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Home My WebLink About198-2207. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-31A Temporary Flowback <30 days Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-220 50-029-22109-01-00 ADL 0028258 13038 Surface Intermediate Liner Scab Liner Liner 8813 2678 10755 251 7072 2143 9500 13-3/8" 9-5/8" 7" 7" x 4-1/2" 2-7/8" 7818 30 - 2708 28 - 10783 10534 - 10785 3679 - 10571 10510 - 12653 30 - 2698 28 - 8727 8546 - 8728 3542 - 8572 8528 - 8784 None 2260 4760 5410 5410 / 7500 13890 9500 5020 6870 7240 7240 / 8430 13450 7999 - 8169 4-1/2" 12.6# x 3-1/2" 9.2# L-80 25 - 104696660 - 6790 Conductor 80 20" 31 - 111 31 - 111 4-1/2" Baker Premier Packer 3-1/2" Baker Premier Packer 7634, 6382 8543, 7078 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com 907-777-8326 PRUDHOE BAY 11/22/2025 Current Pools: PRUDHOE OIL, AURORA OIL Proposed Pools: PRUDHOE OIL, AURORA 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 3000 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.11.21 16:08:30 - 09'00' Torin Roschinger (4662) 325-722 By Grace Christianson at 4:25 pm, Nov 21, 2025 10-404 Approved with operational controls detailed in email attachment titled "FW: [EXTERNAL] S-31A (198-220) Injector Flowback " J.Lau 11/24/25 A.Dewhurst 24NOV25 DSR-11/24/25 11/24/25 Temporary Injector to Producer Well: S-31A PTD: 198-220 API: 50-029-22109-01 Well Name:S-31A Permit to Drill:198-220 Current Status:Operable WAG API Number:50-029-22109-01 Estimated Start Date:11/22/2025 Estimated Duration:<30 days Regulatory Contact:Abbie Barker Service Lines:Ops First Call Engineer:Hunter Gates (215) 498-7274 (M) (907) 777-8326 (O) Second Call Engineer:Tyson Shriver (406) 690-6385 (M) Maximum Allowable Surface Pressure:3,000 psi Last SI WHP:2,100 psi November 21 st, 2025 Brief Well Summary: S-31A is an operable Kuparuk WAG injector that is offset to S-24B by less than 200 where both wells cut the Kuparuk. We have developed a production casing leak around the Kuparuk interval in S-24B and began seeing sustained casing pressure at surface. Being the closest Kuparuk injector to S-24B, we elected to shut-in S-31A and saw an immediate pressure response on S-24Bs IA. Current Status: Shut-In Operable WAGInjector Facts/Depths About Reservoir: Injecting through sliding sleeve at 7703 MD Kuparuk perforations are 7999-8089 MD and 8149-8169 MD Objective: The plan is to temporarily hardline S-31A into a neighboring well and temporarily flow S-31A back, producing water from the Kuparuk reservoir as a form of pressure relief until we are able to perform the cement job to isolate the compromised production casing on S-24B. Attachments: Current Wellbore Schematic Sundry Change Form Temporary Injector to Producer Well: S-31A PTD: 198-220 API: 50-029-22109-01 Current Wellbore Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 21, 2025Subject: Changes to Approved Sundry Procedure for Well S-31ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-31A PRUDHOE BAY UNIT S-31A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 S-31A 50-029-22109-01-00 198-220-0 W SPT 6382 1982200 1596 1896 1896 1897 1897 194 205 203 205 4YRTST P Guy Cook 2/4/2023 Testing done with a Thunderbird Oilfield Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT S-31A Inspection Date: Tubing OA Packer Depth 0 2705 2624 2607IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230204054044 BBL Pumped:4 BBL Returned:3.6 Friday, March 17, 2023 Page 1 of 1           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y Samantha Carlisle at 9:12 am, Mar 02, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV DSR-3/2/22 RBDMS JSB 030222 MGR25JULY2022 $&7,9,7<'$7(6800$5< :(//)/2:,1*21$55,9$/ $'3(5) 0,58(/,1( 581 2)'800<*812'6,7'2:1$7 (/0 3(5)25$7( :,7+63)3+$6(+6& :*(2'<1$0,&65$=25&+$5*(6 &&/76 &&/6723 5'02(/,1( :(//6+87,121'(3$5785( +$1'('%$&.72'62 7,2 $VVLVW(OLQH3XPSHGEEOVGLHVHOWR)3IORZOLQH3XPSHG EEOV )GLHVHOGRZQWXELQJ):+3 V 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%85 Hilcorp North Slope, LLC Stan Golis, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 9/21/2020 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: WAG Injectors S-31 (PTD # 1982200) and S-134 (PTD # 2090830) SVS performance testing non-compliance incident investigation findings and corrective actions. Dear Mr. Regg, On 8/15/2020 WAG Injectors S-31 (PTD # 1982200) and S-134 (PTD # 2090830) were placed on MI injection. On 9/1/2020, it was found that the required SVS performance testing was not completed per AOGCC requirements. After discovering this non-compliance, performance tests were immediately scheduled and completed successfully on 9/1/2020 along with initiating an investigation into why these tests were originally missed. There were two contributing factors for missing these required SVS performance tests: 1) During the week of 8/12 – 8/19/2020 there was a step-up Field Ops Lead covering the role. 2) The SVS tool that tracks testing requirements coming due did not flag these wells for requiring a test. Findings concerning item #1: The GC2 Field Ops lead is responsible for scheduling required SVS testing in the GC2 area. During this week the normal Ops Lead was on vacation and another Wellpad operator was “stepped up” to cover these responsibilities. The guidance the individual was provided was to monitor the SVS tool to schedule required testing and work with the GC1 Field OPS lead for support if there are any questions. Since the tests were never flagged in the SVS Tool as required they were overlooked. Additionally the wellpads normally operated by the step-up Wellpad operator do not have any WAG wells so they were not immediately familiar with this requirement. Had another operator more experienced with WAG wells or the permanent Field Lead been on shift their experience would have likely resulted in scheduling the tests rather than relying solely on the SVS tool. Corrective action for item #1: Prior to Field Ops Lead taking vacation, review planned field activity with the step-up lead operator and provide a list of activity in written handover that may trigger SVS performance testing. Findings concerning item #2: In the week of 8/10/2020 a manual date change was made to the database which supplies injector service type (MI vs. produced water) information to the SVS tool and daily exception reports. This change caused the database tracking well service type to stop updating. When S- 31 and S-134 were swapped to MI service on 8/15/2020 the database continued to show that the wells were on water injection and continued to do so until 8/31/2020. On 8/31/2020 the database with the injector service type information was refreshed with updated data causing S- 31 and S-134 to show as overdue for performance testing in the SVS tool and the daily exception reports on the morning of 9/1/2020. Corrective action for item #2: The logic for the database supplying injector service type information to the SVS tool and daily exception reports has been corrected such that a manual date change to the database will not cause the data to stagnate. This has been implemented and successfully tested. If you have any questions, please call me at 907-564-5231 Sincerely, Stan Golis PBW Operations Manager Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.09.22 09:32:09 - 08'00' Stan Golis f� GA- S— 31 A I, James B (CED' From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, September 4, 2020 2:46 PM To: Regg, James B (CED) k6y_11 11 1 01,6r Cc: Alaska NS - PB - Field Well Integrity; Stan Golis; Bo York Subject: Update: WAG Injectors S-31 and S-134 lapsed on SVS Performance Test Categories: Green Category Mr. Regg, The investigation into the S-31 (PTD # 1982200) and S-134 (PTD # 2090830) SVS performance testing noncompliance incident is still ongoing, but I wanted to give you a status update. We have confirmed that the service type for these wells was correctly changed by the board operator at the time of the transition from water to MI. We have not yet discovered why the daily exception reports and SVS tool did not register this change and therefore alert personnel to the testing requirement, but our IT group is continuing to investigate. As a temporary measure to ensure no other SVS noncompliance incidents occur manual SVS reports are being run daily and are being reviewed by the lead operators and well integrity. Let me know if you have any questions. Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki cz hilcorp cam From: Regg, James B (CED) [ma iIto Jim, regg alaska gov] Sent: Tuesday, September 1, 2020 10:40 AM To: Alaska NS - PB - Field Well Integrity <PBFieIdWelllntegrityChilcarp com_> Cc: Bo York <byork@hilcorp.com>; John Menke <jmenkt2h !corp com>; Stan Golis < olis(a�hiicorp com> Subject: [EXTERNAL] RE: WAG Injectors S-31 and S-134 lapsed on SVS Performance Test When completed, provide a copy of Hilcorp's investigation report including corrective actions relating to Hilcorp's regulatory tracking efforts that address the noncompliance. This request is in accordance with 20 AAC 25.300. Jim Regg Supervisor, Inspections AOGCC 333 W.711 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 jim.regg@alaska.gov. From: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, September 1, 2020 10:31 AM To: Regg, James B (CED) <jim.regg@alaska.Rov> Cc: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com>; Bo York <byork@hilcorp.com>; John Menke <imenke@hiicorp.com>; Stan Golis <sgolis hilcorp.com> Subject: WAG Injectors S-31 and S-134 lapsed on SVS Performance Test Mr. Regg, As a follow up to our phone discussion this morning, WAG Injectors S-31 (PTD # 1982200) and S-134 (PTD # 2090830) were found to be out of compliance and overdue for AOGCC required SVS performance testing. Here is what we know so fa r: S-31 • Was on M I from 03/20/18 — 08/09/18. • Last misc. SVS performance test while on MI performed on 03/25/18 • Shut-in from 08/09/18 — 02/19/19 • Was on PWI from 02/19/19 — 8/10/20 • Last SVS function test while on PWI performed on 03/31/20 • Put on MI on 08/15/20. A performance test was not scheduled. S-134 • Was on M I from 01/02/18 — 08/09/18 • Misc. performance test completed 01/06/18 and routine performance test completed on 02/27/18 • Shut-in from 08/09/18 — 01/31/19 • Was on PWI from 01/31/19 —08/10/20 • Last SVS function test while on PWI performed on 02/25/20 • Put on MI on 08/15/20. A performance test was not scheduled. A witnessed performance test has been scheduled with an AOGCC inspector for both wells. Hilcorp will be conducting an investigation as to why a performance test was not performed within 5 days of putting the well on Miscible Gas Injection. Please feel free to give me a call or email me if you have any questions. Thanks, 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. the use of theor entity named privileged and is int ded The information contained in this email message is confidentiadth s message imay be ln error, you are hereby n otifiedonly t atrany d ssem nationlvdistribution, or copy of this above. If you are not an intended recipient or if you have received 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 lisle above, then promptly and permanently delete this message. e responsibility of the recipient to ensure that the onward transmission, While all reasonable care has been taken to avoid the transmission of viruses, it is th 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. a Regg, James B (CED) From: Regg, James B (CED) Sent: Tuesday, September 1, 2020 10:40 AM Z' To: Alaska NS - PB - Field Well Integrity `� Cc: Bo York; John Menke; Stan Golis Subject: RE: WAG Injectors S-31 and S-134 lapsed on SVS Performance Test When completed, provide a copy of Hilcorp's investigation report including corrective actions relating to Hilcorp's regulatory tracking efforts that address the noncompliance. This request is in accordance with 20 AAC 25.300. 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 jim.regg@alaska.gov. From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, September 1, 2020 10:31 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com>; Bo York <byork@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: WAG Injectors S-31 and S-134 lapsed on SVS Performance Test Mr. Regg, As a follow up to our phone discussion this morning, WAG Injectors S-31 (PTD # 1982200) and S-134 (PTD # 2090830) were found to be out of compliance and overdue for AOGCC required SVS performance testing. Here is what we know so far: 3(A • Was on MI from 03/20/18 — 08/09/18. • Last misc. SVS performance test while on MI performed on 03/25/18 • Shut-in from 08/09/18 — 02/19/19 • Was on PWI from 02/19/19 — 8/10/20 • Last SVS function test while on PWI performed on 03/31/20 • Put on MI on 08/15/20. A performance test was not scheduled. S-134 • Was on MI from 01/02/18 — 08/09/18 • Misc. performance test completed 01/06/18 and routine performance test completed on 02/27/18 • Shut-in from 08/09/18 — 01/31/19 • Was on PWI from 01/31/19 — 08/10/20 • Last SVS function test while on PWI performed on 02/25/20 • Put on MI on 08/15/20. A performance test was not scheduled. A witnessed performance test has been scheduled with an AOGCC inspector for both wells. Hilcorp will be conducting an investigation as to why a performance test was not performed within 5 days of putting the well on Miscible Gas Injection. Please feel free to give me a call or email me if you have any questions. Thanks, 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. Q MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reg2 ��(19 DATE: Monday, March 4, 2019 P.I. Supervisor ' �l SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. S-31 A FROM: Lou Laubensteln PRUDHOE BAY UNIT S-3 IA Petroleum Inspector Pretest Initial 15 Min 30 Min 45 Min 60 Min Src: Inspector S -31A Reviewed By: Type Inj P.I. Supry J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-3 IA API Well Number 50-029-22109-01-00 Inspector Name: Lou Laubenstein Permit Number: 198-220-0 Inspection Date: 2/27/2019 ' Insp Num: mitLOL190227154820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S -31A - Type Inj i W - TVD j 6382 Tubing 1999 Iwo 1800 - 1800 - PTD 1982200 Type Testi SPT Test psi1696 IA 430 2699 bis 645 BBL Pumped: 3 '111111,Returned: 2OA 298 32e 332 332 Interval 4YRTST P/F 1, Notes: —,es�-dae qC(a zoIQ 2Xtt 5—r wAY11 -Py is(7.®Iq Monday, March 4, 2019 Page 1 of I Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, February 18, 2019 2:44 PM To: AK, GWO Well Integrity Engineer; Wallace, Chris D (DOA); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W, AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; AK, GWO Well Integrity Well Information Subject: OPERABLE: Injector S -31A (PTD #1982200) Ready to be brought online for 4 year AOGCC MIT -IA 01 Injector S -31A (PTD #1982200) was made not operable on 1/31/2019 for lapsing on its 4 year AOGCC MIT -IA. The well is ready to be brought online and is hereby reclassified as Operable. An AOGCC witnessed MIT -IA will be performed when the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: AK, GWO Well -Integrity Engineer Sent: Thursday, January 31, 2019 2:21 PM To: 'chris.wa llace@alaska.gov' <chris:waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WelipadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWeliPadDFTN2@bp.com>; AK, OPS Well Pad HUQ<AKOPSWeIIPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeIIPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, January 31, 2019 2:21 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity, AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector S -31A (PTD #1982200) will lapse on AOGCC MIT -IA 0 Injector S -31A (PTD #1982200) is due for its four year AOGCC MIT -IA by the end of January 2019. The well is currently shut in and will not be brought online until a PW I swap is complete. The well is now classified as NOT OPERABLE for tracking purposes. When the swap is complete, the well will be reclassified so it can be put on injection and the AOGCC MIT -IA can be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM .JN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon1T Repair Well Plug Perforations ❑ Perforate CI Other ❑ Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4.Well Class Before Work 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 198-220-0 3 Address P O.Box 196612 Stratigraphic ❑ Service0 6.API Number. Anchorage,AK 99519-6612 50-029-22109-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028258 AURA S-31A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,AURORA OIL/PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary E Total Depth measured 13038 feet Plugs measured 8659 feet R E E I\i E D true vertical feet Junk measured None feet 8813 04 FEB 0 3 2015 Effective Depth measured 8659 feet Packer measured See Attachment feet K [V' true vertical 7168.08 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 30 5-110.5 30.5-110 5 0 0 Surface 2674.85 13-3/8"68#L-80 30-2704 85 30-2695.09 5020 2260 Intermediate 10754 88 9-5/8"47#L-80 28 2-10783 08 28.2-8727 02 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 7999-8089 feet 8149-8169 feet 11097-12618 feet 12653-13038 feet True Vertical depth 6660 07-6729 1 feet 6775.05-6790.35 feet 8762.55-8784 71 feet 8783 79-8813 04 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 11097'-12618', 12653'-13038'. � � - ','1,11t1 Treatment descriptions including volumes used and final pressure. sb�� 58 Bbls cement,1500 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 1109 600 1786 Subsequent to operation 0 0 1973 660 1560 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 0 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 0 Exempt 314-389 Contact Garry Catron Email Garry.CatronBP.Com Pnnted Name Garry Catron Title PDC PE Signature N f4 � �� Phone 564-4424 Date 2/2/2015 r V T L 7-/c,//5RBDMSAk FEB - 4 2015 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028258 SW Name Type MD TVD Depscription S-31A PACKER 3680.09 3543.15 5" Baker ZXP Top Packer S-31A PACKER 7634.06 6381.85 4-1/2" Baker Premier Packer S-31A PACKER 8543.45 7078.39 3-1/2" Baker Premier Ret. 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H II NOCn W J000J N— O' = I2NO .a . ° a) C1� 0CV 5 0 g Z I <<J-sawwu.lp2r to = oEr, �_' a) Ti I D � wOC� N � JHIH H0o � 0 � r Trac— C3 _„ c o H4- � 0cr < , � _I -� Z0OI- u) rnQ - tr 73 U3al D OU v O z000 v _1 W Q � W ZF- 0) 0EL __I03 O4k -a � /D *k C1 04t r 0HIy < WZ W � F- = UDc0OQQOZ * HZIO- � � oI E o a) K 13-) N a 00 Lu UJ C)H Wa. * * zdEWH00 � OIi * 05OCA � * Ua. 0 (5r * co -t3 * HQ ZO * v d- •4- .1- v r r _ r O co O coO N N N N N N 0 0) Or r .- co ao 00 0 co ITS= • 4"C S-31 A SAFES 'TES:H2S READINGS AVERAGE 125 ppm WHEN ' FM WELLHEAD= CON MI.WELL REQUIRES A SSSV WHEN ON Ml. WELL ACTUATOR= OTIS ANGLE>70°4k 10869'.-CHROME TBG&LNR"" OKB.BEV= 66.5(Y BF.ELEI/= 38.30' 2203' H4-1/2"FEB X NP,13=3.813" KOP= 2449' Max Angle= 98"@ 11000' Datum MD=`._...- 13919 I 270T - I FOC Datum TVD- 8800 SS ? = r ST GASLFEMRELS MD ND DEV TYPE VLV LV LATCH PORT DATE 13-3/8'CSG,68#,NT 80,D=12.415" -i 2708' Vf 4 3596 3479 39 MMG DMY RK 0 01125!07 ESTIVATE)TOP OF C EMTBIT ?? ir 9-5/8" X 7"BKR ZXP LTP,D=4.890" 3679' 7571' - 4-12"HES X NP,N3=3.813" 9 5/8'X 7"BRK"FIu1C"LNR D=4.830" 3697' a Ie. 7"x 4-1/2"BKR PREfu 2 PKR,D=3.870" HCR, ,�_ _, �� .11 et ! , 1 e 7703' -4-1/2•BKR"CMD SLD SLY,D=3.812" Minimum ID =2.813" @ 8659" e e 1 1 e OPENED(08/11/14) 3-1/2" HES X1/2"BK11. V 4 7759' -{4-1/2"x3-1/2"x0,03=2.940" 4-1/2"TBG,12.6#,L-80,TC-1,.0152 bpf,D=3.958" -I 7759' �- 7921' -13-1f2"FSS X NP,D=2.813" M 7•x 3-1/2"BKR Pf�utEf2 PICR D=2.870' 8643' ;e►�. ► e� WATER NJECT1ON MANDRELS t/ MI mtti roi, ST MD TVD DEV TY FE VLV LATCH PORT DATE lity 3 7802 6509 40 MMG-W DMY RK 0 12/13/06 TBG PUNCH(08/07/14) 8616'-8621' ►! I i I 2 7860 6554 40 MMG-W DMY RK 0 12/13/06 ►•I 1 8599 7121 39 MMG-W DMY RK 0 12/13/06 .40 3-1/2"PERF PUP JOINT w/18 X 3/8"HOLES -I 10439'-10449' - ' 9G 8659' H3-1/2"FES X NP,ID=2.813" 7"SCAB LNR,26#,L-80,TC-I, .0383 bpf,D=6.276" -I 10456' C tri r 8500'CTDM -iTt 'OF tI(08/10/14) 1. 7'X 4-1/2"XO,D=3.930" -1 10456' t 41��l ,f+ )•0 4-12•TBG,12.6#,L-80,TC-I,.0152 bpf,D=3.958' 10458' I I AeII % 10469' H3-1/2"MULE SHOE,D=2.992" 4-1/2" •TBG STUB(11/28/06) 10466' ►►%tI%I! . 10470' 8-1/8"X 4-12"BKR OVERSHOT,13=7.000" ►4 b%.III + I, 3-12"TBG,92#,L-80,TC-I,.0087 bpf,D=2.992" 10469' !I t�1 II I 10482' N4-12"PKR SWS NI?D=3.813" 9518"X4-12'TtWPKR w/ANCIOR D=4.00" H 10485' aF �� 0 I II A TOP OF 2-7/8'LNR -I 10510' �I 1� �.!=hG 10510' -{4-ill"BKR KB 5111P041* PKR,D=2.60" 3-1/2"X 2-7/8'XO,D=2.44" -I 10515' I TOP OF 7"LNR H 10534 1! 10539' -i4-12"PKR SWS NP,D=3.813•(BEHND PIPE) C KA 4-12"TBG,12.6#,NT-13CR-80,.0152 bpf,D=3.958" 10571' '' 10551' H2-7/8'OTIS X 1P,D=2.313" Zi III''' II wHPSTOac H 10782' ; 'b'4114' � 9-5/8"CSG,47#,NT-80-S,D=8.681• - 10783' •I I�+ 10559' -14-12'PKR SV1N NP,D= 3.725"(BEHIND PIPE) •I II, yj ;4 I,I, I 10571' H4-1/2"TBG TAL W/LEG(BENIN PIPE) 7"LNR,26#,NT-13-CR,.0383 bpf,D=6.276" -I 11428' I II, '/. Io 6A 10562' -ELMD TT LOGGED 01/06/91 PERFORATION SUMMARY 41 4 ►.x it REF LOG: SWS GR-DL-BHCS ON 12/10/90 MLLOUT WNDOW(S-31A)10785'-10792' ANGLEAT TOP PERF:40"•7999' likot i►+�._� Note:Refer to Production DB for historical pert data •�•1•••••1'Vi Alp,. 44444444A It SIZE SPF NTERVAL Opn/Sgz DATE 14/04441 I 44444444 ►44444441 4‘. i 4-1/2" 5 7999-8089 C 12/06/06 f4A4�4�4�4�4A4A44 I :. 4-1/2" 5 8149-8169"* C 12/06/06 �`N.•N. PBTD H 12620' SLID LNR 11097-12618 0 11/05/98 2-7/8'LNR,6.16#,L-80 FL4S, 11097' •••••.. .0058 bpf,D=2.441" I PERF[ THS COSTED PER APE(04/17/09 E-MAIL). 2-7/8"LNR,6.16#,L-80,.0058 bpf, H 12653' ----.-._ ' "' + REFERENCE33 USIT DATED 11/27/06 CORRECTED DEPTHS D=2.441' OR EN HOLE TD -REFERENCED TO SWS BHCS DATED 12/10/90(APPROX 50'OFF) DATE REV BY COMMENTS DATE REV BY CO/MINTS PRUDHOE BAY UNIT 12/20/90 DFF ORIGINAL COMPLETION 07/15/14\SWC1JMC CLOSESLDSLV(07/09/14) WELL: S-31A 11/05/98/VHITLOV SIDETRACK"A" 07/15/14 SW47JMC PULL PX PLUG(07/10/14) FERMTT No: 198-2200 01/21/99 GLM LAST WORKOVER 08/07/14 JS/PJC TBG PUNCH API No: 50-029-22109-01 12/16/06 N7ES RWO 08/10/14 MP/PJC P&A(CMT LNR) SEC 35,T12N,712E,1639'FNL&1450'FAL 06/01/11 S M 1PJC SET PX PLUG(05/08/11) 08/11/14 CJW PJC OPEN SLD SLV 01/19/12 TMWJMD ADDED H2S SAFETY NOTE BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg '7 DATE: Tuesday,January 27,2015 �'� SUBJECT: Mechanical Integrity P.I.Supervisor 1I3UI 1- g Y Tests BP EXPLORATION(ALASKA)INC S-31 A FROM: John Crisp PRUDHOE BAY UNIT S-31A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T0� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-31A API Well Number 50-029-22109-01-00 Inspector Name: John Crisp Permit Number: 198-220-0 Inspection Date: 1/18/2015 Insp Num: mitJCr150120123328 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-31A Type Inj 1 W iTVD 6382 ' Tubing 2650 1 2650 2650 2650 - tPTD 1982200 Type Testl SPT Test psi 1596 IA 302 3303 ' 3250 I 3230 - Interval[4YRTST P/F P `' OA 118 167 173 + 173 Notes: 1 5 bbls pumped for test. _ 1 11 Tuesday,January 27,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /?~'-- ~4~) File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts Pages: Poor Quality Original- Pages' [] Other- Pages: DIGITAL DATA Diskettes, No.,~ [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by:~Mildred Daretha Nathan Lowell -- Date..~./~.~ Is, ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 02, 2011 TO: Tim Regg Ise,- � / /( SUBJECT: Mechanical Integrity Tests P.I. Supervisor 111 BP EXPLORATION (ALASKA) INC S -31 A FROM: John Crisp PRUDHOE BAY UNIT S -31A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry iL ' NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S - 31A API Well Number: 50 029 - 22109 - 01 - 00 Inspector Name: John Crisp - Insp Num: mitJCr11022107I509 Permit Number: 198 - 220 - Inspection Date: 2 /20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S -31A ' Type Inj. G " TVD 6382 - IA 190 2010 " 1950 1940 ' P.T.D 1982200' TypeTest SPT 1 Test psi 1595 ' OA 40 50 50 50 Interval 4YRTST - P/F P 'Tubing 3100 3100 3100 3100 Notes: 2.1 bbls pumped for test I i Wednesday, March 02, 2011 Page 1 of 1 WELL LC~G T~AIIf~M/TT,4L 1.. PROMivE DingNOSric SeRVicES, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and F_. <<_t ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 L 9 ~l ~~ 1) Injection Profile 06-Marv10 S-31A 2) Signed Print Name: 1 BL/ EDE 50-029-22109-01 ~:.' , ~xn Date : MAR L ~ 2010 D A PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8951 FAX: (9071245-8$952 E-MAIL : pdsanchoraaeCa~memorvloa.com WE6SRE : www.memorvlog.com C:\Documems and Settings\Diane Williazns\Desktop\Tnuissi[ut_BP.docx STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other 0 COMMINGLE Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ INJ IN AURORA Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ente Suspended Well ^ & PRUDOHE BAY 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 198-2200 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-22109-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ~ADLO-028258 ` PBU S-31A 10. Field/Pool(s): Prudhoe Bay FIELD / Prudhoe Bay/Aurora POOL 11. Present Well Condition Summary: Total Depth measured ~ 13038 feet Plugs (measured) None feet ~~~~ true vertical ~ 8813.04 feet Junk (measured) None feet Effective Depth measured 12620 feet Packer (measured) 7634 8543 10485 10510 true vertical 8785 feet (true vertical) 6382 7078 8511 8528 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2707 13-3/8" 72# L-80 SURFACE - 2707 SURFACE - 2697 4930 2670 Intermediate 10783 9-5/8" 47# L-80 SURFACE - 10783 SURFACE - 8727 6870 4760 Liner 2143 2-7/8"6.16# L-80 10510 - 12653 8528 - 8784 13450 13890 Liner 6791 7"26# L-80 3679 - 10470 3542 - 8500 7240 5410 Liner 251 7"26# L-80 10534 - 10785 8546 - 8728 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 surface - 7759 surface - 6477 3-1/2" 9.2# L-80 7921 - 10469 6600 - 8499 4-1/2" 12.6# NT-13CR-80 10470 - 10571 8500 - 8572 Packers and SSSV (type, measured and true vertical depth) _, . 