 Orient TF to 90 R. 17:30 - 19:30 2.00 DRILL P PROD1 Drill ahead - 3000 psi free spin - 2.6/2.6 bpm at 3500 psi - ROP at 80 fph - PU 32k; SO 21k 19:30 - 21 :00 1.50 DRILL P PROD1 Drill ahead - 3000 psi free spin - 2.6/ 2.6 bpm at 3500 psi - ROP at 50 fph - PU 32k; SO 17k 21 :00 - 21 :18 0.30 DRILL P PROD1 Wiper to 10250. 21 :18 - 21 :45 0.45 DRILL P PROD1 Orient 73R 21 :45 - 22:30 0.75 DRILL P PROD1 Drill ahead - 3000 psi free spin - 2.6/2.6 bpm at 3500 psi - ROP at 75 fph - PU 32k; SO 17k -Loss rate remaining 10 bbllhr 22:30 - 22:45 0.25 DRILL P PROD1 Orient 100R 22:45 - 23:20 0.58 DRILL P PROD1 Drill ahead - 3300 psi free spin - 2.7/2.7 bpm at 3400 psi - ROP at 120 fph - PU 36k; SO 16k Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 12/31/2004 23:20 - 00:00 0.67 DRILL P PROD1 Wiper to 10250. 1/1/2005 00:00 - 02:00 2.00 DRILL P PROD1 Mud swap while Drill ahead - 3100 psi free spin - 2.7 I 2.7 bpm at 3450 psi - ROP at 90 fph - PU 36k; SO 19k - Fill pits Drill to 10870. 02:00 - 04:00 2.00 DRILL P PROD1 POH for restivity and dial down motor. 04:00 - 05:00 1.00 DRILL P PROD1 LD Bha. Set back injector 05:00 - 06:15 1.25 DRILL P PROD1 Cut and slip drill line. 06:15 - 08:30 2.25 DRILL P PROD1 PU BHA #6 with 1.37 deg motor and resistivity. - Program and upload resistivity. 08:30 - 10:30 2.00 DRILL P PROD1 RIH with BHA #6. SHT. Continue to RIH. Orient through window. 10:30 - 12:00 1.50 DRILL P PROD1 Tie in to RA marker. Correct +19'. RIH to TD. -35k PU; 19k SO 12:00 - 16:15 4.25 DRILL P PROD1 Drill ahead 11,050' MD - 3000 psi free spin - 2.6 / 2.6 bpm at 3450 psi - ROP at 60 fph - PU 35k; SO 19k - Pick fault at 10,840' MD from GR, losses stable at 6 bph. 16:15 - 17:00 0.75 DRILL P PROD1 Wiper trip to window. - PU 36k; SO 15K 17:00-17:10 0.17 DRILL P PROD1 Drill ahead 11,062' MD - 3000 psi free spin - 2.6 / 2.6 bpm at 3450 psi - ROP at 90 fph - TF at 90L 17:10 - 17:25 0.25 DRILL P PROD1 Orient around to 120L. 17:25 - 18:30 1.08 DRILL P PROD1 Drill ahead to 11125 - 3000 psi free spin - 2.61 2.6 bpm at 3450 psi - ROP at 90 fph - TF at 120 L - Sticky off bottom, 10k over pull. 18:30 - 19:50 1.33 DRILL P PROD1 Wiper to window. 19:50 - 20:00 0.17 DRILL P PROD1 Orient 9R 20:00 - 21:10 1.17 DRILL P PROD1 Drill ahead to 11140 - 3050 psi free spin - 2.56/ 2.6 bpm at 3450 psi - ROP at 105 fph - TF at HS 21 :10 - 21 :20 0.17 DRILL P PROD1 Orient 65R 21 :20 - 23:00 1.67 DRILL P PROD1 Drill ahead to 11310. - 3050 psi free spin - 2.561 2.6 bpm at 3450 psi - ROP at 105 fph - TF at 146R 23:00 - 23:35 0.58 DRILL P PROD1 Wiper to 10275 23:35 - 00:00 0.42 DRILL P PROD1 TIE - in log +3' 1/2/2005 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 1/212005 01 :00 - 03:00 2.00 DRILL P PROD1 Drill ahead to 11450 - 3250 psi free spin - 2.56/ 2.6 bpm at 3500 psi - ROP at 105fph - TF at 56R - Swap mud to new flo pro system. 03:00 - 04:00 1.00 DRILL P PROD1 Wiper to window. 04:00 - 06:30 2.50 DRILL P PROD1 Drill ahead to 11600. - 3250 psi free spin - 2.56/ 2.6 bpm at 3500 psi - ROP at 60fph - TF at 165R 06:30 - 08:00 1.50 DRILL P PROD1 Wiper trip to window. Hole in good condition. - PU 37k; SO 15k 08:00 - 09:15 1.25 DRILL P PROD1 Drill ahead to 11720. - 3250 psi free spin - 2.56/2.6 bpm at 3500 psi - ROP at 110fph - TF at 155 L - Losses still at 6 bph; however, lost 20 bbls in 20 minutes at 11,700' MD then stabilized back at 6 bph. 09:15 - 12:00 2.75 DRILL P PROD1 Wiper trip to Tubing Tail, clean 7" low energy annulus. - PU 38k; SO 15k 12:00 - 12:15 0.25 DRILL P PROD1 Orient TF to 130L 12:15-13:00 0.75 DRILL P PROD1 Drill ahead to 11,780 MD, 8980 TVD -- TD as per Geo. - 3000 psi free spin . 2.5/ 2.5 bpm at 3450 psi - ROP at 11 Of ph - Losses at 6 bph. 13:00 - 13:15 0.25 DRILL P PROD1 Final wiper trip. 13:15 - 14:00 0.75 DRILL P PROD1 MAD pass from 10910 to 10270' MD. 14:00 - 14:30 0.50 DRILL P PROD1 Tie in to RA tag/GR. Correct +6'. 14:30 - 15:30 1.00 DRILL P PROD1 RBIH. - Start pill down coil. 15:30 - 16:30 1.00 DRILL P PROD1 Pull out of open hole, laying in 26 bbls liner pill. 16:30 - 18:00 1.50 DRILL P PROD1 POOH to surface. 18:00 - 20:00 2.00 DRILL P PROD1 Stand back injector. Lay down BHA and download RES tool. 20:00 - 21 :45 1.75 CASE P RUNPRD Change out coil connector Pull and Pressure test. Pump Dart. 57.2 bbls. 21:45-22:10 0.42 CASE P RUNPRD PJSM 22:10 - 00:00 1.83 CASE P RUNPRD RU and Run 2001' liner 2-7/8 X 3-3/16. 1/3/2005 00:00 - 03:00 3.00 CASE P RUNPRD Continue to PU liner 2-7/8 X 3-3/16 and running tools. 03:00 - 04:30 1.50 CASE P RUNPRD MU to injector and RIH with liner. 04:30 - 07:30 3.00 CASE P RUNPRD Drop 5/8" steel ball and launch with 800 psi. Diplace with FloPro 2.5/2.4 BLM @ 2500 psi .Ball on seat 45.5 bbl. Shear at 4000 psi. PU released from liner. Change well over to KCL. 07:30 - 08:30 1.00 CEMT P RUNPRD Rig up cementers. Mix bio pill. Batch mix 23 bbls cement. PJSM for cement job. 08:30 - 09:30 1.00 CEMT P RUNPRD Pump Cement. - Test lines to 4000 psi. - Pump 3 bbls fresh water, zero in MM. . Pump 23.1 bbls cement. - Clear/blow down lines. Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 12/27/2004 1/4/2005 N1 Spud Date: 5/2/1982 End: 1/3/2005 08:30 - 09:30 1.00 CEMT P RUNPRD - Load dart. - Pump 30 bbls bio-water. - Follow with 2% double slick KCI at 2.5 bpm 1700 psi. - Losing approximately 0.2 bpm during displacment. - Zero out MM at 48.2 bbls. - No cement loss to formation, 22.9 bbls behind pipe, 0.2 bbls in shoe track. - Slow pump to 1.9 bpm 1100 psi at 55 bbls away. - Latch LWP at 57.7 bbls (57.2 bbls theoretical). - Bump plug at 70.9 bbls (71.2 bbls theoretical). - Pressure up to 2300 psi. - Check floats, ok. - Pressure up to 200 psi. Unsting. 09:30 - 11 :00 1.50 CEMT P RUNPRD POOH, replacing voidage. 11 :00 - 11 :30 0.50 CEMT P RUNPRD Change out injector sling. Lay down CTLRT. 11 :30 - 15:00 3.50 EV AL P LOWER1 Prep tools. PJSM. PU MCNUcleanout BHA. 15:00-16:15 1.25 EVAL P LOWER1 RIH with logging/cleanout BHA. 16:15 - 17:30 1.25 EVAL P LOWER1 Log down at 30 fpm from 9650' MD. Tag bottom at 11,730' MD. 17:30 - 18:00 0.50 EVAL P LOWER1 Log up at 60 fpm from TD to 9650' MD, laying in bleach pill. 18:00 - 19:00 1.00 EVAL P LOWER1 Drop 5/8" circ ball. Shear at 3280 psi. 19:00 - 21 :00 2.00 EVAL P LOWER1 POH 21 :00 - 22:50 1.83 EVAL P LOWER1 Standback CSH 32 stands. Remove source from nuk tool and LD tool. LD cleanout motor and mill. 22:50 - 23:40 0.83 PERFOB P LOWER1 MU nozzle and Stab injector into well and wash stack. 