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Home My WebLink About211-106CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 04-350 (PTD #2111060) Tubing cut pre RWO Date:Tuesday, June 20, 2023 8:44:10 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, June 17, 2023 5:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 04-350 (PTD #2111060) Tubing cut pre RWO Mr. Wallace, Injector 04-350 (PTD #2111060) tubing was cut on 06/16 in preparation for upcoming RWO. The well is now classified as NOT OPERABLE and will remain shut in until two well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Monday, August 22, 2016 5:09 PM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, OPS FS2 Field OTL <AKOPSFS2FieldOTL@bp.com>; AK, OPS FS2 Facility OTL <AKOPSFS2FacilityOTL@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) <jim.regg@alaska.gov>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector 04-350 (PTD #2111060) POI post-seawater line repairs All, Injector 04-350 (PTD #2111060) was shut in as a result of seawater line repairs. While shut in its AOGCC-witnessed MIT-IA expired and was reclassified as Not Operable. The well is now reclassified as Operable and can be POI. Once injection has been stabilized an AOGCC-witnessed MIT-IA will be performed. Thanks! Jack Lau (Alternate: Adrienne McVey) BP Alaska - Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, GWO SUPT Well Integrity Sent: Sunday, July 10, 2016 7:33 PM To: AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector 04-350 (PTD #2111060) Will Remain Shut In Past AOGCC Test Due Date All, Injector 04-350 (PTD #2111060) is due for an AOGCC-witnessed MIT-IA by the end of July. The well will not be brought online by then due to seawater line repairs and facility turnarounds, expected to be completed in August 2016. The well is reclassified as Not Operable. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659-5102 C: (907) 943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:26 Township:11N Range:15E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:10,322 ft MD Lease No.:ADL 0028324 Operator Rep:Suspend:NA P&A:X Conductor:20"O.D. Shoe@ 193 Feet Csg Cut@ NA Feet Surface:13-3/8"O.D. Shoe@ 3879 Feet Csg Cut@ NA Feet Intermediate:9-5/8"O.D. Shoe@ 9270 Feet Csg Cut@ NA Feet Liner1:7"O.D. Shoe@ 9866 Feet Csg Cut@ NA Feet Liner2:4-1/2"O.D. Shoe@ 10322 Feet Csg Cut@ NA Feet Tubing:4-1/2"O.D. Tail@ 9713 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 9815 ft 9752 ft 8.5/7.3 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2820 2750 2725 IA 261 269 270 OA 7 7 7 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location to witness the tag and pressure test of a cement plug that had been dumped on top of a cast iron bridge plug (9815 ft MD). This was to isolate the Lisburne perforations and convert the well to a Ivishak producer. With a 2.5-inch bailer wireline string weighing approximately 250 pounds they tagged the top of the cement (TOC) inside the 4.5-inch liner at 9752 ft MD (45° inclination) with multiple licks. Small amounts of cement was in the bailer once broke down at surface. They then completed a passing mechanical integrity test (MIT-T) to a target of 2500 psi. With more than 25 feet of cement on top of the cast iron bridge plug and a passing pressure test I found no issues with this inspection. June 15, 2023 Austin McLeod Well Bore Plug & Abandonment PBU LISB 04-350 Hilcorp North Slope LLC PTD 2111060; Sundry 323-120 none Test Data: MIT-T P Casing Removal: Chad Kenyon Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2023-0615_Plug_Verification_PBU_04-350_am               7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU LISB 04-350 Convert to Producer , New completion Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-106 50-029-23453-00-00 ADL 0028324 10322 Conductor Surface Intermediate Liner Liner 9373 3837 9233 768 619 10234 13-3/8" 9-5/8" 7" 4-1/2" 9306 41 - 3879 38 - 9270 9098 - 9866 9703 - 10322 2472 41 - 3779 38 - 8571 8426 - 9042 8922 - 9372 none 2260 3090 5410 7500 none 5020 5750 7240 8430 9862 - 10112 4-1/2" 12.6# L-80 L-80 36 - 97139039 - 9217 Structural 4-1/2" HES TNT Perm No SSSV 9587 / 8832 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY 5-1-2023 Current Pools: LISBURNE OIL Proposed Pools: LISBURNE OIL 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:47 am, Feb 24, 2023 323-120 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.24 07:52:34 -09'00' DSR-2/27/23 2472 10-404 Perforate New Pool Prudhoe Oil SFD 3/2/2023 SFD 3/2/2023 * State to witness 30 minute charted pressure test to 2500 psi and tag of bridge plug and top of 25' of cement ~9790' MD to assure isolation of pools. MGR03MAR23 * BOPE test to 3000 psi. Annular to 2500 psi. JLC 3/3/2023 3/3/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.03.03 13:23:46 -09'00' RBDMS JSB 030323 RWO LISB 04-350 PTD:211-106 Well Name:LISB 04-350 API Number:500292345300 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:Summer 2023 Estimated Duration:6days Regulatory Contact:Carrie Janowski Permit to Drill Number:211106 First Call Engineer:Eric Dickerman 907-564-4061 307-250-4013 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Current Bottom Hole Pressure:3,362 psi at 8,900’ TVD 7.3 PPGE | SBHPS 2/29/2020 Max. Anticipated Surface Pressure:2,472psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:50 psi (Taken on 06/02/2022) Min ID:3.725” XN nipple at 9,696’ MD Max Angle:45 Deg at 9,861’ Brief Well Summary: LISB 04-350 is a Lisburne injector that was shut in after observing seawater breakthrough in four wells at L3 Drillsite. The 7” intermediate liner is set across the Ivishak, and the open hole resistivity log indicates possible pay in Ivishak Zones 1 and 2. The current production packer is set at the bottom of Ivishak Zone 1, therefor the Ivishak targets are not accessible. Objective: Convert the well from a Lisburne injector to an Ivishak Producer. Perform a workover to move the production packer above the top of the Ivishak to access Zone 1 and 2 perforation targets. Maintain future access to Lisburne reservoir. Pre RWO work: Slickline: 1. Drift to TD. 2. Caliper tubing. 3. Set TTP and perform MIT-T and CMIT-TxIA. Pull TTP after tests. DHD/Wellhead: 4. Cycle LDS’s 5. PPPOT-T and PPPOT-IC Eline: 6. Set cast iron bridge plug at ~9,815’ to isolate Lisburne perforations. 7. Pressure test bridge plug. 8. Dump bail 25’ of cement on bridge plug. 9. Cut 4-1/2” tubing at ~9,570’. 