7"x4-1/2" bkr premier pkr ~763`~ ; "~~' . 6382 7"x3-1/2" bkr oremier okr 8543 7078 9-5/8"x4-1/2"tiw okr w/ancor 10485 8511 4-1/2" bkr kb okr 10510 8528 12. Stimulation or cement squeeze summary: Intervals treated (measured): j~~$ ~ (}'~ pj~ J~A~~ ? x k~ I~ ~~ ~ . l1 ~-r '* Z~Ui '} ~ Treatment descriptions including volumes used and final pressure: The (PROF was completed on 3/6110. Danielle Ohms analyzed and determined the s its on MI injection ~O be 83% Aurora/ 17% Sag. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2054 3077 Subsequent to operation: 2365 3036 14. Attachments: 1 . Well Class after work: Copies of Logs and Surveys Run x Exploratory^ Development ^ Service ^r Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL G OR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3 10-013 Contact Danielle Ohms Printed Name Daniell s Title P.E. Signature ~, Phone 564-5759 Date 3/19/2010 RBDMS MAR 2 21010 -' " l Form 10-404 Revised 7/2009 3•ZZ /o ~i ~d Submit Original Only 3tl ~ S-31 A 198-220 DFRF ATTArNMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-31A 11/5/98 OH 12,618. 13,038. 8,784.71 8,813.04 S-31A 11/5/98 SL 11,097. 12,618. 8,762.55 8,784.71 S-31A 11/14/06 BPS 10,545. 13,038. 8,553.39 8,813.04 S-31A 12/11/06 BPP 10,545. 13,038. 8,553.39 8,813.04 S-31A 12/14/06 PER 7,999. 8,089. 6,660.07 6,729.1 S-31A 12/14/06 PER 8,149. 8,169. 6,775.05 6,790.35 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • S-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/5/2010;**"WELL INJECTING ON ARRIVAL""* (iprof) EDRIFT TO SSSV @ 2180' SLM/ 2203' MD W/ 3' 1 7/8" STEM, 3.85" GAUGE RING ~ EQUALIZE 4 1/2" MCX W/ 3' 1 7/8" STEM, 3.80" CENT, 4 1/2" X-EQUALIZING i PRONG (ring on prong) ;PULLED 4 1/2" MCX FROM 2180' SLM/ 2203' MD, SN: M-02 I*"* CONT ON 03/06/10 WSR**'` 3/6/2010***CONT FROM 3/5/10 WSR***(iprof) ADRIFT TO DEV @ 10868' SLM W/ 3' 1 1/2" STEM, 2.25" CENT, SAMPLE BAILER (NO SAMPLE) RUN PDS (PROF AS PER PROGRAM- INJ PRESSURE= 2975psi, 88"F, SET 4-1/2" MCX IN SSSV NIP @ 2180' SLM/2203' MD (.625 bean, SER #- M- [ x436) RUN 4 1/2" CHECKSET TO SSSV @ 2180' SLM/ 2203' MD (good set) PERFORM CLOSURE TEST (good test, see log) ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED*** FLUIDS PUMPED BBLS 2 diesel 2 Total TREE _. 4" CMJ WELLHEA = FMC ~~ ACTUATOR = OTIS KB. ELEV = 66.50' BF. ELEV = 38.30' KOP = 2449' Max Angle = 98 @ 11000' Datum MD = 13919' Datum TV D = 8800' SS 13-3/8" CSG, 68#, NT-80, ID = 12.415" - ESTIMATED TOP OF CEMTENT 9-5/8" X 7" BKR ZXP LTP, ID = 4.890" 9-5/8" X 7" BRK "HMC' LNR HGR, ID = 4.830" • 2708' 3679' 3697' ~ 4-1/2" TBG, 12.6#, L-80, TGII, .0152 bpf, ID = 3.958" I-{ 7759' I7" x 3-1/2" BKR PREMIER PKR, ID = 2.870" ~-~ 8543 Minimum ID = 2.313" @ 10551" 2-718" OTIS X NIPPLE 3-112" PERF PUP JOINT w / 18 X 3/8" HOLES -{ 10439' - 10449' 7" SCAB LNR, 26#, L-80, TGII, .0383 bpf, ID=6.276" 10456' 7" X 4-1/2" XO, ID = 3.930" 10456' 4-1/2" TBG, 12.6#, L-80, TGII, .0152 bpf, ID = 3.958" 10458' 4-1/2" TBG STUB (11!28/06) 10466' 3-1/2" TBG, 9.2#, L-80, TGII, .0087 bpf, ID = 2.992" 10469' 9-5/8" X 4-1/2" TMJ PKR w/ANCHOR, ID = 4.00" 10485' TOP OF 2-7/8" LNR 10510' 3-1/2" X 2-718" XO, ID = 2.44" 10515' TOP OF 7" LNR 10534' 4-1/2" TBG, 12.6#, NT-13CR-80, .0152 bpf, ID = 3.958" 10571' PERFORATION SUMMARY REF LOG: SWS GR-DIL-BRCS ON 12/10/90 ANGLE AT TOP PERF: 40° @ 7999' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE SEE PAGE 2 FOR PERF INFORMATION S ~31 A '"`*CHROMETBG & LNR ANGLE> 70° @ 10869' 4-1/2" HES X NIP, ID = 3.813" WHIPSTOCK -i 10782' r 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" 10783' 7" LNR, 26#, NT-13-CR, .0383 bpf, ID = 6.276" 11428' 2-718" LNR, 6.16#, L-80, FL4S, .0058 bpf, ID = 2.441" - 2707' FOC GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DA 4 3596 3479 39 MMG DMY RK 0 0112 7571' 4-1 /2" HES X NIP, ID = 3.813 7634' 7" x 4-1/2" BKR PREMIER PKR, ID = 3.870" 7703' 4-1/2" BKR "CMD' SLD SLV, ID = 3.812" 7759' 4-112" X 3-1/2" XO, ID = 2.940" 7921' 3-112" HES X NIP, ID = 2.813"~ WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 7802 6509 40 MMG-W DMY RK 0 12/13/06 2 7860 6554 40 MMG-W DMY RK 0 12/13106 1 8599 7121 39 MMG-W DMY RK 0 12/13106 8659' 3-1i2" HES X NIP, ID = 2.813" 10469' - j 3-1 /2" MULE SHOE, ID = 2.992" 10470' 8-1/8" X 4-1/2" BKR OVERSHOT, ID = 7.000" 10482' 4-1/2" PKR SWS NIP, ID = 3.813" 10510' I-~ 4-1 /2" BKR KB PKR, ID = 2.60" 10539' -j4-1/2" PKRSWS NIP, 10= 3.813" (BEHNID 10551' 2-7/$" OTIS X NIP, ID = 2.313" 10559' -~4-1/2" PKR SWN NIP,ID = 3.725" (BEHIND PIPI 10571' 4-1/2" TBG TAIL W/LEG (BEHIND PIPE) 10562' ELMD TT LOGGED 01/06/91 MILLOUT WINDOW (S-31 A) 10785' - 10792' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/20/90 DFF ORIGINAL COMPLETION 09/25/08 SWGPJC DRAWING CORRECTIONS 11/05!98 HITLO SIDETRACK "A" 05/31/09 PJC/TLH PERF DEPTH CORRECTIONS 01/21!99 GLM LAST WORKOVER 12/12109 GTW/PJC PULL PXN (12/06/09) 12/16/06 N7ES RWO 01/26/07 KSB/PJC GLV C/O & OPEN SLD SLV 03/05/07 MWS/PJC DRLGDRAFTCORRECTIONS PRUDHOE BAY UNIT WELL: S-31A PERMfT No: 198-2200 API No: 50-029-22109-01 SEC 35, T12N, T12E BP Exploration (Alaska) • • SEAN PARNELL, GOVERNOR ~iIL>•-7~ OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 ~T CO1sS~R~L~~Ols CO~SSIO1~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 _.. ;_... .. . _ .._ PAX . (907) 276-7542 Ms. Danielle Ohms Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 ~~~ ~~~ ~ ~_ Lu'~ ~~--~ Anchorage, Alaska 99519-6612 ~~j'' Re: Prudhoe Bay Field, Prudhoe Bay/Aurora Pool, S-31A Sundry Number: 310-013 Dear Ms. Ohms: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 2010 Encl. Sincerely, `G STATE OF ALASKA /~ ~1~~ ALAS~ILAND GAS CONSERVATION COKAMISSI~ r ~, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~G~~~~~~ ~a~ .IAN ~ 9 2010 ®IASks ail ~ Gas Cans Cornm'issian 1. Type of Request: Abandon^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ Chan~~rogra0 Altercasing^ Plug Perforations ^ Perforate^ Pull Tubing^ Commingle Time Extensic ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ l --ll Other:Commin le In'ection in Aurora and PI~.1hoe Bav Pool 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 198-2200 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ , 6. API Number: Anchorage, AK 99519-6612 50-029-22109-01-00 ~ 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 ^ S-31A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028258 ~ PRUDHOE BAY Field / PRUDHOE BAY/AURORA Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13038 - 8813.04 12620 - 8785 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE 110 SURFACE 110 Surface 2707 13-3/8" 72# L-80 SURFACE 2707 SURFACE 2697 4930 2670 Intermediate 10783 9-5/8" 47# L-80 SURFACE 10783 SURFACE 8727 6870 4760 Liner 2143 2-7/8" 6.16# L-80 10510 12653 8528 8784 13450 13890 Liner 6791 7" 26# L-80 3679 10470 3542 8500 7240 5410 Liner 251 7" 26# L-80 10534 10785 8546. 8728 7240 5410 Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 SURFACE 7759 - - 3-1/2" 9.2# L-80 7921 10469 - - 4-1/2" 12.6# NT-13CR-80 10470 10571 Packers and SSSV Tvoe: 7"x4-1/2" BKR PREMIER PKR Packers and SSSV MD and TVD (ftl: 7634 6382 7"X3-1/2" BKR PREMIER PKR 8543 7078 9-5/8"X4-1/2" TIW PKR W/ANCHOR 10485 8511 4-1/2" BKR KB PKR 10510 8528 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/1/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^Q - Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Danielle Ohms Printed Name Title ielle Ohms P.E. Signature ~ ~ ~r~``% Phone Date / 564-5759 1/18/2010 Cdd~-R-j Prepared by Gary Preble 564-4944 COMMISSION USE ONLY 3/~ ~~1~ Number: Sund witn tif i i th t t ti C diti f l N C ry y on so a represen a ve may ess on ons o approva : o omm ss a „ n C le ara n ce ^ nical Integrity Test ^ Locatio Plug Integrity ^ BOP Test ^ Mecha Q a \ i t ~ i Other: ~ pQc'Q~'cd~~ `~+~ GL_~tp~ ~ ! A\~ ~~C n~da~~t~K~) T ~~V ~ ~~~V"~P~~r~UC~CJ~ < Subsequent Form Required: /a,yO APPROVED BY ~ ~ 3 ~/[J Approved by: MMISSIONER THE COMMISSION Date: ~~S FES. o a ~~ (~~~ G 1 ~~ L Form 10- 3 12/2009 Z•/•/v ~.~/~ Submit in Duplicate S-31 A 198-220 DFRF ATT~('_I-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-31A 11/5/98 OH 12,618. 13,038. 8,784.71 8,813.04 S-31A 11/5/98 SL 11,097. 12,618. 8,762.55 8,784.71 S-31A 11/14/06 BPS 10,545. 13,038. 8,553.39 8,813.04 S-31A 12/11/06 BPP 10,545. 13,038. 8,553.39 8,813.04 S-31A 12/14/06 PER 7,999. 8,089. 6,660.07 6,729.1 S-31A 12/14/06 PER 8,149. 8,169. 6,775.05 6,790.35 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 • by • To: Jerry Bixby /Clark Olsen Date: Jan 18, 2010 GPB Well Ops Team Leaders Patti Philips, S-Pad Engineer (Kuparuk Zone) From: Danielle Ohms S Pad Engineer, Matt Brown, Wells Engineer Subject: S-31A IPROF Lost on MI 1. O Put well on commin led MI injection. 2. S Pull MCX. Run IPROF. Run MCX Current Status SI Last Test: 2.1 MMCFD, 3000 psi WHIP on 11/30/09 Max Deviation 98° at 11001.56 ft Min ID 2.313 at 10551' X Nipple Last Tag: not tagged since ST Last Downhole O: 1/7/10 pull gauges, set MCX Latest H2S value: No data for this well SBHP/T: 3400 psi/ 206 F at 8535 ft SS on 1/5/10 (Sa onl ) Job Objectives/Discussion: The Sag River zone has been identified as an MI target in S-31 A. The objectives of this procedure are: • Put the well on commingled MI injection (Kuparuk and Sag) • Get flow injection splits between the Kuparuk and Sag intervals The Kuparuk was previously open to injection via a sliding sleeve. The Sag has been closed to injection since 2004, the plug was pulled in Dec and pressure gauges hung from another plug set in it's place. Upon pulling the gauges on Jan 5-7, 2010 to retrieve the gauges, the well is set up for commingled injection but remains SI until Sundry approval is obtained. The Sag only pressure was evaluated and is expected to enable the Sag to take injection at current surface injection pressures. The IPROF does not need to be run all the way to the Sag perfs- the objective is only to get splits between the Kuparuk and Sag, so the deepest target depth for the IPROF is 10800' (hole angle about 45 deg). • Because there will be commingled injection between 2 pools, AOGCC regs require an (PROF within 60 days of sustained injection. The memory IPROF would need to be obtained on MI injection. Once the MI cycle is finished (approx end of Feb), the Sag may be left open when the well is returned to PWI. Well History: S-31A was sidetracked in 11/98 to the Sag as an injector. Sag injection occurred continuously until 2001 with a short time of injection in 2004. The well developed a PC leak, so a RWO was planned to fix the ann comm and also to add Kuparuk perfs. A plug was run in the 2-7/8" X nipple to secure the well in prep for the RWO in 11/06. A scab liner was run and the Kuparuk (Aurora) was perf'd. The Kuparuk is isolated by a straddle and injection started into the Kuparuk via a sliding sleeve in 2007. The Sag has been isolated since the RWO so no commingled injection has commenced to date. A SBG treatment was performed on 9/9/09. Contacts for this work are: Matt Brown Danielle Ohms 564-5874 w 564-5759 w 223-7072 c 440-9082 c 344-1130 h 345-2477 h cc: w/a: Well File x - • Slickline: (PROF Procedure- To be performed after well on MI for 2 weeks. 1. MIRU. Pull MCX. Target injection rate is max rate at 3000 psi WHIP. 2. RIH with Memory GR/CCUSpinner/Temp/Pres 3. Park at 7600' and obtain 5 min stop count. (above sliding sleeve) 4. Start at 7600' and log down at 40 fpm to 7800' to view flow entering sliding sleeve (7703'). 5. Park at 7800' and obtain 5 min stop count. 6. RIH to 10475' and obtain 10 min stop count. 7. RIH from 10475' at 40 fpm and log to 10800'. 8. POOH. Download data & correct to driller's depth. 9. Run MCX. 10. RDMO. End of procedure. • TREE = d" C1M W~LHEAD = FMC ACTLI4TOR. ~~~OTIS KB. H-EV - ,_.66.50' BF, l3EV = 38.30' KOP= ....... .....2 449' Max An .le = 98 _ ..-..'Y1000' Datum MD = 13919' Dalum TVD = 8800' SS 4-1l2" TBG, 12.6#, 1-80, TC-It .0152 bpf, D = 3.958' i-- ~ 7759' 7" x 3-1C2" BKRPREAIERPIQt, D=2.870" 8543' Minimum IQ (S-31Aj =2.313" @ 10551" 2-718" OTIS X NIPPLE 3-1:2" PERF PlR JONi w! 18X318" HOLES 10439' - 1044! 7" SCAB. LNR 26#, L-80, TC-1', .0383 bpf, D=6.276" 1(}455 7" X 4-1 t2" XO, D = 3.930" 10456' 4-1f2" TBG, 12,6#, L-80, TC-i~, .0152 bpf, D = 3.958" 10458' A-1l2" TBG STt16 {1 ^128!06) 10465 3-172" TBG, 9.2#, L-80, TC-II, X087 bpf, D=2.992" 10469' 9-5/8"X4-112"TMIFKRw/ANCHORD=4.00" ~ 10485' TOP ~ 2-718" LNR 10510' BG, 12.6#, Ni-13CR-80..0152 bpf, D = 3.958"H 1057' PERFORATION SUMMARY REF IOG: SWS GR-DL_-BRCS ON 12!10/90 ANGLEATTOPPERF.40° ~ 7999' Notes Refer to Production DB for h5tork:al perf data SIZE SPF EITHtVAL Opn/Sgz DALE S~ PAGE 2 FOR PStF NFORMAT~N WHP5TOCK -C 9-5l8" CSG, 47#, NT-BG-S, D = 8.681" 1078 7" LNR 26#, Nf-13-CR .0383 bpf, D = 6276" 1142 I 1 1 12!18106 SAFEfY NOTES: NOPoZONiAL WaL > 70° +~ 70869' S -~ ~ A *"'CHROMETBO S LPIt 2707' FOC GAS LIFT 68#, Ni-80, ID= 12A15" ~ NAATEDTOP OF CEMtFNT t" BKRZXP l TP, ID = 4.890" t149C" LNR HGR D = 4.830" rt¢ rtsxrvir, lu=ss is I '" x 4-112" BKR PR@V7lR PKR D = I-112" BKR "Cfvtfl' SLD SLV, D = 3.'~ 1-112" X 3-112" XO, D = 2.840" S-1 i2" HES X NIP, D = 2.813" 1 WATFR IILLIF(:TYIN RAA NDRR S ST MD TVD DEV TYFE VLV LATCH ART DOTE 3 7802 6509 40 MMG-W DA41' RK 0 12!13!06 2 7860 6554 40 MMG-W f1vTV RFC 0 12l13F06 1 8599 7121 39 PdAAG-W DNP/ RK 0 12/13706 HES X NP. D = 2.813" 1(}469' I- -13-1/2"MIRESHOE,D=2.992" I 10470' 8-118"X4-i!2"BKROVERSFIOT, D=7.000" 10482' 4-112" PKR SWS MP, D = 3.813" 10510' 4-1/2" BKR KB RCR ID = 260" 10539' 4-1l2" FKR SWS NP, D = 3.813" (BBIJ®P~E) 10551' 2-718" 0713 X h1P, ID = 2.313" 10551' 2-718"PXNFLUG(t1/14!06) 10559' ~4-':;2" PKR S'MJ NP,D = 3.725" (8EF0ND PN'E) I 10571' 4-1l2" lBG TAIL W,'LEG (BEtO~ PWE) 10562' aMDTTLOCGEDOV06791 ~\ M1~1.OUT WWDOW (S-31A) 10785' - 10792' \,\~ . ~ \ ru3TD 1252(F' .0058 bpf, D=2.441" H 17097' r 6.16#, L-80, .0058 bpf, ID=2.441" 1i 2-718" LNR 6.16#. L-B0, .0058 bpf, D = BY PRUDHOE BAY lRJ(T WELL: S-31A PE3~AT No: 198-2200 API No: 50-029-22109-Ot SEC 35, T12N, 712E 8P Brplorafion (Alaska) TREE= d"CIW W~LFEAD = FNS ACTUATOR= OTIS KB. LLEV = ~~ 66.SQ' BF ELEV = 38.30' KCB=:,, ., ......,2449' pAa~c_Angle_._ ,~ .Q$ ~-11000' Datum MD= 13919' DatumTVD=^ 8800'SS PERFORAT~J SUMi1ARY REF LOG: SWS GR-OL-BHCS ON 12/10!90 A NGLE AT TOP P6iF: 40° @ 7999' Note: Refer to Produc0on DB for h~lorical pert data SIZE Sf~ INTERVAL OpnlSgz DATE 4-112" 5 7999 - 8089^' O 121(16/06 4-1l2" 5 8149 - 8169"" O 12/06/06 SLTD LNR 11097 - 12618 C 11/05/98 °PEi~ DEPTHS CORRECT® PERAPE (04117109 E-MAILj. ~ USIT DAT®11!27108 CORRECTED ~THS REFE>Ea TO SWS BiiCS DATA 12!10190 (APPROX 50' a ~~ DATE 12/20!90 11/05198 REV BY DFF L COMPiENTS ORIGINAL COMPLETION SIDETRACK "A" DATE 09!25108 05/31109 REV BY SWCIPJC PJC/TLH COMM7TfTS DRAW~JG CORRECTIONS PERF DEPTH CORRECTIONS 01121/99 GLM LAST WORKOVER 12N8106 N7E5 RWO 01/26107 KSB/PJC GLV C!O & OPEN SLD SLV 03K)5/07 Iv1NS1PJC DRLG DRAFT CORRECTIONS SAFETY NOTE5: CTD HORIZ S9~TRACK NV SAG Pot/Ht -31 A FORNIATK)N • 70 ~ 10989' *""CHROMETBG & LNR S PRUDFiOE BAV lHVff WELL: S-31A PERI+AT No: 198-2200 APIPb: 50-029-22109-Ot SEC 35, T12N, T12E BP E (A j ~' - (). ~• 00 East Benson Ba~levaM 'ost Office Box 188612 u~chora~, Alike 99519-6612 elephone (90~ 584 581 ~ `~~~ November 13, 2006 -ane Williamson Hinton Aubert Alaska Oil and Gas Conservation Commission t33 West 7`~ Avenue, Suite 100 anchorage, AK 99501 ~ir~ V I ~ 2006 `~~~~ ~~ ~~~~~ JVe respectfully request administrative approval for modification of Area Injection Orders t & 22 to allow multiple completions of water injection wells with the Aurora and 'rudhoe Western Operating Area Oil pools. Well S-31A, an injector completed within he Sag river formation of the Prudhoe pool is proposed to be re-completed to inject in the i aurora pool and we plan to combine injection into the two pools as detailed below. 'rior to initiation of ca-mingled injection, mechanical isolation between pools will be lemonstrated by a cement evaluation log and approved by the Commission. Results of ogs, surveys or down-hole monitoring used for determining the allocation of water ejection between pools, if applicable, will be supplied in the annual reservoir >urveillance report. Che expected injection requirements will be 2-8 MBWIPD for Aurora and 1-3 MBWIPD For the Sag, depending on futtue off-take. Hydraulic modeling indicates that adequate wttom-hole pressure can be supplied to meet required injection rates into both reservoirs Kith either boosted produced water or Prince Creek water. Because injecrivity is iependent on off-take, the S-31A completion will allow for the ability to Limit rates to each or both reservoirs if necessary. ~ Please call Jim Young 564-5754 if you have any questions. ~ sincerely, ~~~~ E Paskvan GPB WEST Manager CC: Ellen Stevens (BPXA) Sonny Rix (Exxon-Mobil) Dan Kruse (CPAl7 P. Winslow (Forest Oil} G. Frosthoff (Chevron-Texaco) ~~W u ~ O~ ~L~~u ~ ~.P.s~ ou, nrm cns CONSERVATION COMMISSION ADMINISTRATIVE APPROVAL rtUMBERS AIO 2X.002 and AIO 3.010 Mr. Frank Paskvan GPB West Manager BP Exploration (Alaska) Inc. P. 0. Box 196612 Anchorage, AK 99519-6612 SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Re: Request far modification to AIO 22C and AIO 3 to allow for commingled injection within the Aurora and Prudhoe (Western Operating Area) Oil Pools in S-31A Dear Mr. Paskvan: By letter dated November 13, 2006, BP Exploration (Alaska) Inc. ("BPXA'~ requested approval to allow water injection into both the Aurora Oil Pool aml the Sag River 1~ormation of the Fradhoe O~q Po®1 through multiple completions in Well S-31A. In accordance with 20 AAC 25.210, Rule 9 of Area Injection Order ("AIO") 003.000, and Rule 8 of AIO 22C the Alaska. Oil and Gas Conservation Commission ("Commission") hereby grants BPXA's request with the following conditions: 1. An approved Application for Sundry Approval (Form 10-403) is required prior to commencement of commingled injection. 2. A downhole injection survey for purposes of allocation of injection by pool is required within 60 days of sustained injection and at least once per year thereafter so long as commingled injection continues. 3. Monthly reports of injected volumes by pool must be submitted on the Monthly Injection Report (Form 10-406) 4. Annual and total cumulative volumes injected by pool and results of logs or surveys used for determining the allocation of water injection between pools must be supplied in the annual reservoir surveillance report. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day fa11s on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. AIO 2X.002 and AIO 3.010 December 7, 2006 Page 2 of 2 DONE at Anchorage, Alaska and dated December 7, 21106. -~. ~ =w• 'y.'~, win ~ ,~ st h i~ j 9 ya r i ~ ~ ~~ `~ '`>. r Cathy P. oerster Commi sinner Chairman Commissioner by January 22, 2010 Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Amendment to Area Injection Order 2X.042 -- Commingled injection in the Aurora Oil Pool and Frudhoe Oil Pool BP Exploration (Alaska) Inc. respectfully requests administrative approval for an amendment to AIO 2X.002 to allow multiple completions of Water Alternating Gas (WAG) injection wells within the Aurora and Prudhoe Western Operating Oil pools. It is currently approved for commingled water injection only and we'd like to expand to cover WAG service. Injector S-31A is an injector completed in both the Sag River formation of the Prudhoe pool and the Aurora pool where we plan to commence commingled WAG injection upon approval. Results of logs, surveys or downhole monitoring used to determine the allocation of water and gas injection between the two pools, if applicable, will be supplied in the annual reservoir surveillance report. Please call Danielle Ohms 564-5759 if you have any questions or wish to discuss further. Sincerely, r. ;~~~ - ~ cott I3i~ert/ Diane Richmond Subsurface Resource Managers, WF/ GPB WEST cc: Judy Buono (BPXA) Dan Kruse (CPAI) Mark Agnew (Exxon-Mobil} Glen Fredrick (Chevron.-Texaco) ~ ~ ~ BP Exploration (Alaska) Inc. ` ~ ~;.., Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 m Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ ~~~1~:~ ~li~ ~ = 2D~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ . BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad nnee fi/25/2(]09 Wetl Name PTp S Initial [op of cement Vol. of cement um ed Final top of cement Cement top oft date Cortosian inhibitor Corrosion inhibitod sealant date it bbls ft na al S-O78 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 7.7 5/25/2009 5-03 1871900 1325 NA 13.25 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-~ 1821650 0 NA 0 NA 0.9 5/26/2009 5-07A 7920980 0 NA 0 NA 0.9 5/26/2009 5-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 0.25 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-teA 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 OJS NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA t.7 5/25/2009 S-246 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL1 7960720 0 NA 0 NA 0.85 5/27/2009 S30 7900660 0.5 NA 0.5 NA 5.1 5/31/2009 ~ S-31A 1982200 0.5 NA 0.5 NA 3.4 5l26/'2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5l26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S37 1920990 125 NA 125 NA 11.9 5l27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27/2009 S-4t 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/'2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2p00780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 1.25 NA 725 NA 11.9 5/29/2009 S-102L7 2031560 125 NA 125 NA 11.1 5/31/2009 S-1oa 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 S-to4 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 S70s 2010120 16.25 NA 1625 NA 174.3 6/2/2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-toe 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-10s 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2027350 0 NA 0 NA 0.5 5/30/2009 5-713 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 5-7~5 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA t3.6 5/28/2009 5-7~7 2030120 1.5 NA 1.5 NA t5.3 5/29/2009 S-778 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-722 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 77.s 5/26/2009 S-t25 2070830 225 NA 225 NA 20.4 5/26/2009 5-726 20710970 125 NA 125 NA 15.3 6/t/2009 5-200 1972390 ~ 1.25 NA 125 NA 14.5 5/28I2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 73.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1l2009 S-218 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 0.25 NA 025 NA 1.7 6/1/2009 Sd00 2070740 2 NA 2 NA 9.4 5/28/2009 S-aoi 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 Recent MITIAs for Z-103 (PTD #~.Q42290), Y-24 (PTD #1861130), V-112 PTD #2060200), S-2... Page 1 of 1 ~ i Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, March 18, 2008 4:10 PM ~ ~ '~ f I~~~ ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: Recent MITIAs for Z-103 (PTD #2042290), Y-24 (PTD #1861130}, V-112 (PTD #2060200), S-217 (PTD #2070950), S-31A (PTD #1982200) and S-124 (PTD #2061360) Attachments: MIT PBU Z-103 03-16-08 .xls; MIT PBU Y-24 03-16-08 .xls; MIT PBU V-112 03-16-08 .xls; MIT PBU S-217 03-16-08 .xls; MIT PBU S-31A 03-06-08.x1s; MIT PBU S-124 03-06-08.x1s Hi Jim, Tom, and Bob, ~~~,~~~ ~,`a.,~ Please find the attached MIT forms Z-103 (PTD #2042290), Y-24 (PTD #1861130), V-112 (PTD #2060200), and S-217 (PTD #2070950). These tests were witnessed by the North Slope AOGCC Inspector. Z-103: 4-yr UIC Compliance MIT-IA and pre-MI injection Y-24: 4-yr UIC Compliance MIT-IA post tubing patch V-112: MITIA for Administrative Approval request for continued injection with TxIA communication S-217: New well MITIA post initial injection «MIT PBU Z-103 03-16-08 .xls» «MIT PBU Y-24 03-16-08 .xls» «MIT PBU V-112 03-16-08 .xls» «MIT PBU S- 217 03-16-08 .xls» Please find the attached MIT forms S-31A (PTD #1982200} and S-124 (PTD #2061360). These tests were to qualify the well for MI injection and were not witnessed by the North Slope AOGCC Inspector. UIC compliance testing will be conducted by the 4-year anniversary of the last witnessed test. S-31A: MITIA pre-MI injection S-124: MITIA pre-MI injection «MIT PBU S-31A 03-06-O8.xls» «MIT PBU S-124 03-06-08.x1s» Please let us know if you have any questions. Thank you, ,}~nnrx l~u6e, ~? ~E. 