23:40 - 00:00 0.33 PERFOB P LOWER1 Test Liner lap to 3000 psi for 30 min. 1/4/2005 00:00 - 00:30 0.50 PERFOB P LOWER1 Test Liner and Lap to 3075 psi. Lost 6.5% in 30 min.OK. - Initial pressure 3075 - Final pressure 2875 00:30 - 01 :00 0.50 PERFOB P LOWER1 Prep floor and load guns into pipe shed. 01 :00 - 01: 15 0.25 PERFOB P LOWER1 PJSM running perfarating guns. 01:15 - 02:00 0.75 PERFOB P LOWER1 Pu perforating guns 350' + 50 blanks. to perforate intervals: 11100 - 11210 11240 - 11390 11410 - 11500 02:00 - 03:00 1.00 PERFOB P LOWER1 PU 27 stands CSH. 03:00 - 03:25 0.42 PERFOB P LOWER1 PU injector and stab onto well. 03:25 - 06:00 2.58 PERFOB P LOWER1 RIH with perforating assembly. Tag bottom and correct to 11746'. PU to 11500. Pump 10 bbl bleach. Drop 5/8 Aluminum ball. Displace with 5 bbl bleach. 06:00 - 07:30 1.50 PERFOB P LOWER1 POOH. 07:30 - 08:00 0.50 PERFOB P LOWER1 Flow check well at CSH. OFF CRITICAL PATH: Prepare rig floor for laying down CSH. 08:00 - 09:00 1.00 PERFOB P LOWER1 Stand back 27 stands CSH. 09:00 - 11 :00 2.00 PERFOB P LOWER1 PJSM. Prep floor. Lay down guns. Clear floor. 11 :00 - 12:00 1.00 WHSUR P POST MU nozzle. RIH to 2100'. FP to surface. POOH. 12:00 - 12:15 0.25 WHSUR P POST Blow down coil with N2. N2 unit down. 12:15 - 12:45 0.50 WHSUR P POST Wait on replacement N2 unit. 12:45 - 13:15 0.50 WHSUR P POST Blow down coil with N2 Printed: 1/10/2005 9:24:24 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-24 13-24 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/27/2004 Rig Release: 1/4/2005 Rig Number: N1 Spud Date: 5/2/1982 End: 1/4/2005 13:15 - 16:30 3.25 WHSUR P POST ND BOP. NU and test tree cap. Release Rig 1630 hrs. Printed: 1/10/2005 9:24:24 AM Halliburton Sperry-Sun North Slope Alaska BPXA 13-24A . Job No. AKMW3465349, Surveyed: 2 January, 2005 Survey Report 17 January, 2005 Your Ref: API 500292073901 Surface Coordinates: 5932370.13 N, 685622.24 E (70013' 12.7867" N, 148030' 08.4869" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 87.00ft above Mean Sea Level sper"r"Y-sul'1 DRILLING 'SERVIC:ES A Halliburton Company Survey Ref: svy4471 Halliburton Sperry-Sun Survey Report for 13·24A Your Ref: API 500292073901 Job No. AKMW3465349, Surveyed: 2 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10200.00 32.250 316.000 8762.52 8849.52 2220.87 N 3524.64 W 5934503.64 N 682044.05 E 1575.08 Tie On Point MWD Magnetic 10210.00 32.150 316.100 8770.98 8857.98 2224.71 N 3528.34 W 5934507.38 N 682040.25 E 1.132 1578.22 10213.00 32.797 316.055 8773.51 8860.51 2225.87 N 3529.45 W 5934508.52 N 682039.11 E 21.588 1579.17 Window Point 10239.85 38.590 315.710 8795.30 8882.30 2237.10 N 3540.36 W 5934519.48 N 682027.93 E 21.588 1588.34 . 10270.35 50.360 315.310 8817.03 8904.03 2252.32 N 3555.31 W 5934534.32 N 682012.61 E 38.601 1600.72 10300.35 60.910 314.920 8833.94 8920.94 2269.83 N 3572.77 W 5934551.41 N 681994.73 E 35.183 1614.94 10330.18 73.030 314.580 8845.59 8932.59 2289.12 N 3592.23 W 5934570.21 N 681974.80 E 40.644 1630.56 10358.50 83.580 309.940 8851.32 8938.32 2307.72 N 3612.73 W 5934588.30 N 681953.84 E 40.551 1645.32 10389.36 90.180 308.010 8853.00 8940.00 2327.09 N 3636.67 W 5934607.07 N 681929.43 E 22.279 1660.24 10414.48 93.870 307.480 8852.12 8939.12 2342.46 N 3656.52 W 5934621.95 N 681909.21 E 14.840 1671.92 10442.02 98.610 308.180 8849.12 8936.12 2359.24 N 3678.14 W 5934638.20 N 681887.19 E 17.396 1684.70 10478.05 100.280 310.640 8843.21 8930.21 2381.80 N 3705.60 W 5934660.07 N 681859.18 E 8.176 1702.15 10502.11 96.770 313.460 8839.64 8926.64 2397.74 N 3723.26 W 5934675.57 N 681841.14 E 18.632 1714.77 10532.90 90.260 314.510 8837.76 8924.76 2419.07 N 3745.36 W 5934696.35 N 681818.52 E 21.415 1731.94 10562.00 88.310 319.330 8838.12 8925.12 2440.31 N 3765.23 W 5934717.10 N 681798.13 E 17.866 1749.42 10592.45 88.420 327.520 8838.99 8925.99 2464.74 N 3783.35 W 5934741.07 N 681779.42 E 26.888 1770.32 10622.46 84.460 332.440 8840.85 8927.85 2490.66 N 3798.33 W 5934766.61 N 681763.80 E 21.018 1793.25 10652.12 84.640 340.700 8843.68 8930.68 2517.72 N 3810.06 W 5934793.38 N 681751.41 E 27.729 1817.86 10681.70 87.010 346.330 8845.83 8932.83 2546.00 N 3818.42 W 5934821.45 N 681742.35 E 20.603 1844.26 10711.31 88.770 355.470 8846.92 8933.92 2575.19 N 3823.10 W 5934850.51 N 681736.96 E 31.413 1872.19 10744.07 91.140 359.160 8846.95 8933.95 2607.90 N 3824.63 W 5934883.18 N 681734.63 E 13.386 1904.14 . 10774.43 92.640 9.350 8845.94 8932.94 2638.12 N 3822.38 W 5934913.44 N 681736.13 E 33.907 1934.29 10805.11 93.690 12.340 8844.25 8931.25 2668.20 N 3816.62 W 5934943.66 N 681741.15 E 10.315 1964.92 10835.63 93.430 23.070 8842.35 8929.35 2697.18 N 3807.37 W 5934972.85 N 681749.68 E 35.100 1995.06 10871.66 91.980 29.230 8840.65 8927.65 2729.47 N 3791.52 W 5935005.52 N 681764.74 E 17.545 2029.61 10903.85 92.860 34.870 8839.29 8926.29 2756.72 N 3774.46 W 5935033.18 N 681781.12 E 17.717 2059.41 10931.58 91.890 39.620 8838.14 8925.14 2778.76 N 3757.69 W 5935055.63 N 681797.34 E 17.468 2084.03 10959.58 89.520 43.320 8837.79 8924.79 2799.74 N 3739.16 W 5935077.06 N 681815.36 E 15.691 2107.91 10989.60 85.290 48.790 8839.15 8926.15 2820.54 N 3717.58 W 5935098.38 N 681836.42 E 23.016 2132.14 11035.15 85.900 43.150 8842.65 8929.65 2852.09 N 3684.94 W 5935130.73 N 681868.27 E 12.418 2168.88 11063.89 87.140 36.630 8844.40 8931 .40 2874.09 N 3666.55 W 5935153.17 N 681886.11 E 23.051 2193.74 11092.59 86.080 31.340 8846.10 8933.10 2897.84 N 3650.54 W 5935177.31 N 681901.53 E 18.767 2219.90 11130.89 83.260 27.990 8849.66 8936.66 2930.96 N 3631.67 W 5935210.89 N 681919.58 E 11 .404 2255.80 11169.76 89.600 31.170 8852.08 8939.08 2964.68 N 3612.53 W 5935245.06 N 681937.89 E 18.239 2292.33 11202.05 98.060 35.750 8849.92 8936.92 2991.53 N 3594.79 W 5935272.34 N 681954.96 E 29.772 2321.85 17 January, 2005· 14:31 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 13-24A Your Ref: API 500292073901 Job No. AKMW3465349, Surveyed: 2 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11233.81 98.500 41 .560 8845.34 8932.34 3016.06 N 3575.17 W 5935297.35 N 681973.97 E 18.155 2349.42 11265.47 94.800 43.680 8841 .68 8928.68 3039.20 N 3553.88 W 5935321.00 N 681994.68 E 13.446 2375.90 11295.68 91.010 37.860 8840.15 8927.15 3062.03 N 3534.19 W 5935344.32 N 682013.81 E 22.966 2401.81 11327.86 88.810 38.210 8840.20 8927.20 3087.38 N 3514.37 W 5935370.14 N 682033.00 E 6.923 2430.21 11362.44 85.900 44.560 8841.79 8928.79 3113.28 N 3491.55 W 5935396.60 N 682055.18 E 20.180 2459.68 . 