10. Circ out well to 8.4ppg 1%KCl with diesel freeze protect on tubing and IA. DHD: 11. Bleed WHP’s to 0 psi. Valve Shop: 12. Set and test TWC. 13. Nipple Down Tree and tubing head adapter. Inspect lift threads. 14. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. CBL shows TOC on 9-5/8" casing at 6920' MD showing isolation for the PB oil pool from zones above. - Original cement job on 7" intermediate and 4-1/2" production liners recorded plugs bumped and excess cement returned from TOL's. No losses, good lift pressure, 1:1 returns. Liners should be fully cemented. CBL and USIT were run to verify. Lisburne injector to an Ivishak Producer. mgr 30 minute charted test. 24 hour notice for state to witness tag and pressure test to confirm isolation of pools. RWO LISB 04-350 PTD:211-106 Proposed RWO Procedure: 15. MIRU Thunderbird #1 Rig. 16. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Thunderbird #1 BOP test procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8” x 5-1/2” VBR’s with 4-1/2” test joint. Test the Annular preventer with a 4-1/2” test joint. e. If a workstring run is required, stop and test VBR’s and annular with a 2-7/8” test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 17. Pull TWC (utilize lubricator if pressure is expected) 18. RU control line spooler. 19. MU landing joint or spear, BOLDS and pull hanger to the floor. Circulate bottoms up with 8.4ppg KCl. a. Expected PU weight in 8.4ppg KCl = 105k # b. Tensile Strength of 4-1/2”, 12.6# = 288k # (may be de-rated based on caliper results) c. TC-II Connection strength = 288k # 20. Pull existing 4-1/2” tubing from cut. 21. Run 4-1/2” 13Cr tubing gas lifted completion as detailed on the proposed schematic. 22. Land hanger and reverse in corrosion inhibited 8.4ppg KCl. 23. Drop ball and rod and pressure up to set packer. 24. Perform MIT-IA to 3,000 psi for 30 charted minutes. 25. Shear valve in top GLM. 26. Set TWC. 27. Rig down Thunderbird #1. Post rig valve shop work 28. ND BOPE. 29. NU tree and tubing head adapter. 30. Test both tree and tubing hanger void to 500psi low/5,000psi high. 31. Pull TWC and freeze protect to ~2,500ft with diesel. Post rig Slickline Work 32. Pull Ball and rod and RHC profile. 33. Set gas lift valves. 34. Drift and tag TD for perforating guns. Post rig Eline Work 35. Add target Ivishak perforations. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing Add target Ivishak perforations. RWO LISB 04-350 PTD:211-106 Current Wellbore Schematic RWO LISB 04-350 PTD:211-106 Proposed Wellbore Schematic RWO LISB 04-350 PTD:211-106 RWO BOPs RWO LISB 04-350 PTD:211-106 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, September 10, 2020 Jim Regg �] P.I. Supervisor I � 1 �� 1 �� SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 04-350 FROM: Bob Noble PRUDHOE BAY UN LIS 04-350 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS 04-350 ' API Well Number 50-029-23453-00-00 Permit Number: 211-106-0 Insp Num: mitRCN200811130258 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 8/10/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min `dell 04-350 Type Inj w TVD 8832 Tubing 2203 _ 2203 2201 2202 - PTD L 2111060 - Type Test SPT"fest psi 2208 - IA 31 2872 - 2822 2799 - BBL Pumped: 6 - BBL _ Returned: 6 OA 343 759 759 - 755 - Intervall� 4YRTST jPIF P Notes: Thursday, September 10, 2020 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:211-106 6.50-029-23453-00-00 PRUDHOE BAY, LISBURNE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10323 10234 9306 None None 8435,8832,8931 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 151 Surface 3838 13-3/8" 41 - 3879 41 - 3779 5020 2260 Intermediate 9232 9-5/8" 38 - 9270 38 - 8571 5750 3090 Liner 768 7" 9098 - 9866 8426 - 9042 7240 5410 Perforation Depth: Measured depth: 9862 - 10112 feet True vertical depth:9039 - 9217 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 36 - 9713 36 - 8930 9587 8832Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 619 4-1/2" 9703 - 10322 8922 - 9372 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9373 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing5 Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028324 LISB 04-350 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 9109,9587,9715 55 By Samantha Carlisle at 8:48 am, Sep 01, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.31 11:20:35 -08'00' Bo York RBDMS HEW 9/1/2020 DSR-9/1/2020 SFD 9/1/2020MGR04SEP2020 ACTIVITYDATE SUMMARY 8/15/2020 T/I/O=2200/320/570 Temp=70* Acid Treatment (ACID) Pumped 30 bbls 3%KCL w/ Musol, 60 bbls 15% HCL acid, 22 bbls VDA, 65 bbls 15% HCL, 4 bbls neat methanol, 39 bbls 3%KCL w/ Musol, and 183 bbls 3% KCL down Tbg for Acid job and overflush. Witness injection pressure slowly breakover during tail end of acid treatment in perfs. DSO to POI. FWHP's=1200/1270/780 SV,WV=C SSV,MV=O IA,OA=OTG Daily Report of Well Operations PBU 04-350 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY David Wages Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU 04-350 Permit to Drill Number: 211-106 Sundry Number: 320-054 Dear Mr. Wages: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W Wxv.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, V. J re M rice C air DATED this�day of January, 2020. RBDMS ±JAN 3 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Vin.,^�F+•, w,�..q rrorav ,r KRA ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. t zy. Submit Form and Attachments in Duplicate i. Type of Request: Abandon ❑ Plug Perforations ❑ FractureStimulate ❑ Repair Well ❑ Operationsshuttlown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 r Pull Tubing ❑ Change Approved Pr5gram ❑ Plug for Retlrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other "'- ` - - "-.' ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 211-106. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ 6. API Number. 50-029-23453-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04-350 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028324 PRUDHOE BAY, LISBURNE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10323 9373 10234 9306 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 151 20" 42-193 42-193 Surface 3837 13-3/8" 41 -3879 41 -3779 5020 2260 Intermediate 9233 9-5/8" 1 38-9270 38 - 8571 5750 3090 Liner 768 7" 9098 - 9866 8426 - 9042 7240 5410 Liner 619 4-1/2" 9703-10322 8922-9372 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9862-1 0112 9038 - 9217 4-1/2" 12.6# L-80 36-9713 Packers and SSSV Type: 4-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 9587/8832 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: February 25. 