'U4/ell integrity Coordinator GPB 4tltetis Group Phone; (9{37) 659-51€32 Pager: {907) 659-5100 x1154 v>~! MAR ~ ~ 200 3/19/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT !PAD: Prudhoe Bay /PBU / S-Pad DATE: 03/06/08 ~~ OPERATOR REP: Andrea Hughes AOGCC REP: 3j~~~~ Packer Dep Pretest Initial 15 Min. 30 Min. Well S-31A Type Inj. W TVD ~ 6, 2' Tubing 1550 1550 1550 1500 Interval O P.T.D. 1982200 Type test P Test psi 596 Casing 0 4000 3940 3920 P/F P Notes: MIT-IA pre-MI service. OA 50 520 500 480 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~-- ~'~./ INTERVAL Codes t =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during W orkover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU S-3'IA 03-06-08.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~t(f¿;(' -zjllolo? P.I. Supervisor ( DATE: Monday, February 12, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) rNC S-31A PRUDHOE SAY UNIT 5-31A ~ ~ ct/ ';} FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Su prv .:J8¡z.--- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT S-31A API Well Number 50-029-22109-01-00 Inspector Name: Bob Noble Insp Num: mitRCN070211190515 Permit Number: 198-220-0 Inspection Date: 2/l1l2007 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ! S-3IA [Type Inj.1 w ---¡- I .._- Well TVD 6382 ...1 IA > 790 2760 2730 2715 ! , ---;---- P.T. 1982200 'TypeTest. 5PT Test psi 1595.5 OA 0 210 2]0 i 210 ...'/ , -~ --~--~~~~-'--- /' , Interval WRKOVR P/F P Tubing 2125 2125 2125 2125 Notes i~MEÐ FEB 2 7 Z007 Monday, February 12,2007 Page 1 of 1 S-31A (PTD #1982200) MITlA . . Jim and Bob, Please see the attached MIT form for a passing MITIA on S-31A (PTD #1982200). The MITIA was completed post initial injection and was witnessed by AOGCC representative Bob Noble. Thank you, Andrea Hughes &C:ANNED FEB 1 2 2007 Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 xl154 Content- Type: application/ms-tnef winmail.dat Content-Encoding: base64 1 of 1 2/12/2007 9:54 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email 10:Winlon_Aubert@admin.slale.ak.us;Bob_Fleckenslein@admin.slale.ak.us;Jim_Regg@admin.slale.ak.us;Tom_Maunder@admin.slale.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Well P.T.D. Notes: Well P.T.D. Notes: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / S pad 02/11/07 Andrea Hughes Bob Noble ~D %"'}- \0\ 30 Min. 2,125 I nlerval P/F I P I nlerval P/F Well P.T.D. Notes: I nlerval P/F TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R :;;: Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT PBU S-31 02-11-07 .xls a.t: ", 1 a. Well Status: DOH DGas D Plugged D Abandoned D Suspended 181 WAG 1 b. Well Class: 411cr' '<'ffS. Catrl0" 20AAC 25.105 20AAC25.110 D Development :~rato 11, $iùtJ DGINJ DWINJ D WDSPL No. of Completions One Other ~~_L~ J D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or A~ftJó~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1-2144t2ODß J ~ /¡ ~ 198-220 / 306-360 3. Address: 6. Date Spudded 13. API Number .¡ P.O. Box 196612, Anchorage, Alaska 99519-6612 1 0/29/1998 50-029-22109-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 11/03/1998 PBU S-31A j 1639' FNL, 3828' FEL, SEC. 35, T12N, R12E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 911' FSL, 1017' FEL, SEC. 27, T12N, R12E, UM 66.5' ./ Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool & Prudhoe BÃield / . ~I t" 'LA.O~ 4415' FSL, 1351' FEL, SEC. 27, T12N, R12E, UM 12620 + 8785 Ft \ 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: ~ 'J" Surface: x- 619612 y- 5979855 Zone- ASP4 ,f 13038 + 8813 Ft ADL 028258 ¡ ~1 ad! TPI: x- 617102 y- 5982366 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: , Total Depth: x- 616707 y- 5985864 Zone- ASP4 None MD DVes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: GR 22. CASING, LINER AND CEMENTING RECORD '.',... SETTINGDEPTHMD SËTTING DEPTH TVD ................. A< . . ..v~i.oG .., Wr. f>ËR FT. GRADE Top BOTTOM Top BOTTOM ...$IZE .;., .·.c. .. Þti~~~£J" 20" x 30" Insulated Conductor Surface 110' Surface 110' 306" 13-3/8" 72# L-80 I Surface 2707' Surface 2697' 17-1/2" 3723 cu ft Arcticset II 9-5/8" 47# L-80 Surfar.e 10783' Surface 8727' 12-1/4" 2343 cu ft Class 'G' 7" 26# L-80 10534' 10785' 8546' 8728' 8-112" 300 cu ft Class 'G' 2-7/8" 6.16# L-80 10510' 12653' 8528' 8784' 3-3/4" Uncemented Slotted Liner 7" 26# L -RO 3679' 10470' 3542' 8500' Scab _nr 1063 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ... iJå¡\GRËcd;~tr ...) i< ...... .··....·.i·...&...'... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET lMD) 4-1/2" Gun Diameter, 5 spf 2-7/8" Slotted Section 4-1/2", 12.6#x 3-1/2",9.2#, L-80 10469' , 7634' & 8543' MD TVD MD TVD 4-112",12.6#, NT13Cr80 10464' - 10571' 10486' 7950' - 8040' 6622' - 6692' 11097' - 12618' 8763' - 8785' 25. ACI£J,:-' Þ... ^ i~;rc.... 8100' - 8120' 6738' - 6753' .......> DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED SCANNED JAN 1 7 2007 Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Vet N/A Date ofT est Hours Tested PRODUCTION FOR OIL-BeL GAs-McF WATER-BeL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL-BeL GAs-McF WATER-BeL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE'" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r!Ot~ nl'-6 None RBC)MS 8Ft '4fI~h::7)b_ 1 6 200ì ¿~ YF'lì~,) r; ,/I'" ~.~,.-.,..~:."".,.,>,:"-~ ~ð . STATE OF ALASKA I /,/"f-Q? '.'Y'€C'f:'- "'C/V'- ALASKA OIL AND GAS CONSERVATION COM'SION .' 1::::['1. WELL COMPLETION OR RECOMPLETION REPORT AND LOG4/ask. ·J4!¡¡ 1 1 ,i a ail & G 7 Form 10-407 Revised 12/20030 RIG I N A tNTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly ummarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". No new markers: S-31A Kicked Off in the Sag River, (Markers from S-31) None Kuparuk 7998' 6659' Sag River 10770' 8718' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0\ lu 0 PBU S-31A Well Number 198-220 306-360 Permit NO.1 A roval No. Prepared By NameINumber: Drilling Engineer: Terrie Hubb'e, 564-4628 Ken Allen, 564-4366 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 1212003 Submit Original Only . Well Events for 5urfaceWell - 5-31 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> S -> S-31 Date Range: 12/Nov/2006 to 23/Nov/2006 Data Source(s): AWGRS Digital Wellfile Events Source Well AWGRS S-31A 8WGRS S-31A 8WGRS S-31A AWGRS S-31A AWGRS S-31A 8.WÇ,RS S-31A AWGRS S-31A 8WGRS S-31A AWJiß--5 S-31A AWGRS S-31A 8WGRS S-31A AWGB.~ S-31A AWGRS S-31A A\NJ2B.S S-31A Date 11/23/2006 11/23/2006 11/23/2006 11/22/2006 11/22/2006 11/2112006 11/21/2006 11/20/2006 11/20/2006 11/20/2006 11/19/2006 11/19/2006 11/19/2006 11/18/2006 8.\NGRS S-31A 11/17/2006 AWGRS S-31A 11/16/2006 AWGRS S-31A 11/16/2006 . Page 1 of 2 Description Pulled a 4" CIW BPV AFTER RIG MOVED OFF OF WELL. SET 4" CIW BPV PRE RIG O-PRESSURE ON WELL SET 4" CIW TWC THRU TREE TO ND TREE NU BOP. & TEST. T/I/0=VAC/0+/10. Temp=SI. NO AIL. Bleed WHP's to 0 psi (Pre-Rig). IA FL near surface. Bled lAP from 10 psi to 3 psi in 1 hr. and 30 mins. Shut-in casing valve and monitor lAP for 15 mins. After15 mins. lAP remained @ 3 psi. Continued with bleed for 45 mins. Final WHP's =VAC/O+/O. IA has integral 2" and hardline still installed from circ-out job. *** Job continued from 11/21/06 WSR *** T/I/O = 620/620/0 - Post Circ out bleed and rig down. Well still bleeding off, turned well over to DHD. Freeze protect hardline to S-07 w/2 bbls neat meth. FWP's = 0/5/0 T/I/O= 300/400/200 ***Circ-out Pe-RWO*** Pumped 5bbls Meth, 760bbls 9.8# NaCI, down tubing, up lA, to S-07's flowline (S-07 is flowing.) Bullheaded 1090 bbls 9.8# NaCI down IA. Bled TP and lAP. TP and lAP increased to 620 psi when shut in. Bled OAP to 0 psi. DID NOT freeze protect well per PE. Freeze protected hardline to S-07 w/4 bbls neat meth. *** Job continued on 11/22/06 WSR *** ****** AWGRS CONTINUED FROM 20 NOV ***** CHEMICAL CUT AT 10464 3 5/8" CHC IN 4.5" NS-80 TBG, 2 x 2" x 48" CYLINDERS WITH EXTENSION SPACER. MAX IMUM TOOLSTRING LENGTH RIH=32.8'. MAX OD=3.625". TUBING AND IA PRESSURE UNCHANGED AFTER FIRING CHC.DH ***WELL SHUT IN ON DEPARTURE. SSV CLOSED*** T/I/0=0/200/220 Assist SLB w. MIT TBG to 3500 psi (PASS) & LLR x IA to 2400 psi. (Pre RWO) Pumped 3.9 bbls to pressure up TBG to 3500 psi. On 2nd try TBG lost 10 psi in 1st 15 min and 20 psi in second 15 min for a 30 min loss of 30 psi. Bled TBG psi. *** LLR IA to 2400 psi. Pumped a total of 23 bbls neat meth to establish IA LLR of .9 BPM @ 2400 psi. *** Final WHP's=0/460/200 Assist E line, job postponed. Missed run with plug. **** AWGRS CONTINUED FROM 19-NOV STRING SHOT OVER INTERVAL 10454-10456' WEATHERFORD WPR RUN IN HOLE TO X-NIP AT 10482'. UNABLE TO PASS THROUGH NIPPLE TO SET IN 3' PUP JOINT ON FIRST DESCENT. CHANGE OUT WRP. NO VISIBLE DAMAGE OR OD SEEN ON PLUG. PASS THROUGH WRP ON SECOND ATTEMPT BY RATTLING TOOL. SET WRP IN THE 3' PUP BELOW THE SWS NIP WITH MID ELEMENT AT 10483.9' AND BOTTOM OF SLIPS AT 10485.9'. PRESSURE TEST TUBING TO 3500 PSI WITH LRS. MIT-T PASSED. LOST 30 PSI IN 30 MINUTES ON SECOND TEST. SEE LRS SUMMARY. SET 4.5 JUNK CATCHER ON TOP OF WRP. SMALL TUBING PUNCHER SHOT OVER INTERVAL 10406-10408' ***** AWGRS CONTINUED TO 21-NOV ***** **** WELL SHUT-IN ON ARRIVAL ***** AWGRS CONTINUED ON 10/20/2006 *** WELL S/I UPON ARRIVAL *** PULLED JUNK CATCHER FROM 10, 502' SLM. RDMO *** WELL LEFT SI, DSO NOTIFIED ON DEPARTURE *** ***Job continued from 11-18-06 WSR*** Set the 33/8" Baker treating packer at 10,477.6'. Pressue up below packer to 4000 psi CTP. Test failed. Lost 1450 psi in 15 minutes. No communication to backside or IA. Repeat test with same results, MIT-T to 3500 psi. Lost 95 psi in 1st 15 minutes. 60 psi in 2nd 15 minutes. IA pressure climbed form 360 psi to 404 psi and stabilized quickly. The liner top packer or 2 7/8" plug is leaking. Release Baker treating packer. POOH. Tubing freeze protected w/ 38 bbls 60/40 meth. Prep wellhead for S/L work on well. ***Job Complete*** ***Job continued from 11-17-06 WSR*** Drift CT w/ 1.25" ball. Perform BOP tests. RIH w/ 3 3/8" Baker treating packer. Tag junk basket @ 10,500' CTM. Correct depth to center of element 10,493.6'. PU to set depth of 10,477' CTM. Packer appeared to soft set. Attempted to get to work, no luck, equalized & POOH. Break down tool. & send to shop, packer appeared to have soft set. MU new Baker 3 3/8" treating packer. RIH. ***Job in progress*** MIRU CTU #5. ***Job Scope: Set Treating Packer, Test XX Plug & Liner Top Packer, MIT- T***. T/I/O= 550/420/300. Temp.=SI. WHP's, TBG (pre-RWO). TP decreased 190 psi overnight. lAP increased 80 psi overnight. OAP decreased 20 psi overnight. T/I/0=650/320/300 CMIT Tx IA to 3500 not done due to LLR in IA and TBG not tracking. MIT- T TO 3500 FAILED (pre-rwo) Pumped 25 bbls crude to reach test pressure tbg failed test on 3 attempts (see mit data sheet) rig up to OA pumped 40 bbls crude down OA established LLR of 3 bpm at 1300 psi. Rigged up on IA and established a LLR of 1.8 BPM @ 3500 psi. Rigged http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 1/9/2007 Digital Wellfile AWGRS S-31A 11/15/2006 AWGRS S-31A 11/14/2006 A WGRS S-31A 11/13/2006 AWGRS S-31A 11/12/2006 . Page 2of2 back up on tubing to MIT- T to 3500 psi. FAILED on 2 . attempts. Bled pressures down Final WHP=700/780/280. T/I/O=740/340/320 Temp=SI WHPs TGB, IA & OA FLs (Pre-RWO). TBG FL @ 1200' (18 bbls). IA FL @ surface and OA FL near surface. ***CONTINUED FROM 11-13-06***(pre rwo) BRUSH X NIPPLE @ 10527' SLM SET 27/8" XX PLUG (OAL 32" CLOSED 6 X 1/8" EQU PORT HOLES) SET 3.70" JUNK CATCHER @ 10512' SLM ( OAL 116" ) ***WELL LEFT S/I ON DEPARTURE*** ***WELL 5/1 ON ARRIVAL**** BEGIN RU ***CONTINUED ON 11-14-06*** *** JOB CaNT FROM 11/11/06 *** UNABLE TO DO WORK DUE TO PIN HOLE LEAK ON SSV WHEN PRESSURED UP. *** WELL LEFT S/I ON DEPARTURE, NOTIFIED PAD OPERATOR.*** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 1/912007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 11/19/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. ( Slip on 1320' of new 1 1/4" drilling line. Replace proximiity switch for top drive link tilt function. Service top drive. Blow down water to pit modual. Disconnect water lines at interconnect. General house keeping and miscellaneous paniting projects while waiting on completion of pre rig work.) Rig ready to move and accepted at 00:00 but waiting on BP for preparation of S-31. 06:00 - 00:00 18.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. ( Build and fit and weld brackets for 3" vacuum system on sub base roof. Seal drip pan/riser under rotary table. General house keeping and miscellaneous paniting projects while waiting on completion of pre rig work.) 11/20/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. Continue miscellaneous painting and projects. Weld brackets on sub base roof for OBM vacuum system. Plumbing and fitting PVC pipe for the same. 06:00 - 00:00 18.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. Plumbing and fitting PVC pipe for OBM vacuum system. Continue miscellaneous painting and projects. 11/21/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. Continue clean, paint, maintenance. Work on vac system. Have Peak tire man check all tires before move. 06:00 - 00:00 18.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. Continue work on vac system and maintain, clean, paint. Wells Group cut 41/2" tubing at 10,464' with chemical cutter. Rig down E-line unit. Hot oil pumpers circulate 760 bbl 9.8 ppg brine down tubing through cut and up IA at 550 psi taking returns to S-07. Rig up lines on IA and bull head 330 bbl 9.8 ppg brine down IA at 2800 psi. 11/22/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Waiting on Completion of Pre Rig Work on S-31. Continue general rig maintenance. Bleed tubing and IA to neighboring well 8-07 to 250 psi. Close in and see pressure build back. Repeat bleed and build up pressure four times until pressure drop to 250 psi. Continue bleeding tubing and IA to slop tank until psi = O. 06:00 - 00:00 18.00 MOB N PRE Wait on Pre Rig Work on S-31. Clean, paint, and maint. Move 3 well houses away f/S-31. Break out flow lines. Hold S-31 pre-spud meetings w/day and night crews. Discuss slip, trip, fall hazards and non-skid boot traction device requirement. 11/23/2006 00:00 - 01 :30 1.50 MOB N WAIT PRE Wait on Pre Rig Work on S-31. Clean, paint, and maint. Break out flowlines. 01 :30 - 06:00 4.50 MOB N WAIT PRE Roads and pads equipment spreading gravel and levelling pad. 06:00 - 10:00 4.00 RIGD P PRE Hold PJSM w/Peak truck pusher, drivers, all hands. Move pits, pull mats f/S25. Hang new tree f/S-31 in rig cellar. Spread herculite on S-31. Jack up and move rig over S-31A at 11 :00. Spot mats. Move in pits. RU steam lines, RU lines at interconnect. Take on 102 deg. 9.8 ppg brine at 14:00 and accept rig. (For billing purposes, rig ready to move and Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 11/23/2006 06:00 - 10:00 4.00 RIGD P PRE accepted at 00:00 11-19-2006 but waiting for BP pre rig well work on S-31 until 06:00 11-23-2006.) RU lines to circulate and find IA on vacuum, OA = 17 psi. Bleed down to bleed tank. 10:00 - 14:00 4.00 RIGD P PRE RD f/S-25. Move rig. RU over S-31. 14:00 - 17:00 3.00 WHSUR P WHDTRE Test lines to IAlOA to 3500 psi. Pressure up on OA to 1025 psi. and chart. Bled to 880 psi in 30 min. Bleed off OA to 0 psi. Pressure up on IA to 1250 psi. and chart. Bled to 350 psi in 30 mins. Bleed off IA to 0 psi. 17:00 - 18:30 1.50 WHSUR P WHDTRE Pull BPV wllubricator. RU lines to circulate. Test lines to 2000 psi. 18:30 - 20:00 1.50 WHSUR P WHDTRE Circulate safe surf pill and 120 deg. 9.8 ppg brine. 6 bpm, 760 psi. Soap back at surface after 427 bbls on calculated total of 720 bbls. 20:00 - 20:30 0.50 WHSUR P WHDTRE Monitor well. OK. Fluid levels at surface. 20:30 - 22:00 1.50 WHSUR P WHDTRE Install TWC w/lubricator. Test above and below to 1000 psi. OK. RD lubricator. BD test lines. LD lubricator. 22:00 - 00:00 2.00 WHSUR P WHDTRE Hold PJSM in cellar w/FMC and all hands. ND tree. FMC hand bled down control lines. Hang tree in cellar. MU 4.5" TDS XO. 8.25 turns by hand. 11/24/2006 00:00 - 02:30 2.50 BOPSU P DECOMP PJSM in cellar and NU BOP stack. 02:30 - 08:00 5.50 BOPSU P DECOMP BOP test. 250 psi low pressure and 4000 psi high pressure. Test w/4" and 4.5" test jt. Contacted AOGCC representative Lew Grimaldi who waived AOGCC attendance at test. Test witnessed by Lowell Anderson, BP WSL and Biff Perry, Nabors tourpusher to 06:00 and Duncan Ferguson WSL and Chris Weaver toolpusher f/06:00 until conclusion of test. 08:00 - 10:00 2.00 BOPSU P DECOMP Replace choke HCR valve. 10:00 - 11 :00 1.00 BOPSU P DECOMP Cont. w/BOP test. 250 low pressure and 4000 high pressure. 11 :00 - 12:00 1.00 BOPSU P DECOMP RD test jt. and BD choke and all lines. 12:00 - 12:30 0.50 CLEAN P DECOMP RU tubing handling equipment and prepare to LD 4.5" TDS tubing. 12:30 - 13:30 1.00 CLEAN P DECOMP Pull TWC w/DSM lubricator. 13:30 - 14:00 0.50 CLEAN P DECOMP MU landing jt. PU wt. to pull 4.5" tubing hanger free = 140K. PU wt. to continue pulling to rig floor = 130K. 14:00 - 16:00 2.00 CLEAN P DECOMP CBU w/9.8 ppg brine. 6 bpm, 228 psi. 5 bbls brine lost while CBU. Hold PJSM & RU power tongs to LD tubing while circulating. 16:00 - 17:00 1.00 CLEAN P DECOMP LD landing jt. and hanger. BD topdrive. MW = 9.8 ppg. 17:00 - 21 :00 4.00 CLEAN P DECOMP POH laying down 4.5" 12.60# TDS tubing. Spool control line. Recover 27 of 27 clamps and 4 of 4 SS bands. LD SSSV. 21 :00 - 21 :30 0.50 CLEAN P DECOMP RD spooling unit and clear floor. 21 :30 - 22:45 1.25 CLEAN P DECOMP Cont. POH w/4.5" tubing. 22:45 - 23:15 0.50 CLEAN P DECOMP Safety stand down for 30 mins. at request of Nabors Dan Hebert to discuss N33 foot injury incident w/all hands. Refocus on PJSM requirement before all tasks no matter how routine. Discuss importance of body placement and hazard recognition to avoid personal injury. 23:15 - 00:00 0.75 CLEAN P DECOMP Cont. to POH and LD 4.5" tubing. 82 jts. out at 00:00. 11/25/2006 00:00 - 00:30 0.50 CLEAN N RREP DECOMP Replace sensor on skate. 00:30 - 05:00 4.50 CLEAN P DECOMP Continue to POH w/4.5" 12.6# TDS tubing. Laid down total of 1 SSSV, 5 GLM's w/pups, 266 jts tbg + a clean cut on 2.21' of stub f/top of 9.62' pup under GLM # 1 leaving 7.41' of stub Printed: 12/18/2006 11:27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: looking up in hole to stab over w/Unique overshot. LD tbg. handling equipment and RU and TEST lower rams w/4" and 4.5" test jt. 250 psi low pressure, 4000 psi high pressure. 07:00 - 07:30 0.50 CLEAN P DECOMP RD test equipment and install wear bushing. 07:30 - 10:00 2.50 CLEAN P DECOMP PU cleanout BHA #1w/8.5" USED BIT, BIT SUB, UPPER STRING MILL, XO 4.5 IF PIN X 4.5 R PIN, 7" BOOT BASKET, 6-7/8" BOOT BASKET, 9-5/8' CASING SCRAPER, BIT SUB 4.5 R BOX X 4.5 H90 BOX, XO 4.5 H90 PIN X 4.5" IF BOX, 6.25" LUB. BMPR SUB, 6.25" OIL JARS, XO 4.5" PIN X 4.5" XH BOX, NINE 6.25" DRILL COLLARS, XO 4.5 IF X 4.5" XH, XO 4" HT40 X 4.5" IF. 10:00 - 20:00 10.00 CLEAN P DECOMP PU 4" HT40 drill pipe f/pipe shed and RIH to 10424'. No tight spots while RIH. 180K PU, 145K SO. 20:00 - 21 :30 1 .50 CLEAN P DECOMP Circulate a 40 bbl. 80 Vis Sweep, 500 gpm, 2897 psi. Full returns, no fluid loss. 21 :30 - 00:00 2.50 CLEAN P DECOMP PJSM. Monitor well. OK. BD top drive. POH to 5964'. 11/26/2006 00:00 - 02:00 2.00 CLEAN P DECOMP POH w/cleanout BHA f/5694'. MW = 9.8 ppg brine. 02:00 - 03:00 1.00 CLEAN P DECOMP Rack back drill collars and lay down BHA. 03:00 - 03:30 0.50 CLEAN C DECOMP PU RTTS packer. 03:30 - 05:00 1 .50 CLEAN C DECOMP RIH to 2882'. 05:00 - 05:30 0.50 CLEAN C DECOMP Test 9-5/8" x 4" DP annulus to 3500 psi for 5 mins. OK. Test below RTTS at 2882'. Test failed. 05:30 - 07:00 1.50 CLEAN C DECOMP RIH to 6039'. 07:00 - 08:00 1.00 CLEAN C DECOMP Test at 6039' above and below RTTS. Both tests failed. 08:00 - 09:00 1.00 CLEAN C DECOMP Well out of ballance. CBU. 7 bpm, 530 psi. Well stabilized. 09:00 - 11 :00 2.00 CLEAN C DECOMP RIH to f/6039' t/6141 , and test down drill pipe below RTTS. Test failed. Monitor well. DP psi built to 200 psi. Bleed pressure to O. Unset RTTS. Monitor well. Pressure stabilized at 0 psi. 11 :00 - 11 :30 0.50 CLEAN C DECOMP POH to 4698'. 11 :30 - 12:00 0.50 CLEAN C DECOMP Test annulus to 3500 psi at 4698' above RTTS. OK. Test down drill pipe below RTTS and test failed. Monitor well. 12:00 - 14:00 2.00 CLEAN C DECOMP RIH f/4698' to 5838'. No test above or below RTTS. 14:00 - 16:00 2.00 CLEAN C DECOMP POH. Testing annulus and Isolate top of leak between 5647' and 5674'. No test pumping down drill pipe w/RTTS set at 5674'. Test above RTTS to 3500 psi and held for 5 minutes. 16:00 - 17:30 1.50 CLEAN C DECOMP PJSM. Monitor well. OK. RIH f/5674' to 10424'. RTTS would not set at 10424'. 17:30 - 00:00 6.50 CLEAN C DECOMP Monitor well and POH testing below RTTS at 10404', 9369', 8318',7362' down to 9-5/8" packer at 10486' and plug in cut off tubing stub at 10483'. Test again below RTTS at 6311 '. No test. Summary of testing: Holes isolated between 5647' and 7362'. 9-518" casing tested OK to 3500 psi f/5 minutes w/chart above 5647' and below 7362'. 9-5/8" packer at 10486' X 4-1/2" plugged tubing at 10483' tested to 3500 psi f/5 mins. w/chart. 11/27/2006 00:00 - 03:00 3.00 CLEAN C DECOMP BD topdrive. Monitor well. MW = 9.8 ppg brine. POH and LD 9-5/8" RTTS. Function test BOPs. 03:00 - 04:00 1.00 CLEAN P DECOMP RU Schlumberger wireline f/USIT. 04:00 - 10:00 6.00 CLEAN P DECOMP Log w/Schlumberger e-line. Acquire CBL f/10410' to surface. 10:00 - 11 :30 1.50 CLEAN C DECOMP RIH to 7500'. Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 11/27/2006 11 :30 - 14:30 3.00 CLEAN C DECOMP Acquire USIT f/7470' to 5560'. 14:30 - 15:30 1.00 CLEAN P DECOMP PJSM on W/L rig-down safety. RD wireline unit. 15:30 - 17:30 2.00 CLEAN P DECOMP PJSM. PU 4.5" stub dress mill BHA #2 w/8-1/8"OD x 4-1/2" 10 dress mill shoe, 8-1/8" wash pipe extension, 6-1/4" x 3-7/8" tubing dress mill (internal at top of washpipe), xo sub, 7" boot basket, 6-7/8" boot basket, bit sub, 6-1/4" lubricated bumper sub, 6-1/4" oil jars, xo sub, 96-1/4" drill collars, xo sub, xo sub to HT-40 drill pipe. BHA OAL = 325.09', Max 00 = 8.125", Min ID =1.50". 17:30 - 21:30 4.00 CLEAN P DECOMP RIH w/drill pipe to 10455'. 21 :30 - 22:30 1.00 CLEAN P DECOMP Work dress mill over 00 and inside 10 of 4.5" tubing stub at 10465'. Mill top of tubing w/6K SO for 5 minutes. 420 gpm, 1859 psi, 80 rpm, 7K tq, 180K PU wt., 145K SO wt., 165K ROT. wt. 22:30 - 00:00 1.50 CLEAN P DECOMP PU to 10460'. Circulate 40 bbls. 100 vis brine sweep. 500 gpm, 2490 psi. Small amount of metal shavings across shakers. 11/28/2006 00:00 - 03:30 3.50 CLEAN P DECOMP POH w/4.5" tubing stub dress mill BHA#2. MW = 9.7 ppg brine. 03:30 - 05:00 1.50 CLEAN P DECOMP LD BHA#2. 05:00 - 05:30 0.50 CLEAN P DECOMP Clean rig floor 05:30 - 07:30 2.00 CLEAN P DECOMP PU 4" GS spear junk catcher retrieving tool BHA#3 w/8-1/8" cutlip shoe, washpipe extension, xo, internal GS spear to catch 4" GS profile of junk catcher, xo, 5-3/4" spear guide assy., 2 jts 2-7/8" PAC pipe, 2-7/8" PAC pump out sub, xo, xo, 6-1/4" lubricated bumper sub, 6-1/4" oil jars, xo to HT-40 drill pipe. BHA = 99.99' OAL. Min ID = 1.50". Max 00 = 8-1/8". 07:30 - 11 :00 3.50 CLEAN P DECOMP RIH w/ BHA #3 to 10410'. 11 :00 - 11 :30 0.50 CLEAN P DECOMP Wash down f/10410' to top of tubing stub at 10464'. See guide shear w/8K SO. Continue to wash down to top of junk catcher at 10474' and engage junk catcher w/4" GS retrieving tool. 175 gpm, 2020 psi. 11 :30 - 13:00 1.50 CLEAN P DECOMP Drop ball and wait 15 mins for ball to seat onCirc sub. Pump until shub shears at 2800 psi. CBU at 10474', 502 gpm, 2493 psi. 13:00 - 18:00 5.00 CLEAN P DECOMP Monitor well. BD topdrive. POH to BHA. 18:00 - 20:00 2.00 CLEAN P DECOMP PJSM. LD BHA #3. Small amount of scale in junk catcher. 20:00 - 21 :00 1.00 CASE C TIEB1 PJSM. PU tubing stub washover and sand spotting BHA #4 w/8-1/8" x 4-1/2" dress shoe, 8-1/8" wash pipe extension, 8-1/8" wash pipe drive sub, xo sub to HT40 drill pipe. 21 :00 - 00:00 3.00 CASE C TIEB1 RIH to 7656'. 