11397.98 88.370 52.310 8843.57 8930.57 3136.81 N 3465.01 W 5935420.77 N 682081.13 E 22.860 2487.46 11428.41 90.570 57.770 8843.85 8930.85 3154.24 N 3440.08 W 5935438.81 N 682105.62 E 19.343 2508.95 11461.58 90.400 67.470 8843.57 8930.57 3169.47 N 3410.66 W 5935454.76 N 682134.65 E 29.247 2529.07 11494.03 85.730 66.940 8844.67 8931.67 3182.03 N 3380.77 W 5935468.05 N 682164.23 E 14.484 2546.63 11526.52 80.530 69.580 8848.55 8935.55 3193.98 N 3350.83 W 5935480.73 N 682193.87 E 17.922 2563.59 11562.28 74.180 70.640 8856.38 8943.38 3205.85 N 3318.03 W 5935493.40 N 682226.36 E 17.991 2580.97 11595.72 67.750 71 .520 8867.28 8954.28 3216.10 N 3288.15 W 5935504.38 N 682255.99 E 19.388 2596.26 11630.83 61.760 69.230 8882.25 8969.25 3226.74 N 3258.25 W 5935515.76 N 682285.62 E 18.050 2611.93 11663.84 55.950 71.520 8899.31 8986.31 3236.24 N 3231.66 W 5935525.91 N 682311.97 E 18.573 2625.91 11697.76 51.190 66.940 8919.46 9006.46 3245.88 N 3206.15 W 5935536.18 N 682337.23 E 17.741 2639.83 11734.24 45.810 62.360 8943.63 9030.63 3257.53 N 3181.46 W 5935548.43 N 682361.63 E 17.484 2655.59 11757.92 42.820 54.430 8960.58 9047.58 3266.16 N 3167.38 W 5935557.40 N 682375.49 E 26.567 2666.53 11783.00 42.820 54.430 8978.98 9065.98 3276.07 N 3153.51 W 5935567.65 N 682389.11 E 0.000 2678.70 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. . The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 10.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11783.00f1., The Bottom Hole Displacement is 4547.23f1., in the Direction of 316.0920 (True). 17 January, 2005 - 14:31 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 13-24A Your Ref: API 500292073901 Job No. AKMW3465349, Surveyed: 2 January, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10200.00 10213.00 11783.00 8849.52 8860.51 9065.98 2220.87 N 2225.87 N 3276.07 N 3524.64 W 3529.45 W 3153.51 W Tie On Point Window Point Projected Survey . Survey tool program for 13-24A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10200.00 0.00 10200.00 8849.52 11783.00 8849.52 CB-GYRO-MS (13-24) 9065.98 MWD Magnetic (13-24A) . 17 January, 2005 - 14:31 Page 4 of 4 DrillQuest 3.03.06.008 TREE = WELLHEAD = Max Angle = Datum MD = Datum FMCGEN 12 FMC 87' 113-318" CSG, 72#, L-80, 10 = 12.347" I Minimum iD = 2.37" @ 10989' I 2-7/8" STL pin iD 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892"1-f I TOP OF 4-1/2" 1-( TOPOF 7" LNR 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, 10 = I 9-5/8" CSG, L-80, 10=8.681" PERFORATION SUMMARY REF LOG: SWS MEMORY CNUGR OF 01/03/05 ANGLE AT TOP PERF: 86 Deg. @ 11,100' Note: Refer to Production DB SIZE SPF INTERVAL Opn/Sqz DATE 2.0" 6 11,100-11,210' 6 11,240 -11,390' 6 11,410 -11,500' I 7" LNR, 29#, L80, .0371 bpf, = 6,184" DATE OS/22/82 01/08/83 01/03/01 01/29/01 06/19/01 REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-SLT CONVERTED TO CANVAS SIS-MO FINAL RNlTP CORRECTIONS 9717' 9717' . ~ "- I I - L J z \ J i I 9822' I I SAFETY NOTES 1-15-1/2" 9580' 9686' 9106' 9117' x 9809' 1-( ELMD TT : DATE REV BY COMMENTS 01/06/05 RRW CTD SIDETRACK WELL: 13-24 A PERMIT No: 82-065 API No: 50-029-20739-01 SEC14 FNL BP . AOGCC Helen Wafman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well 13-24A Deaf Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,200.00 I MD 10,213.00' MD 11,783.00' MD (if applicable) 18-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date;2) ~)("""^:tf'f \" Signed /7 / .'.' " it /' I ¿' (~t'w~~l O/t V Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ;lD tf - J- <¡ 1 · . ~~~~E ffiJF ~~~~~~ AI,ASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay K-07D BP Exploration (Alaska) Inc. Permit No: 204-243 Surface Location: 2342' NSL, 1584' WEL, SEC. 14, TI0N. RI4E, UM Bottomhole Location: 347' NSL, 4924' WEL, SEC. 11, TI0N, RI4E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development welL This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- (pager). reI ......... DATED this bay of December, 2004 cc: Department ofFish & Game, Habitat Section w/o encL Department of Environmental Conservation w/o encL o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2342' NSL, 1584' WEL, SEC. 14, T10N, R14E, UM Top of Productive Horizon: 4579' NSL, 5122' WEL, SEC. 14, T10N, R14E, UM Total Depth: 347' NSL, 4924' WEL, SEC. 11, T10N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685622 y- 5932370 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 10210 feet Maximum Hole Angle: 91 degrees \.J4 I\- i LIII t..d<"t . STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION~MMISSION PERMIT TO DRILL 20 MC 25.005 'yJ 6ft- \1b. Current Well Class OFxploratory~velopment Oil 0 Multiple Zone o Stratigraphic Test ßjJ'Service 0 Development Gas 0 Single Zone 5. Bond: 181 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 13-24A ./ 6. Proposed Depth: 12. Field 1 Pool(s): MD 11595 TVD 8981ss Prudhoe Bay Field 1 Prudhoe Bay 7. Property Designation~ I. f/# Pool ADL 02831Yo2.<15/5 8. Land Use Permit: 13. Approximate Spud Date: December 28, 2004 14. Distance to Nearest Property: 13,150 9. Acres in Property: 2560 18. Casing Program: Size Hole Casing 4·1/8" x 3-3/4" 3·3/16" x 2·7/8" Weight 6.2# 16.16# Spec:jficat¡on~ Grade Coupling Length L-80 TCIII STL 1820' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 87' feet 16-06A is 1710' away 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3260 Surface: 2380./ Setting . Depth Top .......... ... ... ..... ..... .. ..Sottom MD TYD MD TYD (including stage data) 9775' 8408' 11595'" 8981' 82 sx Class 'G' 19. PR,E$ENTWELL.CONDITIONSUMMAR'( (To Total Depth MD (ft): Total Depth TYD (ft): Plugs (measured): Effective Depth MD (ft): 10721 9299 None 10673 Junk (measured): None Structural _ Conductor 79 20" 490 sx Arcticset 11 Surface 2525' 13-3/8" 2555 sx Fondu, 400 sX PF 'C' Intermediate 10103' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' _ Production Liner 924' 7" 327 sx Class 'G' 79' 2525' 10103' 79' 2525' 8768' 9792' - 10716' 8509' - 9295' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TYD (ft): 8792' - 9101' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements Date: Perforation Depth MD (ft): 10132' - 10494' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sean McLaughlin Title CT Drilling Engineer ( Signature ) .r-'" Contact Sean McLaughlin, 564-4387 (.L..~ Phone 564-4387 Date I Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Permit Approval/See cover letter for Number:...z 0'7 - 2'7'3 50- 029-20739-01-00 Date: IÄ-f 7/bt/ other requirements Conditions of Approval: Samples Required 0 Yes gNo Mud Log Required I 0 Yes ..:J8·No Hy n Sulfide Measures ~Yes 0 No Directional Survey Required .J8Yes 0 No Other: Te<:.t- t 0 ·~S"OO pr,../, AlrI.T) œV¡,(eI-L~ ÓUt:<{,'t"l (OCI -rOÓv-i'N'd" ---- ORIGINAL APPROVED BY THE COMMISSION Date ¡'74¡;~ :Zm~" ~~Iicate . BP 13-24Ai Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement Mud Program: . Well kill: 8.4 - 8.9 PP~. tin e · Milling/drilling: 8.5 (8.9 pg used Flo Pro or biozan for milling, new PIo Pro for drilling. \::: ... Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 33/16" x 2 7/8" solid cemented liner comp.