2020 15. Well Status after proposed work: Oil ❑ WINJ 0 WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ O ❑ P Shutdown Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Contact Email: DaVId.Wagesablocom Authorized Name: Wages, David Contact Phone: 907.564.5669 Authorized Title: Well I terventi ns Engm,$t '7 C%l Authorized Signature: '--' - Date: 112 -7 Z COMMISSION USE ON Y Conditions of approval: Notify CommissiBn so that a representative may witness Sundry Number: U1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other. RBDMS L�JAN 312020 Post Initial Injection MIT Reqd? Yes ❑ No ❑J/ Spacing Eception Required? ED No Ld Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date I KRA ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. t zy. Submit Form and Attachments in Duplicate David Wages M, C: 713.380.9836 0:907.564.5669 04-350 was drilled & completed in November 2011 as the first Lisburne periphery water injector in nearly 20 years. Early injectivity tests indicated the formation was tight but after a CT acid job injection rates improved considerably and in fact the well injectivity proved to be so high the well was unable to hold any injection back pressure at surface at the initial target injection rates of 2000-3000 bwpd. This required a downhole choke to be set in the lower X nipple to hold sufficient back pressure at surface to engage the low pressure pilot. This downhole choke was upsized to 0.55" in November 2014 when the injection target changed to 5000 bwpd and then removed completely in August 2015. However, holding a target water injection rate of 5000 bwpd has proven elusive, the most effective means to boost ✓ injectivity appears to be via acid stimulation. 2/25/2016: pumped roughly this schedule, boosted injection from 3109 bbls @ 2030 psi to 6000 bbls @ 1890 psi — Latest MIT: AOGCC MIT -IA PASSED to 2500 psi (9-2-2016) No Recent Caliper, Memory gauges will be pulled prior to acid job. 04-350 Fullbore BullheadAcid Stimulation Job design considerations • 15%i}Qchosenover EmulsifiedAcid(SXE) due tolow BHT. The reaction rateofEmulsifiedacid would be slowed down to a point that would not allow for WWXa4,Fatodevelop. • Self -diverting acid (VDA) withoutfibers chosen for diversion due to low BHT. The fibers could take months to breakdown at low temperatures. • No MIT -IA required. Casing was previously tested (MIT -IA to passecito 24DO psi on 7/10/12) Pre -lob • Freeze Protect flowline then pump stimulation within 24 bawhile the formation is still charged up. This will keep that fracture gradient elevated thus providing a greater maximum allowable stimulation treating pressure at matrix rates. • Coordinate with ops to put well back on injection postjob Pressures • PT hardline to 4000 psi • Pump at matrix rates, defined as less than 2400 psi treating pressure • Maximum allowable treati ng pressure= 3500 psi o Only treat above 2400 psi to achieve the WjQVW_4M2 bpm pump rate • Pump trips= 3500 psi Pump Schedule State Rate Stage Cum. Fluid Volume Volume [bpm) [bbl] [bblj 2 2-5 60 90 15%j 3 2-5 20 110 2096 VDA d 2-5 60 170 1516 5 2.5 30 200 396, 6 2-S 135 33S 3%j(, 7 2-5 30 365 60/40 M9,,Qd Max PressureCommenti (psi) 2400 RSI&VZ�w/1096p0j" 2400 Main Acid 2400-r ' Acid 2400 Main Acid 2400 Q, J w/10%,q7j" 2400 Displacement 2400 Freeze Protect TRFF = 4-1116" CAN WELLHEAD= FMC ACTUATOR= BAKER C OKB. ELEV = 70.08' BF. ELEV = 31.81' KOP = 240' Max Angle = 45" 9860' Datum MD = 97.67' Datum TVD= 8900' SS 20" CONDUCTOR 154#, X-53, ID = 18.500" 793' 13-3/8" CSG, 68#, L-80 BTC, D = 12.415" 3879' - TOP OF 7" LNR 9099' Minimum ID = 3.725" @ 9696' 4-1/2" HES XN NIPPLE 9-5/8" CSG, 40#, L-80 HYD 563, D = 8.835" 9270' 4-12" TBG, 12.6#, L-80 TC -1 1, .0152 bpf, D = 3.958" TOP OF 4-1/2' LNR ' LNR, 26#, L-80 VAMTOP HQ 383 bpf, D=6.276" PERFORATIONSUMMARY REF LOG: SLB-HNGRS LOG (11/08/11) ANGLE AT TOP P971=: 45" @ 9862' Note: Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sgz SHOT SQZ 2-12" 6 9862-9876 O 07/18/18 BK BK 3-3/8" 6 9876-9924 O 02/19/12 3-3/8" 6 9942-9976 O 02/18/12 2-12" 6 10067-10077 O 07/18/18 2-112" 6 10102 -10112 O 07/18/18 PB1D 10234' t, 12.61t, L-80 BT, 10327 D = 3.958" 04-350 SAFETY NOTES: "FESX NP, D=3.81; GAS LIFT MANDRELS ISTI MD I ND DEV TYPE VLV LATCH POR! DATE 2 1 1 3580 4983 1 3504 4758 20 28 KBG2 KBG2 OMY DMY BK BK 0 0 02/05/12 11/18/11 WIDXI-� 1 9521' 1 1 9557 1 1 9713' 1 DATE I REV BY I COMMENTS DATE REV BY COMMENTS 11/19111 0-25 INITIAL COMPLETION 08/19/15 SJWIJMD PULLED DH CHOKE (08/09/15) 08/10/12 PJC CHOKE CORRECTION 0724/18 KFM/JMD ADPERFS (07/18/18) 08/11/12 FP/PJC PROD LINER CORRECTIONS 012020 CJN/JMD SET X -LOCK W1 MEMORY GAUGES 10/02/12 MSS/JM PULLED & RESET CHOKE (0929112) 012720 MLIJ —MD ADDED BF & COND DEPTH 0620/13 DJS/JMD PULLED & RESET CHOKE (06117/13) 11/15/14 JMG1 PJC RUN CHOKE ASSEMBLY -518"X 7" BKRZXPN LTP, /10' TIEBACK, D=6.180" -5/8" X 7" FLEX LOCK HGR; D = 6.220" 12" HES 1/2"SGM-NDPG-CA NGLE DROP SUB, D = 3.958" X 4-12" HES TNT PKR, D = 3.856- 1/2" HES 12" HES XN NIP, ID = 3.725" 12' XLOCK w! MEMORY GAUGES (01/1 TIEBACK SLV (10'), D = 5.25" X 5- BKR HRD-E-ZXPN LTP, D = 4.19" 12" WLEG, [)=4.00" MD NOT LOGO X 5" BKR FLEX LOCK HGR, D = 4.22- X 4-12' XO, D = 3.958"' PRUDHOE BAY UNIT WELL: 04-350 PERMITNo:r2111060 APINo: 50-029-23453-00 T11 N, R1 5E, 237' FSL & 397' FWL BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,September 07,2016 P.I.Supervisor e"'/(t Ile" SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-350 FROM: Chuck Scheve PRUDHOE BAY UN LIS 04-350 Petroleum Inspector Src: Inspector Reviewed By:,�-p P.I.Supry Jb"---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS 04-350 API Well Number 50-029-23453-00-00 Inspector Name: Chuck Scheve Permit Number: 211-106-0 Inspection Date: 9/2/2016 Insp Num: mitCS160902153757 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-350 -jType Inj W'TVD 8832 ' Tubing 1960 - 1970 - 1960 - 1960 - PTD 2111060 'Type Test SPT Test psi 2208 - IA 0 2690 ' 2624 - 2604 - Interval 4YRTST P/F P ✓ OA 518 908 - 907 901 - Notes: Wednesday,September 07,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Monday, August 22, 2016 5:09 PM To: AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy;Worthington, Aras J Subject: OPERABLE:Injector 04-350 (PTD #2111060) POI post-seawater line repairs All, Injector 04-350 (PTD#2111060)was shut in as a result of seawater line repairs. While shut in its AOGCC-witnessed MIT- IA expired and was reclassified as Not Operable. The well is now reclassified as Operable and can be POI. Once injection has been stabilized an AOGCC-witnessed MIT-IA will be performed. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent MO NOV 0 8 2016 W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK,._GWO SUPT Well Integrity Sent: Sunda ,July 10, 2016 7:33 PM To: AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector 04-350 (PTD #2111'060) Will Remain Shut In Past AOGCC Test Due Date All, Injector 04-350 (PTD#2111060) is due for an AOGCC-witnessed MIT-IA b th nd of July.The well will not be brought Y � Y g online by then due to seawater line repairs and facility turnarounds, expected to be completed in August 2016.The well is reclassified as Not Operable. Thanks, • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 10, 2016 7:33 PM To: AK, OPS FS2 OSM;AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL;AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: NOT OPERABLE:Injector 04-350 (PTD#2111060)Will Remain Shut In Past AOGCC Test Due Date All, Injector 04-350(PTD#2111060) is due for an AOGCC-witnessed MIT-IA by the end of July.The well will not be brought online by then due to seawater line repairs and facility turnarounds,expected to be completed in August 2016.The well is reclassified as Not Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 soma) EC 0 5 2C16 H:2376 Email: AKDCWellintegrityCoordinator@BP.com 1 STATE OF ALASKA II/ALASKA OIL AND GAS CONSERVATION COMM! N • REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon ❑ Plug Perforations LI Fracture Stimulate ❑ Pull Tubing LI Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate I?J Alter Casing 0 Change Approved Program 0 s Plug for Redrill CIPerforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: `� c1-a 511.1,:kv Ly 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 211-106 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory [11 AK 99519-6612 Stratigraphic 0 Service O 6. API Number: 50-029-23453-00-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number LISB 04-350 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL/PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10323 feet Plugs 9s measured feet true vertical 9373 feet Junk measured feet RECEIVED Effective Depth: measured 10234 feet Packer measured 9588 feet MAY 0 5 2016 true vertical 9306 feet Packer true vertical 8832.44 feet Casing: Length: Size: MD: TVD: Burst: Aocc Structural Conductor 151 20"1544 X-52 42-193 42-193 Surface 3837 13-3/8"68#L-80 42-3879 42-3780 5020 2260 Intermediate 9233 9-5/8"404 L-80 38-9271 38-8572 5750 3090 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9876-9884 feet feet 9884-9904 feet 9904-9924 feet 9942-9956 feet 9956-9976 feet True vertical depth: 9049-9055 feet feet 9055-9069 feet 9069-9083 feet 9096-9105 feet 9105-9120 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.64 L-80 36-9714 36-8930 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUIN 2 1 ZUIS 9876'-9924',9942'-9976'. Treatment descriptions including volumes used and final pressure: 20 Bbls 20%VDA Acid,160 Bbls 14%HCL Acid,195 Bbls 2%KCL,38 Bbls 60/40 Methanol/Water,2010 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 3109 40 2030 Subsequent to operation: 5989 40 1886 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development 0 Service El Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP LI 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: 316-056 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature _Act,f�c.{`,ti CL — Phone +1 907 564 4424 Date 5/4/16 Form 10-404 Revised 5/2015 V TL 579 Pc. RBDMS A/ MAY 0 6 2016 Submit Original Only • • a 0 0 0 0 Corno — N . oCO N CO if) N- I- U 0 0 0 0 0 L N V co M m O LU N- CO CO M O N N M O O CO I, ti CO I"- U') O CO 61 Cr) CO O (g) CO H CO CO N N O N N Cfl vcr V CO V' O CO CO CO I— C M a7 O ? CO r CO N CO MO CO 6) 6) 6) V 4-0 0 M •.:1- N N CO 6) O CO d- V CO O N- 0) C_ M0 6) 6) O O J (NI F,0) co co J i co O J J = d (0 CO C A N (10 4 N N U) O co _ U co -00 - O Ch N N Ncrj co co co 67 N- a Ln co N O ' CO J co 6) ~ O 6) W LL H >a O — C F w o .111 U D Q W 0 UoLI_ W W WZ Z c W w w O D H Z_ Z D U) Z J J • • Packers and SSV's Attachment LISB 04-350 SW Name Type MD TVD Depscription 04-350 PACKER 9108.7 8434.95 7" Baker ZXP Top Packer 04-350 TBG PACKER 9587.66 8832.44 4-1/2" HES TNT Perm Packer 04-350 PACKER 9714.8 8931.03 5" Baker ZXP Top Packer . • I I $ \ - f U � CD I .2 a + / R Lo% f \ # R 0 -3E k \ f/ / < k § > 7 > a) co E % / g u) to 9 � / C 0 o 2 f o >- < a & E L. 2 > f ( % E ak cti> B ® O o / % I £ / 0 i I .-coet E ƒ 44 \ � / 0 C $ e t � ƒ 02 o —1 co R 6 0. kw $ = \ ■ o c n Ti Ce / - 7 7 E - a �� o_ a) / .CIS g ._ / )gCI CD_ k E \ \ 9 f mn 0 IL 9 = \ y0 $ \ f •. / A/ � U - kƒ y7 E60& s2 > I0o } / / / 1 : / / \ / L 0 ,- / / o � .- . � \ CN < TREE=, 4-1/16'CfW 11- S NOTES: VV91541: FMC ACTUATOW BAKER C 04-3 50 6KB.BEV= BF.B.EV 29.48 KOP= 240"- Max-Angle= 45",,9860' 2147' —cir2-G:Essun.XhIPMA,C w=3,81 s3" Datum PAD= 9767' Dat UM TVE ----8906 §S 20"CONDUCTOR 154#, X-53,ID=18.500" —f —194 ST PA) TVD DEV TY F VLV LATCH PORT DATE 13-3/8"CSG,68#,L-80 BTC.1.)=12.415' I— 3879' ...-4 2 3580 3504 20 KBG2 DON BK 0 02/05/12 1 4983 4758 28 KBG2 DMY BK 0 11/18/11 9098' —9-5/8"X 7'BKR ZXPN LIP, TOP OF 7'LNR — 9098' /10'TEBACK,U=6.180' 9114' —,9-5/8-X 7"R_ID(LOCK HGR, =6220' Minimum ID = 3.725" @ 9696' 4-1/2" HES XN NIPPLE 9-5/8"CSG,40#,L-80 HY D 563,1D=8.835" — 9270' 11 9521' —4-1/2"FES X 1,313, =3,813" 9552' —4-1/r SGM-NOPG-CA SINGLE DROP SW, =3.958' PC 9587' j—7"X 4-1/2"HES TNT FKR,ID=3.856' • 9624' —4-1/2'FISS X MR D=3.813• " 9696' —4-1/2"FES XNNIP, =3.725" 4-1/2"TBG, 12.6#,L-80 TC-11, H 9713' .0152 bpf,ID=3.958" — 9703' —1 7'TEf3ACK SLV(10), =525' TOP OF 4-1/2'LNR — 9713' 9713' —7'X 5"BKR HRD-E-ZXPN LTP, =4.19' 7'LM,26#,L-80 VAPATOP HC, — 9866' 1.0383 bpf,13=6.276" 1'{ HELMD NOT LOGGED 99771139'. --4-7.1/757E9 BKR IDE:41W HGR,ID=422' 9734. —5'X 4-1/2-X0, =3.958— PERFORATION SUPAAARY REF LOG: SLB-I-MRS LOG(11/08/11) ANGLE AT TOP PERE:45°@ 9876' F'bte.Refer to Production DB for historical perf data SIZE SF F INTERVAL Cpn/Sqz SI-10T SQL 3-3/8d 6 9876-9924 0 02/19/12 3-3/8" 6 9942-9976 0 02/18/12 R3TD — 10234' •••I•*4 0**0* •••• 4-1/2"LNR, 12,6#, L-80 — 10322' 4•61164 .0152 bpf, =3.958" DATE RB/BY COMMENTS DATE I. BY COMENT'S PRUDHOE BAY UNIT 11/19/11 D-25 IMT1AL COM PLET1ON 08/19/15 SJWIJMCi PULLED OH CHOKE(08/09/15) WELL: 04-350 08/10/12 PJC CHOKE CORRECTION FERMI No: 2111060 08/11/12 FP PJC PROD LIkER CX)RRECTIONS AR Fb 50-029-23453-00 10/02/12 PASS/Jki FULLED&RESET CHOKE(09/29/12) SEC 26,T11N,R15E,237'FSL&39T FWL 06/20/13 WS/MD FU_LED&RESET CHOKE(06/17/13) 11/15/14'JPAG/PJC RUN CHOKE A SSEM3LY BP Exploration(Alaska) • 2tt—�o� tiOF T� • 0)s\\I%7 kv THE STATE Alaska Oil and Gas , of/\ L /\ Conservation Commission si.