11/29/2006 00:00 - 01 :00 1.00 CASE C TIEB1 RIH w/ drill pipe to 10454'. 01 :00 - 04:00 3.00 CASE C TIEB1 RU and dump 20 sacks (10 cu. ft.) sand down drill pipe and displace to 4 bbl short of bottom of drill pipe. PU and see pipe overpull. Start pumps and see packoff occur. Pipe torqued up. Work pipe free. Re-establish circulation. BD top drive. POH to 9986' and wait one hour for sand to fall out. 04:00 - 05:00 1.00 CASE C TIEB1 RIH and tag sand at 10450'. Wash over tubing stub cleaning out sand around tubing stub f/10464' to 10474'Ieaving sand inside tubing stub in place. 05:00 - 06:00 1.00 CASE C TIEB1 Pump 45 bbls 115 vis sweep around. 515 gpm, 2231 psi. 06:00 - 06:30 0.50 CASE C TIEB1 POH to 10434'. Wait 30 min. to let any sand settle. RIH over stub and tag up to confirm no sand behind tubing stub. Printed: 12/1812006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: POH. MW = 9.8 ppg brine. LD sand spotting BHA # 4. Function test BOPs. C/O top pipe rams to 7" to run liner and test to 250 psi low presssure and 4000 psi high pressure w/chart. 12:00 - 13:30 1.50 TIEB1 Test annular wIT' test jt, 250 psi low pressure and 3500 psi high pressure w/chart. Pull test plug and install wear bushing. 13:30 - 15:30 2.00 CASE C TIEB1 PJSM w/casing hand, WSL, toolpusher, and all hands on casing running procedures. RU to run 7" 26# TCllliner wfTorqueTum and compensator. 15:30 - 00:00 8.50 CASE C TIEB1 Check floats. OK. RIH w/111 jts. 7" liner to 4621' filling w/brine f/hose. Change out YC to sidedoor elevators. 11/30/2006 00:00 - 03:00 3.00 CASE C TIEB1 RIH f/ 4621' to 6760' w/ 7" 26# TCllliner, 164 joints. 03:00 - 04:00 1.00 CASE C TIEB1 PU Flex-Lock liner hanger/ZXPpacker/run tool assembly and MU to 7" liner. RIH w/one stand of drill pipe. Circulate 196 bbls. 5 bpm, 250 psi, 170K PU wt., 143K SO wt. RD casing equipment while circulating. 04:00 - 06:30 2.50 CASE C TIEB1 RIH w/liner on 4" drillpipe f/derrick to 10442'. Fill liner using topdrive every ten stands. 06:30 - 07:00 0.50 CASE C TIEB1 MU top drive cement head and circulating lines. 07:00 - 09:00 2.00 CASE C TIEB1 RIH and tag up early at 10458'. Set down 30K. Rotate string to left 1 1/2 tums in 1/4 turn increments and attempt to work torque down. Circulate at 5 bpm, 600 psi. wIno change. 220K PU wt., 160K SO wt. Review all tallies and depths. OK. Consult w/town team. 09:00 - 09:30 0.50 CASE X DPRB TIEB1 BD lines. LD cement head. 09:30 - 11 :00 1.50 CASE X DPRB TIEB1 POH to 6760'. 11 :00 - 12:00 1.00 CASE X DPRB TIEB1 RU casing equipment and prepare to LD 7" liner. 12:00 - 13:30 1.50 CASE X DPRB TIEB1 PJSM. LD liner hanger/packer/running tools. 13:30 - 00:00 10.50 CASE X DPRB TIEB1 PJSM. LD 7" 26# TCllliner f/6760' to 353'. 12/1/2006 00:00 - 01 :30 1.50 CASE X DPRB TIEB1 LD 7" 26# liner f/353' to surface. PJSM w/welder and set fire watch. Heat Baker Locked shoe track jts. and LD. Pins in overshot were not sheared. No marks on shoe to indicate contact w/tubing stub. 01 :30 - 02:00 0.50 CASE X DPRB TIEB1 Clear rig floor. RD casing running equipment. 02:00 - 04:00 2.00 BOPSU X DPRB TIEB1 CO 7" Rams to 3-1/2" x 6" variables and test ram doors 250 psi low pressure and 3500 psi high pressure. 04:00 - 05:00 1.00 CASE X DPRB TIEB1 PJSM. PU cleanout BHA #5. PU tubing stub washover BHA #5 w/8-1/8" wash shoe, 12' of 8-1/8" wash pipe extension, 8-1/8" boot basket drive sub w/internaI4-13/16" x 3-7/8" dress off mill f/top of tubing stub, 6-1/4" lubricated bumper sub, 6-1/4" oil jar, xo sub to HT40 drill pipe. OAL = 43.08'. 05:00 - 08:30 3.50 CASE X DPRB TIEB1 RIH w/cleanout BHA # 5 to 10455'. 08:30 - 11 :00 2.50 CASE X DPRB TIEB1 RU to reverse circulate. Tag up at 10456'. Wash down to 10477'. 3 bpm, 615 psi. PU wt 170K, SO wt. 140K. 11 :00 - 13:30 2.50 CASE X DPRB TIEB1 Reverse circulate a 25 bbl. 125 Vis sweep around. 5 bpm, 995 psi. Pump total of 760 bbls around. See good returns of 20/40 frac sand, carbolite, scale, and well debris. 13:30 - 14:30 1.00 CASE N DPRB TIEB1 Monitor well. OK. OA pressure = 280 psi. RD. BD all lines. 14:30 - 15:00 0.50 CASE X DPRB TIEB1 RIH and tag up on stump at 10467'. Wash down over stump. 3 bpm, 200 psi. Dress stump, 80 rpm, ROT wt. 147K, 5K tq. 15:00 - 16:00 1.00 CASE X DPRB TIEB1 RU and reverse circulate. 3 bpm, 395 psi. Pump 135 bbls. 16:00 - 16:30 0.50 CASE X DPRB TIEB1 Monitor well. RD. BD all lines. Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: Spud Date: 11/27/1990 End: 11/17/2006 12/14/2006 1211/2006 16:30 - 17:00 17:00 - 17:30 17:30 - 18:00 18:00 - 22:00 22:00 - 23:00 23:00 - 00:00 121212006 00:00 - 03:00 03:00 - 04:00 04:00 . 05:30 05:30 - 06:00 06:00 . 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 - 17:00 17:00 - 18:30 18:30 - 19:00 19:00 - 21 :00 21 :00 - 23:00 23:00 - 00:00 1213/2006 00:00 - 08:30 08:30 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 15:30 0.50 CASE X 0.50 CASE X 0.50 CASE X 4.00 CASE C DPRB TIEB1 DPRB TIEB1 DPRB TIEB1 TIEB1 1.00 BOPSU TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 1.00 BOPSU TIEB1 3.00 BOPSU TIEB1 1.00 BOPSU 1.50 CASE 0.50 CASE 4.50 CASE 0.50 CASE X DPRB TIEB1 0.50 CASE X 0.50 CASE X 5.00 CASE X DPRB TIEB1 DPRB TIEB1 DPRB TIEB1 1.50 CASE X 0.50 BOPSU X 2.00 BOPSU X DPRB TIEB1 DPRB TIEB1 DPRB TIEB1 2.00 CASE X DPRB TIEB1 1.00 CASE X DPRB TIEB1 8.50 CASE X DPRB TIEB1 2.00 CASE X DPRB TIEB1 2.50 CASE X 0.50 CASE C 2.00 CASE C DPRB TIEB1 TIEB1 TIEB1 POH f/10695' to 10395'. PJSM. Run RTTS Stormpacker and set at 67' RKB. Test RTTS t/1000 psi f/above. Test good. Secure well. Night tour safety stand down w/BP town mgmt, BP WSL, RLG reps, Nabors town mgmt, all Nabors hands, and service hands to plan 7ES HSE strategy improvement; and to record individual commitments to the HSE plan forward. PJSM w/all hands, WSL, tourpusher. Pull wear ring. RU for BOP test. BOP test. 250 psi low pressure, 4000 psi high pressure. Test witnessed by Lowell Anderson, BP WSL and Biff Perry, Nabors tourpusher. AOGCC representative Jeff Jones waived AOGCC representation of BOP test. Continue BOP test 250 psi low pressure, 4000 psi high pressure. RD BOP test equipment and clear floor. PJSM. Cut and slip 163' of drilling line. Rig maintenance. Service topdrive. Day tour safety stand down w/BP town mgmt, BP WSL, RLG reps, Nabors town mgmt, all Nabors hands, and service hands to plan 7ES HSE strategy improvement; and to record individual commitments to the HSE plan forward. RU running/retrieving tool for RTTS storm packer. RIH to 67' and engage storm packer. Pull to floor and LD. RIH and tag up on top of stub at 10467'. No fill. Monitor well. Remove blower hose. Pump dry job. Monitor well. POH f/ 10467' to BHA #5. Drop 2-3/16" rabbit from stand 99 at 9599'. PJSM w/Baker, all hands. LD BHA #5. Clear floor. Pull wear ring and set test plug. PJSM w/all hands. CO rams f/3-1/2" x 6" variable to 7" and body test 250 psi low and 3500 psi high. RD BD test equipment. Set wear ring. PJSM w/ Nabors csg. crew and RU torque turn running equipment. PJSM w/WSL, Baker, all hands, tourpusher, casing crew on RIH w/casing. MU Baker overshot, and tieback sleeve/tieback stem assy. 15K tq. on bowl, 4k tq. on guide, 4K tq. on 5-1/2" EU, 3.2K on 4-1/2" IBT. Use torque turn for all TCII. RIH w/7" 26# TCII scab liner using compensator and torque turn for all connections. Optimum torque 10100 ft.llbs. MU liner hanger and circulate 1-1/2 liner volume. 6 bpm, 210 psi. RD casing running equipment. Monitor well. OK. RIH filling every 10 stands to 10441'. RU liner cementing head, lines and manifold. Circulate 167 gpm, 250 psi and see 200 psi pressure increase to 450 psi washing down over stub. Shut down and engage stub to 10470'. PU and see 10K overpull to 230K. Grapple engaged. Pressure up to 500 psi to check seals. OK. PU and see tieback stem shear free of tieback extension sleeve w/20K overpull at 240K. PU slowly until pressure bled to O. Circulation holes in place above tieback stem. CBU staging pumps up 85 gpm = 95 psi, 126 gpm = 126 psi, 167 gpm = 250 Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 12/3/2006 13:30 - 15:30 2.00 CASE C TIEB1 psi, 211 gpm = 400 psi, 252 gpm = 580 psi. 15:30 - 18:30 3.00 CEMT C TIEB1 PJSM wlSchlumberger, all hands, WSL, toolpusher. Test lines to 4500 psi. Schlumberger pump 10 bbls fresh water ahead. Mix and pump 189 bbls of 15.8 ppg cement at 5 bbls/min. Drop drill pipe wiper plug and see indicator trip. Schlumberger pump 1st 10 bbls of displacement wlfresh water. Switch to rig pumps and pump 283 bbls. 9.8 ppg brine 150 gpm. Catch cement at 2550 stks. Did not see drill pipe wiper plug engage liner wiper plug. Build pressure to 2050 psi at 135 gpm. Slow to 80 gpm at 4720 stks/272 bbls. See pressure spike early to 2300 psi at 4759 stks/274 bbls of 4904 stks/283 bbls. expected. Shut down at 2350 psi to avoid 20 % +- range of liner hanger set pins at 2976 psi. SO until seals engaged PBR barrel. CIP @ 17:48. Bleed off and shut in 3 times and see pressure build slowly to 1500 psi each time. Increase pressure from 1500 psi to 4000 psi to set liner hanger and activate ZXP liner top packer setting tool. See positive set of ZXP packer at floor. PUlSO to check set of hanger and packer. OK. Immediately bleed pressure to zero. Check floats/seals and get slow build up to 850 psi. 18:30 - 19:00 0.50 CASE C TIEB1 Rotate 20 turns to right at the liner top and PU free of liner wt. 30' above liner top. CBU at 550 gpm, 1600 psi attempting to hold some backpressure on liner and floats. See green water turn to 5 bbls. contaminated cement w/fluid wt. of 12.2 ppg. back to green water. SD and check floats/seals. No flow back. Close hydril and pressure to 95 psi and hold to see if pressure builds. OK. Seals holding. 19:00 - 20:00 1.00 CASE C TIEB1 CBU 380 gpm, 900 psi. 20:00 - 20:30 0.50 CASE C TIEB1 RD cement head. BD lines. 20:30 - 22:30 2.00 CASE C TIEB1 POH f/3671'. Make surface breaks and LD liner running tools. Note: Out of critical path pump 243 bbls. 9.8 ppg brine down OA. Break down at 1200 psi., 3 bpm. Pump away at 3 bpm 970 psi. SD. ISIP = 650 psi. 22:30 - 00:00 1.50 BOPSU C CLEAN Pull wear ring. Install test plug. CO top pipe rams f/7" to 3.5" x 6" variables. 12/4/2006 00:00 - 03:00 3.00 BOPSU P CLEAN Cont. wlchangeout of top rams and test door seals to 250 psi low pressure and 4000 psi high pressure. Test upper and lower rams to 250 psi low pressure and 4000 high pressure w/both 3.5" and 4.5" test jts. Note: OA pressure had bled to 0 on gage at 01 :00. Open valve and rig to pits and continue to monitor in preparation of 9-5/8" packoff replacement. 03:00 - 04:00 1.00 CLEAN C CLEAN PU Cleanout BHA #6 wI 6-1/8" bit, three 4-3/4" boot baskets, bit sub w/float, 4-3/4" lubricated bumper sub, 4-3/4" oil jars, six 4-3/4" drill collars, XO sub to Ht-40 drill pipe. 04:00 - 08:30 4.50 CLEAN C CLEAN RIH wI cleanout BHA#6 to 10157'. 08:30 - 10:00 1.50 CLEAN C CLEAN CBU 430 gpm, 2380 psi. 10:00 - 11 :00 1.00 CLEAN P CLEAN MU RTTS. Set 67' below 7ES KB. Test flbelow to 1000 psi fl5 mins. OK.. 11 :00 - 12:00 1.00 BOPSU P CLEAN Pull wear bushing. MU packoff running tool. "J" in and back Printed: 12/1812006 11:27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 12:00 - 14:30 CLEAN 14:30 - 15:30 1.00 CLEAN N CLEAN 15:30 - 16:30 1.00 CLEAN P CLEAN 16:30 - 18:30 2.00 CLEAN C CLEAN 18:30 - 19:30 1.00 CLEAN C CLEAN 19:30 - 21:30 2.00 CLEAN N SFAL CLEAN 21 :30 - 23:30 2.00 CLEAN C CLEAN 23:30 - 00:00 0.50 CLEAN C CLEAN 12/5/2006 00:00 - 01 :00 1.00 BOPSU SFAL CLEAN 01 :00 - 01 :30 0.50 BOPSU SFAL CLEAN 01 :30 - 03:00 1.50 BOPSU SFAL CLEAN 03:00 - 03:30 0.50 BOPSU SFAL CLEAN 03:30 - 04:30 1.00 CLEAN CLEAN 04:30 - 06:00 1.50 CLEAN C CLEAN 06:00 - 10:00 4.00 CLEAN C CLEAN 10:00 - 14:30 4.50 CLEAN C CLEAN 14:30 - 16:00 1.50 CLEAN C CLEAN 16:00 - 16:30 0.50 CLEAN P CLEAN 16:30 - 19:00 2.50 PERFUB P OTHCMP 19:00 - 00:00 5.00 PERFUB P OTHCMP 12/6/2006 00:00 - 02:30 2.50 PERFUB P OTHCMP 02:30 - 04:00 1.50 PERFUB P OTHCMP 04:00 - 06:00 2.00 PERFUB P OTHCMP 06:00 - 07:00 1.00 PERFUB P OTHCMP off lock down screws. Pull packoff w/20K overpull. Pressure wash packoff area clean. MU new 9-5/8 pack off and set. Run in lock down screws. Test packoff to 5K psi f/30 mins. OK. RD packoff running tool. Set wear bushing. Repair hydraulic hose on pipe skate. PU RTTS storm packer retrieving tool. RIH to 67' and retrieve storm packer. POH and LD. RIH to 10157' and tag cement. PU wt. 170K, SO wt. 135K, ROT wt. 147K. Circulate at 278 gpm, 60 rpm, 1910 psi off, 1960 psi on, Tq. off 6K, Tq. on 8K. Drill wiper plug at 10196', drill to 10207'. CBU. 360 bbls, 418 gpm, 2350 psi, rotate and reciprocate. 50 rpm, 7.5K tq. RU test equipment and lines f/casing test. Test casing to 4K psi f/30 mins. No test, due to gland nut packing leaking on tubing spool. Mobillize FMC f/wellhead and Halliburton f/RTTS storm packer. RD and BD test equipment. POOH f/10207' to 10061'. Mobilizing Halliburton and FMC. Clean rig and work on housekeeping. PU RTTS storm packer and MU in drill pipe string and RIH to 67' and set. RU and test RTTS storm packer to 1000 psi f/below f/5 mins. Replace gland nut packing in tubing spool upper flange. Test gland nut packing over RTTS storm packer to 4000 psi f/5 min. POH and LD RTTS storm packer. RU test equipment and test casing f/10207' to surface 4000 psi f/30 mins. and chart. Cleanout cement f/shoetrack at 10456'. Up wt. 188k, S/O wt. 120k, Rot wt. 145k, 370 gpm 2080 psi, 70 rpm, 9k tq. Pump 60 bbl HI-Vis sweep around and displace wellbore with new 8.5 ppg sea water at 465 gpm, 2710 psi, 60 rpm, 9k tq. Sea water wt. In 8.5 ppg. Out 8.5 ppg. Monitor well bore. Remove blower hose. Pull out of the hole from 10456' to 292'. Lay down BHA #6. Empty boot baskets. Clean and clear rig floor. Service Top drive. PJSM with Schlumberger.' Rig up handling equipment. Pick up 41/2" 5 shots per/ft perf guns. 189.08'.Totalloaded 110'. Blanks 79.08'. Run in the hole with DPC guns at 90 secs a stand to 5239'. Filling every stand and topping off every 10 stands run. Run in the hole with DPC guns at 90 secs a stand from 5239' to 8134'. Filling every stand and topping off every 10 stands run to 6000' to obtain 500 psi underbalance. PJSM with Schlumberger wire line. Rig up wire line. Run in the hole with wire line to correlate perforating depth. Unable to correlate perforating depth. Pull out of the hole to 4000' and correlate depth at 4000'. Pull out of the hole with wire line. Too much interference from drill pipe tool joints, while looking for clear gamma ray signature. Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: Rig down wire line equipment. Hang wire line sheave in derrick on drill collar finger. Run in the hole with 4" HT-40 drill pipe to 8169' DPM. Run in the hole with wire line to correlate perforating depth. Rig down wire line equipment. Space out 4 1/2" perforating guns to firing depth of 7950' - 8040'. 150k up wt. Top shot at 8100. Bottom shot at 8120'. Set packer, verify set with 15k down wt. Test packer to 750 psi. for 5 minutes. Bleed pressure to 500 psi and hold pressure. Rig up Schlumberger firing manifold. . OTHCMP PJSM. Pressure annulus to 1200 psi to open PTV. Bleed pressure off to 500 psi and hold pressure. Pressure test lines to firing manifold to 1000 psi. Purge lines with nitrogen and test to 1000 psi for 30 minutes. Start pressure sequence to fire guns. Guns did not fire. Second sequence to fire guns also failed. 19. Drop 1.75" bar to fire guns. Confrim guns fired. No intial fliud f/:¡Y losses or flow after firing of guns. Unseat packer. Encountered 40k overpull. Reverse circulate 110 bbls, 168 gpm, 680 psi. 12 bbl/hr fluid loss while reverse circulating. Dumped 15 bbls of contaminated seawater/oil at bottoms up. OTHCMP Rig down firing manifold and pull out of the hole above top set of perfs at 8100'. OTHCMP Monitor well bore for 10 minutes. Static loss rate 5 bbl/hr. Circulate bottoms up 1.5 times. 168 gpm, 245 psi. Sea water discolored at bottoms up. Monitor well bore for 10 minutes. Static loss rate 5 bbl/hr. Blow down top drive, remove blower hose. Sea water wt. In 8.5 ppg. Out 8.5 ppg. Pull out of the hole slowly from 8009' to 2276'. Lost a total of 20 bbls sea water. Pull out of the hole slowly from 2276' to 285'. Lay down Schlumberger packer assy. Recover 1.75" firing bar. Change handling equipment. Pull out of the hole from 285' to 189'. Rig up power tongs. Lay down 4.5" perforating guns. All guns fired. j' Clean and clear rig floor. Pick up BHA #7 consiting of a 3 7/8" bladed mill, bit sub, (2) joints of 2 7/8" pac dp, X-O, (3) 4 3/4" boot baskets, 7" casing scraper, bit sub wI float, bumper sub, oil jar, pump out sub, (6) 4 3/4" drill collars, X-O = 292.54' CLEAN Run in the hole from 292' to 10421'. Install blower hose for top drive. No fluid losses while tripping in the hole. CLEAN Tag cement at 4.5" x 7" cross over at 10458'. Drill cement from 10458' to 10470'. 210 gpm, 875 psi. Wash sand from 10482' to 10470'. Up wt. 185k, S/O wt. 135k, Rot wt. 158k,285 gpm, 1500 psi, 30 rpm, 7k tq. Some gas and oil to surface pior to bottoms up. Monitor well bore. No flow, Well static. Pull out of the hole to above the 4.5" x 7" cross over. CLEAN Circulate bottoms up at 335 gpm, 2225 psi. Monitor well bore. Static. CLEAN Wash sand from top of WRP at 10482'. Pumping 45 bbls 12/6/2006 07:00 - 08:00 1.00 PERFUB P OTHCMP 08:00 - 10:30 2.50 PERFUB P OTHCMP 10:30 - 11 :00 0.50 PERFUB P OTHCMP 11 :00 - 13:30 2.50 PERFUB P OTHCMP 13:30 - 15:00 1.50 PERFUB P 15:00 - 15:30 0.50 PERFUB N DFAL OTHCMP 15:30 - 16:00 0.50 PERFUB N DFAL OTHCMP 16:00 - 16:30 0.50 PERFUB P OTHCMP 16:30 - 17:00 0.50 PERFUB P OTHCMP 17:00 - 18:00 1.00 PERFUB P 18:00 - 20:00 2.00 PERFUB P 20:00 - 00:00 4.00 PERFUB P OTHCMP 12/7/2006 00:00 - 01 :00 1.00 PERFUB P OTHCMP 01 :00 - 02:00 1.00 PERFUB P OTHCMP 02:00 - 02:30 0.50 PERFUB P OTHCMP 02:30 - 03:00 0.50 PERFUB P OTHCMP 03:00 - 04:00 1.00 PERFUB P OTHCMP 04:00 - 04:30 0.50 PERFUB P OTHCMP 04:30 - 06:00 1.50 CLEAN C CLEAN 06:00 - 10:00 4.00 CLEAN C 10:00 - 11 :00 1.00 CLEAN C 11 :00 - 11 :30 0.50 CLEAN C 11 :30 - 13:00 1.50 CLEAN C Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 12/7/2006 11 :30 - 13:00 1 .50 CLEAN C CLEAN Hi-Vis (100) sweep. Position mill 2' above WRP. Drop dart and poen circ sub with 2200 psi. Circulate sweep out of the hole at 503 gpm 2615 psi. No increase in folw or returns at bottoms up. Monitor well bore. Static. No losses while circulating. Remove blower hose. Blow down top drive. 13:00 - 18:00 5.00 CLEAN C CLEAN Pull out of the hole from 10480' to 292'. 18:00 - 20:00 2.00 CLEAN C CLEAN Lay down BHA #7. Recovered 1 cup of small aluminum pieces and sand from center boot basket. Remaning 2 boot baskets empty. 20:00 - 20:30 0.50 CLEAN C CLEAN Pick up BHA #8 consiting of 3.75" OD WRP retrieving tool, X-O, (2) joints 2 7/8" pac drill pipe, X-O, bumper sub, oil jar, pump out sub, X-O = 89.81' 20:30 - 00:00 3.50 CLEAN C CLEAN Run in the hole from 89' to 10334'. No fluid loss for the last 24 hrs. 12/8/2006 00:00 - 01 :30 1.50 CLEAN C CLEAN Slip and cut drilling line. Service top drive. 01 :30 - 02:00 0.50 CLEAN C CLEAN Run in the hole from 10334' to 10470'. Up wt.190k. S/O wt. 130k. 02:00 - 03:00 1.00 CLEAN C CLEAN Rig up to reverse circulate. Attempt to reverse circulate at 126 gpm. Reversed circulated 45 bbls when pressure increased from 710 psi to 1150 psi. Pulled out of the hole to above 4.5" x 7" cross over at 10456'. Reverse circulate at 126 gpm 450 psi. Run in the hole to 10470' and attempt to reverse circulate with the same results as first attempt. Pull up to 10457' 03:00 - 08:00 5.00 CLEAN X DPRB CLEAN Circulate down the drill pipe at 10457' at 126 gpm 525 psi. Washing down slowly. Pressure increase varing from 1200 psi to 910 psi. every couple of feet. Pick up 3' and pressure returns to 525 psi. Increase rate to 226 gpm at 604 psi and continue to wash down very slowly 10483', Set down 20k on WRP, Failed to latch, did not see any overpull. Drop dart and pump down at 126 gpm, 235 psi. Circ sub opened at 1900 psi. Pump Hi-Vis sweep around at 503 gpm, 2255 psi. No increase in cuttings or flow while sweep returned to surface. Attempt to latch on to WRP with no success. Monitor well bore Static. Blow down top drive. Sea water wt. In 8.5 ppg. Out 8.5 ppg. 08:00 - 13:30 5.50 CLEAN DPRB CLEAN Pull out of the hole from 10483' to 89'. 13:30 - 16:30 3.00 CLEAN DPRB CLEAN Rig up handling equipment. Lay down BHA #8. 16:30 - 17:30 1.00 BOPSU DPRB CLEAN Pull wear bushing. Install test plug. Rig up test equipment. 17:30 - 21 :30 4.00 BOPSU CLEAN Test BOPs and all associated valves to 250 psi low 4000 psi high. Utilizing 41/2" and 3 1/2" test joints. Wittness of BOP test waived by AOGCC rep Chuck Sheive. Test Wittnessed by BP WSL Wade Frame, Nabors Toolpusher Bift Perry. 21 :30 - 22:30 1.00 BOPSU CLEAN Rig down test equipment. Pull test plug. Install wear bushing. 22:30 - 00:00 1 .50 CLEAN DPRB CLEAN Pick up BHA #9 consiting of (1) 27/8" pac drill pipe mule shoe jt. (1) 2 7/8" pac drill pipe, (2) cross overs, (3) 43/4" boot baskets, bit sub, bumper sub, oil jar, circ sub, cross over = 100.01' 12/9/2006 00:00 - 05:00 5.00 CLEAN X DPRB CLEAN Run in the hole with 2 7/8" mule shoe from 100' to 10455'. Top of 4.5 x 7" cross over at 10456'. Up wt. 190K. S/O wt. 125K 05:00 - 05:30 0.50 CLEAN X DPRB CLEAN Rig up lines to reverse circulate. 05:30 - 11 :30 6.00 CLEAN X DPRB CLEAN Reverse circulate down to WRP plug from 10455' to 10482' at 204 gpm 1010 psi. Setting 5k down at 10482'. A pressure increase was observed, pick up to 10481' and circulate down the drill pipe at 204 gpm, 950 psi. Circulate 2 bottoms up with Printed: 12/18/2006 11:27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: DPRB CLEAN no increase in cuttings. Reverse circulate 3 bottoms up at 158 gpm 790 psi, with no increase in cuttings. Shut down and pump 35 bbl Hi-Vis sweep down the drill pipe and circulate sweep around. No increase in cuttings. Sea water wt. In 8.5 ppg. Out 8.5 ppg. No fluid lost while circulating. Monitor well bore. Static. Remove blower hose. Blow down top drive and lines from reverse circulating. Pull out of the hole from 10481' to 100'. Lay down BHA #9. Recovered half a cup of sand from boot baskets. Pick up BHA #10 consiting of 3.75" OD WRP retrieving tool, X-O, (2) joints 2 7/8" pac drill pipe, X-O, bumper sub, oil jar, pump out sub, X-O = 89.81' Run in the hole from 100' to 10456'. Up wt. 180k. S/O wt. 135k. Wash from 10456' to 10482' at 116 gpm 180 psi. Pressure increased to 405 psi at 10482'. Setting 10k down. Pick up with no overpull. Pressure returned to 180 psi. Set back down at 10482' without pumps, pick up with no over pull. Circulate at 10481' at 216 gpm 520 psi for 10 minutes, shut down pumping and set 15k down at 10482', pick up with no over pull. Rotate from 10479' to 10481.5' at 5 rpm and 3k tq. Set 15k down at 10482'. Pull out of the hole to 10387' with no over pull. DPRB CLEAN Circulate 2 bottoms up at 262 gpm 610 psi. Sea water wt. In 8.5 ppg. Out 8.5 ppg. Monitor well bore, well flowing slightly. Continue circulating 2 bottoms up increasing sea water wt. from 8.5 ppg to 8.7 ppg. Monitor well bore for 10 minutes. Static. Sea waterwt. In 8.7 ppg. Out 8.7 ppg. Service top drive. Pull out of the hole from 10387' to 89'. Monitor well bore. Static. Lay down BHA #10. Found WRP retrieving tool slighly concave at the bottom. PJSM with Schlumberger slick line personal. Rig up lubricator and SLB BOP. Run in the hole with 3.5" impression block to 10510' Slick line measurment. Impression block showed a 1/2" diameter mark in center of impression block. 12/9/2006 6.00 CLEAN X 05:30 - 11 :30 11 :30 - 18:00 6.50 CLEAN X DPRB CLEAN 18:00 - 18:30 0.50 CLEAN X DPRB CLEAN 18:30 - 19:00 0.50 CLEAN X DPRB CLEAN 19:00 - 00:00 5.00 CLEAN X DPRB CLEAN 12/10/2006 00:00 - 01 :30 1.50 CLEAN X DPRB CLEAN 01 :30 - 08:00 6.50 CLEAN X 08:00 - 13:00 5.00 CLEAN X DPRB CLEAN 13:00 - 14:30 1.50 CLEAN X DPRB CLEAN 14:30 - 18:00 3.50 CLEAN X DPRB CLEAN 18:00 - 20:30 2.50 CLEAN X DPRB CLEAN 20:30 - 22:00 1.50 CLEAN X DPRB CLEAN 22:00 - 00:00 2.00 CLEAN X DPRB CLEAN 12/11/2006 00:00 - 02:30 2.50 CLEAN X DPRB CLEAN 02:30 - 03:30 1.00 CLEAN X DPRB CLEAN 03:30 - 06:00 2.50 CLEAN X DPRB CLEAN 06:00 - 10:00 4.00 CLEAN X DPRB CLEAN Run in the hole with 3.70" WRP retrieving tool with SLB slick line to 10510'. Pull out of the hole with WRP retieving tool, no over pull. Inspect retrieving tool, Ok. Run in the hole with 3.70" WRP retrieving tool with SLB slick line to 10510'. Pull out of the hole with WRP retrieving tool. Inspection of retrieving tool showed no signs of going over WRP. Remove 4" from bottom of WRP retrieving tool. Run in the hole with 3.70" WRP retrieving tool with SLB slick line to 10510'. Unable to retrieve WRP. Pull out of the hole with WRP retrieving tool. Run in the hole with 3.625" OD over shot dressed with a 2.25" grapple to 10510' slick line measurement. Numerous attempts were made to work over shot over WRP with only one over pull, believed to be just a friction over pull. Pull out of the hole with over shot. Inspection of over shot indicate the possiblity of trash/junk around WRP. Printed: 12/18/2006 11 :27:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/17/2006 12/14/2006 Spud Date: 11/27/1990 End: 12/11/2006 10:00 - 12:30 2.50 CLEAN X DPRB CLEAN Consult with town about options while waiting on 3-11/16" bailer. Perform miscellaneous maintenance while waiting on Schlumberger slick line bailer. 