~~ · The liner cement volume is planned to be &'bls of 15.8 ppg class G. Casin2lLiner Information 13 3/8", L-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8", L-80 47#, Burst 6870, collapse 4750 7", L-80, 29#, Burst 8160 psi; collapse 7020 psi 5 W', L-80, 17#, Burst 7740 psi, collapse 6280 psi. 4 W' N-80, 12.6#, Burst 8430 psi; collapse 7500 psi planned 3 3/16" L-80 TCll, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") // 2 7/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") Well Control: · BOP diagram is attached. ~;~J · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and t& psi. · The annular pre venter wi 11 be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 91deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property is 13,150 ft. · Distance to nearest well within pool 1710 ft to 16-06A. Logging · MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. Hazards · DS 13 i.§..,a designated H2S pad. · One fault crossing is anticipated. ../ Lost circulation risk is considered "medium". Reservoir Pressure · Res. press. is estimated to be 3260 psi at 8800' ss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2380 psi. / TREE " I WELLHEAD = ,ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max. Angle .~. Datum MD = Datum lVD = FMC GEN 12 FMC AXELSON 87' . 13-24 . I SAFETY NOTES I! 41 @ 6700' 10244' 8800' SS .i"..' "'~ l 2160' H5-1/2" OTIS RQMSSSV NIP,ID=4.562" I l13-3/8" CSG, 72#, L-80, ID = 12.347" H 2525' r.JI 6 Minimum ID = 3.725" @ 9809' 4-1/2" OTIS XN NIPPLE ..LL 9580' H 5-1/2" OTIS XA SLIDING SL V I 15-1/2" TBG-PC,17#, L-80, .0232 bpf, 10 = 4.892"H 9717' TOPOF4-1/2" TBG-PC H 9717' L J 9686' H5-1/2" BOT PBRASSY I Z z ---1 9706' H9-5/8" x 5-1/2" BOT 3-H PKR I \ ! I 9717' 1-15-1/2" X 4-1/2" XO I I TOP OF 7" LNR H 9792' ~ II 9809' 1-14-1/2" OTIS XN NIP, 10 = 3.725 I f4-1/2"TBG-PC,12.6#, N-80, .0152bpf, ID=3.958"-{ 9822' " 9821' 9822' 9837' H4-1/2" BOT SHEA ROUT SUB I 1-14-1/2" TUBING TAIL I H ELMO TT LOGGED 12/09/85 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 10103' ~ ~ ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/16/82 ANGLEATTOPÆRF: 34 @ 10132' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 10132-10153 0 12/14/91 3-3/8" 4 10244-10264 0 12/09/85 3-3/8" 4 10274-10284 0 12/09/85 3-3/8" 4 10294-10334 0 12/09/85 3-3/8" 4 10352-10392 0 12/09/85 3-3/8" 4 10401-10421 0 12/09/85 3-3/8" 4 10430-10460 0 12/09/85 3-3/8" 4 10484-10494 0 12/09/85 I PBTD H 10673' \7" LNR, 29#, L80, .0371 bpf, 10 = 6.184" H 10716' ~-i 10721' . DATE OS/22/82 01/08/83 01/03/01 01/29/01 06/19/01 REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-SL T CONVERTED TO CANV AS SIS-MD FINAL RNlTP CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNIT" WELL: 13-24 PERMIT" No; 82-065 API No: 50-029-20739-00 SEe 14 T10N R14E5281.23 FEL 518.22 FNL BP Exploration (Alaska) TREE = WELLHEAD = ACTUA TOR = KB. BF, KOP= Max Angle = Datum MD = TVD= FMCGEN 12 FMC AXELSON 87' 2800' 41 @ 6700' 10244' 8800'SS 113-3/8" CSG, 72#, L-80, ID = 12.347" H . 2525' ~ Minimum iO = 3.725" @ 9809' 4-1/2" OTIS XN NIPPLE 15-1/2" TBG-PC,17#, L-80, .0232 bpf, 10 = 4.892"1-1 I TOP OF 4-1/2" TBG-PC H 9717' 9717' 9792' 14-1/2" TBG-PC,12.6#, N-80, .0152 bpf, 10= 3.958"H 9822' ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/16/82 ANGLEAT TOP PERF: 34 @ 10132' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 10132-10153 3-3/8" 4 10244-10264 3-3/8" 4 10274-10284 3-318" 4 10294-10334 3-3/8" 4 10352-10392 3-3/8" 4 10401-10421 3-3/8" 4 10430-10460 3-3/8" 4 10484-10494 19-5/8" CSG, 47#, L-80, 10 = 8.681" 17" LNR, 29#, L80, .0371 bpf, ID=6.184" DATE OS/22/82 01/08/83 01/03/01 01/29/01 06/19/01 REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-SLT CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS H 10716' 10721' ..LL L J \ 11 OA TE REV BY COMMENTS ~ I SAFETY NOTES 2160' H5-1/2" OTIS RQMSSS\l NIP, 10 =4.562"1 9580' H 5-1/2" OTIS XA SLIDING SL vi 9686' H5-1/2" BOTPBRASSY I 9706' 1-i9-5/8" X 5-1/2" 9717' XOI I 9809' H4-1/2" OTIS I 9821' H4-1/2" BOT SHEAROUT SUB I I 9822' 1-14-1/2" TUBING TAIL I r H ELMD TI LOGGED 12/09/85 t 10673' PRUOHOE BAY UNIT WELL: 13-24 . . B.. -III. INTEQ Obp BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 13 TR-10-14 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5932645.45 ft 685828.44 ft Latitude: 70 13 Lon~tude: 148 30 Nortb Reference: Grid Convergence: Alaska, Zone 4 Well Centre bggm2004 15.444 N 2.303 W True 1.41 deg Well: 13-24 Slot Name: 24 13-24 Well Position: +N/-S -270.18 ft Nortbing: 5932370.13 ft Latitude: 70 13 12.787 N +E/-W -212.93 ft Easting : 685622.24 ft Lon~tude: 148 30 8.487 W Position Uncertainty: 0.00 ft Wellpatb: Plan#4 13-24A 500292073901 Current Datum: 39: 24 5/2/1982 00:00 Magnetic Data: 12/3/2004 Field Strengtb: 57627 nT Vertical Section: Deptb From (TVD) ft 41.00 Heigbt 87.00 ft Drilled From: Tie-on Deptb: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 +N/-S ft 0.00 Targets 13-24 10210.00 ft Mean Sea Level 25.03 deg 80.82 deg Direction deg 10.00 13-24A Polygon4.1 0.00 2016.38 -3568.95 5934298.00 682005.00 70 13 32.610 N 148 31 52.157 W -Polygon 1 0.00 2016.38 -3568.95 5934298.00 682005.00 70 13 32.610 N 1483152.157W -Polygon 2 0.00 2481.21 -4002.67 5934752.00 681560.00 70 1337.179N 148 32 4.763 W -Polygon 3 0.00 2957.89 -3697.84 5935236.00 681853.00 70 1341.869 N 148 31 55.915 W -Polygon 4 0.00 3464.81 -3321.23 5935752.00 682217.00 70 13 46.856 N 148 31 44.980 W -Polygon 5 0.00 3284.33 -3060.58 5935578.00 682482.00 70 13 45.082 N 148 31 37.405 W -Polygon 6 0.00 2758.35 -3475.66 5935042.00 682080.00 70 13 39.907 N 148 31 49.458 W -Polygon 7 0.00 2538.61 -3530.09 5934821.00 682031.00 70 13 37.746 N 148 31 51.036 W -Polygon 8 0.00 2303.16 -3230.77 5934593.00 682336.00 70 13 35.432 N 148 31 42.338 W 13-24A Fault 1 0.00 2724.68 -4180.75 5934991.00 681376.00 70 13 39.573 N 148 32 9.940 W -Polygon 1 0.00 2724.68 -4180.75 5934991.00 681376.00 70 13 39.573 N 148 32 9.940 W -Polygon 2 0.00 2637.34 -3883.79 5934911.00 681675.00 70 13 38.715 N 148 32 1.312 W -Polygon 3 0.00 2602.69 -2922.29 5934900.00 682637.00 70 13 38.379 N 148 31 33.380 W -Polygon 4 0.00 2637.34 -3883.79 5934911.00 681675.00 70 13 38.715 N 148 32 1.312 W 13-24A Fault 2 0.00 2724.68 -4180.75 5934991.00 681376.00 70 13 39.573 N 148 32 9.940 W -Polygon 1 0.00 2724.68 -4180.75 5934991.00 681376.00 70 13 39.573 N 148 32 9.940 W -Polygon 2 0.00 3266.23 -3707.26 5935544.00 681836.00 70 13 44.901 N 148 31 56.193 W -Polygon 3 0.00 3750.85 -3603.30 5936031.00 681928.00 70 13 49.668 N 148 31 53.179 W -Polygon 4 0.00 3266.23 -3707.26 5935544.00 681836.00 70 13 44.901 N 148 31 56.193 W 13-24A T4.2 8841.00 3066.07 -3541.12 5935348.00 682007.00 70 13 42.933 N 148 31 51.363 W 13-24A T4.1 8846.00 2471.14 -3755.83 5934748.00 681807.00 70 13 37.081 N 148 31 57.593 W 13-24A T4.3 