(A. 333 West Seventh Avenue = GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFALASY'� 1 ?1�,h Fax: 907.276.7542 Main: 907.279.1433 to _ I I ` www.aogcc.alaska.gov Mark Sauve Lisburne Lead Petroleum Engineer O BP Exploration (Alaska), Inc. 1, 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, LISB 04-350 Permit to Drill Number: 211-106 Sundry Number: 316-056 Dear Mr. Sauve: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy :. Foerster Chair DATED this 3 day of February, 2016. RBDMS 1,'- FEB 0 4 2016 kiECEIVED E •ALASKA OIL AND G STCONSERVATION COMMI ION APPLICATION FOR SUNDRY APPROVALS JAN 2 7 2016 20 AAC 25.280 or 1'�2/?/) 1. Type of Request: Abandon ❑ Plug Perforations ID Fracture Stimulate ❑ Repair Well ❑ o Seat n shhutdown El Suspend ❑ Perforate ❑ Other Stimulate O. Pull Tabing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other a,-,•ci 5 r.,»,+ b 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 211-106 - Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 3. 6. API Number: 50-029-23453-00-00 99519-6612 Stratigraphic ❑ Service 0- 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes El No II LISB 04-350 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028324 ' PRUDHOE BAY, LISBURNE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10323 . 9373 - 10234 9306 - Casing Length Size MD TVD Burst Collapse Structural Conductor 151 20"154#X-52 42-193 42-193 Surface 3837 13-3/8"68#L-80 42-3879 42-3780 5020 2260 Intermediate 9233 9-5/8"40#L-80 38-9271 38-8572 5750 3090 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 36-9714 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic g 13.Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service El 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ 0 - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned El 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sauve,Mark A be deviated from without prior written approval. Email Mark.Sauve@bp.com Printed Name Sauve,Mark A Title GPMA/Lisburne Lead PE Signature /_4,..,..-1,4_.. .____ Phone +1 907 564 4660 Date J—2 2-/6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\Le - oLe Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ No ❑ Spacing Exception Required? Yes❑ No 1. Subsequent Form Required: /0— 4 0 4- APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: Z _3./6 rt //z, /6G ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS 'L FEB 0 4 2016 ._.-- /:2-7 / .., • a o O O o O co Cc.Orn :Tr FA IS C N CO (f) N N- U y o 0 0 o O i N (t) - CO CO 7 O N CO M) (n N. CO 00 M O NNM O CO N- CO LO O CO O) CO 00 C7) 0) CO CI I Co co N N CO N N CO 'Cl" CO "Cr O co 00 CO C V O N N CO M CO N 00 f` `- M (7) (7) O (7) V LO4- (7ct M )N N 00 (7) O (0 • v• N' `Cr CO Cl f� _C rn 0) XI 03 • Cn O O O O N CO M CO CO J J CO X 4t J J • C) co J O (O O fn () V CO N- 00 '&) N _ U CO =LO N N N M CO M 0) • (n CO M () N- JC co cy) 0) W E— <-- • O• W • U W co D U O L CC CC CC Z Z W W W O J ~ Z Z D • U) Z J J • • a) N f6 m Lo LO co CO O CO LO ca S\01 LO O O ,-,a) „cc) p rn O 0) H 0 F cn Lo cn cn oo O LC) Ni- t. oo cc; In In 0 O 0 c 0 0 > Q 0) (3) 0) 0) 0) 0 w a w p• p co z H w0 w g g J o "' N Y U O mW Y Y F 0 U w w vr++ a co O N CO CO J J J d w o z Q 0 0 w CI 0) 0) 0) 0) 0) z zE z o -' p J N 0 1-1 a a w a 0• 0 0 w 2 aez O z L1 2 2 2 O co co c co U¢) M aa1- O C r - o rn rn rn rn rn — CU J co O - U) CC = H I- Ci) a 2 2 2 O U) co co co co w a 0 U .2 El m Y Y Y Y Y a) 00000 a 0 a) m a d H w � o cn Ln cn Lo 0 O C o 0 0 0 0 w Z • N N N N N Z 1 1 Q w a) a) a) a) O W JJ 0 JJ W p W LL Es a) a) a) a) a) z a J 0 w w LL w a• a000aoo O m p Y Y W J J 1 < < oa � cn u 1LO W a a d E Z o 0 co 0 0 10 10 10 10 C7M CO CO CO co 4w a U O LL N 2 LL v V 4 V CO a a MO -100010- a CD C3 C3 CD < < CO m a E cn (n a s • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 04-350 Well Type: Water Injection Well API Number: 50-029-23453-00 Well Activity Conventional 4 Classification: Activity Description: Bullhead Acid Stim Cost Code/AFE: APBINJEC Field/Reservoir: LISBURNE 12 Month Avg IOR, bopd: Job Type: Acid-Bullhead Estimated Cost, $K: AWGRS Job Scope: ACID Other regulatory requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Mark Sauve Contact numbers: (907) 564-4660 (907) 748-2865 Well Intervention Engineer: Jerry Lau Contact numbers: (907) 564-4090 (907)360-6232 Lead Engineer: Mark Sauve Contact numbers: (907) 564-4660 (907) 748-2865 Date Created: January 20, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injectior Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 1/13/2016 3,205 2,045 Current Status: Operable Flowing Inclination>70°at Depth(ft) Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 45° 9,861' MD — Datum depth,ft TVDss 8,900' TVDss Dogleg Severity(Angle and Depth) 4° 3,516' MD Reservoir pressure(date, psig) 10/8/2014 3,377 psi Minimum ID and Depth 3.725" 9,696' MD Reservoir Temp,F 100° F Shut-in Wellhead Pressure Known mech. integrity problems(specifics) Last downhole operation(date, 8/9/2015 Pull DH choke from nipple @ 9521' MD. operation) Most recent TD tag (date,depth, toolstring OD) 8/9/2015 10,149' MD Tagged TD with 3.25'centralizer. Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, 04-350 was drilled&completed in November 2011 as the first Lisburne periphery water injector in nearly background information, 20 years. Early infectivity tests indicated the formation was tight but after a CT acid job injection rates - etc: improved considerably and in fact the well injectivity proved to be so high the well was unable to hold any injection back pressure at surface at the initial target injection rates of 2000-3000 bwpd. This required a downhole choke to be set in the lower X nipple to hold sufficient back pressure at surface to engage the low pressure pilot. This downhole choke was upsized to 0.55"in November 2014 when the injection target changed to 5000 bwpd and then removed completely in August 2015. However, the target water - injection rate still proved elusive indicating a further drop in well infectivity or rise in reservoir pressure. • S Well Intervention Details Suspected Well Problem: Low well injectivity Specific Intervention or Well Objectives: 1 Stimulate well and achieve target injection rate of 5000 bwpd. 2 3 Key risks,critical issues: Mitigation plan: 1 Pumping Acid Refer to RP:Acidizing 2 Hydrates Freeze Protect flowline from manifold building 3 Summary Step# Service Line Activity 1 F Freeze Protect Flowline 2 F Bullhead Acid Stimulation. 