12:30 - 15:00 2.50 CLEAN X DPRB CLEAN Run in the hole with 3-11/16" bailer to 10510' slick line measurement. Pull out of the hole recovering 1/4 cup of very small metal filings. 15:00 - 17:30 2.50 CLEAN X DPRB CLEAN Run in the hole with 3-11/16" bailer to 10510' slick line measurement. Pull out of the hole with bailer. Recovered a trace amount of small metal filings. 17:30 - 19:00 1.50 CLEAN C CLEAN Run in the hole with WRP retrieving tool dressed with a slick line GR spear (shear up). Latch onto WRP and jar down to shift collate and open by pass. Pull 1200 Ibs to shear off WRP retrieving tool. Pull out of the hole. 19:00 - 19:30 0.50 CLEAN C CLEAN Strip 50' of slick line from unit. Redress GR spear to GS spear (shear down). 19:30 - 21 :30 2.00 CLEAN C CLEAN Run in the hole with GS and latch onto WRP retrieving tool at 10510' slick line measurement and begin jarring up. Requiring 30 mins of jarring up with 1350 Ibs to work WRP thru SWS nipple at 10482'. 21 :30 - 22:30 1.00 CLEAN C CLEAN Pull out of the hole. Recovering WRP and WRP retrieving tool. 22:30 - 00:00 1.50 CLEAN C CLEAN Rig down Schlumberger slick line BOP and lubricator. 12/12/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN Service top drive, changing out broken dies in pipe gripper on top drive. 01 :30 - 05:30 4.00 CLEAN P CLEAN Run in the hole with mule shoe and 4" HT-40 drill pipe to 10328'. 05:30 - 08:30 3.00 CLEAN P CLEAN Circulate bottoms up at 263 gpm 602 psi. Some gas at bottoms up. Continue to circulate another 365 bbls at 167 gpm 272 psi. Monitor well bore for 10 minutes. Static. Brine wt. In 8.7 ppg. Out 8.7 ppg. 08:30 - 20:00 11.50 CLEAN P CLEAN Pull out of the hole from 10328' to surface laying down 4" HT-40 drill pipe. 20:00 - 21 :00 1.00 BOPSU CLEAN Pull wear bushing. Make dummy run with hanger. 21 :00 - 23:30 2.50 RUNCO RUNCMP Change bails out on top drive. Rig up Nabors torque tum equipment. PJSM with Baker personnel. 23:30 - 00:00 0.50 RUNCMP Run 3.5" mule shoe, Blank pup and perorated pup with 2 each 6" centralizers. Lost 26 bbls 8.7 ppg brine water. 12/13/2006 00:00 - 05:00 RUNCMP Run 3 .5" 9.2# L-80 TC-II tubing to 2709'. Running a total of 80 joints of 3.5" 9.2# 1-80 TC-II. Average make up torque 2900 ftllbs. 05:00 - 06:30 1.50 RUNCMP Rig down 3.5" torque turn equipment and rig up 4.5" torque turn equipment. Make up 3.5" x 4.5" cross over. 06:30 - 17:30 11.00 RUNCMP Run 4.5" 12.6# L-80 TC-II tubing to 10462'. Running a total of 183 joints of 3.5" 9.2# 1-80 TC-II. Average make up torque 3850 ftllbs. 17:30 - 18:30 RUNCMP Confrim tag up at 10462' with 5k down wt. Space out. lay down joint #264 and 263. Pick up 1 space out pup 5.75"', and joint #263.3.5" mule inserted 5' into 4.5" at 10468.5' Ran a total of 80 joints of 3.5" + 183 joints of 4.5" and (1) 5.75' space out pup. Up wt.121 k. S/O wt. 105k. 18:30 - 19:30 RUNCMP Make up landing joint and hanger. Land hanger. Run in lock down screws. Printed: 12/1812006 11:27:37 AM , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-31 S-31 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: Spud Date: 11/27/1990 End: 11/17/2006 12/14/2006 Rig up circulating lines. Reverse circulate 251 bbls of 8.7 ppg brine water followed by 101 bbls of inhibited brine water. Spot inhibited brine water with 193 bbls of 8.7 ppg brine water at 3 bbllmin 126 gpm 176 psi. RUNCMP Drop 1 7/8" ball and rod, allow to fall. Pressure up on tubing to 2800 psi to set Bakers 3.5" and 4.5" premier packers. Continue pressuring up to 4000 psi and test packer for 30 minutes. Bleed pressure down to 1900 psi. Note: Lost 52 bbls of 8.7 ppg brine in 24 hours. RUNCMP Pressure annulus to 4000 psi. Chart and hold for 30 minutes. Bleed annulus pressure then tubing pressure to zero. Shear DCK valve with 2450 psi by pumping down the annulus. Pump 5 bbls each way to confirm DCK valve sheared. Wittness of MIT wavied by AOGCC rep. Lou Grimaldi. Blow down and rig down lines. Install TWC and test from below to 1000 psi. Nipple down BOP. Nipple up adapter flange and 4-1/8 x 5m tree. Test adapter flange to 5000 psi. Good test. Test tree to 5000 psi. Good test. Wait on DSM to pull TWC. Prepare rig floor for move while waiting on DSM. Rig up DSM lubricator and pull TWC. PJSM. Rig up Hot Oil and pressure test lines to 3000 psi. Good test. Reverse circulate 150 bbls of diesel at 70 dgrees 2 bbllmin 700 psi. Allow freeze protect to U-tube. Rig up DSM lubricator. Install BPV. Lay down DSM lubricator. Test BPV from below to 1000 psi. Good test. Rig down and blow down lines. Remove residual fluid from mud pits. Remove secondary annulus valve. Secure tree, 23:00 - 00:00 12/14/2006 00:00-01:30 01 :30 - 02:00 0.50 RUNCO RUNCMP 02:00 - 02:30 0.50 RUNCO RUNCMP 02:30 - 06:30 4.00 BOPSU P RUNCMP 06:30 - 07:30 1.00 WHSUR P RUNCMP 07:30 - 08:00 0.50 WHSUR P RUNCMP 08:00 - 10:00 2.00 WHSUR N WAIT RUNCMP 10:00 - 11 :00 1.00 WHSUR P RUNCMP 11 :00 - 12:00 1.00 WHSUR P RUNCMP 12:00 - 13:30 1.50 WHSUR P RUNCMP 13:30 - 14:30 1.00 WHSUR P RUNCMP 14:30 - 15:00 0.50 WHSUR P RUNCMP Rig Released from S-31a at 15:00 hrs. 12-14-2006. Printed: 12/18/2006 11:27:37 AM ES: C'fD HORlZ SIDETRACK IN SAG RIVER FORMA 110P\!· 70" @ 108&9' AND 90" @ 10928' CHROME TBG AND lNR 2203' 113-3/8" CSG, 68#, NT-80, 10= 12.415" H 10539' 10551' 10559' 10571 ' MILLOUT WINDOW' 10785' - 10792' Minimum 10 = 2.313" @ 10551 2-7/8" OTIS X NIPPLE 11338' PRUDHOE SAY UNIT WELL: S-31A PERMIT No: 198-2200 API No: 50-029-22109-01 BP 01/05/2007 Schlumberger NO. 4101 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ttCANNED JAN 1 () 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 u:r~ 1415-é)f)Ò Field: Prudhoe Bay C Well Job# Lon Description Date BL Color D 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROFILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P·25L 1 11513656 LDL 12/05/06 1 W-29 11549353 US IT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 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 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 20m Date Delivered: Received by: . . . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ro bert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-66112 Re: Prudhoe Bay Field, Aurora Oil Pool Well name S-31A Sundry Number: 306-360 ,- Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Chair DATED this1!/day of November, 2006 Encl. I ~ "if ,c9dô Ù ( I / . ·R>· ~lï¡' L. " IW~II \ t'JO~ S I 13/.. h¿ ;!/l'Y . rJ!"Y,~~ v- . /( /"1'1 (A7 - oþ STATE OF ALASKA U;{"~ \1 g 'r r . ALASKA OIL AND GAS CONSERVATION COMM SION .. 2006 APPLICATION FOR SUNDRY APPROVAL . 20 AAC 25.280 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown -e-PËÎrforate o Time Extension o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program g Pull Tubing Ø"Perforàte New Pool o Waiver o Other µ6A- 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 198-220 3. Address: o Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22109-01-00 7. If peñorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU S-31A ,/ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field 1 Pool(s): .....- ADL 028258 66.5' Prudhoe Bay Field 1 Prudhoe Bay Pool 12.. ..... ...... . v'¡.ELL .. ... +« .... <eC....CCš;Ce.. . .... .' .... Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13038 8813 12620 8785 None None Casino Lenoth Size MD / TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Suñace 2707' 13-3/8" 2707' 2697' 4930 2670 Intermediate 10783' 9-5/8" 10783' 8727' 6870 4760 Production Liner 251' 7" 10534' - 10785' 8546' - 8728' 7240 5410 Liner 2143' 2-7/8" 10510' - 12653' 8528' - 8784' 13450 13890 Peñoration Depth MD? I Peñoration Depth TVD (ft): Tubing Size: / Tubing Grade: Tubing MD (ft): 11097' - 12618' 8763' - 8785' 4-112", 12.6# NT13Cr80 10571' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW packer I Packers and SSSV MD (ft): 10486' /' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program ~. 15. Estimated Date for Novemir 15,)006 16. Well Status after proposed work: Commencinç¡ Operations: OOil o Gas o Plugged o Abandoned 17. Verbal Approval: DaV ~~ ~WAG OGINJ ~INJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Signature E1ít :rAO f. 1Jf'(lAd. Phone 564-4166 Date II/rid? Terrie Hubble, 564-4628 'l Commission Use Onlv I Sundry Number: ~-.3(PO Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~BOP Test o Mechanical Integrity Test o Location Clearance Other: T -e $. t ]SOVE to 4-00c!J .p (,{ . ¡ltïT1 ~t ÔLUt t~~ to l ftðuÂ~d. ~ / I evp pJ'Ol/wl V'~ ~ to to W\~Vt1 ) e.- f'~\i ~tJtrr- . Ilf~Þ ~ "'^-..1iI.Ivt ~ u Þv'- .-./. R80MS BFI. S 7006 gpD Subsequent Form Required: 10 rl' JI-IL/-1Jb -/ -J 'Á/ APPROVED BY ,.~ ~~/ -L ApDroved Bv: COMMISSIONER THE COMMISSION Date '....'7 -V- Form 10-403 Revised 06/2006 \.,../ - ~ --..... Submit In Duplicate ORIGINAL . . Obp G16JJ..8M6rA'y To: Winton Aubert - AOGCC Date: November 3, 2006 From: Ken Allen - BPXA GPB Rotary Drilling Subject: S-31A Application for Sundry Approval- RWO The S-31 A RWO is currently scheduled for Nabors 7ES beginning around November 15, 2006. The pre- rig work for this sidetrack will be priority scheduled after the Application for Sundry is approved. Well Status: Shut-in Sag injector. This well was has remained shut-in due to insufficient available well head injection pressure. Proposed work: Retrieve the existing tubing above the current production packer. The cement behind the ^_ 9-5/8" casing will be evaluated and perforations will be added in the Kuparuk formation. Ti,e ..;ell will be rc ¡,J6/<r ....a!3 a dual injector (I<tll'ðluk and Cag niver) eSR'lJ3IGted vvill, 4-112",12.0#, L-BO TCII tl:JBing. Provide AOGCC field inspectors 24 hour notices, as required, to witness BOP and post packer setting pressure tests. Scope Pre-Ri!:! Work: 1. Rig up slickline, drift 4-1/2" tubing and 2-7/8" liner through 2-7/8" X nipple. Set PXX-plug in 2-7/8" X nipple at 10,551'. 2. Pressure test T X IA to 4,000 psi for 30 minutes. Pressure test the OA to 2,000 psi for 30 minutes. Note: If CMIT test fails contact Anchorage ODE. A WRP will probably be set above 2-7/8" liner top for isolation. 3. Set 4-1/2" junk catcher on top of 2-7/8" liner top. Note: Ensure OD smaller than 3.725" XN nipple restriction in planned completion. 4. Fluid pack the tubing and inner annulus. 5. Chemical cut the 4-1/2" tubing at - 1 0,464' MD (top of 2nd pUp above packer). 6. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to -2,200'. 7. Bleed OA, IA & TBG to zero. ~est the 9-5/8" pack-off to 4,000 psi. Test tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 8. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 9. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Ri!:! Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Test all down hole barriers: a. CMIT T x IA: 2000 psi for 30 minutes. b. MIT OA: 2000 psi for 30 minutes. / 4. Nipple down tree. Nipple up and test BOPE. Pull TWC. " 5. Pull 4-1/2" tubing w/GLM's from above pre-rig cut at -10,464' md. S-31 A Application for Sundry . . 6. Test casing to 4000 psi. / 7. RU e-line. Run oriented USIT/CBL log from just above the tubing stub to surface. a. CMT evaluation must be performed to decide the plan forward. The evaluation can be performed while running the dressing assembly. If 50' cumulative of cement is not found between the Top Kuparuk and base Schrader a cement squeeze will be required. Plan to be distributed if required. 8. PU Overshot dressing mill and scraper on DP. RIH, wash over to clean possible fill behind tubing stub and dress tubing cut at the same time. Pump viscous sweeps and CBU at least 2 times to ensure well bore is clean. POOH -30 stands. PU Storm Packer (RTTS) and hang off string. Test RTTS. /' 9. Change out 9-5/8" PO. Lay down RTTS and continue to POOH with Overshot assembly. Note: The 9- ,/ 5/8" PO was plastic packed and will require a nipple down to clean out the bowl area. Ensure new barrier policy is reviewed before this step to ensure compliance. 10. RU and RIH with DPC perf guns. Planned guns are 4.5" "Big Hole" at 12 spf. Note: Ensure rig team is prepared for possible gas and or for the well to start loosing fluid. 11. PU 9-5/8" x 4-1/2" L-80 Unique Machine custom overshot, 4-1/2" assembly with 2 premier production packers, nipples and gauge w/cable on 4-1/2" 12.6# L-80 TCII tubing. 12. Swallow 4-1/2", 12.6#, L-80 tubing stub. Space out overshot - 2' above no-go point. RILDS. Circulate ,/ inhibited sea water. ' 13. Drop ball and rod, set both packers and individually test the tubing and annulus to 4,000 psi for 30 minutes each. Record each test. Note: Well will require 1 GLM. 14. Set and test TWC to 1000 psi. 15. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. Pull TWC. 16. Freeze protect the well to -2,000' TVD. 17. Set BPV. 18. Secure the well. 19. Rig down and move off. Post-Riq Work: 1. Install well house and flowlines. 2. MIRU slickline. a. Pull the ball and rod / RHC plug from 'XN' nipple below the new bottom production packer. b. Pull junk catcher from top of 2-7/8" liner. o. PI:III 2 7/8' rxx plug fml'1'1--X RiJ3J3lc at 10,551' 1'1'1e1. W ~ Estimated Pre-rig Start Date: 11/10/06 Estimated RWO Date: 11/15/06 Ken Allen Operations Drilling Engineer 907-564-4366 S-31A Application for Sundry TREE = 4"CrN . Yl/ELLHEAP = FMC S-31A ~ NOTES: CTD HORlZ SIDETRACK IN SAG ACTUA TOR = OTIS RlV FORMATION· 70° @ 10869' AND 90° @ 10928' KB. ELEV = 66.50' CHROM E TBG AND LNR BF. ELEV = . 38.30' KOP= 2449' . I 2144' H4-1/2" OTIS SSSV NIP, ID = 3.813" I Max Angle = 98 @ 11000' Datum MD = 13119' Datum TVD = 8800'SS .~ . ~---i 2707' HFOCI 113-3/8" CSG, 68#, NT-80, ID = 12.415" I 2708' ~ ~ GAS LIFT MANDRELS ~ ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 3156 3038 28 9CR-1 MO DV RK 11/98 4 5987 5119 45 9CR-1 MO DV RK 11/98 Minimum 10 = 2.313" @ 10551 3 8330 6835 40 9CR-1 MO DV RK 12/92 2-7/8" OTIS X NIPPLE 2 10190 8227 46 9CR-1 MO DV RK 12/90 1 10454 8405 45 9CR-1 MO DV RK 12/92 I · 10482' -14-1/2" PARKER SWS NIP, ID = 3.813" I I ~ ~ 10485' HTrNTBGANCHOR I :8: ¡.::..::o I 10486' - 9-5/8" X 4-112" TrN A<R, ID = 4.00" I TOPOF 2-7/8" LNR I 10510' I ...., - BAKER KB A<R I I2S I 10510' '-' ITOPOF7" LNR I 10534' I II!I III I · I 10539' -14-1/2" PARKERSWS NIP, ID = 3.813" I I . I 10551' -2-7/8" OTIS X NIP, ID = 2.313" I I · I 10559' -4-1/2" PARKER SWN NIP,ID = 3.725" I 14-1/2" TBG, 12.6#, NT-13-CR-80, 10571' I I 10571' -4-1/2" TBG TAIL W/LEG I I 0.0152 bpf, ID = 3.958" 1 10562' H ELMD 1T LOGGED 01/06/91 I 19-518" CSG, 47#, NT-80-S, ID = 8.681" I 10783' 1---4 III.. I WHIPSTOCK I 10782' I ~~l=WI~ IRA TAG 10791' I 10785' - 10792' ~ ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... , 11097' I' '~ -1 12620' I I~OPOF2-7/8" SL TO LNR 2-7/8" SL TD LNR, 12618' 1~~ I PBTO I 11338' 6.16#, L-80 12-7/8" LNR, 6.16#, L-80 17" LNR, 26#, NT-13-CR, 0.0383 bpf, ID = 6.276" I 0.0058 bpf, ID = 2.441" 11428' I 13038' I OÆN HOLE TD DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 12/20/90 DFF ORIGINAL COMPLETION 03/01/02 RNlTP CORRECTIONS WELL: S-31A 11/05/98 WHITLOVl SIDETRACK COMPLETION PERMIT No: 198-2200 01/21/99 GLM LASTWORKOVER API No: 50-029-22109-01 03/15/01 SIS-MH CONVERTED TO CANVAS SEC 35, T12N, T12E 03/16/01 SIS-CS FINAL BP Exploration (Alaska) TREE = 4" CrN . 5-31 A ~OTES: CTD HORlZ SIDETRACK IN SAG WELLHEAD = FMC ACTUA TOR = OTIS Pre-Rig RIVER FORMATION· 70° @ 10869' AND 90° @ 10928' KB. ELEV = 66.50' CHROM E TBG AND LNR BF. ELEV = " 38.30' KOP= 2449' . I 2144' 1-14-1/2" OTIS SSSV NIP, 10 = 3.813" I Max Angle = 98 @ 11000' Datum MD = 13119' Datum NO = 8800'SS . ~---1 2707' I~ 113-3/8" CSG, 68#, NT-80, 10 = 12.415" I 2708' µ ~ GAS LIFT MANDRELS !·31 ST MD NO DEV TYÆ VLV LATCH PORT DATE L ~~ 5 3156 3038 28 9CR-1 MO DV RK 11/98 Minimum ID = 2.313" @ 10551 ~ 4 5987 5119 45 9CR-1 MO DV RK 11/98 2-7/8" OTIS X NIPPLE 3 8330 6835 40 9CR-1 MO DV RK 12/92 y;; 2 10190 8227 46 9CR-1MO DV RK 12/90 Chemical Cut - 10464' P" 1 10454 8405 45 9CR-1MO DV RK 12/92 Unknown CMT height. ¡ I · 10482' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" I '; Plan to squeeze CMT to ..... I isolate KUP if needed ... ...-1_ 10485' HTrNTBGANCHOR I during RWO operations .'~ þ8: ~ -19-5/8" X 4-112" TrN A<R, 10 = 4.00" I after running US IT. £It F I 10486' TOPOF 2-7/8" LNR I Junk Catcher - OD must be smaller than 3.725" 10510' ~ f-' I 10510' -1 BAKER KB A<R I I TOP OF 7" LNR I 10534' ~~ ..; .1. I · jt I 10539' -14-1/2" PARKER SWS NIP, 10 = 3.813" I 2-7/8" PXX plug - 10551' '0 ..... I 10551' -12-7/8" OTIS X NIP, 10 = 2.313" I /. ~i~ ~ I · I 10559' -14-1/2" PARKER SWN NIP, 10 = 3.725" I .'~ 14-112" TBG, 12.6#, NT-13-CR-80, 10571' I' I 10571' -14-112" TBG TAIL W/LEG , 0.0152 bpf, 10 = 3.958" -µ I 10562' H ELMO TT LOGGED 01/06/91 I I 9-5/8" CSG, 47#, NT-80-S, 10 = 8.681" , 10783' 1 WHIPSTOCK , 10782' ~LL=W~~ IRA TAG' 10791' I 10785' - 10792' , , , , , , , , , , , , , , , , . , , I PBTO -1 12620' I TOP OF 2-7/8" 11097' I ~ SL TO LNR 2-7/8" SL TO LNR, 12618' 12Ji\ I PBTO I 11338' I 6.16#, L-80 I 2-7/8" LNR, 6.16#, L-80 17" LNR, 26#, NT-13-CR, 0.0383 bpf, 10 = 6.276" I 0.0058 bpf, 10 = 2.441" 11428' I I 13038' I OÆN HOLE TO I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 12/20/90 OFF ORIGINAL COMPLETION 03/01/02 RN/TP CORRECTIONS WELL: S-31A 11/05/98 WHITLO'" SIDETRACK COMA-ETION 11/01/06 KWA Pre-Rig RNO PERMIT No: 198-2200 01/21/99 GLM LAST WORKOVER API No: 50-029-22109-01 03115/01 SIS-MH CONVERTBJ TO CANVAS SEC35, T12N, T12E 03/16/01 SIS-CS FINAL BP Exploration (Alaska) TREE = W8.LHEAÐ = ACTUATOR = KB. 8.8/ = BF. 8.8/ = KOP= Max Angle = Datum MO = Datum lVO = 4"CrN FMC OTIS 66.50' ~ 38.30' 2449' 98 @ 11000' 13119' 8800'SS . S-31A Proposed RWO Completion SA NOTES: CTD HORlZ SIDETRACK IN SAG RIVER FORMATION - 70° @ 10869' AND 90° @ 10928' CHROM E TBG AND LNR 4-1/2" 12.6# TBG, L-80, TCII 113-3/8" CSG, 68#, NT-80, 10 = 12.415" I 2708' 3.813" HES X - Nipple - 7980' BKR Premiere PKR with 1/4" port for PT line- 8000' BKR sliding sleave 3.813" ID - 8010' Phoenix dual-press 1 temp gauge - 8024' 3.813" HES X - Nipple wlretrievable venturi - 8028' Phoenix gauge #2 below venturi - 8030' BKR Premiere PKR base KUP - 8230' 3.725" HES XN - Nipple - 8250' 9-5/8" x 4-1/2" Unique Overshot - 10464' 4-1/2" Tubing Stub - 10464' TOP OF 2-7/8" LNR I 10510' ITOPOF7" LNR I 10534' Unknown CMT height. Plan to squeeze CMT to isolate KUP if needed during RWO operations after running USIT. 2-7/8" PXX plug - 10551' 4-1/2" TBG, 12.6#, NT-13-CR-80, 0.0152 bpf, 10 = 3.958" 19-5/8" CSG, 47#, NT-80-S, 10 = 8.681" I 10571' I WHIPSTOCK I IRA TAG I 10782' 10791' Minimum 10 = 2.313" @ 10551 2-7/8" OTIS X NIPPLE I PBID I 11338' 17" LNR, 26#, NT-13-CR, 0.0383 bpf, ID = 6.276" I 11428' OA TE REV BY 12/20190 OFF 11/05198 WHfTLO 01/21/99 GLM 03/15/01 SIS-MH 03/16/01 SIS-CS COMMENTS ORIGINAL COMPLETION SIDETRACK COMPLETION LAST WORKOVER CONVERTBJ TO CANVAS FINAL OATE 03/01102 11/01/06 2200' "4-1/2" HES X-NIP, 10 - 3.813" 2707' H FOC I -14-1/2" PARKER SWS NIP, 10 = 3.813" 10551' -12-7/8" OTIS X NIP, 10=2.313" I 10559' -14-1/2" PARKER SWN NIP, 10 = 3.725" 10571' -14-1/2" TBG TAIL W/LEG I 10562' H 8.MD TT LOGGED 01/06/91 MILLOUT WINDOW: 10785' - 10792' I 13038' REV BY COMMENTS RN/TP CORRECTIONS KWA A"e-Rig ~O PRUDHOE BA Y UNrr W8.L: S-31A PERMrr No: 198-2200 API No: 50-029-22109-01 SEC 35, T12N, T12E BP Exploration (Alaska) RE: S-31A injector recompletion . . Subject: RE: S-31A injector recompletion From: "Young, Jim" <JimYoung@bp.com> Date: Mon, 13 Nov 200610:17:44 -0900 To: "AHen, Kenneth W"<Kénneth.Allen@bþ.carn>, <winton_aubert@adrnin.state.ak.us> Winton, I just talked with Jane, Since AIO 22 doesn't have the verbage for commingled injection yet, we request that you just approve the sundry for Kuparuk injection only for now. We'll still get the cement log to verify mechanical isolation between the poolrs, but leave the Sag isolated with a plug until we can get a letter to you for administrative approval on the commingled injection. Thanks Jim Young ="".'="."==~·,,'''O·'==·.__·'~-=~·===''==~_..··_''.=.'.'O='~=.=·O_=_O====7"__='=,",'~~'''~='.,··=~..·.====< From: Allen, Kenneth W Sent: Thursday, November 09,20062:40 PM To: Young, Jim; Winton Aubert Subject: RE: S-31A injector recompletion Importance: High Winton, I realize this e-mail is from a few years back and things may have changed so feel free to give us a shout and we can discuss what else may be needed. I am sorry for forgetting the nearby well status from the Sundry application, Below is information you'll be looking for that Jim has put together. , prA- 1'110 rq pt fr ell Status Oil Well on Gas-Lift Oil Well on Gas-Lift Miscible Fluids Jnj op Kup 7284' 7880' 762' Bond Log No No No Offset 1142' 775' 04' Int CSG Shoe Int eSG Size 98849-5/8" 109289-5/8" 1 01807" Int Hal 12-114' 12-1/4' 8-112" Please let me know if you need this in a different format or if you need further information. Thanks, Ken Allen Operations Drilling Engineer GPB Rotary Mobile: 907,748.3907 Office: 907.564.4366 e-mail: Kenneth.Allen~BP.com =·,___-==···_-===""-_,..·,·,-.=-',""=-=~=''''""_~_====____=o,=....____===___~--__ ----.-.---------,--...,-- ..,'.----,----_...._----- From: Young, Jim Sent: Thursday, November 09,20062:14 PM To: Allen, Kenneth W Subject: FW: S-31A injector recompletion 1 of 2 11/13/200610:19 AM RE: S-31A injector recompletion . . ---,',-' .._--,------ --------,._-,----,----- .._---._--"-------------------, ---------,'---- ..------..----... -----.--------------.. _._--_._._-~.._---------_._-_..._--_.._-.- -_.------_..--- ---,"_.--- ----...---....-.- ----,-----_..--- From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Tuesday, December 02,2003 12:35 PM To: Young, Jim Subject: Re: S-31A injector recompletion Jim, As long as access is maintained to both the Sag and Kuparuk, all required information to make your proposed conversion can be submitted with a 10-403 (Sundry). To abandon the Sag, a 10-407 is required (in addition to the 403 for the Kuparuk). Thanks, Winton Aubert AOGCC 793-1231 Young, Jim wrote: Winton, Heres the general steps for recompleting this well (PTD#1982200 completed per 20 MC 25. 005) : - isolate Sag with plug in top of 2-7/8" liner - pull existing tubing - injection containment to Sag has been confirmed by an FIT on the 9-5/8" shoe & P&A of original perforations in 7" casing - to confirm injection containment to Kuparuk the following steps will be taken: 1. run US IT log to evaluate cement over Kuparuk interval 7980-8180' 2a. if US IT (or water-flow log if necessary) indicates adequate cement for containment, run tubing w/packer set above top Kuparuk (similiar to attached) 2b. if cement across Kuparuk is not adequate, 9-5/8" casing will be milled so that a 7" scab can be cemented across the Kuparuk - initial produced water injection will be into the Kuparuk zone only to establish injectivity data - after injection stabilizes, Sag will be re-opened by pulling plug from 2-7/8" liner - required injection pressures to each zone expected to be similiar (accounting for hydrostatic head) - flow-rates & separate pressures within each zone can be determined with spinners & isolation plugs/downhole gauges as necessary. I will also have cement integrity information on offset Kuparuk penetration points within 1/4 mile of S-31's proposed injection point. Would all this information in the 10-403 be adequate for approval or would we need to do anything else? One thing I'm not sure of is, does API# or any other pool codes for this well need to be changed, especially if we we're to abandon the Sag & go-to Kuparuk only injection? Thanks for your help. Jim Young «Young, Jim.vcf» «S-31A RecompletionSchematic.ZIP» ~'-~._-'-'~"-----~-----" rYoung,-Jim~~~J3@~~~II,1 Ii Production Engineer II BPXA 11 ill GPB/WEND II ~~~~~~~~__~c~~d! 20f2 11/13/200610:19AM - - \.- - - ~ ~~..--~..\'.~ .. ,./"'.....=--) Winton, Jim and Bob, Please see the attached MIT forms for the following wells: / PBU 03-10: CMIT-IAxOA for Waiver compliance'! i !!:c':- / l PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver / PBU R-25A: MITIA Pre-dewatering (; I {.¿èc:5', , ' /PBU 04-13: MITIA Pre MI swap !"