8981.00 3266.60 -3356.12 5935553.00 682187.00 70 1344.906 N 148 31 45.991 W ObP . . BP-GDB Baker Hughes INTEQ Planning Report .... ..... I.NTEQ Annotation 10200.00 8762.52 TIP 10210.00 8770.98 KOP 10230.00 8787.74 end 9 DLS / begin 38 DLS 10382.34 8854.90 end 38 DLS / begin 15 DLS 10582.34 8850.23 5 11102.34 8842.32 6 11257.34 8842.20 7 11595.00 8981.10 TD Plan: Plan #4 Date Composed: 12/3/2004 Identical to Lamar's Plan #4 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10200.00 32.25 316.00 8762.52 2220.85 -3524.65 0.00 0.00 0.00 0.00 10210.00 32.15 316.10 8770.98 2224.68 -3528.35 1.13 -1.00 1.00 151.99 10230.00 33.92 315.54 8787.74 2232.50 -3535.95 9.00 8.87 -2.80 350.00 10382.34 91.40 307.08 8854.90 2315.98 -3635.05 38.00 37.73 -5.55 350.00 10582.34 91.21 337.09 8850.23 2471.92 -3756.52 15.00 -0.09 15.00 90.00 111102.34 90.25 55.09 8842.32 2933.78 -3623.27 15.00 -0.18 15.00 90.00 11257.34 89.84 31.84 8842.20 3045.51 -3517.37 15.00 -0.27 -15.00 269.00 11595.00 40.04 42.68 8981.10 3284.55 -3343.16 15.00 -14.75 3.21 171.00 Survey 10200.00 32.25 316.00 8762.52 2220.85 -3524.65 5934503.48 682044.25 1575.06 0.00 0.00 TIP 10210.00 32.15 316.10 8770.98 2224.68 -3528.35 5934507.23 682040.46 1578.19 1.13 151.99 KOP 10225.00 33.48 315.68 8783.58 2230.52 -3534.01 5934512.92 682034.66 1582.96 9.00 350.00 MWD 10230.00 33.92 315.54 8787.74 2232.50 -3535.95 5934514.86 682032.67 1584.57 9.00 350.36 end 9 DL 10250.00 41.43 313.55 8803.56 2241.06 -3544.67 5934523.19 682023.74 1591.48 38.00 350.00 MWD 10275.00 50.84 311.76 8820.87 2253.24 -3557.92 5934535.05 682010.20 1601.18 38.00 351.58 MWD 10300.00 60.27 310.40 8834.99 2266.76 -3573.45 5934548.18 681994.34 1611.80 38.00 352.82 MWD 10313.13 65.23 309.79 8841.00 2274.27 -3582.38 5934555.47 681985.23 1617.65 38.00 353.59 13-24A T 10325.00 69.72 309.28 8845.55 2281.25 -3590.84 5934562.24 681976.61 1623.05 38.00 353.87 MWD 10326.32 70.22 309.22 8846.00 2282.04 -3591.80 5934563.00 681975.62 1623.66 38.00 354.07 13-24A T 10350.00 79.17 308.28 8852.24 2296.32 -3609.59 5934576.84 681957.49 1634.63 38.00 354.09 MWD 10375.00 88.63 307.35 8854.90 2311.54 -3629.21 5934591.57 681937.50 1646.22 38.00 354.34 MWD 10382.34 91.40 307.08 8854.90 2315.98 -3635.05 5934595.86 681931.55 1649.57 38.00 354.44 end 38 D 10400.00 91.40 309.73 8854.47 2326.94 -3648.89 5934606.49 681917.45 1657.97 15.00 90.00 MWD 10425.00 91.39 313.48 8853.86 2343.54 -3667.57 5934622.62 681898.37 1671.07 15.00 90.06 MWD 10450.00 91.38 317.23 8853.25 2361.32 -3685.13 5934639.96 681880.38 1685.53 15.00 90.16 MWD 10475.00 91.36 320.98 8852.65 2380.21 -3701.49 5934658.44 681863.56 1701.29 15.00 90.25 MWD 10500.00 91.33 324.73 8852.07 2400.12 -3716.58 5934677.98 681847.99 1718.29 15.00 90.34 MWD 10525.00 91.30 328.49 8851 .49 2420.99 -3730.33 5934698.50 681833.73 1736.44 15.00 90.42 MWD 10550.00 91.27 332.24 8850.93 2442.71 -3742.69 5934719.90 681820.84 1755.69 15.00 90.51 MWD 10575.00 91.23 335.99 8850.39 2465.19 -3753.60 5934742.11 681809.38 1775.93 15.00 90.60 MWD 10582.34 91.21 337.09 8850.23 2471.92 -3756.52 5934748.76 681806.29 1782.05 15.00 90.68 5 10600.00 91.21 339.74 8849.86 2488.34 -3763.01 5934765.02 681799.40 1797.09 15.00 90.00 MWD 10625.00 91.20 343.49 8849.33 2512.05 -3770.90 5934788.53 681790.93 1819.08 15.00 90.06 MWD 10650.00 91.19 347.24 8848.81 2536.23 -3777.21 5934812.54 681784.03 1841.79 15.00 90.14 MWD 10675.00 91.18 350.99 8848.29 2560.77 -3781.93 5934836.96 681778.70 1865.14 15.00 90.21 MWD 10700.00 91.16 354.74 8847.78 2585.57 -3785.04 5934861.67 681774.99 1889.02 15.00 90.29 MWD 10725.00 91.13 358.49 8847.28 2610.52 -3786.51 5934886.57 681772.90 1913.34 15.00 90.37 MWD 10750.00 91.10 2.24 8846.80 2635.51 -3786.35 5934911.56 681772.45 1937.97 15.00 90.44 MWD ObP . BP-GDB Baker Hughes INTEQ Planning Report . ... ..... INTEQ Survey 10775.00 91.06 5.99 8846.32 266Q.43 -3784.56 5934936.52 681773.63 1962.83 15.00 90.52 MWD 10800.00 91.02 9.74 8845.87 2685.19 -3781.14 5934961.35 681776.44 1987.81 15.00 90.59 MWD 10825.00 90.98 13.49 8845.43 2709.67 -3776.10 5934985.95 681780.87 2012.79 15.00 90.65 MWD 10850.00 90.93 17.24 8845.02 2733.77 -3769.48 5935010.20 681786.90 2037.67 15.00 90.72 MWD 10875.00 90.87 20.99 8844.63 2757.38 -3761.29 5935034.00 681794.50 2062.35 15.00 90.78 MWD 10900.00 90.82 24.74 8844.26 2780.41 -3751.58 5935057.26 681803.64 2086.71 15.00 90.84 MWD 10925.00 90.76 28.49 8843.91 2802.75 -3740.38 5935079.88 681814.28 2110.66 15.00 90.90 MWD 10950.00 90.69 32.24 8843.60 2824.32 -3727.75 5935101.74 681826.39 2134.09 15.00 90.95 MWD 10975.00 90.63 35.99 8843.31 2845.01 -3713.73 5935122.77 681839.89 2156.91 15.00 91.00 MWD 11000.00 90.56 39.74 8843.05 2864.74 -3698.39 5935142.87 681854.74 2179.00 15.00 91.04 MWD 11025.00 90.49 43.49 8842.82 2883.43 -3681.79 5935161.96 681870.88 2200.29 15.00 91.08 MWD 11050.00 90.41 47.24 8842.63 2900.99 -3664.00 5935179.95 681888.22 2220.67 15.00 91.11 MWD 11075.00 90.34 50.99 8842.47 2917.35 -3645.10 5935196.77 681906.71 2240.06 15.00 91.14 MWD 11100.00 90.26 54.74 8842.34 2932.44 -3625.18 5935212.35 681926.26 2258.38 15.00 91.16 MWD 11102.34 90.25 55.09 8842.32 2933.78 -3623.27 5935213.73 681928.14 2260.04 15.00 91.18 6 11125.00 90.19 51.69 8842.24 2947.29 -3605.08 5935227.69 681945.99 2276.50 15.00 269.00 MWD 11150.00 90.13 47.94 8842.17 2963.42 -3585.98 5935244.28 681964.68 2295.70 15.00 268.99 MWD 11175.00 90.06 44.19 8842.13 2980.77 -3567.98 5935262.06 681982.25 2315.91 15.00 268.98 MWD 11200.00 89.99 40.44 8842.12 2999.25 -3551.15 5935280.95 681998.62 2337.03 15.00 268.97 MWD 11225.00 89.92 36.69 8842.14 3018.79 -3535.57 5935300.87 682013.71 2358.98 15.00 268.97 MWD 11250.00 89.86 32.94 8842.18 3039.31 -3521.30 5935321.74 682027.47 2381.67 15.00 268.97 MWD 11257.34 89.84 31.84 8842.20 3045.51 -3517.37 5935328.02 682031.25 2388.45 15.00 268.98 7 11275.00 87.22 32.26 8842.66 3060.47 -3508.00 5935343.21 682040.25 2404.82 15.00 171.00 MWD 11300.00 83.52 32.85 8844.67 3081.47 -3494.59 5935364.54 682053.13 2427.83 15.00 170.99 MWD 11325.00 79.81 33.45 8848.30 3102.18 -3481.07 5935385.57 682066.14 2450.57 15.00 170.94 MWD 11350.00 76.11 34.06 8853.51 3122.50 -3467.49 5935406.22 682079.22 2472.94 15.00 170.85 MWD 11375.00 72.41 34.70 8860.29 3142.36 -3453.90 5935426.40 682092.31 2494.86 15.00 170.73 MWD 11400.00 68.71 35.36 8868.61 3161.66 -3440.38 5935446.03 682105.36 2516.22 15.00 170.55 MWD 11425.00 65.02 36.05 8878.43 3180.33 -3426.96 5935465.02 682118.31 2536.93 15.00 170.33 MWD 11450.00 61.33 36.79 8889.71 3198.28 -3413.72 5935483.29 682131.10 2556.90 15.00 170.06 MWD 11475.00 57.64 37.58 8902.40 3215.44 -3400.71 5935500.76 682143.68 2576.06 15.00 169.73 MWD 11500.00 53.96 38.44 8916.45 3231.73 -3387.99 5935517.36 682156.01 2594.31 15.00 169.33 MWD 11525.00 50.28 39.38 8931.80 3247.08 -3375.60 5935533.01 682168.01 2611.59 15.00 168.84 MWD 11550.00 46.61 40.43 8948.38 3261.44 -3363.60 5935547.66 682179.65 2627.80 15.00 168.27 MWD 11575.00 42.96 41.61 8966.12 3274.72 -3352.05 5935561.22 682190.87 2642.90 15.00 167.57 MWD 11594.87 40.06 42.67 8981.00 3284.49 -3343.22 5935571.20 682199.46 2654.05 15.00 166.73 13-24A T 11595.00 40.04 42.68 8981.10 3284.55 -3343.16 5935571.27 682199.51 2654.12 15.00 165.93 TD Date: 12/312004 12/3/2004 12:40 PM Plan: Plan #4 (13-24!Plan#4 13-24A) Created 8y: Brij Potnis Magnetic Field Strength: 57627nT Oip Angle: 80.820 Date: 1213/2004 Modei: bggm2004 36 Amoco WEt.LPATH DErAILS f'Wm,#41302M 500z921J73001 Parent WeUpath: ,3-0, T!e()nMD: 10211},t)(I .... N()rdk;1 Ref,Datum: 39: 24 512119:82 OO:Gß 87,GQft V..