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 F Freeze Protect Flowline 2 F Bullhead Acid Stimulation (see attached detailed proceedure) 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI (bfpd/psi dp) Post job POP instructions: Put back on Injection ASAP Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: S • TREE- 4 MG'CAV WTY NOTES ia.±1-16s.C. MC 04-3SAFE 50 1 ACII AIN,- HAW-14 , 01(13 IILV- 70 08'' pir R Pd= 79 46 i i I KOP= 240' ) —t Nkkx A !le- ib"0 6860' / I 2147 —F-1/2'1123 X Pr,C-3 81371 Datum PAD- 9757' / arum WI). 8900 s-..; / ,_..._., G GAUT 1.4A113-51.3 PM mtrxx.ILAIA IF.* x-ro,in-Ia sax 1—: -194 1 Fil 1613 !VI) 111-V Iv V 3/1V AICI-I li*it DAIi WV 1--40 L 2 3580 35C4 20 Kf3G2 CAIY BIK 0 02/05,12 1 4%3 47F,8 20 KE3CQ [MY BOK 0 11)1011 .../.1 9098' 19 5.16"x r ercR zxmi LTF I I To P oF T-ori — scow I w 110 IEBAIX,V.6 180' Minimum ID la 3.725- 9696' i I 9114 H - X 7^F FX I CO(HC.R.113-fi 770- I 4-1/2"HES XN NIPPLE 9-W CSG,408,L-80 KY 0563,0-8.53r 1-4 9270' j 116 i r1 9621' —14-We 14±.-X W L=3 8137-1 9- 9552' 4-1/2'5CIANUIG-CA Sittil F MOP S,K1 U)7 1 95Y a 25-1 9587' I I 9624' H4-1i2"WS X F8',.C-3 813" I I 9606"-1-14-1/2-ItS MM.U nv 4-12°11:IU,12_11,L-80 IC-11, —. 9713' .., 0152 bpf.D.3.955' N. 9709' Hr TACK SLV(1ol,I)-525 l I 70POF 4-02'Urn —1 97 ' I 1 c. 1713. _J7'K A.nkn t ran,r-.7xrN I TT,II-1 •1) -1 9713' F-14-1/2"%LK:,V=4 OW I I H13.143 Nor Lo.3GEo I 7*UR 284,,L40 vAmmr i-c, — 9886' L 1711' --7'X s'Illat'I nr I rir.K 11(47 II"3-4 27, I 038:!OW 0=129r 6, 9734' —0'X 4-Irr A0.47-3.1M" I 1,14414 VIA NON Kl11.0"141' F4+I OCi :4 3 I I,4i1Ci I 00(110u611) ANGLE A!TCP PEPE 45'0 90178' Nose Refer to Pwas.icsior C.18 fo•hiskwica,per(czta SWF Eza P41114VAI Oprekv 3111(31 SW' 0 678-5 9924 0 OV19/12 3- '4 6 E942-9973 0 02119,12 1 HAW— 10234' , 444•1110.441 41.4.10,1,41,4 4-1/2'LW tz.88,L-80 lb I. 1 0321" 0152 NA D=3955' neaF 'IS'.'Iv' croasairs MTF 'iv me avAcurS Many AY 1.14T 11119,11- 0-215 IIITIAL COMPLETION 0/1/18/'5'SJVC1111 RI Fr)no a IOW(01V14(15) 1 1/44 I 01-150 181/10/17 PIC (141KFOORRFCTICIN I aFFAAT No. 711 10A111 milieu' -II PJC MILE LPI±coraibci Ports dui m::. E0-029-23453-00 1110012 Mu JP.0 RA.LLC&REM/TUCK((09/29/12) 5CC 26,711N R15C 237 I-GL&397'Pe91_ 0e.aw11 CUS.310R1LLII&RGSE7 CI OKE(06117/13) 1 ^1115714-Al&PJC`FIJNC9OICEASSZMILY SP&coloration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 41 I - 1 04) Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: o r Items: ❑ Ma s: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: 1112 BY: Maria Date: .W f lsl Project Proofing BY: AI. Date: uI. r /s/ PI ID Scanning Preparation 4- x 30 = cg0 + 7 = TOTAL PAGES /a q (Count does not include cover sheet) ryi BY: Maria Date: i69 /s/ __) Production Scanning Stage 1 Page Count from Scanned File: /3O (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 410. Date: v I 61/11+ /s/ fff 1 jO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o M 9 o O % c,1O w r cy O Q O N 6" N c a) a) 0 = a) tn -to0 C7 O a a) 7 _T N co N >• N O '0 Vy u) > a a) N ,co '� O) + a) O) a) U >. T _ y N 0 O J p N a J E E 'C C o) N ( CC m t J 'U ~ a a a E >. 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E z aai N• a) , W ci mu 0 o Id d d J co z Q o o I Z Co. 0 w UV� 0 0 `0 \ o a) c.) m J o 0 a m C7 E U O v' oI LL af°i y O y 0 0 0 0 0 0 0 a I d Z o o m 0 o a) 0 O a 2 W J W J W W W _ 0 a 0 0 0 a: 0 M O 1 O O I 1 eq O H ri MO N M } N d _ r/ a o) U I m C 0 Z F. Q z_ QZ• e' Y a,. rN J u) 0 ce Q N O z EL O U WO Ce J a W W z U m 5 I Z Qea N J a f0 C O U11 c M o G — O 0 N n OM of C) �, o O o N J M ai Q c aoa ti - _ z ZSN 5 G/�/� Q W m r O a) U) I N 0 Q � `s l'' a) a) Q c a ' E -01 U 00 z m 3 n Ii M 1 m 11 03 O O 'O N 3 to.; N N i N a' O CN O o C U a C7 E 0 oE 0 a 2 0 a4- 350 1")N6 z-it IO(00 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, July 30, 2012 3:38 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA); Daniel, Ryan; Cismoski, Doug A Subject: RE: Missing MITs Attachments: MIT PBU 04-09,04-13,04-350 07-10-12.xls; MIT Z-116 3-26-12 .xls; 04-350 (PTD#2111060) iv- and Z-116 (PTD#) Injection Plots.xlsx; MIT 04-350 02-05-12 .xls Jim, Regarding the 2 wells that you note: 4.7 PBU 04-350(PTD#2111060) had an AOGCC witnessed MIT-IA completed 07/10/2012. The previous MIT-IA test on this was 02/05/2012. The well was shown to be on injection from May 5th-22nd, 2012 which was the initial injection since the completion of the rig workover finished 11/19/2011. When the well was brought on MaySth,there were suspected flow meter problems as the well indicated 2500 bbls per day with 0 psi injection pressure and was showing a flat line injection o the rate and pressure. Operations worked on repairing the flow meter from 05/05-05/22. At that time, an AOGCC MIT-IA was not planned until the well could show stabilization and scheduling with an inspector could be coordinated. The well was left shut in until completion of the Flow Station 1 turnaround and did not return to water injection on 07/02/2012. PBU Z-116 (PTD#2111240) has not had a witnessed AOGCC MIT-IA since it went to injection 05/15/2012. The last MIT- IA was performed on 03/29/2012 after well tests were completed while pre-producing the well and the gas lift valves were dummied off. While being produced from 03/19-22/2012, the well was classified initially as a "Producer" in our database system. After the completion of the production tests, the well was never reclassified as a "WAG Injector" in the AnnComm database. This failure, which was a human error on the Well Integrity Coordinator's position, which resulted in the well not being highlighted as requiring a MIT-IA for compliance in our reporting system. It has been corrected, and a review of the incident to insure no other wells are mislabeled in the system is taking place. The well has been scheduled for a witnessed AOGCC MIT-IA on Thursday(8/2), which is the first available time the slope inspector had. I have included copies of the MIT-IA's that were performed prior to injection for both wells, the current AOGCC witnessed test on 04-350, and an excel sheet with TIO and Injection data for the last 6 months for both wells for reference. I'm apologize for this error. Please let me know if I can answer any other questions or concerns regarding this matter. Regards, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Email: AKDCWeIIIntegrityCoordinatorCa�BP.com 1 From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Monday, July 30, 2012 11:47 AM To: AK, D&C Well Integrity Coordinator Cc: Wallace, Chris D (DOA) Subject: Missing MITs PBU 04-350(PTD 2111060); injected 18 days in May; unknown since. No record of MIT in our files PBU Z-116 (PTD 2111240); injected 17 days May, 26 days June; unknown since. No record of MIT in our files Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(cDalaska.gov; doa.aogcc.prudhoe.bav(rDalaska.gov• phoebe.brooksc alaska.aov; tom.maunderOalaska.aov OPERATOR: BP Exploration(Alaska),Inc. 1--<",./M (e)(1(17....