¡ Z¿-c; ') v,PBU P1-25: MITIA Pre MI swap {ì k /-Ze'Cf: ',/a::;5> /PBU 8-101: MITIA Pre MI swap 1\ \'231 ZC L3; :)'", ,./PBU NK-13: MITIA for UIC Compliance, Chuck Schéve witnessed >7 J t-,~, '~i(,. " ,,¡,fhe MIT form for PBU X-36 (PTD #1961670) was emailed by Anna Dube on 9/10106. If you need an additional copy or did not receive the email, I will gladly send it again. ,~ Thank you for your patience. «MIT PBU 8-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.xls» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xls» «MIT PBU 03-10 09-30-05.xls» «MIT PBU NK-13 09-19-06.xls» Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~I\NNe~) SEP 2 92GDE Hi Jim, Thank you for the note. To update you on MITs that are , 1) PBU 04-13; due 1/8/2006 ,.2) PBU S-101; due 2/25/2006 3) PBU NK-13; due 5/4/2006 ;./4) PBU X-36; due 5/20/2006 5) PBU R-25A; due 7/24/2006 past due: Completed Completed Completed Completed Completed 8/10/03 11/23/03 9/9/06 9/5/06 - 6/12/05 Sent in earlier e-mail We agree to schedule MITs on the following wells once on injection: 1 of 4 9/25/20069:15 AM -~~~,~-"'-- "'V_'VJ'V' VV\, .~...vv,v.~~V,,\' ,>V ,/... . Schedule when Schedule post Rig Schedule when Schedule post Rig 1) MPU H-06¡ due 2/28/2006 (81 since 7/2002) returned to injection 2) PBU WGI-01¡ due 4/22/2006 (SI since 12/12/2005) Sidetrack later this year 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) returned to injection 4) PBU S-31A¡ due 6/1/2006 (S1 since 12/2004) Workover ~ 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection j 6) PBU Pl-25¡ due 7/2/2006 (81 since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (SI since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others ,/1) PBU 03-10¡ M1T 9/30/2005 (CMIT 1AxOA) 2) PBU 04-08¡ M1Ts (1A and OA) doneper monthlyinjector rpt¡ date unknown- ';Þ' this well is currently SI with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of M1T data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13¡ due 1/8/2006 2) PBU S-101¡ due 2/25/2006 3) PBU NK-13¡ due 5/4/2006 4) PBU X-36¡ due 5/20/2006 5) PBU R-25A¡ due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06¡ due 2/28/2006 (SI since 7/2002) 2) PBU WGI-01¡ due 4/22/2006 (S1 since 12/12/2005) 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) ~) PBU S-31A¡ due 6/1/2006 (S1 since 12/2004) 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) 6) PBU Pl-25¡ due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (S1 since 4/2006) A M1T for each well injecting on the list should be conducted as soon as practical¡ please notify the Commission for an opportunity to witness. Regarding S1 injectors, the Commission suggests deferring testing (at least 2of4 9/25/2006 9: 15 AM · the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. '.VV'.~ ~Vn \' ,,v.. ,/... v-' ",-, ,.... ".......... ,,~, /,-,,,-,,.LV}, '-J' '-'v \.1. .I.......... There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; M1Ts (IA and OA) done per monthly injector rpt; date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad; perform tests during the more temperate months; etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: MIT PBU S-lOl 11-23-03.xls MIT PBU S-101 11-23-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT GPMA Pl-25 09-06-06.xls MIT GPMA PI-25 09-06-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-13 08-1O-03.xls MIT PBU 04-13 08-10-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-08 08-04-05.xls MIT PBU 04-08 08-04-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU R-25A 06-12-05.xls MIT PBU R-25A 06-12-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 4 9/25/20069: 15 AM V,J 'V\' ,>v",'/v~,vhv",-VU\' 'L/'''''VV',,''-''-,Jr,\, <L/"I/... . Content-Description: MIT PBU 03-10 09-30-05.xls MIT PBU 03-10 09-30-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBUNK-13 09-19-06.xls MIT PBU NK-13 09-19-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 4 of 4 9/25/2006 9: 15 AM S-31A (PTD# 1982200) IAxOA communication o~ (Je- Subject: S-31A (PTD# 1982200) IAxOA communication From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 17 Dee 2004 14:37:38 -0900 T~: jim _regg@admin.state.ak.us, "AOGCC - Winton Aubert (E-mail)" <winton_aubert@admin.state~ak.us> '. . ..' . . '." . C<C: "Rossberg, R Steven" <RossbeRS@BP.com>, uGPB,.GC2 Area Mgr"<GPBGC2TL@BP.com>,- nNSU, ADW Well-Operations Supervisor" <NSUADWWellOperatiönsSupervisor@BP.com>,uNSU,' AIDW-Well Integrity Engineer" <NSUADWWellIritegrityEngineer@BP.com>,,,Engêl, Harry R". . <SrigelHR@BP.com>, "Reeves, Donald F" <ReevesDf@BP.com>, "Young; Jim" -"'..'. - . - <):foungJ3@BP.com>, "GPB, Well-Pads SW" <GPBWellPadsWZLV@BP.com>, "GPB, FldOps' Lead" <GPBFldOpsLead@BP.com> . :.. . . ) ~~~,,'}ß Hello Jim & Winton, Well S-31A (PTD 1982200) appears to have slow IAxOA communication. The IA was pressured to 1540 psi and the OA pressure was observed to increase at a rate between 70-90 psi/day. The well is in the process of being shut-in. Plan is to conduct an MITIA and MITOA, then evaluate for an Administrative Approval. The well will remain shut-in. Attached is a wellbore schematic. «S-31A.ZIP» Please call if you have any questions. Thanks, Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWe 11 In t e9E.:?:!..z~.:ng inee r@~E.:...c;.,?~ Content-Description: S-31A.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 SCANNED JJ.\N 11 2005 1 of 1 12/20/2004 8:51 AM ) ') TREE = 4" OW W8.LHEA 0 = FMC A ClUA TOR = OTIS KB:'"äE.V = 66.50' BF .-ECBi "':;;-----"""'--'-'-'-3'8.30 'j KOP= . 2449' r¡¡;ã-x'Ä-ñgïë-; "g-ã-@-1100Q' ÖätÚm M[f; , """"""""'''''1'à1'Üji OatlÚnT\ÍO= 8800' SS S-31A SAFETY NOTES: CTO HORIZ SIDETRACK IN SAG RIVER FORMATION -700@ 10869' AN) 900 @ 10928' CHROME TBG AN) LNR 113-318" CSG, 68#, NT-80, 10 = 12.415" 1-1 2708' I,;~; t 2144' 1-i4-1/2" OTIS SSSV NIP, 10 = 3.813" 1 Minimum ID = 2.313" @ 10551 2-7/8" OTIS X NIPPLE 2707' I~ ~ GAS LlFTMANDR8.S ST IVD lVO ŒV TYÆ VLV LATCH FORT DATE 5 3156 3038 28 9CR-1MO D\I RK 11/98 4 5987 5119 45 9CR-1MO D\I RK 11/98 3 8330 6835 40 9CR-1MO D\I RK 12/92 2 1 0190 8227 46 9CR-1MO D\I RK 12/90 1 10454 8405 45 9CR-1MO D\I RK 12/92 I I I 10482' 1-14-1/2" PARKERSWS NIP, 0=3.813" I ~ 10485' 1-111WlBGANCHOR I :g: 10486' 1-19-5/8" X 4-1/2"TIW PKR, 10=4.00" I 4-1/2" TBG, 12.6#, NT-13-CR-80, -I 10571' >1 0.0152 bpf, 10 = 3.958" 19-5/8" CSG, 47#, NT-80-S, 10 = 8.681" H 10783' I ;~JtJ ITOPOF 2-7/8" LNR 1-1 10510' I ~ ~ I 10510' 1-1 BA KER KB A<R I ITOPOF7" LNR H 10534' I I . I I 1 10539' 1-14-1/2" PARKERSWS NIP, 0=3.813" I ~ I I 10551' l-þ-7/8"OTISX NIP, 0 =2.313" I J , I 10559' 1-14-1/2" PARKERSVVN NIP, 10 = 3.725" I I 10571' 1-14-1/2" TBG TAIL WILEG 1 ... 1 10562' Ii 8.MO TT LOGGED 01/06/91 I I PBTO I~ 11338' I WINDOW: - 10792' IWHIPSTOCK H 10782' I I RA TAG H 10791' I 17" LNR, 26#, NT-13-CR, 0.0383 bpf, 10 = 6.276" H 11428' 1 TOP OF 2-7/8" SL TO LNR 2-7/8" SLTOLNR, -I 12618' 1 6.16#, L-80 <:...~é ;~~~;.,,:}~ ~::~: \:: ~ ~ ~:~:'~ --j 12653' 1'\ 1 13038' H OÆN HOLE TO ()I\ TE RBI BY COM'v1ENTS 12/20/90 OFF ORGINA.L COMPLETION 11/05/98 WHrrLOW SIDETRACK COMR..ETION 01/21/99 GLM LAST WORKOVER 03/15/01 SIS-MH CONVERTffiTO CANVAS 03/16/01 SIS-CS FINAL OA TE REV BY COMrvENTS 03/01/02 RN/lP CORRECllONS PRUDHOE BA Y UNIT VVELL: S-31A PERMrr No: 198-2200 AA No: 50-029-22109-01 SEC 35, T12N, T12E BP Exploration (Alas ka) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair DATE' June 1, 2002 THRU' Tom Maunder, ,.,~.. /1' P.I. Supervisor, FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX S Pad S-31A Prudhoe Bay Field Prudhoe Bay Unit Packer Depth Pretest Initial 15 Min. 30 Min. We,,IS-31AType,nj.[N'! T.V.[,. I Tu~ingl 2375 I 2~75 I 23~0 I ~'390 l',nterva, l'v ! P Test psiI 3500 Casing 320 3520I 3450I 3390I' P/F ! P . P.T.D.I 1982200 Type testI ] i ! I -, I Notes: Well has variance for water injection, yearly MIT required. ,4,4.~L\\~ ~ ~';:~~\,.~ ~._~ ~,~.~ ~ We,ll Type Inj.ie ' ! T.V.D. I' I Tubing I I I i l'i'n~erVallI ,, '~ P.,T.D.I" , TYPe testJ,P.lTestpS'! I c~sin~l i ,,l' I Notes: Well P.T.D. Notes: P.T.D. Notes: Type ,nj. ! G I T.V.D. I ' ' i Tubing Type testI . I~ lTest psi l I Casing I I ! I ' I P/F "1 Type Inj. I' G J T.V.D. i ! Tubing I I' I I ' I'nt;r~a'l Type test] P ITest psi l i CasingI I ' i I ! I...... P/F I ,, Notes' Type INJ. Fluid Codes F = FRESH WATER INJ. G: GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's Pmdhoe Bay Field S Pad to wimess MIT on S-3 lA. This well was tagged ~ the well head for known IA to Tbg. commuication. Tag stated that after 24 hrs. of injection Tbg. & IA would have equal pressures. Well was not on injection ~ time of test. M.I.T.'s performed' 1_ Number of Failures: _0 Attachments: Total Time during tests: 2 hrs. cc' MIT report form 5/12~00 L.G. MIT PBU S 02jc.xls 6~4~02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ ACID WASH Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1639' FNL, 3828' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 2680' FNL, 2032' FEL, Sec. 27, T12N, R12E, UM At effective depth 1186' FNL, 1557' FEL, Sec. 27, T12N, R12E, UM At total depth 864' FNL, 1351' FEL, Sec. 27, T12N, R12E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 619612, 5979855) (asp's 616058, 5984038) (asp's 616507, 5985539) (asp's 616707, 5985864) 6. Datum elevation (DF or KB feet) RKB 67 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-31A 9. Permit number / approval number 198-220 10. APl number 50-029-22109-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 13038 feet Plugs (measured) 8746 feet Effective depth: measured true vedical Casing Length Conductor 110' Surface 2679' Production 10755' Liner 894' SideTrack Liner 2143' 12653 feet Junk (measured) 8717 feet Size Cemented Measured Depth 20" x 30" 72 c.f. concrete 138' 13-3/8" 3723 c.f. Arcticset II 2707' 9-5/8" 2343 c.f. 10783' 7" 300 c.f. Class 'G' 10534' - 11428' 2-7/8" Slotted Liner 10510' - 12653' Perforation depth: measured Slotted Liner 11097' - 12618' true vertical Slotted Liner 8697' - 8717' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, 13-Cr-80 TBG @ 10486'. 4-1/2" Tailpipe to 10562'. True Vertical Depth 138' 2697' 8727' 8774'- 8765' 8528'- 8784' Packers & SSSV (type & measured depth) 9-5/8"x4-1/2"TIW Packer@ 10486'. 4-1/2" x 2-7/8" Baker KB Packer @ 10510'. 4-1/2" SSSV Landing Nipple @ 2144'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/22/2001 Subsequent to operation 10/25/2001 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In Well Shut-In Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended__ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schn~'rr ~ Date December 15, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · OR SOI S 8Fl 9!I' AL SUBMIT IN DUPLICATE 10/15/2001 10/16/2001 10/23/2001 10/24/2001 10/25/2001 11/20/2001 11/21/2001 10/15/01 10/16/01 1 o/23/o 1 1 o/24/o 1 1 o/25/O 1 11/20/01 11/21/01 S-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SCHMOO B GONE: DFF (PRE SCALE REMOVAL / ACID STIM) - IN PROGRESS. SCHMOO B GONE: DRIFT (PRE SBG) SCHMOO B GONE: SCALE BLAST TBG/ACID WASH LINER SCHMOO B GONE: SCALE BLAST TBG/ACID WASH LINER SCHMOO B GONE: SET 4 1/2" X" MCX W/1" BEAN SBHP/FBHP SURVEY: PULL MCX/D&T/SBHPS/SET MCX SBHP/FBHP SURVEY: PULL MCX/SBHPS/D&T/SET MCX EVENT SUMMARY DRIFTED WITH 2.20" CENTRALIZER/SAMPLE BAILER TO 10634' WLM. ( - 100' INTO LINER) NO OBSTRUCTIONS. SAMPLE OF DRY INJECTION MUNG. RAN 3.625" CENTRALIZER. SAT DOWN @ 1174' WLM. TOOLS HUNG UP & PULLING VERY HARD. IN HOLE AT 1100' WLM W/3.625" CENTRALIZER. HARD TO POOH. TOOLS CAME FREE @ - 930' SLM. HYDRATES & INJECTION MUNG ON TOOLS. (NOTE: RETRIEVED SAMPLE FROM RUN MADE ON 10/15/01) RDMO. MIRU CTU #8. RIH W/SCALE-BLAST TOOLS. SCALE BLAST TBG FROM SURFACE TO TOP OF LINER TAKING RETURNS THRU S-7'S FLOWLINE. SCALE-BLAST TO LINER TOP AT 10525' CTM. POOH SCALE-BLASTING ON WAY OOH. RIH W/JSN. JET LINER FROM 10520' TO 12635' AND BACK TO LINER TOP. TD TAGGED @ 12635'. LAY IN 15 BBLS 7.5% HCL W/20% XYLENE FROM TD TO LINER TOP. SOAK. BEGIN PUMPING 50 BBL STAGE OF 7.5% HCL. JET 50 BBL 7.5% HCL IN LINER FROM 12360' TO 10500'. JET 100 BBL 2% KCL UP/DOWN PASSES FROM 10500' TO 12360'. PARK ABOVE LINER TOP, PERFORM SRT @ 0.5, 0.75, 1, 2, 3, 4 AND 4.4 BPM. POH . FREEZE PROTECT COIL AND WELLBORE TO 2000'. DRIFT TO SSSVN W. 3 80 CENT SB SET 4 1/2 MCX SSSV SN.# M-64B W/1" BEAN & 4 1/2 EQ. DEVICE W/X-KEYS @ 2129' SLM RUN CK. SET. RAN 3.83" GAUGE RING TO ISSSV @ 2120' SLM. PULL 4 1/2" MCX @ 2120' SLM. DRIFT W/2.27" SWAGE & SB TO 10,938' RKB. ' BAILER CAME BAC~ EMPTY. RUN TANDEM PETRADAT SURVEY AS PER PROCEDURE. **** ISSSV IS OUT OF THE HOLE. LONG TERM SHUT IN. DUMP SSV. WILL NEED SSSV IF PUT ON MI INJECTION *** Page 1 S-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 2 iPRESSURE TEST LUBRICATOR TO 3000 PSI W/1 BBL OF DIESEL, (2 TEST) 65 60/40 METHANOL WATER 15 METHANOL WATER 215 2% KCL 740 2% KCL W/XSLICK WATER 15 7.5% HCL W/10% XYLENE 54 7.5% HCL 1106 TOTAL Page 2 • • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWeilIntegrityEngineer @BP.com] Sent: Monday, May 14, 2001 11:54 PM To: Maunder, Thomas E (DOA) Subject: S -31A High IA Pressure (PTD 1982200) Hello Tom. Well S -31A (PTD 1982200) is exhibiting high IA pressure. Current wellhead pressures are Tubing /IA /OA = 2900/2900/800. A booster pump has been installed to increase the injection pressure from 2000 to 2900 psi. Current injection rate is 1100 BWPD at 2900 psi. An MITIA passed to 3500 psi on 5/12/01. However, when the IA is bled, it re- pressures to the tubing pressure in approximately 24 hours. We would like to continue injection with the high IA pressure without pursuing a sundry. This is based on the passing MITIA on 5/12/01. Production casing integrity is monitored via the OA pressure. There is currently a 2100 psi difference between IA & OA pressures. IA and OA pressure readings are being recorded daily. We have also increased the MITIA frequency to a 1 -year MIT schedule. The AOGCC will be notified of any indication of a measurable leak. Call if you have any questions. Joe Joe Anders, P.E. / Kevin Yeager I�i�I'! Well Integrity Engineer BP Exploration, (Alaska) Inc. (907) 659 -5102 email: NSUADWWellIntegrityEngineer @bp.com 1 0 FI I I--I-- I I~1G SEFI~JICE S WELL LOG TRANSMITTAL To: State of Ah4ca Alaska Oil and Gas Conservation Comm_ Att~: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs S-3 lA AK-MW-80426 June 3, 1999 1 LDWG formatted Disc with vefifimtion listing. API#: 50-029-22109-01 ,EASE ACKNOWLEDGE RECTJPT BY SIGNING AND RETURNING THE ATFACHED COPIES OF THE TRANSMHTAL LETTER TO ~ ATFENTION OF: Sperry-Sun Drilling Services Attm Jim Galvin 5631 Silvemdo Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: ,.JUN 0 3 1999 Alaska 0ii & Gas Cons. Commission An~oracje BP Exploration (Alaska) Inc. Petro-teehnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALA ~IL AND GAS CONSERVATION CO ~' 'ION WELL Cor~,,~-~ETION OR RECOMPLETION REPO-~'~tD LOG CT Sidetrack well 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration/Alaska) Inc. 98-220 3. Address 8. APl Number JAN P.O. Box196612, Anchorage, Alaska 99519-6612 50-029-22109-01 4. Location of well at surface :. . _ .,'~'--"'"""'"~, ~ -~. ;,'~ 9. Unit or Lease ~a~8 Oil & Gas Cons. 1639' SNL, 3828' WEL, SEC. 35, T12N, R12E i ,:?:' <<.~'.'..:."..i i l:~?¢....~.~_' i~' Prudhoe Bay Anch0r~ At top of productive interval ' ~ .)~..,~ _ '/~'~' -~ ,:~.~' ~'~' '~¢.?~ ~ ,~ 10.. . ,-.. Well Number 2680'SNL, 2032 WEL, SEC. 27, T12N, R12E - ~i,,...~'~¢~._~ r~'i S-31Ai At total depth ~,._,. ; 11. Field and Pool 4416' NSL, 1356' WEL, Sec. 27, T12N, R12E , - -. ~~-~' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE=66.50I ADL 028258 12. Date Spudded10~29~98 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre 116' NO' Of COmpletiOns11 ~3~98 11 ~6~98 N/A MSLI One 1'~. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional SurveyI 20. Depth where SSSV setl¢?.l. Thickness of Permafrosl 13038 8746 FT 12653 8717 FT I~Yes I~No I 2144 MD! 1900'(Approx.) 22. Type Electric or Other Logs Run GR 23. CASING, LINER AND CEMENTING RECORD CASING S E'I-FI NG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTI-OM SIZE CEMENTING RECORD AMOUNT PULLED 20x30 Insulated Conductor Surface 110 36" 13-3/8" 72# L-80 Surface 2707 17 1/2" 3723 c.f. ........... 9-5/8" 47# L-80 Surface 10783 12-1/4" 2343.c.f. 7" 26# L-80 10534 11428 8-1/2" 300 c.f. 2-7/8" 6.16# L-80 10510 12653 3-3/4" slotted liner ~4. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) .......... SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, 10571 10486' MD TVD NT13CR-80 11097-12618 8697-8717 slotted liner 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ............. 27. PRODUCTION TEST [ lr-4ii\lA i Date First Production ]Method of Operation (Flowing, gas lift, etc.) 12/1/98 ] Flowing , Date of Test Hours Tested PRODUCTION OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I FOR TEST Flow Tubing Casing Pressure SALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) · Press. ?4-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,, Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mark,:., ...... 30. .... :..~ ~.,:ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby c,ertify that the foregoing is true and correct to the best of my knowledge Signed ?~N"' j2,~_ ~ '"'Theres¢ Mills Title Coiled Tubing Drilling TA Date Prepared By Name/Number: Theresa Mills 564-5894 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: S-31A Accept: 10/25/98 Field: Prudhoe Bay Spud: 10/29/98 APl: 50-029-22109-01 Release: 11/6/98 Permit: 98-220 CTD Unit: Nordic #1 Date Day Depth '10/26/98 '1 Move onto S-31a. Accept Rig 07:00 10/25/98. Rig Waited on Weather for 23 hrs before winds allowed rig move from J pad to S pad. NU BOP, run lines. Test BOP. Chuck Scheve w/AOGCC waived witnessing test. Fax'd report to AOGCC Deadhorse / Anc. Offices. Bull headed 100 BBL seawater at 3.5 BPM to clean liner. R/U SWS to run Baker whipstock. RIH and had steady whipstock face of 100R at setting depth. Worked up/dwn with no change. POOH and added 6 ft of eccentered weight bar. Check tool face indicator. Bull headed 50 bbls at 5.5 BPM to reduce mung problem. RIH with eccentered wt bar added to BHA. Had steady tool face reading of 39L near setting depth. Work tool up/dwn with no change. Pump 2 BPM while moving tool. No change. POOH. SWS had to re-build second weight bar in their shop and change out a shorted adaptor. Made up second 6 ft. weight bar in BHA. 0/27/98 2 RIH with whipstock and 12 ft of eccentered wt bar on E-Line. Tie-in with CBL/GR. Set top of · whipstock at 10,782 ft with high side at 12 deg L. POOH. R/D SWS. M/U Cement Squeeze BHA. RIH with Sqz Cmtg BHA. Tag whipstock and correct CTD. Held pre-job Safety meeting. Pump 4 BBL 17 PPG "G" neat cmt, 8 BBL Cmt with aggregate [10 PPB] and 13 BBL 17 PPG neat "G" cement. [Total of 25 BBL]. Displace CMT with seawater. Bullhead 20 BBLS cmt to perfs and circ in last 5 bbls. Hesitation Squeeze in 4 BBLS and pressure test Squeeze Cement plug to 1500 PSI. Good Test. RIH and tag firm cement at 10,766 ft. [16 ft high]. Circ. Biozan sweep to clean liner and POOH jetting GLM's. L/D Cmtg BHA. Cut off 150ft of coil for fatigue management. M/U BHA #2 with 3.50" x 5.75" Inteq Underreamer. Tag up at 10750' UR down through stringers and green cement. Saw more motor work at 10772'. Attempt to inch down into cement but it appears that we are on whipstock top from continuous stalls at 10782'. 0/28/98 3 '! 0799 Verify underreamer depth as top of whipstock. POOH. Lay out underreamer. M/U 3.80" dimple mill and flexjt. RIH. Tag "SWN" Nipple at 10551' CTD and correct to 10550' BKB. Mill thru nipple, backream and RIH to top of whipstock at 10782 ft BKB. Drill cement from 10782 - 10785 fl BKB. Mill window from 10785 - 10790.6'. Stacking 2000 WOB without stall. Good sign of formation. Ream up/down/up over window. POOH. Dimple mill has good signs of wear in center and was in gauge. RIH with 3.75" diamond mill and standard 3.8" string reamer. Difficult building any motor torque at first. Broke through remaining metal lip to formation at 10793'. Drill to 10799'. 0/29/98 4 '10932 Ream window area with string reamer / mill. Ream 3 full up/down cycles. Window is clean. Circ. in FIoPro and recover seawater. POOH. L/O BHA #4. Re-head with DS CTC. Pull test and press test. M/U BHA #5 with 2.60 deg motor and M09BQPX bit for building BHA. RIH with BHA #5. No trouble RIH. Orient TF to high side. Run thru window with no tag. Drill building interval from 10800 - 10932'. Had trouble with GGG readings on MWD. Continued drilling on inclination at constant TF, until readings came back later. Azimuth checked out good. POOH for new BHA. Checked pipe at 3747'. 1% UG. 0/30/98 5 11560 Continue in hole. Shallow test MWD at 5,000ft. RIH. Tie-in with GR at RA tag. Orient TF. Drill horizontal hole from 10932 - 11008 ft. Short trip to shoe. Drill 11008 - 11105 ft. Back ream to 10920 ft. Log mad pass with Sperry GR from 10920- 11105 ft. Drill to 11279'. Short trip to 10800', hole feels clean. Drill to 11480'. Short trip to 10810'. Hole very clean. Had trouble orienting toolface. Needed 3 clicks to get 1 orient increment. Drill to 11558'. Still having trouble orienting and holding TF when getting back to bottom. '10/3'1/98 6 '1 '167'1 Troubleshoot orientor problems. MWD failed. POOH. Lay out MWD and orientor. Bit and motor OK. RIH and shallow test MWD. RIH to window. Orient TF to high side. Tie-in to RA tag and subtract 13 ftCTD. RIHtoTD. Orient TF. Rig back on clock at 13:30 hrs. Drill horizontal hole from 11560 - 11659 ft. MWD quit and unable to drill ahead, appeared to have leak in BHA. RIG OFF CLOCK AT 17:30 HRS. Flag CT at TD of 11659 ft. POOH. LD tools. No sign of washouts. MWD tool completely dead. Hold safety meeting. Congratulate crews on 2 years without an LTA. Cut off 200ft of coil for fatigue management. MU new MWD string and BHA#8. Tag TD and correct to flag. Make MAD pass over 11530 - 11659 to capture GR lost on previous run. Back on clock at 03:30 hrs. Orient TF and drill to 11672'. MWD quit working. POOH. '1 '1/1/98 7 '12100 POOH due to MWD failure. C/O Sperry MWD tools to new SOLAR MWD tools. Re-run motor and bit #2RR. RIH with BHA #9 [1.0 deg motor and DS49 bit]. Shallow test MWD - OK. RIH. Went thru window with no wt loss. RIH clean to TD. Orient TF to 45R. RIG BACK ON CLOCK AT 15:00 HRS. Drill Sag River formation from 11672 - 11870'. Having spurious DLS readings. Short trip to window. Hole very clean. Drill 11870 - 12050'. Make short trip to window. Attempt to tie in but G-totals too high. Drill 12050 - 12100'. '11/2/98 8 1263'1 Continue drilling from 12100 - 12250 ft. Short trip to window. Tie-in with RA tag, add 4 ft to CTD. RIH to TD. Drill horizontal hole from 12250 - 12443 ft. Short trip to window. Hole is clean. RIH to TD. Unable to orient TF. POOH for Orientor. RIG OFF CLOCK AT 16:00 HRS. Change out motor, orientor, Sperry probe. TIH. Rig back on clock at 02:30 hrs. Drill to 12580', stuck in fault area, work pipe free and short trip to clean hole. Continue drilling. Pull up hole to verify GR data, data appears OK. Drill to 10631'. Orient toolface to drop angle. '1113198 9 '13038 Orient TF. Drill from 12631 - 12648 ft. Back ream 200 ft to check hole condition. Hole was clean. Drill from 12648 - 12771 ft. Short trip to window. Tie-in with GR, add 17 ft to CTD. RIH to TD. Hole was clean. Drill from 12787 - 12845 ft. Orient TF. Drill to 12870', short trip while geologist confirms cuttings sample analysis. Orient toolface to drop angle, drill ahead to 13,035'. TD well, short trip to 12,700'. POOH, GR log for correlation. Correct depth (+4'). TD is '13,038'. POOH 1/4/98 10 L/D drilling BHA #10. Prepare to run liner. Held pre-job Safety Meeting. RIH with 60 Jts. of 2 7/8" slotted liner and 19 Jts 2 7/8" STL and FL4S liner. Set liner in slips. RIH with Baker 10 ft. stinger and 40 stands of 1.25" CSH workstring. Space out with pups. M/U Baker 4 %" KB Packer, CTLRT, Hyd Disc, Swivel and CTC. RIH with liner on CT. Went thru window slick. RIH easy to 12880 ft and set down in shales. Work liner down to 12930 ft. Unable to work liner deeper. PUH to 12600' clean while circ in 17 BBL Lubetex pill to reduce open hole friction. Had trouble working back to bottom starting at 12710'. Work to 12860' with pill past shoe. Unable to work deeper. Got sticky and packing off with 20-30K overpulls. POOH with liner. Discuss with town-will hang liner off bottom with slotted jts covering sand from 11096-12618'. LD Baker packer. Stand back CSH workstring. Stand back 18 jts liner. LD 12 jts slotted liner. MU 18 jts stood back liner. Prep to RIH with workstring. '1/5/98 11 Finish M/U 2 7/8" Liner. RIH with 10 Ft Baker stinger and 34 Stds of CSH workstring. M/U Baker 4 %" KB packer and running tools. RIH with slotted liner on CT. RIH thru window with no wt loss. Run to setting depth of 12653 