$<e>ctiOf;\ O+1ß~ ~~:J ~::~j~ A1tgkl 10.00' .... .... 41.00 REFERENCE INFORMATION 87 S¡;¡enolll DETAIUii - .. ,~ .... "'" ~,~ +Ef·W DUt¡ TFØ<>$ _Th_ , , , , , , , , ANNOTATIONS TV. 3762:,52 811O.U 67ft1.74 ....... ....... a842.32 8842.20 898M!) at --326 -300 -0 --200 ---250 -300 -326 ViEt,I_DETA!LS COMb\NY DETAf1 S ANTI-COLLISION SETTJNGS Bi'Amn.¡:ott DepL~ Fm IJ"p1h T", lO20000 I tS'}5üo !'I,mnnd PI"n,.·iVt Rig [kiWm #4 250 200 150 ]00 50 50 100 150 TmveHing Cylinder Azimuth (TFü+AZl) [deg] vs Centre to Centre Separation [100ft/in] SllRVFY PROGRAM WEUYA11J DE'fAJLS PJan#4ß-24A. SOO29207W(¡1 MW!) Par<.'mWdlpa\b l'k<mM]) 13·24 W21O,OO V~c!ì"n A»gle lO()O" Origin Starting i-Fl·W From TVD OJ)() LEGEND 06-12 (06-12), Major Risk 06-12A (06-12A), Major Risk 13-24 (! 3-24), NO ERRORS Plan#4 13-24A Plan #4 lNT SECTiON DETAIL$- 12/3/2004 12.3::1 PM .. Plan: Plan (13 1 1 800 400 200 o I I I I I I ! 10800 11000 Measured 11400 11600 10200 10400 10600 12 (06-12) 12A 12A) 1 (13-24) 11800 . Obp BP-GDB Anticollision Report . ... ..... lNTEQ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ar~lIrells in thii'lDebIPlan #4 & NOT PLANNED PROGRA 111 Interpolation Method: MD + Stations Interval: 10.00 ft Error Model: ISCWSA Ellipse Depth Range: 10210.00 to 11595.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1355.40 ft Error Surface: Ellipse + Casing Casing Points 2525.00 10103.00 10210.00 11595.00 2524.91 8768.26 8857.98 9068.10 13.375 9.625 7.000 2.875 17.500 12.250 8.500 3.750 133/8" 9 5/8" 7" 2 7/8" Plan: Plan #4 Identical to Lamar's Plan #4 Principal: Yes Date Composed: Version: Tied-to: 12/3/2004 1 From: Definitive Path Summary PB DS 06 PB DS 06 PB DS 13 06-12 06-12A 13-24 06-12 V1 06-12A V1 13-24 V3 10210.00 10210.00 0.00 0.00 Out of range Out of range 0.00 FAIL: NOERRORS Site: PB DS 13 Well: 13-24 Wellpath: 13-24 V3 Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 10210.00 8857.98 10210.00 8857.98 201.55 201.69 316.10 0.00 7.000 0.00 0.00 0.00 FAIL 10220.00 8866.40 10220.00 8866.45 201.54 201.98 315.81 0.00 7.000 0.09 0.00 0.09 Pass 10229.99 8874.74 10230.00 8874.93 201.53 202.27 124.18 168.64 7.000 0.35 0.00 0.35 Pass 10239.92 8882.79 10240.00 8883.42 201.51 202.55 124.25 169.78 7.000 1.04 0.00 1.04 Pass 10249.72 8890.35 10250.00 8891.92 201.51 202.85 124.25 170.67 7.000 2.40 0.00 2.40 Pass 10259.30 8897.34 10260.00 8900.43 201.53 203.17 124.15 171.33 7.000 4.41 0.00 4.41 Pass 10268.60 8903.72 10270.00 8908.94 201.55 203.49 124.00 171.83 7.000 7.05 0.00 7.05 Pass 10277.55 8909.46 10280.00 8917.47 201.59 203.83 123.84 172.23 7.000 10.29 0.00 10.29 Pass 10286.11 8914.56 10290.00 8926.01 201.63 204.17 123.66 172.54 7.000 14.09 0.00 14.09 Pass 10294.25 8919.05 10300.00 8934.55 201.68 204.52 123.48 172.79 7.000 18.41 0.00 18.41 Pass 10301.96 8922.95 10310.00 8943.10 201.73 204.87 123.31 173.00 7.000 23.21 0.00 23.21 Pass 10309.23 8926.32 10320.00 8951.66 201.79 205.21 123.15 173.18 7.000 28.44 0.00 28.44 Pass 10316.08 8929.21 10330.00 8960.22 201.85 205.56 123.00 173.34 7.000 34.08 0.00 34.08 Pass 10322.50 8931.66 10340.00 8968.78 201.91 205.91 122.86 173.47 7.000 40.08 0.00 40.08 Pass 10328.51 8933.73 10350.00 8977.35 201.96 206.26 122.72 173.58 7.000 46.42 0.00 46.42 Pass 10334.14 8935.46 10360.00 8985.93 202.02 206.61 122.58 173.68 7.000 53.05 0.00 53.05 Pass 10339.40 8936.89 10370.00 8994.50 202.07 206.95 122.45 173.76 7.000 59.96 0.00 59.96 Pass 10344.32 8938.07 10380.00 9003.09 202.12 207.29 122.33 173.83 7.000 67.11 0.00 67.11 Pass 10348.92 8939.04 10390.00 9011.67 202.17 207.63 122.21 173.88 7.000 74.48 0.00 74.48 Pass 10353.22 8939.81 10400.00 9020.27 202.22 207.97 122.09 173.93 7.000 82.06 0.00 82.06 Pass 10357.23 8940.43 10410.00 9028.86 202.26 208.29 121.98 173.97 7.000 89.82 0.00 89.82 Pass 10360.99 8940.92 10420.00 9037.47 202.30 208.62 121.85 173.99 7.000 97.75 0.00 97.75 Pass 10364.50 8941.28 10430.00 9046.08 202.34 208.94 121.73 173.99 7.000 105.83 0.00 105.83 Pass 10367.79 8941.55 10440.00 9054.70 202.37 209.26 121.61 173.99 7.000 114.06 0.00 114.06 Pass 10370.88 8941.74 10450.00 9063.32 202.40 209.57 121.49 173.98 7.000 122.41 0.00 122.41 Pass 10373.77 8941.86 10460.00 9071.95 202.43 209.89 121.36 173.97 7.000 130.88 0.00 130.88 Pass 10376.48 8941.93 10470.00 9080.59 202.46 210.20 121.24 173.95 7.000 139.45 0.00 139.45 Pass 10379.03 8941.94 10480.00 9089.23 202.49 210.51 121.12 173.92 7.000 148.13 0.00 148.12 Pass 10381.43 8941.92 10490.00 9097.88 202.52 210.81 121.01 173.89 7.000 156.89 0.00 156.88 Pass f . BP-GDB Anticollision Report . B. ..... lNTßQ Obp Site: PB DS 13 Well: 13-24 Wellpath: 13-24 V3 Rule Assigned: NOERRORS Inter-Site Error: 0.00 ft 10385.31 8941.82 10500.00 9106.54 202.37 210.99 121.40 173.88 7.000 165.71 0.00 165.71 Pass 10390.23 8941.70 10510.00 9115.21 202.11 211.05 122.15 173.89 7.000 174.55 0.00 174.55 Pass 10395.15 8941.58 10520.00 9123.88 201.85 211.08 122.92 173.92 7.000 183.38 0.00 183.38 Pass 10400.09 8941.46 10530.00 9132.56 201.59 211.07 123.69 173.96 7.000 192.22 0.00 192.22 Pass 10405.03 8941.34 10540.00 9141.25 201.19 211.03 124.50 174.02 7.000 201.06 0.00 201.06 Pass 10409.97 8941.22 10550.00 9149.95 200.78 210.95 125.31 174.08 7.000 209.91 0.00 209.91 Pass 10414.92 8941.10 10560.00 9158.66 200.38 210.84 126.13 174.16 7.000 218.76 0.00 218.76 Pass 10419.86 8940.98 10570.00 9167.38 199.98 210.69 126.96 174.25 7.000 227.61 0.00 227.61 Pass 10424.81 8940.86 10580.00 9176.10 199.57 210.51 127.80 174.35 7.000 236.46 0.00 236.46 Pass 10429.75 8940.74 10590.00 9184.83 199.01 210.30 128.64 174.45 7.000 245.32 0.00 245.31 Pass 10434.69 8940.62 10600.00 9193.58 198.44 210.05 129.49 174.56 7.000 254.17 0.00 254.17 Pass 10439.64 8940.50 10610.00 9202.32 197.86 209.77 130.35 174.67 7.000 263.03 0.00 263.03 Pass 10444.59 8940.38 10620.00 9211.07 197.29 209.45 131.21 174.79 7.000 271.89 0.00 271.89 Pass 10449.56 8940.26 10630.00 9219.82 196.72 209.09 132.09 174.92 7.000 280.74 0.00 280.73 Pass 10454.53 8940.14 10640.00 9228.56 195.99 208.70 132.96 175.05 7.000 289.58 0.00 289.58 Pass 10459.51 8940.02 10650.00 9237.31 195.25 208.27 133.85 175.19 7.000 298.42 0.00 298.42 Pass 10464.49 8939.90 10660.00 9246.05 194.51 207.80 134.74 175.33 7.000 307.26 0.00 307.26 Pass 10469.48 8939.79 10670.00 9254.80 193.77 207.31 135.63 175.47 7.000 316.09 0.00 316.09 Pass 10474.47 8939.67 10680.00 9263.55 193.02 206.77 136.53 175.62 7.000 324.92 0.00 324.92 Pass 10479.45 8939.55 10690.00 9272.29 192.13 206.20 137.43 175.78 7.000 333.74 0.00 333.74 Pass 10484.44 8939.43 10700.00 9281.04 191.23 205.60 138.33 175.93 7.000 342.57 0.00 342.56 Pass All Measurements are from top of Riser :0.