- FIELD e)(I(1vFIELD/UNIT/PAD: Prudhoe Bay/PBU/DS-04 DATE: 07/10/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-09 Type Inj. W TVD 7,928' Tubing 1282 1262 1254 Interval 4 P.T.D. 1760300 Type test P Test psi 1982 Casing 334 2302 2258 P/F F Notes: 4 year AOGCC MITIA OA 631 843 924 IA took 4 bbls to pressure up.IA x OA noted,aborted MITIA Well 04-13 _ Type Inj. W TVD 8,195' Tubing 757 750 745 765 Interval 4 P.T.D. 1780310 Type test P Test psi 2048.75 Casing 505 2,410 2,354 2,331 P/F P Notes: 4 year AOGCC MITIA OA 458 390 430 571 IA took 4.7 bbls to pressure up Well 04-350 ' Type Inj. W TVD " 8,832' Tubing 213 _ 221 ' 217 217 ' Interval 4 P.T.D. 2111060. Type test P Test psi ' 2208"Casing 0 2,436" 2,366 2,351- P/F P Notes: 4 year AOGCC MITIA OA 97 268- 228 212 IA took 4.4 bbls to pressure up Well Type Inj. ND Tubing Interval • P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT PBU 04-09,04-13,04-350 07-10-12.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test . Submit to: jim.reggaalaska.gov doa.aogcc.prudhoe.bav(rDalaska.aov phoebe.brooks@alaska.gov tom.maunder(rDalaska.aov OPERATOR: BP Exploration(Alaska),Inc. <e1? C FIELD/UNIT/PAD: Prudhoe Bay/PBU/04 DATE: 02/05/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-350 ' Type Inj. N TVD 8,832' Tubing 200 500 500 500 Interval ID P.T.D. 2111060 ' Type test P Test psi ' 3000 Casing 214 3020 2980 2966 P/F P Notes: Initial injection MIT-IA OA 140 160 160 160 Well Type Inj. TVD _ Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Typelnj. 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 IN.'Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT PBU 04-350 02-05-12.xls McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) [Joseph.Lastufka@bp.com] Sent: Tuesday, May 22, 2012 1:55 PM To: McMains, Stephen E (DOA) Subject: PBU 04-350/PTD#211-106 Hi Steve, Please reference the following well: Well Name: PBU 04-350 Permit#: 211-106 API #: 50-029-23453-00-00 This well began Injection on: 5/15/2012 Method of Operations on this date: Water Injection 1 RECEIVED STATE OF ALASKA MAY 1 12012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing D Stimulate-Frac ❑ Waiver 0 Time Extension 0 Change Approved Program D Operat.Shutdown❑ Stimulate-Other X❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. DevelopmentdJloratory 0 - 211-106 3.Address: P.O. Box 196612 Stratigraphic[2 Service © 6.API Number: Anchorage, Alaska 99519-6612 50-029-23453-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 028324 PBU 04-350 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Prudhoe Bay Field / Lisburne Pool 11.Present Well Condition Summary: Total Depth measured 10323 feet Plugs measured NONE feet true vertical 9373 feet Junk measured NONE feet Effective Depth measured 10234 feet Packer measured SEE BELOW feet true vertical 9306 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 154# X-52 41'-118' 41'-118' Surface 3839' 13-3/8" 68# L-80 40'-3879' 40'-6450' 4930 1950 Production 9231' 9-5/8" 40# L-80 39'-9270' 39'-8571' 5750 3090 Liner 768' 7" 26# L-80 9098'-9866' 8426'-9042' 7240 5410 Liner 619' 4-1/2" 12.6# L-80 9703'-10322' 8922'-9372' 8430 7500 Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6# L-80 38'-9713' 38'-8930' 7" BKR ZXPN LTP 9098' 8426' Packers and SSSV(type,measured and true vertical depth) 4-1/2" HES TNT PKR 9587' 8832' 4-1/2" BKR HRD-EZXPN LTP 9703' 8922' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI SI SI Subsequent to operation: SI SI SI 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 1T1 — Stratigraphic 0 Daily Report of Well Operations 16.Well Status after work: . Oil ❑ Gas ❑ WDSPL❑ GSTOR p WINJ X❑ WAG p GINJ ❑ SUSP p 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: Contact Nita Summerhays Printed Name Nita Sum ; =ys Title Petrotechnical Data Technician Signa 0.-//rAri ,�,�� _,.��. Phone 564-4035 Date 05/10/2012 RBDMS MAY 14 101 _j _ Sia4� Form 10-404 Revised 11/2011 q ' Submit Original Only TREE= 4-1/16'CMV WELLHEAD= FMC SAF .Y NOTES: ACTUATOR= BAKER C 04-350 Ofd.KB.ELEV= 70.08' ORG, BF.ELEV= 29.48 I KOP= _ 240' Max Angle= 45'@ 9860' Datum N®= 9767' I 2147' —{4-12"HES X NIP, ID=3.813" Datum TVD= 8900" SS GAS LIFT MANDRELS 1 20"CONDUCTOR, 154#,X-53, ID=18.500" — —194 ST MD TVD DEV TYPE VLV LATCH PORT DATE ' 2 3580 3504 20 KBG2 DMY BK 0 02/05/12 13-3/8"CSG,68#,L 80 BTC,ID=12.415"' H 3879' r 1 4983 4758 28 KBG2 DMY BK 0 11/18/11 9098' —9-5/8"X 7"BKR ZXPN LW, TOP OF 7"LNR —I 9098' L r w/10'TIEBACK, ID=6.180" Minimum ID = 3.726" @ 9696' T 9114' —{9-5/8"X 7"FLEX LOCK I-IGR, ID=6.220" 4-1/2" HES XN NIPPLE 9-5/8"CSG,40#,L-80 HY D 563,ID=8.835" —I 9270' I. II , 9521' H4-1/2" HES X NIP, ID=3.813" • 9552' —4-1/2"SG%NDPG-CA SINGLE DROP SUB, ID=3.958" E zr { 9587' —17"X 4-12"HES TNT PKR, ID=3.856" 9624' —14-12" HES X NIP, ID=3.813" I ' 9696' —4-12"HES XN NIP, ID=3.725" TOP OF 4-1/7 LNR —+ 9703' 9703' —17"X 4-1/2'BKR HRD-EZXPN LTP 4-12"TBG, 12.6#, L-80 TC-11, --I 9713' w/FLEX LOCK LNR HGR,ID=4.190" .0152 bpf,ID=3.958" 9713' --14-1/7'WLEG, ID=4.00" H ELMD NOT LOGGED 7"LNR,26#, L-80 VAMTOP HC, — 9866' 1 ---41 , .0383 bpf, ID=6.276" PLHFORATION SUMMARY REF LOG: SLB-HNGRS LOG(11/08/11) ANGLE AT TOP PERF:45°@ 9876' Note: Refer to R'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9876-9924 0 02/19/12 3-3/8" 6 9942-9976 0 02/18/12 PBTD H 10234' 41114 14444444444 4-12"LNR, 12.6#,L-80 IBT, —I 10322' ,11404444 .0152 bpf, ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/19/11 D-25 INITIAL COMPLETION 01/07/12 LEC/PJC GLV C/O(01/06/12) WELL: 04-350 12/04/11 PJC DRLG DRAFT CORRECTION 02/09/12 JLJ/JMD GLV C/O(02/05/12) N±HMIT No:'2111060 12/06/11 DDG/PJC FINAL DRLG CORRECTIONS 02/19/12 JTC/JMD ADPERFS(02/18-19/12) API No: 50-029-23453-00 12/17/11 DOK!PJC TREE INFORMATION 03/28/12 MP/PJC DATUM MD CORRECTION SEC 26,T11 N, R15E,237'FSL&397'FVVL 01/06/12 LEC/PJC GLV C/O(01/04/12) 01/06/12 LEC/PJC GLV C/O(01/06/12) BP Exploration(Alaska) ■ CO22 © 2 CO 10 0) It) CO. al Cl. o r "I "3 -c co 0 cm a 0 > w p co U ■ ul v. v• © CO U) U) CO U) I- ■ o Tr o = ooro0) o) 0) 0) 0. 