ft with no problem. Circ. 40 bbls of 2% KCL water, drop 5/8" ball and displace with KCL water. Ball on seat at 56 bbls. Press up to 1500, 2000 and 2650 psi. Set down wt on packer and found packer slips had not set. Increased pressure to 3000 psi. Packer slips still not set. Increased press to 3200, 3400, 3600 and 3800 psi. Pick up and moved string easily. POOH to replace packer and re-dress CTLRT. LD packer and CTLRT. Stand back CSH. Redress ball seat shear pins on stinger. RIH with CSH. WO Baker packer (2 hr). MU packer and new CTLRT. RIH with liner on CT. RIH to set depth at 12653' shoe, top of packer at 10510'. Pump ball to seat and set packer. Verify with pull test and slackoff. Begin 30 minute charted packer test at 2000 psi. 1116198 12 Test Baker 2 7/8" Packer X 4 %" tubing seal to 2000 psi for 30 min. OK. Release CTLRT and POOH jetting slotted liner with 2% KCL water. Recover FIoPro from well. POOH with CT and workstring. Lay out Baker liner running tools. Stand back 34 Stds of workstring. Prep to RIH and freeze protect tubing. Found pinhole leak in CT. Cut off CT past pinhole. M/U CTC and nozzle. RIH and freeze protect tubing from 2000 ft. Blow down reel with Nitrogen. Prep CT to replace reel. NDBOPE. PT tree cap @ 3500 psi. Rig released at 2100 hrs 11/5/98 (11 days 14 hrs). Move to S-25a for sidetrack. WELLHEAD: FMC CMT'd- ~ 13 3/8", 68#/ft, 12708' I ~ ~ ' GAS LIFT MANDRELS I I ~.AMC..O 9~r-lMn I 1/?" RK NO I KOP: 2000' I 5 3156' 3038' MAX ANGLE: 47° @ 4550' 4 5987' 5119' 3 8330' 6835' 1 2 10190' 8227' 4 1/2", 12.6#/ft, NT13Cr- 1 10454' 8405' 80, TDS TBG TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT CHROME TBG ! I' --41/2 .... SWS"NIPPLE 110,482, & 7" LINER 1 0,48 ' I _~ 718" SLOTTED LINER CTD COMPL. '1 r ~, 9 5/8" PACKER 2 7/8", 6.16#, STL, b-80 TUBING, ~._. --, 10,486' -- 4 1/2", 12.6 #/ft, NT13Cr-80 TOP OF BAKER KB PACKER; 10510' '---- ~j ~ TAILPIPE OTIS X NIPPLE:10,551' [ID= 2.313"] I~ ~ 41/2 .... SWS"NIPPLE 110,539, FULL BODY TUBING TO 11,097' ~ ] [' i ~ ~ 41/2 .... SWN"NIPPLE 110,559' i \ -- J 1 TOP OF TIW[[ 10,534' ~, 41/2" WLEGI 10:571 i ELMD 10,562' 9 5/8l" 47#/ft' I ~°'783'1 ~I Window cut in 7" liner: 10785-10792' Whipstock top at 10782' RA Tag in whipstock at 10791' 7" liner Squeeze Cemented to top I of whipstock at 10782'. All perforations P & A. 7",26#, NT13 Cr-80 shoe at 11,428' SLOTTED LINER SUMMARY I I 2 7/8", 6.16#, STL, L-80 TUBING ! ! I I TOP OF SLOTTED LINER: 11,097' BTM OF SLOTTED LINER: 12,618' J l Il 'Ill CTD HORIZONTAL I SIDETRACK 2 7/8", 6.16#, L-80 GUIDE SHOE i~z,~b~'I 3 3/4" OPEN HOLE TD 1 l:~,u~u'I _ DATE REV. BY COMMENTS PRUDHOE BAY UNIT 12-20-90 DFF INITIAL COMPLETION WELL: S-31(32-27-12-12) 1-8-91 A. TELL INITIAL PERF APl NO: 50-029-22109-01 11-1-91 A. TELL PREFRAC / REPERF SEC $5; TN 12N; RGE 12E 8-27-93 MCBRIDE SAG PERFS 11-5-98 WHITLOW CTDHOR~ZONTALSIDETRACK BP EXPLORATION GAS LIFT MANDRELS ~AM~O 9~r-lMn 1 No 5 3156' 3038' 4 5987' 5119' 3 8330' 6835' 2 10190' 8227' 1 10454' 8405' EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: BP Exploration Rig: Nordic #1/CTU #7 Job No: 102047 Well: S-31A Field: Prudhoe Bay, Alaska AFE No: 4P1214 Calculation Method: Minimum Curvature Mag. Declination: 27.690 APl No: Vertical Sect. Plane: 12.760 TRUE Grid Correction: 0.900 BHI Rep: H. Wagoner, M. Miller Vertical Sect. Plane: 11.860 GRID Total Correction: 26.790 Job Start Date: 28-Oct-98 Measured Depth from: RKB Dip: .lob End Date: 06-Nov-98 True Vertical Depth: Sea level RKB Height: 66.500 Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) · (del~) (deg) (ft) (TIP) °/lOOft. Lat. (Y) Dep. (X) (del~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 10600.00 43.43 334.73 8527.46 0.00 0.00 4007.50 -3387.16 333.83 3953.80 -3449.69 5983809.01 616161.6(~ 10782.00 43.63 335.63 8659.41 99.34 0.36 4121.27 -3439.78 334.73 4066.73 -3504.09 5983921.94 616107.26 10812.00 52.00 337.50 8679.54 117.27 28.28 4141.65 -3448.59 336.60 4086.97 ~3513.21 5983942.18 616098.14 10842.37 64.19 338.90 8695.56 138.48 40.33 4165.55 -3458.12 338.00 4110.72 -3523.13 5983965.93 616088.22 10868.89 72.80 340.10 8705.28 159.09 32.74 4188.64 -3466.75 339.20 4133.67 -3532.11 5983988.88 616079.24 10898.97 82.60 336.50, 8711.68 183.28 34.61 4215.91 -3477.62 335.60 4160.76 -3543.41 5984015.97 616067.94 10928.17 91.30 332.50 8713.23 206.15 32.78 4242.19 -3490.16 331.60 4186.85 -3556.36 5984042.06 616054.99 10967.04 95.401 335.60 8710.961 236.42 13.21 4277.07 -3507.13 334.70 4221.46 -3573.88 5984076.67 616037.47 11001.56 97.60 340.20 8707.05 264.55 14.69 4308.84 -3520.04 339.30 4253.02 -3587.28 5984108.23 616024.07 11041.74 97.40 344.10 8701.80 298.83 9.64 4346.75 -3532.24 343.20 4290.73 -3600.08 5984145.94 61601 1.27 11083.12 95.50 342.80 8697.16 334.68 5.55 4386.16 -3543.96 341.90 4329.95 -3612.41 5984185.16 61,59~)8jc ¥' 11116.57 93.33 349.60 8694.58 364.49 21.28 4418.53 -3551.90 348.70 4362.19 -3620.87 5984217.40 615990? I 1154.32 91.00 351.90 8693.15 399.46 8.67 4455.75 -3557.97 351.00 4399.32 -3627.52 5984254.53 61598 ~"., 11192.19 89.70 355.30 8692.92 435.23 9.61 4493.38 -3562.19 354.40 4436.88 -3632.33 5984292.09 615979.02 1 i 225.54 88.80 356.00 8693.36 467.10 3.42 4526.63 -3564.72 355.10 4470.08 -3635.38 5984325.29 615975.97 11276.34 87.20 2.90 8695.13 516.47 13.93 4577.37 -3565.21 2.00 4520.80 -3636.66 5984376.01 615974.69 I 1310.57 88.80 2.50 8696.33 550.15 4.82 4611.54 -3563.59 1.60 4554.99 -3635.59 5984410.2{) 615975.76 11341.84 89.10 9.40 8696.90 581.18 22.08 4642.61 -3560.35 8.50 4586.12 -3632.84 5984441.33 615978.51 11375.19 89.50 il.80 8697.31 614.50 7.30 4675.39 -3554.22 10.90 4618.99 -3627.22 5984474.20 615984.13 11420.07 87.80 11.50 8698.36 659.36 3.85 4719.33 -3545.16 10.60 4663.06 -3618.85 5984518.27 615992.50 11452.29 86.40 5.70 8700.00 691.44 18.50 4751.13 -3540.35 4.80 4694.94 -3614.54 5984550.15 615996.81 11485.94 84.80 5.30 8702.58 724.72 4.90 4784.53 -3537.13 4.40 4728.38 -3611.85 5984583.59 615999.50 I 1527.64 84.40 2.10 8706.50 765.71 7.70 4825.95 -3534.46 1.20 4769.84 -3609.82 5984625.05 616001.53 11564.34 83.90 359.70 8710.24 801.44 6.65 4862.45 -3533.88 358.80 4806.35 -3609.82 5984661.56 616001.53 i 1613.72 84.00 359.00 8715.45 849.20 1.42 4911.56 -3534.44 358.10 4855.43 -3611.15 5984710.64 616000.20 11655.82 84.10 356.28 8719.81 889.62 6.43 4953.39 -3536.16 355.38 4897.23 -3613.53 5984752.44 615997.82 11700.00 83.80 1.05: 8724.47 932.22 10.76 4997.30 -3537.19 0.15 4941.12 -3615.24 5984796.33 615996.1 I Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+~S(-) E(+)/W(-) A~. N(+~S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) (de~) (de~) (~) (TIP) °/lOOfL Lat. (Y) Dep. (X) (de~) Lat. (Y) .Dep. (X) Lat. (Y) Dep. (X) 11739.29 84.95 7.93 8728.33 970.89 17.67 5036.25 -3534.13 7.03 4980.12 -3612.80 5984835.33 615998.55 11774.46 88.15 11.17 8730.45 1005.93 12.94 5070.86 -3528.30 10.27 5014.82 -3607.52 5984870.03 616003.83 11818.21 88.02 8.99 8731.91 1049.61 4.99 5113.91 -3520.65 8.09 5057.98 -3600.54 5984913.19 616010.81 11886.56 88.11 11.99 8734.22 1117.86 4.39 5181.07 -3508.21 11.09 5125.33 -3589.16 5984980.54 616022.19 11948.99 88.28 16.57 8736.18 1180.22 7.34 5241.53 -3492.83 15.67 5186.02 -3574.72 5985{)41.23 616{)36.63 11979.26 88.19 20.62' 8737.12 1210.311 13.38 5270.20 -3483.18 19.72 5214.84 -3565.53 59850?0.05 616045.82 12034.66 91.28 23.79 8737.37 1264.94 7.99 5321.48 -3462.25 22.89 5266.44 -3545.41 5985121.65 616065.94 12114.21 92.51 33.84 8734.73 1341.25 12.72 5391.05 -3423.98 32.94 5336.60 -3508.24 5985191.81 616103.11 12170.19 93.80 39.30 8731.65 1392.37 10.01 5435.92 -3390.69 38.40 5381.99 -3475.66 5985237.20 616135.6° 12218.06 92.33 44.23 8729.09 1434.16 10.73 5471.56 -3358.86 43.33 5418.13 -3444.39 5985273.34 616166 12302.74 91.54 54.80 8726.22 1501.87 12.51 5526.43 -3294.58 53.90 5474.00 -3380.98 5985329.21 616230~ 12340.8 90.57 56.57 8725.52 1529.74 5.30 5547.89 -3263.15 55.67 5495.95 -3349.89 5985351.16 616261.46 12412.36 89.34 57.45 8725.58 1580.99 2.11 5586.85 -3203.13 56.55 5535.84 -3290.49 5985391.05 616320.86 12447.61 90.40 57.27 8725.66 1606.09 3.05 5605.86 -3173.45 56.37 5555.32 -3261.11 5985410.53 616350.24 12492.74 93.04 57.60 8724.30 1638.16 5.90 5630.14 -3135.44 56.70 5580.19 -3223.49 5985435.40 616387.86 12526.24 91.54 56.21 8722.97 1662.18 6.10, 5648.41 -3107.40 55.31 5598.91 -3195.73 5985454.12 616415.62 12555.17 92.95 50.58 8721.83 1684.11 20.05 5665.64 -3084.20 49.68 5616.50 -3172.81 5985471.71 616438.54 12597.54 93.92 45.82 8719.29 1718.56 11.45 5693.82 -3052.68 44.92 5645.17 -3141.74 5985500.38 616469.61 12634.89 91.89 44.41 8717.40 1750.06 6.61 5720.15 -3026.25 43.51 5671.91 -3115.73 5985527.12 616495.62 12674.49 86.78 42.29 8717.86 1784.14 13.97 5748.93 -2999.08 41.39 5701.11 -3089.01 5985556.32 616522.34 12711.59 84.05 40.36 8720.82 1816.61 9.00 5776.70 -2974.66 39.46 5729.26 -3065.03 5985584.47 616546.32 12752.86 83.08 33.13 8725.45 1854.05 17.57 5809.53 -2950.14 32.23 5762.48 -3041.03 5985617.69 616570.32 12801.74 84.41' 35.071 8730.78 1899.31 4.79 5849.76 -2922.90 34.17 5803.13 -3014.43 5985658.34 616596.92 12830.79 88.28 33.84 8732.63 1926.24 13.98 5873.66 -2906.51 32.94 5827.29 -2998.41 5985682.50 616612.94 12860.39 89.16 31.37 8733.29 1954.07: 8.86 5898.59 -2890.56 30.47 5852.46 -2982.86 59857{)7.67 616628.49 12895.49 85.20 31.02 8735.02 1987.33 11.33 5928.57 -2872.41 30.12 5882.72 -2965.18 5985737.93 616646.17 12925.49 85.29 29.25 8737.51 2015.86 5.89 5954.43 -2857.40 28.35 5908.81 -2950.57 5985764.02 61666011 12974.54 84.32 28.55 8741.95 2062.78 2.44 5997.19 -2833.79 27.65 5951.94 -2927.64 5985807.15 61668~i 13006.67 86.52 22.21 8744.52 2094.01 20.83 6026.11 -2820.07 21.31 5981.07 -2914.38 5985836.28 6166961¥~ 13038.00 86.52 22.21 8746.42 2124.86 0.00 6055.07 -2808.25 21.31 6010.21 -2903.02 5985865.42 616708.33 7800 8000 8200 0 8400 .-- -4,-- (g 8600 8800 9ooo B.P. Exploration (True) Structure : Pod S Field : Prudhoe Boy Well : S-51A, APl 50-029-22109-01 Location : North Slope, Alaska, K-- West (feet) 4400 4200 4000 5800 5600 5400 5200 5000 2800 2600 2400 2200 I I I I I I I I I I I I I I I t I I I I I I I I~ £ ~0 ORIGINAL 6400 6200 6000 5800 5600 A 5400 I 5200 5000 -+, 4800 4600 4400 4200 4000 Crcotcd h~/ plenner I~to plotted: 24-Mot-99 Plot Refe-ence. is $-51A . . - M~L - . B.P. Exploration (True) Pad S S-31A S-31 Prudhoe Bay North Slope, Alaska SURVEY L [ ST [NG by Baker Hughes !NTEQ Your ref : S-31A Our ref : svylO0 License : AP! 50-029-22109-01 Date printed : 24-Mar-99 Date created : 24-Mar-99 Last revised : 24-Mar-99 Field is centred on ?08179.340,5930615.440,999.00000,N Structure is centred on 618134.580,5981470.630,999.00000,N Slot location is nTO 21 12.911,w149 1 43.366 Slot Grid coordinates are N 5979855.210, E 619611.350 Slot local coordinates are 1638.65 S 1451.23 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad S,S-31A Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 10600.00 43.43 334.73 8527.46 10782.00 43.63 335.63 8659.41 10812.00 52.00 337.50 8679.54 10842.37 64.19 338.90 8695.56 10868.89 72.80 340.10 8705.27 10898.97 82.60 336.50 8711.68 10928.17 91.30 332.50 8713.23 10967.04 95.40 335.60 8710.96 11001.56 97.60 340.20 8707.05 11041.74 97.40 344.10 8701.80 11083.12 95.50 342.80 8697.15 11116.57 93.33 349.60 8694.58 11154.32 91.00 351.90 8693.15 11192.19 89.70 355.30 8692.92 11225.54 88.80 356.00 8693.35 11276.34 11310.57 11341.84 11375.19 11420.07 11452.29 11485.94 11527.64 11564.34 11613.72 11655.82 11700.00 11739.29 11774.46 11818.21 11886.56 11948.99 11979.26 12034.66 12114.21 12170.19 12218.06 12302.74 12340.81 12412.36 12447.61 12492.74 12526.24 12555.17 12597.54 12634.89 12674.49 12711.59 12752.86 12801.74 87.20 2.90 8695.13 88.80 2.50 8696.32 89.10 9.40 8696.90 89.50 11.80 8697.31 87.80 11.50 8698.36 SURVEY LISTING Page 1 Your ref : S-31A Last revised : 24-Mar-99 R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 4007.50N 3387.16W 1.08 0.00 616161.70 5983808.46 4121.27N 3439.78W 0.36 100.53 616107.30 5983921.37 4141.65N 3448.5914 28.28 118.67 616098.17 5983941.61 4165~55N 3458.12W 40.33 140.10 616088.26 5983965.36 4188.64N 3466.75W 32.74 160.92 616079.27 5983988.31 4215.91N 3477.62W 34.61 185.37 616067.97 5984015.39 4242.19N 3490.16W 32.78 208.52 616055.02 5984041.48 4277.07N 3507.13W 13.21 239.16 616037.50 598z~076.08 4308.84N 3520.04W 14.69 267.60 616024.10 5984107.64 4346.75N 3532.24W 9.64 302.19 616011.29 5984145.35 4386.16N 3543.96W 5.55 338.35 615998.96 5984184.57 4418.53N 3551.90W 21.28 368.40 615990.51 5984216.80 ,4455.75N 3557.9714 8.67 403.58 615983.86 5984253.93 4493.38N 3562.19W 9.61 439.54 615979.04 5984291.48 4526.63N 3564.72W 3.42 471.56 615975.99 5984324.68 4577.37N 3565.21W 13.93 521.11 615974.70 5984375.40 4611.54N 3563.5914 4.82 554.88 615975.77 5984409.59 4642.61N 3560.35W 22.08 585.96 615978.52 5984440.71 4675.39N 3554.22W 7.30 619.30 615984.14 5984473.57 4719.33N 3545.16W 3.85 664.17 615992.50 5984517.65 86.40 5.70 8699.99 4751.13N 3540.35~ 18.50 696.28 615996.81 5984549.52 84.80 5.30 8702.58 4784.53N 3537.13W 4.90 729.62 615999.50 5984582.96 84.40 2.10 8706.50 4825.95N 3534.46~ 7.70 770.71 616001.53 5984624.42 83.90 359.70 8710.24 4862.45N 3533.88W 6.65 806.55 616001.52 5984660.92 84.00 359.00 8715.45 4911.55N 3534.44~ 1.42 854.49 616000.19 5984710.00 84.10 356.28 8719.81 4953.39N 3536.16W 6.43 895.08 615997.81 5984751.80 83.80 1.05 8724.47 4997.30N 3537.19W 10.76 937.84 615996.09 5984795.68 84.95 7.93 8728.33 5036.25N 3534.13~ 17.67 976.59 615998.54 5984834.68 88.15 11.17 8730.44 5070.86N 3528.30~ 12.94 1011.66 616003.82 5984869.37 88.02 8.99 8731.91 5113.91N 3520.65~ 4.99 1055.36 616010.79 5984912.53 88.11 11.99 8734.21 5181.07N 3508.21W 4.39 1123.64 616022.16 5984979.88 88.28 16.57 8736.18 5241.53N 3492.83W' 7.34 1185.97 616036.59 5985040.56 88.19 20.62 8737.11 5270.20N 3483.18~ 13.38 1216.01 616045.78 5985069.38 91.28 23.79 8737.37 5321.48N 3462.25W 7.99 1270.50 616065.90 5985120.98 92.51 33.84 8734.73 5391.05N 3423.98~ 12.72 1346.45 616103.07 5985191.14 93.80 39.30 8731.65 5435.92N 3390.69W 10.01 1397.21 616135.64 5985236.53 92.33 44.23 8729.09 5471.56N 3358.86~ 10.73 1438.63 616166.90 5985272.66 91.54 54.80 8726.22 5526.43N 3294.58W 12.51 1505.54 616230.30 5985328.53 90.57 56.57 8725.52 5547.89N 3263.15W 5.30 1533.00 616261.39 5985350.48 89.34 57.45 8725.58 5586.85N 3203.13W 2.11 1583.45 616320.78 5985390.38 90.40 57.27 8725.66 5605.86N 3173.45~ 3.05 1608.16 616350.15 5985409.85 93.04 57.60 8724.30 5630.14N 3135.44W 5.90 1639.73 616387.78 5985434.73 91.54 56.21 8722.96 5648.41N 3107.40~ 6.10 1663.38 616415.52 5985453.44 92.95 50.58 8721.83 5665.64N 3084.20~ 20.05 1685.01 616438.44 5985471.03 93.92 45.82 8719.29 5693.82N 3052.68~ 11.45 1719.07 616469.51 5985499.70 91.89 44.41 8717.40 5720.15N 3026.25W 6.61 1750.26 616495.52 5985526.44 86.78 42.29 8717.86 5748.93N 2999.08W 13.97 1784.01 616522.23 5985555.64 84.05 40.36 8720.82 5~6.70N 2974.66W 9.00 1816.21 616546.21 5985583.79 83.08 33.13 8725.45 5809.53N 2950.14W 17.57 1853.38 616570.20 5985617.01 84.41 35.07 8730.78 5849.76N 2922.90~ 4.79 1898.35 616596.80 5985657.66 All data fn feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from S-31 and TVD from rkb - MSL = 66.5ft. Bottom hole distance is 6674.59 on azimuth 335.12 degrees from wellhead. Vertical section is from tie at N 4007.50 W 3387.16 on azimuth 11.86 degrees. Grid is ataska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad S,S-31A Pruclhoe Bay,North SLope, Alaska SURVEY LISTING Page Your ref : S-31A Last revised : 24-Har-99 Neasured lnc[in Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 12830.7~ 88.28 33.84 8732.63 5873.66N 2906.51~ 13.98 1925.11 616612.82 5985681.81 12860.39 89.16 31.37 8733.29 5898,59N 2890.56W 8.86 1952.7'9 616628.37 5985706.99 12895.49 85.20 31.02 8735.02 5928,57N 2872.41W 11.33 1985.86 616646.05 59857'57.25 12925.49 85.29 29.25 8737.51 5954:43N 2857,40W 5.89 2014,25 616(:~:~).64 5985763.34 12974.54 84.32 28.55 8741.95 5997,19N 2833.7914 2.44 2060,95 616683.57 5985806.46 13006.67 86.52 22.21 8744.51 6026.11N 2820.0714 20.83 2092.07 616696.83 5985835.59 13038.00 86,52 22.21 8746.42 6055,07N 2808.25~ 0.00 2122,84 616708.19 5985864.73 All data in feet unless otherwise stated. Calculation uses minimt~n curvature method. Coordinates from S-31 and TVO from rkb - MSL = 66.5ft. Bottom hole distance is 6674.59 on azimuth 335.12 degrees from wellhead. Vertical section is from tie at N 4007.50 ~ 3387.16 on azimuth 11.86 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ C] P! I I--I--I IM CS SEFI~JIr' E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Co~afion Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 June 8, 1999 MWD Fonnmion Evaluation Logs S-31A, AK-MW-80426 S-31A: 2" x 5" MD Gamma Ray Logs: 50-029-22109-01 1 Blueline 1 Rolled Sepia 2" x 5" TVD Gamma Ray Logs: 50-029-22109-01 1 Bhleline 1 Rolled Sepia PLEASE ACKNOWI,EIIGE ~ BY SIGNING AND RETURNING ~ ATFACHE~ COPIES OF THE TRANSMITT~.LE~ TO ~ON OF: Sperry-Sun Drilling Services BP Expbration (Alaska) Inc. Attn: Jun Galvin Petro-technical Data Cemer, MB3-3 5631 Silvemdo Way, Suite G. 900 E. Benson Blvck Anchorage, Alaska 99518 Anchorage, Alaska 99519-6612 RECEIVED Date: JUN 0 8 ]09e} , S 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ~ALASKA~ leared rvices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: March 31, 1999 From: Terrie Hubble Technical Assistant Subiect: Revised Surveys Enclosed, in duplicate, are updated directional surveys for the following wells: G-14A, Permit #98-53 S-31A, Permit #98-220 G-09A, Permit #98-263 R-06A, Permit #98-127 Baker Hughes INTEQ has submitted these revised surveys to us correcting the grid coordinates. These surveys do not require changes to the Completion Reports which were previously submitted by Theresa Mills, and are being provided to you simply for your records. However, I have also attached a revised Completion Report for R-06A as I have found a few errors in the previously submitted form and have chosen to revise it at this time. These changes are primarily minor (corrected TD was 12308', open hole completion was from 12038' to 12308'), but felt that it was important to make the corrections. The well histories and logs have previously been filed with the Commission and there are no changes. Thank you. /tlh BP EXPLORATION BP Exploration (AIsska) Ina, ~J00 E~! Ben~on Boulevard Anchorage, Alaska P.2 , Date: Oct. 29, 1998 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska g9501 Attention: Blair VVondzell Sr. Reservoir Engineer Re: Well S-3 lei casing integrity Yesterday we discussed procedures to demonstrate casing integrity on this injection well. Prior to beginning.this sidetrack the casing x tubing annulus was pressure tested to 3000 psi to prove integrity, of the production packer and the tubulars above-the packer, Tl~s was a successful test but will be repeated after completion of the sidetrack to insure that nothing was changed by the drilling of the sidetrack. Another concern we discussed yesterday was over a method to confirm integrity of the 9 5/8" casing below the production packer. Since the sidetrack liner will not be cemented there is a potential flow path that would subject the casing below the production packer to injection fluid, I met yesterday afternoon with the asset team and other advisors to discuss methods to demonstrate casing integrity below the prod,uction packer. We found no practical way to do this with the existing window and open hole in the Sag R. However, we believe that the squeeze pressure achieved during perforation abandonment provided adequate proof of casing integrity. As described in the Sundry application for plugging, the existing perforations were cement squeezed. This work was done by the coil drilling unit rather than by service coil in this instance. Twenty five (25) bbl$ of cement were used in this perforation abandonment. A squeeze pressure of 1500 psi was obtained and held for 25 minutes. Witnessing of this work was waived by the AOGCC inspector but the pressure test was recorded on a chart and is attached. This pressure test is a demonstration of casing integrity below the production packer, Please contact me if further work is needed on this issue. The pressure chart was left on the recorder after the cement squeeze and contains quite a bit of extraneous data. Ted Stagg CT Drilling Engineer BP EXPLORATION BP Exploration (/kine, ks) Irto, PO Box t 9~81P_ Anchorage, Alam(n gg519-6612 TELECOPY COMMUNICATIONS CENTER Date: P.1 TO: Name: Company: Location: Fax # FROM: Name & E~t.: Department: mi Confirm # PAGES TO FOLLOW __ (Does Not Include Cover Sheet) SECURI'I'Y CLASSIFICATION PRIVATE SECRET CONFIDENTIAL ! Telecopy #.564-5500 Confirm # 564-5823 For Communications Center Use Only Time In _ Time Sent Jam Time Confirmed Confirmed By i i i i fl 198~220,0 MD 13038 Microfilm Roll PRUDHOE BAY UNIT S-31A 50- 029-22109-01 BP EXPLORATION (ALASKA) INC TVD 08746 Con; 'ion Date: 11/6/98 Completed Status: ! ~J Current: / - Ro!._ / _ Spud 10/29/98 Elevation: KB 0066 T Name Interval Run Sent Received T/C/D D 9206 1-6 SPERRY GR OH 6/3/99 6/3/99 . L SRVY LSTNG Bill 10600-13038. OH 1/4/99 1/12/99 D R SRVY CALC BI-II 121-9390. OH 1/19/99 1/20/99 ! . . SOi~..- -o ' I I . · BP EXPLORATION P.£ ....o/-/ ~00 Ea~ Bens0n Boulevard An~ho~ge, Ala~ ~Slg~612 (9~ 561.5111 Date; Oct. 28, 1998 To: Alaska Oil & Gas Conservation.Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzeli Sr, Reservoir Engineer Re: Well S-31ai change in completion liner A coil tubing sidetrack of S-31iis in progress. The window has been milled and formation drilling wilt begin today. This sidetrack was permitted for a fully cemented 2 7/8" liner. The completion requirements have now been re-evaluated. This letter is a request to change the completion to an un-cemented solid and slotted liner configuration as shown on the attached schematic and described below. S-31 ai is to be a Sag River only Water injector, Prior to the sidetrack, S-31iwas injecting water into both the Sag R. and Zone 4, The window for the sidetrack has been milled completely within the original Sag R, i,njection perforations. The window was located with!n these perforations to preserve the existing 7" liner cement that isolates the Sag R. for injection conformance.' Drilling the horizontal Sag R. interval will re,quire that the wellbore dip into the Shublik for a short distance before inverting and leveling off in the Sag R. The proposed completion design-would place solid liner through the build section in the Sag and Si~ublik then cross over to slotted liner for the Sag R. injection interval. The solid portion of the liner would be un-cemented but would utilize a liner hanger/packer to confine injection to the 2 7/8" liner. A section of the $-31 cement evaluation log, showing excellent 7" liner cement quality, is attached. change, in completion plans. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center Please adviae if further information is required for approval of this OCT 28 '98 TREE: WELLHEAD: ACTUATOR: 01: 15PH BP EXPLORRTZOH 4. c~w 8-31ai Proposed Completior FMC . 'revised 10128198 - -' OTIS KB. ELEV = 66.50' BF. ELEV = 38.30' 888V LANDING NIPPLE (0TI8)($.813" ID) F ~144'] CMT'd 13 318", 68#/ft, KOP: 2000' MAX ANGLE: 47' ~ 4550' GAS LIFT MANDRELS' CAMG~_~_C_r-lMo, I I/2" RK LATC~ N° MD{BKB) . T,V. Ds~. 5 3156' 3038' 4 5987" 5119' 3 8330' 6835' 2 10190' 8227' 1 10454' 8405' 4 1/2", 12.1~!/fl, NT13Cr- 80, TDS TBG TUBING ID: 3.958" .CHROME TBG & LINER TOP OF TIW ------- LINER HANGER I10,534' J 9 5/8", 47#/fl, 4 1/Z' "SWS" NIPPLE (PARKER) (3,813" ID) W TUBING ANCHOR [_~0,485' ! lei 9 5/8" PACKER , 2 718" x 4 112" Liner Hgr.tPacker. 4 1/2" "8WS" NIPPLE (PARKER) (3.813" 4 1/2 .... 8WN" NIPPLE (PARKER) (3.725" ID) 4 1/2" WLEG ELMD 2 718" un.cemented Liner Top of Whipstock 10,782' --~ Window t~ be t0,787.10,793' Abandonment Cement PERFORATION $ UlY[MAI~ REF LOG: SVV8-BHC$- 12-14-g0 SIZE 8'l~P INTERVAL OPEN/SQZ'D 3 3/8 6 10785- 10825 ADD PERF 3 318" 6 10,9§7- 10,991' REPERF/11-l-91 " 6 11,001 - 11,030' REPERF/1 I-1-91 " 4 11,030 - 11,044' OPEN/I-7-91 " 4 11,054 - 11,122 ..... " 4 11,132 - 11,1g0 ..... 2 7/8" un-cemented liner to be run through the build section and crossed over to 2 718" slotted liner in the Sag R. injection interval. PBTD ~ 7", 26#/ft, NTt3Cr-80 'lO, CF0' ~BP EXF BriTTI:]I,I 10900 ,.- BP EXPLORATION BP Exploration (Naska) Inc. PO Box 196612 An(3horage, Alaska 99519-6512 TELECOPY COMMUNICATIONS CENTER Date: P.1 TO'. Name: Company: Location: Fax # Confirm # FROM: Name Department: PAGES TO FOLLOW (Does Not Include Cover Sheet) SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL Telecopy #,564-5500 Confirm # 564-5823 iFor Cammunioatione Center Use Only Time In Time Sent Time Confirmed Confirmed By STATE OF ALASKA ALAS' OIL AND GAS CONSERVATION COM, SION · -,~PPLICATION FOR SUNDRY APPROVAL Plug back for CT sidetrack 1. Type of Request: ~ Abandon i~ Suspend ,~ Plugging ~ Time Extension E] Perforate [] Alter Casing ~ Repair Well i~ Pull Tubing ~, Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1639' SNL, 3828' WEL, SEC. 35, T12N, R12E At top of productive interval 2680'SNL, 2032 WEL, SEC. 27, T12N, R12E At effective depth 2405' SNL, 2142' WEL, SEC. 27, T12N, R12E At total depth 2377' SNL, 2153 WEL, SEC. 27, T12N, R12E Type of well: Development !