- Q) (f) .- a:: top of bag r "- bttm of bag middle of slips Blind/Shears 12/2/2004 13-24Ai ~ BAG 7 1/16" 5000 psi. ~ I'· ........................ TOTs 23/8" combi ram/slips 1..........................71/16" 5000psi middle of pipes .---. middle of flow cross Mud Cross - middle of blind/shears I variable bore pipe 31/2"-2 7/S" I ,23/8" combi ram/slips middle of pipe/slips Flow Tee ............ Mud Cross 71/16" 5000psi --- I'· '" ..................... TOTs 1......................····7 1/16" 5000psi . . Winton, Just after I hung up I remembered that the closest well is listed in the permit to drill summary that should have been sent with the application. I verified with the Geologist that the nearest well is 16-06A, which is 1710 ft away. I've also noted that the well class should be "service" for an injector. Thanks, Sean Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 564-551 0 Fax TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE/AK9951~6612 89-611 252 164 "Mastercard Check" \~~OIo.D (1 DA TE ì !Pf)6C9 ICO. (ú asJoo --1f;fì -~;f ~ . PAY TO THE O~_ DOLLARS First National Bank Alaska Anchorage. AK 99501 MEMO \3r1~L{~ .: ¡. 2 5 2000 b 0 -: q q ¡. Ie I" b 2 2 ? II. ¡. 5 5 b II- 0 ¡. b Ie . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME//??t /~-/~,£J PTD# ?,(J~- 24.5 ><: Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ~'CLUE"· The permit is for a new weJlboresegment of existing wen·. . Permit No, .' API No. Production. sbould continue to be reponed as a function' of tbe original API number. stated above. HOLE In accordance witb 20 AAC 25.005(f), an records, data and logs acquired for tbe pilot bole must be cJearly differentiated ID botb name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing nception. (Company Name) assumes the liability of any protest to tbe spacing .exception that may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample inter:vals tbrough target zones. 1Jr[Š { 1( 7 ( ~ \~~ Geologic Commissioner: Date: Engineering Commissioner: Date 35 36 37 38 39 Conta_ct namelphone_ for weekly prpgre¡;sreport$ [exploratpr:y _onlYl No NA NA _NA NA Appr RPC Date 2/6/2004 S_eç¡be5:fconditipo $urvey _S_etsmic_analysjs_ Qf $baJlow gas_z_ooes o1t-¡;h_ore) if Permit _D_ata_ preseoted on potential pveJPre¡;suœ _zpne_s Geology . Appr WGA Date 12n /2004 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 G.an be iS$ued w/Q hydrogen_ sulfide meaS_Ure$ Work wiJI occur withoutoperatio_n _shutdown J¡; pre¡;ence of H2S gas_ probable Meçba_n[cç¡Lcpodition_of well$ w[thin AOR yertfied (for service welJ only) tncomments) CMke manifold cQmpHes w/APt RP-53 (May 84) BOPE_pres$ Ifdjverter reC1-uired, doe$ jtmeet reguJatipns_ _Qrilliog f]ujdprogram schematic_& eC1-uipli$ta5:fequate _BØPE$._d_o If a_ re-drill~ has_ a 10-403 for _abandonment A5:fequate _wellbore ¡;ep¡;¡ratJo_n -Pfopp¡;e5:f be_en approved AdequateJank¡;¡geor re_serye pit Casiog design¡; adeQuate for C._T:. B&_permafr_ost _CMT vot adequate_ to _CMT wi!] coyer all koownproductiye horizons_ tie-inlong_string to_SJJl:f C!;g _CMT vol adequate to circ_ulate oncpnd_uctor _C_oJlductor _S_udaceca¡;ing_ prQtects alLknown USDWs ra_tiJlg ¡;¡ppropriate; _they meet reguJation 8. surfc_sg NA NA NA NA _Y_e$ Ye$ Ye$ Y_e$ Ye$ NA Yes Yes Ye$ Ye$ Ye$ Ye$ Ye$ 1:f2S pad 3-24_ is exi¡;tiJlg WAGiojection well T:BA jest to (p ut psig Test to 350Q psi. Sidetrack. Max MW8.9 ppg. CTDU. * Engineering . Appr RPC 12/6/2004 Date o 11 12 13 14 15 16 17 ¡;tÖng_ pJovided eJl/jCce we ~ th¡;¡n 3 months ACMP finding of Con_ststency_ h_a$ been i¡;sued for thi$ project Pre-produ_ced injector _ducationof pre-productipo le$~ # (put lOti in_c_omment$) (For OFJIYL _ _ _ _ _ _ _ __ (Forservtce well onJy) Well AJI we Us_ within 15-day wait located wtthiFJ area and_strataautnorized by_ 1l4_mile_area_of review jd_eotified (For Can permit be approved before ojectipo Order _Operator Eermit can be [s$ued wjtbout Permit G.aJl be tS$ued wjtbout ¡;¡dmiFJistrati\le appr_oval PTD#: 2042430 Administration Qperator only affected party _S_ufficieFJt _acreélge _aYélilable Ifdevi¡;¡ted. js weJlbore platiFJcJu_ded WeUIQcated inadefiFJe_d_pool Well located proper _d[stance from driJling UFJit bOUFJdar:y Well located pr_oper _dtstance from other welJs_ Company P_ermit fee atta Leas_e number~...... name_and oumb_er 2 3 4 5 6 7 8 9 in drilliog unjt _U_ntque welt BP EXPLORATION (ALASKA) Field & Pool has_appropnate_ bond tnJorce co_n$erva_tiOFJ order ~nn'opriate_ PRUDHOE BAY. PRUDHOE OIL NC 640150 Initial ClasslType _Y_e$ Yes Ye$ Ye$ Y_e$ Ye$ Yes Ye$ Ye$ Ye$ Ye$ _Ye$ Yes Ye$ Y_e$ NA NA AI04C, 3_-24_ (exi¡;ting WAG_ ioi welJ TeAL Well Name: PRUDHOE BAY UNIT SER / WAG IN GeoArea 890 13-24A Unit 11650 Program SER On/Off Shore On Well Annular Disposal bore seg D D . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ng Services LIS Scan Utility . JJJ-I~ ;f> lq *\ "> ?-- $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 17 17:12:44 2005 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .05/08/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 13 -24A 500292073901 BP Exploration (Alaska) Inc. Sperry Drilling Services 17-AUG-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003465349 B. JAHN B. HOLT/B. L MWD RUN 2 MW0003465349 B. JAHN B. HOLT/B. L MWD RUN 3 MW0003465349 B. JAHN B. HOLT / B. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003465349 B. JAHN B. HOLT / B. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 14 10N HE 2342 1584 87.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 4.125 4.125 . SIZE (IN) DEPTH (FT) 7.000 10209.0 4.500 9837.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 13-24 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 10209'MD/8770'TVDSS. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUN 4 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4). RESISTIVITY DATA FOR THE OPEN-HOLE INTERVAL ABOVE RUN 4 WERE ACQUIRED WHILE POOH AFTER REACHING TD. THESE MAD PASS DATA WERE MERGED WITH THE MWD DATA FOR RUN 4 - NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER CCNL GAMMA RAY LOG RUN IN 13-24A ON 3 JANUARY 2005. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 16 AUGUST 2005, AS AUTHORIZED BY STEVE JONES (BP GEOSCIENTIST) . 7. MWD RUNS 1 - 4 REPRESENT WELL 13-24A WITH API#: 50-029-20739-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11783'MD/8979'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ RESISTIVITY ( EXTRA RESISTIVITY ( SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type................ LO . Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 10122.5 10198.5 10198.5 10198.5 10198.5 10198.5 10230.0 STOP DEPTH 11735.0 11748.0 11748.0 11748.0 11748.0 11748.0 11779.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10122.5 10124.5 10128.5 10131.5 10135.0 10151.5 10153.5 10204.5 10215.0 10218.0 10221.0 10225.5 10235.5 10243.0 10246.0 10255.5 10261.5 10272.0 10276.0 10279.5 10282.5 10297.5 10301.5 10303.5 10310.5 10318.0 10334.5 10336.0 10346.0 10369.5 10376.0 10379.0 10407.5 10415.5 10424.5 10440.0 10445.5 10464.0 10480.5 10489.5 10501.5 10508.0 10526.0 10529.5 GR 10123.0 10125.0 10130.0 10132.5 10136.5 10152.0 10155.0 10205.5 10216.0 10218.5 10221.5 10226.5 10236.5 10243.5 10246.0 10255.5 10262.0 10271.5 10276.0 10279.0 10282.0 10297.0 10300.5 10302.5 10312.5 10318.5 10333.0 10334.5 10344.5 10368.0 10376.5 10379.5 10407.0 10414.5 10424.5 10441.0 10445.5 10465.0 10481.5 10490.5 10503.0 10510.5 10527.0 10531.5 10558.5 10568.5 10627.5 10660.5 10668.0 10680.0 10685.5 10744.0 10766.5 10784.0 10833.0 10837.5 10852.5 10910.5 10942.5 10975.5 10998.0 11018.5 11057.0 11066.0 11075.0 11090.0 11188.5 11212.0 11231.0 11284.5 11300.5 11303.0 11309.5 11340.5 11407.5 11419.0 11456.5 11498.0 11508.5 11514.0 11555.0 11566.5 11583.0 11589.5 11616.0 11620.0 11640.0 11645.0 11646.5 11650.0 11779.0 $ . 10562.5 10574.0 10628.0 10663.0 10668.5 10680.5 10686.0 10745.0 10767.5 10784.5 10833.5 10839.0 10854.5 10912.5 10944.0 10977.5 10999.0 11020.0 11056.5 11066.0 11077.0 11089.5 11189.5 11212.0 11232.5 11288.0 11303.0 11307.5 11312.0 11341.5 11407.5 11419.5 11457.5 11498.5 11508.5 11512.5 11554.5 11567.5 11584.0 11591.5 11617.5 11621. 5 11643.0 11649.0 11651.0 11654.0 11783.0 . # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 10123.0 10380.0 10502.0 10870.0 MERGE BASE 10380.0 10502.0 10870.0 11783.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined . . Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type.. .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10122.5 11779 10950.8 3314 10122.5 11779 ROP MWD FT/H 0.01 2215.18 86.5095 3099 10230 11779 GR MWD API 20.06 852.02 42.7589 3140 10122.5 11735 RPX MWD OHMM 0.3 2000 8.38684 3100 10198.5 11748 RPS MWD OHMM 0.3 2000 9.61952 3100 10198.5 11748 RPM MWD OHMM 0.62 2000 13.2975 3100 10198.5 11748 RPD MWD OHMM 0.13 2000 12.2447 3100 10198.5 11748 FET MWD HOUR 0.24 88.2 23.8481 3100 10198.5 11748 First Reading For Entire File......... .10122.5 Last Reading For Entire File.......... .11779 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10123.0 10231.0 STOP DEPTH 10349.5 10380.0 # . LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Code Nsam Rep 1 68 1 68 1 68 Name Service Unit Min Max 31-DEC-04 Insite 7.75 Memory 10380.0 10230.0 10380.0 38.6 83.6 TOOL NUMBER TLGOll 4.125 9837.0 Flo Pro 8.60 60.0 9.0 20000 6.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean Nsam . .0 133.3 .0 .0 First Reading Last Reading . . DEPT FT 10123 10380 10251.5 515 10123 10380 ROP MWD010 FT/H 0.01 83.72 36.4142 299 10231 10380 GR MWD010 API 27.81 852.02 90.3411 369 10123 10349.5 First Reading For Entire File......... .10123 Last Reading For Entire File.......... .10380 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/08/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10350.0 10380.5 STOP DEPTH 10471.5 10502.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 31-DEC-04 Insite 7.75 Memory 10502.0 10380.0 10502.0 90.2 100.3 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG011 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9837.0 # . BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Rep 68 68 68 Code Units FT FT/H API Size 4 4 4 Nsam 1 1 1 MWD020 MWD020 Flo Pro 8.60 60.0 9.0 20000 6.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 133.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10350 10502 10426 305 10350 10502 ROP MWD020 FT/H 30.61 438.37 116.342 244 10380.5 10502 GR MWD020 API 23.29 59.96 34.5977 244 10350 104'(1.5 First Reading For Entire File......... .10350 Last Reading For Entire File.......... .10502 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header . Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10472.0 10502.5 STOP DEPTH 10839.0 10870.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 01-JAN-05 Insite 7.75 Memory 10870.0 10502.0 10870.0 84.5 96.8 TOOL NUMBER TLGOll 4.125 9837.0 Flo Pro 8.70 52.0 8.5 57300 5.4 .000 .000 .000 .000 .0 137.5 .0 .0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD030 MWD030 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10472 10870 10671 797 10472 10870 ROP MWD030 FT/H 1 2215.18 80.7444 736 10502.5 10870 GR MWD030 API 21.97 111.51 32.0038 735 10472 10839 First Reading For Entire File......... .10472 Last Reading For Entire File.......... .10870 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.......... ...STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET 5 header data for each bit run in separate files. 4 .5000 START DEPTH 10199.5 10199.5 10199.5 10199.5 10199.5 STOP DEPTH 11752.0 11752.0 11752.0 11752.0 11752.0 GR ROP $ . 10839.5 10870.5 11739.0 11783.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code . 02-JAN-05 Insite 4.3 Memory 11783.0 10870.0 11783.0 42.8 98.5 TOOL NUMBER 78005 171170 4.125 9837.0 Flo Pro 8.70 51. 0 8.5 23600 5.2 .180 .095 .175 .170 70.0 138.0 70.0 70.0 Offset o 4 8 Channel 1 2 3 , .. . . RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10199.5 11783 10991.3 3168 10199.5 11783 ROP MWD040 FT/H 0.22 1414.03 92.7847 1826 10870.5 11783 GR MWD040 API 20.06 135.96 38.327 1800 10839.5 11739 RPX MWD040 OHMM 0.3 2000 8.40341 3106 10199.5 11752 RPS MWD040 OHMM 0.3 2000 9.63067 3106 10199.5 11752 RPM MWD040 OHMM 0.62 2000 13 .2991 3106 10199.5 11752 RPD MWD040 OHMM 0.13 2000 12.8844 3106 10199.5 11752 FET MWD040 HOUR 0.24 88.2 23.8122 3106 10199.5 11752 First Reading For Entire File......... .10199.5 Last Reading For Entire File.......... .11783 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/08/17 Maximum Physical Record. .65535 File Type.. . . . .. .. . . . . . .. LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/08/17 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/17 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File