~ Service Exploratory Stratigraphic 6. Datum Elevation (DF or KB) KBE=66.50 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-31i 9. Permit Number 90-159 10. APl Number 50-029-22109 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11430' feet 9187' feet 11388' feet 9158' feet Length Size Structural Conductor 110' 20x30 Surface 2679' 13-3/8" Intermediate 10755 9-5/8" Production Liner 894 7" Plugs (measured) Junk (measured) Cemented 3723 cu ft Arcticset II 2343 cu ft Class G 300 cu ft Class G MD TVD 138 138 2707 2659 10783 8688 10534-11428 8507-9148 Perforation depth: measured 10967' - 11911' true vertical subsea8793' - 9512' Tubing (size, grade, and measured depth) 4-1/2" 12.6# NT13CR-80 @10571' Packers and SSSV (type and measured depth) Packer @10486' and SSSV @2144' 13. Attachments ~] Description summary of proposal ~ Detailed operations program I-~ BOP sketch 14. Estimated date for commencing operation 1 O/22/98 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Ted Stagg 564-4694 15. Status of well classifications as: [--]. Oil .,~ Gas ~ Suspended Service Prepared By Name/Numbec Theresa Mills 564-5894 17. I hereby certify that the forego~g is true and correct to the best of my knowledge Signed -"¢ ~ ~ Ted Staqq ~ Title Coiled Tubing Drilling Engineer !" ~//:~ Commission Use Only Date Conditions of Approval: Notify Comm~entative ma.Y..witness P lug~ [~,~est~'~~ (-~Qcation clearance Approved by order of the Commission ~~..._.-~~~~ ~,% Commissioner Form 10-403 Rev. 06/15/88 ~ \ ~ I Approval No...~-~ ?¢ Submit I~ Tl~piicate TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 21.1998 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re' Prudhoe Bav Unit S-3 iAi BP Exploration (Alaska) Inc. Permit No: 98-220 Sur. Loc. 1639'SNL, 3828'\¥EL. Sec. 35. T12N. R12E. Btmhole Loc. 4479'SNL. 1450'WEL Sec. 27, T12N, R12E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrit?' (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission mav witness the tests. Notice max, be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ._ David W. Johm;ton Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC; Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conse~'ation w/o encl. STATE OF ALASKA ALASKA "IL AND GAS CONSERVATtON C(. . . MISSION PERMIT TO DRILL cT Sidetrack well 20 AAC 25.005 la. Typeofwork I~Drill []Redrill ilb. Typeofwell r-]Exploratory I-']StratigraphicTest I-I Development Oil [] Re-Entry [] DeepenI [] Service I--I Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE=66.50 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation ,~,/,e_ Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 2. 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1639' SNL, 3828' WEL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2680'SNL, 2032 WEL, SEC. 27, T12N, R12E S-31Ai Attotaldepth 9. Approximate spud date Amount $200,000.00 4479' SNL, 1450 WEL, SEC. 27, T12N, R12E 10/24/98 12. Distance to nearest property line 113. Distance to nearest well 14. Number oi acres in property 15. Proposed depth (MD and TVD)' ADL 028256 @ 800'I No Close Approach 2560 13,062, 8696' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10,792', 8665 Maximum Hole Angle 95° Maximum sudace 3350 psig, At total depth (TVD) @ 8800', 3715Psig i18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 2542' 10520 8468 13062 8696 135 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. R. EC~IVE Present well condition summary Total depth: measured 11430' feet Plugs (measured) ,_f)t? true vertical 9187' feet Effective depth: measured 11388' feet Junk (measured) true vertical 9158' feet Alaska 0il & Gas 0OHS. ~ommiss[or' A~ch0rage Casing Length Size Cemented MD TVD Structural ConductOr 110' 20x30 138 138 Surface 2679' 13-3/8" 3723 cuft Arcticset II 2707 2659 Intermediate ' 10755 9-5/8" 2343 cuft Class G 10783 8688 Production Liner 894 7" 300 cuft Class G 10534-11428 8507-9148 Perforation depth: measured 10967' - 11911' true vertical subsea 8793' - 9512' 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth PIct [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ted Staao Title Coiled Tubing Drilling Engineer Date Commission Use Only Permit Number APl Number I Approval Date I See cover letter ~'oc7- 2_ ~<:~ 50- ~ ~-.~- ~ ~-- / o ~ - ~ /I / ~ "' C;~/"",~'~I for other requirements Conditions of Approval: Samples Required [] Yes,~ No Mud Log Requiredl-1 Ye~ ~ No Hydrogen Sulfide Measures .,~Yes [] No Directional Survey Required'~ Yes [] No R~,,quired,Wpj'kin~PressureforBOPE [] 2k; [] 3k; ~ 4k' [] 5k; [] 1Ok; [] 15k ~,.,,,t . .C)~rl, ,.je ~ Approved By uav,,uw. Johnston Commissioner the commission or. ,o, D te/ Form 10-401 Rev. 12-01-85 Submit In Triplicate STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION CC .... ~VilSSlON PERMIT TO DRILL CT Sidetrack well 2O AAC 25.005 [] Drill [] Redrill Ilb Type of well [] Exploratory [] Stratigraphic Test [] Development la. Type of work E~ Re-Entry E~] Deepenl ' [] Service E~ Development Gas [] Single Zone E~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE=66.50 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation ~(. Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 2-~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1639' SNL, 3828' WEL, SEC. 35, T12N, R12E. Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2680'SNL, 2032 WEL, SEC. 27, T12N, R12E S-31Ai At total depth 9. Approximate spud date Amount $200,000.00 4479' SNL, 1450 WEL, SEC. 27, T12N, R12E 10/24/98 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028256 @ 800'I No Close Approach 2560 13,062, 8696' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10,792', 8665 Maximum Hole Anqle 95° Maximum surface 3350 psig, At total depth (TVD) @8800', 3715psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 2542' 10520 8468 13062 8696 135 c.f. 19. To be completed for Redrill, Re-entry, and Deepen OperationS.Present well condition summary ~ ~&, Total depth: measured 11430' feet Plugs (measured) true vertical 9187' feet 0~'~.~ ~ 0 Effective depth: measured 11388' feet Junk (measured) true vertical 9158' feet Casing Length Size Cemented '-J~ MD~¢'t¢'~0~ 8'0¢~ TVD Structural Conductor 110' 20x30 138 138 Surface 2679' 13-3/8" 3723 cu ft Arcticset II 2707 2659 Intermediate 10755 9-5/8" 2343 cu ft Class G 10783 8688 Production Liner 894 7" 300 cu ft Class G 10534-11428 8507-9148 Perforation depth: measured 10967'-11911' ORIGINAL true vertical subsea 8793' - 9512' 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Plot [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ted $~¢aa Title Coiled Tubing Drilling Engineer Date - ( ' /~' Commission Use Only / ( ' ¢?% 2_-~_._(~ 50- 0.2--7- :2. 2. /4:~ c~- ,o,/ /~ "',~1 '" ~'~ forother requirements Conditions of Approval: Samples Required [] Yes'~ No Mud Log Required[~ Ye/,~1_ No Sulfide Measures/~"Yes [] No Directional Survey Required~ Yes [] No Hydrogen Required Working Pressuref~r BOPE [] 2k; [] 3k; ~!~ 4k; [] 5k; [] 1Ok; [] 15k Other: Signed By by order of /¢ Approved By . ,., , ,. , Commissioner the commission Date /~ :orm 10-401 Rev. 12-01-85 i]avld W. Johnston Submit In Triplicate BPX S-31ai Sidetrack Summary of Operations: S-31 is an existing injection well that is being sidetracked to improve injectivity into the Zone 4 interval. This sidetrack will be conducted in two phases. Phase 1: set whipstock, abandon existing perfs, mill window: Planned for 10122/98. · S-31i has been tested for mechanical integrity, drifted for the whipstock and a Kinley caliper has been run to evaluate liner and tubing condition. · A Schmoo-Be-Gone treatment has been performed to eliminate mung from the wellbore. · Existing perforations will be abandoned with approx. 20 bbls cement. Abandonment cement will be downsqueezed past a mechanical whipstock set within Sag R. perforations at approx. 10,780'. Abandonment cement will be squeezed to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. · Service coil will mill the window utilizing a flowline to the GC for all fluid returns. The service coil will conduct a full BOPE test, with AOGCC witness, prior to the milling operation. Phase 2: Mill Window and Drill Directional Hole: Planned for 10/24/98. Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,520' MD and cemented with approx. 24 bbls. cement. The top of cement will be designed to be a minimum of 200 ft above the window. A Cement Evaluation Log will be run across the upper portion of the liner and pressure testing will be carried out to confirm mechanical integrity. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,792' MD (8,665' TVD ss) - TD: 13,062' MD (8,696' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Cement Evaluation Log will be run in the upper portion of the 2 7/8" liner. TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS -r,~'31ai Proposed Completion~ KB. ELEV = 66.50' BF. ELEV = 38.30' SSSV LANDING NIPPLE (OTIS)(3.813" ID) I 2'144' I CMT'd -- 13 3/8", 68#/ft, NT-80CYHE, BTRS 12708' [ KOP: 2000' MAX ANGLE: 47° @ 4550' GAS LIFT MANDRELS CAMCO, 9Cr-lMo I 1/2" RK LATCF N° MD(BKB) TVDss 5 3156' 3038' 4 5987' 5119' 3 8330' 6835' 2 10190' 8227' 1 10454' 8405' 4 1/2", 12.6#/ft, NT13Cr- 80, TDS TBG TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT CHROME TBG & LINER TOP OF TIW LINER HANGER 9 5/8", 47#/ft, NT-80S, NSCC 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 110,482' I TUBING ANCHOR 9 5/8" PACKER (TIW) (4.00" ID) 110,485' I I 10,486'1 1/2", 12.6 #/ft, NT13Cr-80 TAILPIPE 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWN" NIPPLE (PARKER) (3.725" ID) 4 1/2" WLEG r 10,539' I I o,ss9'l I o,s7 'l 2 7/8" Cemented Liner Whipstock Abandonment Cement PERFORATION SUMMARY REF LOG: SWS-BHCS- 12-14-90 ' I ~ I~,°°~- ~,°~°' " I 4 111,030-1~,044' "I 4 111,054-11,122' "J 4 J11,132-11,190' ADD PERF REP ERF/11-1-91 REPERF/11-1-91 OPEN/I-7-91 II II II Il PBTD I 11,388' I 7", 26#/ft, NT13Cr-80 ~ S-31ai CT Drilling & Completion BOP LLI · 22.5" 15"I 38" 2 3/8" CT ~1 I ~o,ooo psil Pack-Offl 7 1/16" Annular Blind/Shear ~ 7 1/16" Pipe/Slip ~ 2 318" 1~7 1/16" x 5,000 psiI L~ 7 1,16~" ~x 5,000 psi I~F !~ I Slips,, ~li -~ 2 7/8" :: :~:: SWAB OR MASTER VALVE I S-31 Vertical Section 86OO 8650 8700 8750 8800 8850 0 5O0 ITSGR ] Top Perf , /TSHU I ~8,700~.~ TSAD Path Distance (Feet) 1,000 1,500 2,000 2,500 3,000 Angle@K.O.= 44 deg MD:10782 Tot Drld:2280 ft 13062 TD Marker Depths (~Orig Wellbore TSAG I 01ffTVD TSHU I 01ffTVD 8,7001 8,7001fl 'I-VD TSAD [ 8,7931ff TVD Kick Off I 8,660 ft TVD I 10,782 ft MD Deprtr @KO 5,382 ft MD KO Pt lO,782I IMD New H°le 2280I I Total MD 13,062I I T--~ ~-O 8,---~I DLS deg/100 Tool Face Length Curve 1 6 0 20 Curve 2 38 -5 129 Curve 3 6' 90 249 Curve 4 6 180 59 Curve 5 6 90 1,099 Curve 6 6 -90 724 2,280 Drawn: 10/19/98 14:59 Plan Name: Case 301 -4,500 -4,000 S-31 -3,500 X distance from Sfc Loc -3,000 6,500 6,000 5,500 5,000 4,500 4,000 3,500 -2,500 Well Name S-31 [ CLOSURE Distance 6,774 ft [ I Az 334 deg NEW HOLE E/W (X) N/S (Y) Kick Off -3,504 4,066 TD -3,005 6,071 State Plane 616,607 5,985,927 Surface Loc 619,611 5,979,855 DLS deg/100 Tool Face Length Curve 1 6 0 20 Curve 2 38 -5 129 Curve 3 6 90 249 Curve 4 6 180 59 Curve 5 6 90 1,099 Curve 6 6 -90 724 2,280 Drawn: 10/19/98 14:59 Plan Name: Case 301 BPX S-31ai Sidetrack Summary of Operations: S-31 is an existing injection well that is being sidetracked to improve injectivity into the Zone 4 interval. This sidetrack will be conducted in two phases. Phase '1: set whipstock, abandon existing perfs, mill window: Planned for 10122198. · S-31i has been tested for mechanical integrity, drifted for the whipstock and a Kinley caliper has been run to evaluate liner and tubing condition. · A Schmoo-Be-Gone treatment has been performed to eliminate mung from the wellbore. · Existing perforations will be abandoned with approx. 20 bbls cement. Abandonment cement will be downsqueezed past a mechanical whipstock set within Sag R. perforations at approx. 10,780'. Abandonment cement will be squeezed to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. · Service coil will mill the window utilizing a flowline to the GC for all fluid returns. The service coil will conduct a full BOPE test, with AOGCC witness, prior to the milling operation. Phase 2: Mill Window and Drill Directional Hole: Planned for 10124198. Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan. Mud Program: -Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,520' MD and cemented with approx. 24 bbls. cement. The top of cement will be designed to be a minimum of 200 ft above the window. A Cement Evaluation Log will be run across the upper portion of the liner and pressure testing will be carried out to confirm mechanical integrity. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,792' MD (8,665' TVD ss) - TD: 13,062' MD (8,696' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Cement Evaluation Log will be run in the upper portion of the 2 7/8" liner. TREE: 4" CIW WELLHEAD: FMC ACTUATOR: OTIS S-31ai Proposed Completio,~__~. KB. ELEV - 66.50' BF. ELEV = 38.30' SSSV LANDING NIPPLE (OTIS)(3.813" ID) 13 3/8", 68#/ft, NT-80CYHE, BTRS CMT'd 2708'I KOP: 2000' MAX ANGLE: 47° @ 4550' GAS LIFT MANDRELS CAIVCO, 9Cr-tMo 1 1/2" RK LATCF NO MD(BKB) TVDss 5 3156' 3038' 4 5987' 5119' 3 8330' 6835' 2 10190' 8227' 1 10454' 8405' 4 1/2", 12.6~/ft, NT13Cr- 80, TDS TBG TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT CHROME TBG & LINER TOP OF TIW LINER HANGER I10,534' I~-- 9 5/8", 47#/ft, 110,783' I~ NT-80S, NSCC 2 718" Cemented Liner Whipstock Abandonment Cement 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 110,482' I TUBING ANCHOR 110,485'1 9 5/8" PACKER (TIVV) (4.00"ID) i 10,486'1 1/2", 12.6#fit, NT13Cr-80 TAILPIPE 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWN" NIPPLE (PARKER) (3.725" ID) 4 1/2" VVLEG 0,539' I o,ss9'l I 10,571'1 ELMDI 1 0,562'[ PERFORATION SUMMARY REF LOG: SWS-BHCS- 12-14-90 SIZE I SPF I INTERVAL OPEN/SQZ'D 3 3/8 6 ,,I 110785 - 10825 33/81 6 I 0,967-10,991' " I 6I 1,001-11,030' " I. 1~,0~0-~,04~' " I~ I~,03.-1~,~2~' "1411,132-11,190. ADD PERF REPERF/11-1-91 REPERF/11-1-91 OPEN/I-7-91 It II II II PBTD I 11,388' I 7", 26~/ft, NTI3Cr-80 '~S-31ai CT Drilling & Completion BOP LU 22.5" 18" 38" 2 3/8" CT Pack-Off I ! __ __ 7 1/16" Annular I 7 1/16 ~ 7 1/16"x 5,000 psi ~'!11/16" x 5,000 psi ~ '-'- =~1 ~ i = ~ ~" 7 1/16" Pipe ~ ~ 2 3/8" SWAB OR MASTER VALVE S-31 Vertical Section Path Distance (Feet) 0 500 1,000 1,500 2,000 2,500 3,000 8600 ............... ~----I ............... ~ ................... ~- ................... i ............ i ............ ~ 8650 m[m[m~ ~ Angle @ K.O.= 44 deg Ped ....... ~ 8700 8 ~oo 8750 88OO 8850 .............. TSAD ............... Tot Drld:2280 ft 13062 TD Marker Depths (~Orig Wellbore TSAG J 01ffTVD TSHU J 01ffTVD 8,7001 8,700Jif TVD TSAD I 8,793Jft -I'VD Kick Off 8,660 Jif TVD 10,782Jft MD Deprtr ~KO 5,382 ft JMD KO Pt 10,782J MD New Hole 2280J I Total MD 13,062J TVD TD 8,696J DLS deg/100 Tool Face Length Curve 1 6 0 ' 20 Curve 2 38 -5 129 Curve 3 6 90 249 Curve 4 6 180 59 Curve 5 6 90 1,099 Curve 6 6 -90 724 2,280 Drawn: 10/19/98 14:59 Plan Name: Case 301 S-31 6,500 6,000 5,500 5,000 4,500 4,000 I .... t ....... 3~500 -4,5 O0 -4,000 -3,500 -3,000 -2,500 X distance from Sfc Loc IWellName S-31 I CLOSURE Distance 6,774 ft Az 334 deg NEW HOLE E/W (X) NIS (Y) Kick Off -3,504 4,066 TD -3,005 6,071 State Plane 616,607 5,985,927 Surface Loc 619,611 5,979,855 DLS deg/100 Tool Face Length Curve 1 6 0 20 Curve 2 38 -5 129 Curve 3 6 90 249 Curve 4 6 180 59 Curve 5 6! 90 1,099 Curve 6 6 -90 724 2,280 Drawn: 10/19/98 14:59 Plan Name: Case 301 · WELL PERMIT CHECKLIST ADMINISTRATION 1 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. ~R D/~TE / 12. 15. 16. 17. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. COMPANY WELL NAME ,/~/ ~-- ?~/~/"' INIT CLASS /-C,x d,_../~Z;r/' GEOL v · Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well Iocaled proper distance from other wells .......... N Sufficienl acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CM'[ vol adequate to tie-in long string to surf csg ........ CMl will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a t0-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation .............. : . BOPE press rating appropriate; test to ~)00 ping. Choke manifold complies w/APl RP-53 (May 84) ........ PROGRAM: exp L] dev [] redrll~serv/~wellbore seg II ann. disposal para req II AREA ~ 7(,--) UNIT// ON/OFF SHORE (:~_. .... GEOLOGY 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. CO N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~. ~ ........................................................................................................................... 31. Data presenled on potential overpressure zones ....... Y,~'~-//~,, 32. Seismic analysis of shallow gas zones ..... ' ........ /Y N ~'/~,/~ 33. Seabed condition survey (if off-shore) ............. / Y N 34. Cogtact.nam. elphon.e.for weekly progress reports ....... lexplora~ory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone;..~ .......,..----: . . (B) will not contaminate freshwater;~ng waste... to surface; ~-----'~ (C) wiii i:ibt'impair.~ec~al integrity of the well used for disposal; (D) will not d_..am~e producing formation or impair recovery from a poo~d (E) <~not circu .mve, n,! ,,2,0 AAC 25.252 or 20 AAC 25.412:, ,, G_EQ~Y: COMMISSION: Y N Y N Y N ENGINEERING: I.~11~/An~a[ J D ...1::1~-----'-- Y N DWJ ~ .,~ RNC ~. Comments/Instructions: Mcheklist ~ev 05129198 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 Drilling Services LIS Scan Utility Tue Jun 01 14:47:25 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/06/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 80426 B. JAHN ANGELL/WHITL RECEIVED JUN OO 1999 S - 3 IA ~J~k~ Oil & Gas Cons. Commission 5 0 0 2 9 2 210 9 01 ""'"'"'" ,u,,, ,umue BP EXPLOP, ATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 01-JUN-99 MWD RUN 2 MWD RUN 3 AK-MW-80426 AK-MW- 80426 B. JAHN B. JAHN ANGELL/WHITL ANGELL/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MW-80426 B.JAHN ANGELL/WHITL MWD RUN 5 MWD RUN 6 AK-MW-80426 AK-MW-80426 B. JAHN B. JAHN ANGELL/WHITL ANGELL/WHITL 35 12N 12E 1639 FEL: 3828 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 66.50 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 10783.0 2ND STRING 7.000 10791.0 3RD STRING 4.500 10562.0 PRODUCTION STRING 3.750 13038.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 6 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DAVE DOUGLAS FOR STEVE JONES OF BP EXPLORATION (ALASKA), INC. RECIEVED ON 24 M_ARCH, 1999. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13038'MD, 8746'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10777.0 13013.0 ROP 10801.5 13037.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 3 MWD 4 MWD 5 MWD 6 $ REMARKS: BIT RUN NO MERGE TOP 10801 0 10932 0 11566 0 11660 0 11672 0 12441 0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10932 0 11566 0 11660 0 11672 0 12441 0 13038 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10777 13037.5 11907.2 4522 10777 GR 61.88 858.54 108.796 4473 10777 ROP 5.6 2491.07 75.818 4473 10801.5 Last Reading 13037.5 13013 13037.5 First Reading For Entire File .......... 10777 Last Reading For Entire File ........... 13037.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 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 ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE N-UMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10777.0 ROP 10801.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10908.0 10932.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 29-0CT-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 10932.0 10801.0 10932.0 43.6 87.8 TOOL NLIMBER NGP SPC 270 3.750 3.8 FLOPRO 8.80 .0 9.0 5.4 .000 .000 78.0 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10777 10932 10854.5 311 10777 ROP 17.05 1588.62 45.1662 262 10801.5 GR 61.88 858.54 107.137 263 10777 Last Reading 10932 10932 10908 First Reading For Entire File .......... 10777 Last Reading For Entire File ........... 10932 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 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 ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10908.5 ROP 10932.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11548.5 11565.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 30-0CT-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11566.0 10932.0 11566.0 84.4 97.6 TOOL NUMBER PCG 42 3.750 3.8 FLOPRO 8.80 .0 9.5 5.6 .000 .000 .000 58.4 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10908.5 11565.5 11237 1315 10908.5 ROP 20.09 2491.07 89.4537 1267 10932.5 GR 62.73 778.93 90.3558 1281 10908.5 Last Reading 11565.5 11565.5 11548.5 First Reading For Entire File .......... 10908.5 Last Reading For Entire File ........... 11565.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 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 ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NL~4BER: 4 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11549.0 ROP 11566.0 $ 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: STOP DEPTH 11635.5 11660.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: 30-0CT-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11660.0 11566.0 11660.0 77.8 88.4 TOOL NUMBER NGP SPC 270 3.750 3.8 FLOPRO 8.90 .0 9.2 6.2 .000 .000 .000 .000 60.3 Dat NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REM3LRKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11549 11660.5 11604.8 224 11549 ROP 9.7 1534.67 64.6259 190 11566 GR 72 82.78 76.5233 174 11549 Last Reading 11660.5 11660.5 11635.5 First Reading For Entire File .......... 11549 Last Reading For Entire File ........... 11660.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 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 ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11636.0 11646.5 ROP 11661.0 11672.0 $ LOG HEADER DATA DATE LOGGED: 31-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: 84.1 MAXIMUM ANGLE: 84.1 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 11672.0 11660.0 11672.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 217 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3 .750 3.8 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: FLOPRO 8.90 .0 8.9 5.8 .000 .000 .000 .000 61.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REM_ARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11636 11672 11654 73 11636 ROP 9.21 97.8 55.7783 23 11661 GR 75.85 92.33 83.6483 22 11636 Last Reading 11672 11672 11646.5 First Reading For Entire File .......... 11636 Last Reading For Entire File ........... 11672 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate'files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11647.0 12414.0 ROP 11672.5 12440.5 $ LOG HEADER DATA DATE LOGGED: 01-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: 83.8 MAXIMUM ANGLE: 93.8 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 12441.0 11672.0 12441.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER SOLAR GM 77113 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 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: FLO-PRO 8.80 .0 8.8 6.4 .000 .000 .000 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11647 12440.5 12043.8 1588 11647 ROP 5.6 1772.38 81.9495 1537 11672.5 GR 63.48 90.25 77.0806 1535 11647 Last Reading 12440.5 12440.5 12414 First Reading For Entire File .......... 11647 Last Reading For Entire File ........... 12440.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12414.5 ROP 12441.0 $ 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: STOP DEPTH 13013.0 13037.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 03-NOV-98 MSC 1.32 ISC 5.08 5.74, 3.00e, 3.28, 3.06, 1.21 MEMORY 13038.0 12441.0 13038.0 83.1 93.9 TOOL NUMBER SOLAR GM 69702 3.750 3.8 FLO-PRO 8.90 .0 9.0 5.4 .000 .000 .000 .000 .0 MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12414.5 13037.5 12726 1247 12414.5 ROP 7.12 207.06 62.3487 1194 12441 GR 78.35 394.18 174.665 1198 12414.5 Last Reading 13037.5 13037.5 13013 First Reading For Entire File .......... 12414.5 Last Reading For Entire File ........... 13037.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/06/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File