0 O mw k > 00 0 § w -I k k ea0) CDC0 � 2 ■ mR as .c n 0 0 U. a)O. � Wa. o. � N00 tn LWI- 00011.111.1 2 w w -I Q a 3 J 1- 1- m a � V) mm � CO � � W 4cc-ri4 0 2 = 1--- CO o 0 Q= CD 0) 0) 0) 0) 9 I- a J \ <40 C4 co ■ U. ■ CO � Q 0 i2 a & � $ $ 2kCOCO k0 Q w o M \ w ■ a) O 0 MIU Li. U. U. U. a'. ?x- Dw 00 iii C%1 a CO D—m V) — eopcoco ■ C) 0 g22 � o � w , c -6,-- zu. a QUU -I o0 w ce w % 2ao ° Q III2 0) < 0 0 0 -J -I 0 0 0 w a. 01022 _1 -Iwwwa O « « mm17: Er. 2220 E 0 0 0 0 0 2 10 ill iel MI io U. a@0 cem � ■ I mr U v1:1- Cl- C.) -I - - -I _ (1) 00000 et m 03 u_ LT 2220 04-350 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/21/2012;CTU 8. 1 3/4" 30 CTV Scope of Work: Acid Treatment :MU BHA, PT surface equipment. <<<Cont'd on 4-22-12 WSR>>>> 4/22/2012 CTU#8 w/ 1.75"CT(CTV=30.0) Objective:Acid treatment to put new welLoninjection.. Open swab, MV, SSV. RN with BHA: 1.9" ctc, 1.75" dfcv, 2 x 1.75" stinger, 2.1" crossover, 2.5"jet swirl nozzle. (oal= 9.35'). Tag © 10,208'. POOH above top perf @ 9870'. Pump 50 bbls of 90 degree F diesel down CT. RD LRS. Pump 90 bbls KCI down CT. RU acid equipment. Perform injection test prior to acid and could not establish any rate @ 1700 psi and hadslow bleed off. Injected 84 bbls of 12% KCI to treat peas. Perfs broke down after--3 bbls of acid were out of the nozzle and had no whp after 10 bbls pumped. Treated at 1.0 bpm thruout job w/no whp while performing 3 recips over perf interval. Overdisplaced acid with 62 bbls KCI. Performed injection test while FP well with 70 bbls of diesel and had 4.0 bpm w/ 550 psi and whp rising slowly. Last 10 bbls was pumped at 3.0 bpm @ 500 psi and whp rising slowly. POH. Left well FP with 70 bbls diesel and 6 bbls McOH. Ready to POI. RDMO to G-29 Job complete FLUIDS PUMPED BBLS 70 DIESEL 150 KCL 40 60/40 METH 84 ACID 40 FW 384 TOTAL al = 0 N n iv L � f,, O m p ro 0 1- (A O a a a 0 0 0 0 0 0 al 0 = ri su m n A O n A A A A A A A A A Z ° n a fD r N -, N O w w w w w w w w w m m 0 o < • C o N c o O D ca 0 D o �o D v, v+ vt of vt CO cn vt al m ,` n co ,&, c < D 0 0 0 0 0 0 0 0 0 0 = < - l0 7 F 7 DJ 0 02 5 N n l0 N J Lo crn ma n. ki • 0 a �' CO W CO CO CO CO CO O CO CO CO CO CO W W W CO CO Wo < ® `�° co ono 1 Q 0) D D CO W W Z m rn Cl)Cm rn aa) rn rn m aa) a) ,i o 2 '.. m n 43C- 0X C T T n cc A cn ca co ca tO <c gc cc 0 N o o CD T 0 00 0 0 0 0 0 0 0 0 0 0 a m — , -< p 0 0 0 0 0 0 .-' 0000000000 .-103 DZ F p o 0 0 0 0 o w p o 0 0 0 0 0 0 o m <_ CA Ti Q p CTI -' a/ 0 A N 0 0 0 0 0 0 0 0 0 P` f)- CO m CD CD VD v_ _,. XXXXXXXXXXXXXXXXXXo m, N m -1 :mr`: 3L G N i O r, 3 N_201 O r O N 0 3'. Win'-, X x3COc -0 -o (nc (nmxmx3 (nx zmm00x003Cf3cOrZ (Digzri O O 0 O O (noo (n -iiDD —1W = 3 (n - n (n cc W m > D 3 r -< -G r- -I --Ii z N zi CO W 0 z0 22O mr_ D09DO G1 z zr ( Z m _I• _4 ro 73 x z 7a O 000 Or c ° z z 71E073 -I m � mm > > m z ot .+i O 0 m v - ate. F m � ZZ ZZ : ,xt o 4, `k - A3 r w v, w w w 0 v aw ODoa) a> o00r • . ° iD Z Z Z O v f ;, T v P, h om o v v o e c v 0 0 0 0 0 0 0 D a)' py (D 0 C .a N N N N N N N N v (ho' 7C 3 a -v i ) j Y 1 L.0 C tO fD 07173 CO. ' ‘-i ed ., N Z c OW CDD 4' (,) Ut a) 0- viZ to c a 0 c o ;4 0 Co � ten _' t�; CD 00 0 r -� Z 'Oi., ' ui C} cin XL 1-1 ms + a It n : i-r N , )- 1„ t'. (pe CIS uc ut _ 0- N „004 -4 6' cry .-P N 0 t V I� u \� N ��' V � SEAN PARNELL,GOVERNOR )' J 13, 3 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Matt Brown Petroleum Engineer I BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU 04-350 Sundry Number: 312-127 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy °. Foerster Chair DATED this /t, day of April, 2012. Encl. STATE OF ALASKA 0 it/10lJ,, AL/- k OIL AND GAS CONSERVATION COMMI._ JN APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well❑ Change Approved Program❑ Suspend 0 Plug Perforations ❑ ^ Perforate❑ Pull Tubing 0 Time Extension 0 Operation Shutdown❑ Re-enter Susp.Well 0 ,A0,x Stimulate0 • Alter Casing ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Development ❑ Exploratory 0 211-1060 , 3.Address: P.O.Box 196612 Stratigraphic ❑ Service 0 • 6.API Number: Anchorage,AK 99519-6612 50-029-23453-00-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No /'y 0 PBU 04-350 9.Property Designation(Lease Number): 10.Field/Pool(s): c' 1 / ADLO-028324 • PRUDHOE BAY Field/LISBURNE Pool J4 .•, 11. PRESENT WELL CONDITION SUMMARY APR 2 O 1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(mems Junk(measured): 10323 . 9373 • 10234 ' 9306 • NONE ®fat Olt , (;� SSI�OR Casing Length Size MD ND Bu4P"t: rule Collapse Structural Conductor 78' 20"154#X-52 40 118 40 118 Surface 3840' 13-3/8"68#L-80 39 3879 39 3779 4930 2270 Intermediate 9232' 9-5/8"40#L-80 38 9270 38 8571 5750 3090 Production 768' 7"26#L-80 9098 9866 8426 9042 7240 5410 Liner 619' 4-1/2"12.6#L-80 9703 10322 8922 9372 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): SEE ATTACHED- - 4-1/2"12.6# L-80 37 9713 Packers and SSSV Tvoe: 7"BKR ZXPN LTP Packers and SSSV MD and ND(ft): 9098 8426 4-1/2"HES TNT PKR 9587 8832 4-1/2"BKR HRD-EZXPN LTP 9703 8922 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/16/2012 Oil 0 Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed NameTitle PE �. : o `i Signature . t /��/ Phone Date 564-5874 4/2/2012 Prepared by Nita Summefiays 564-4035 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5'Z-\ (i� Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Subsequent Form Required: /o-- 1O LI gle APPROVED BY Approved by: /9e/7 COMMISSIONER THE COMMISSION Date: 4- ! - lZ- 7:a y-G.1 �t, A., 1 RBDMS APR 112012 - .� ''� Form 10-403 Revised 1/2010 R Ir'J' t y' e' `; Submit in Duph a �, r /rte a) a0Trtov. co m• O0e- Oco ci ci w c_ a) a la H O qt M O O CL co O V' CC! mr I- cooa) omro t 0 0 o co acococ) co C a N Z W I— > O 0 0• o$ co co cooCO co W W W W Q Q mciciwwci ZatnQ as r 7,000 U. W W CL a IL W O.O. N N a a � aa LLJ a) Wwja < 00i- i- z2 aCCv) mmmv) cnm W el: NCC; (.G4 20-o4Otiao CC1O0coco C o U t~ cocic)ci coO O .... < 0 Q IL. tn WC, WaJaa.au1--- l- a2 0. C4mmmmmcnm d V a o W 0 > c 0 o 2 c WN L ISL o. as O W F- H 't LL LL LLL,, LL LL, & QQQQQ J f- N N N N N a CO j N CO co co cococo o) p = = O 44 a za v v vNNNNN a G LLWWJ zzL ILI -1 co � aOOo xxx m � � J � wwac.O ammLLiI� LZwO a> co0 0 0 0 0 Z O In 10 O O MMMMMLLay0 myY 3 m 4 a s V J _ _ J x fn00000 a ¢ aaLI. u. 2220 To: C. Olsen/T. Norene Date: March 27, 2012 J. Bixby/R. Liddelow AFE: X3-00YXF- C:PREPOST From: Megan Peltier/Matt Brown Production Engineer/Wells Group Subject: 04-350 HCL Acid Stimulation IOR: New Well 1 S Drift/tag 2 C HCL acid stimulation Current Status New Injector Last Inj: No injection history. Max Deviation 45° at 9861 ft Min ID 3.725" at 9696' (XN) Last Tag: 17-Feb-2012 10236' Last Downhole Op: 19-Feb-2012 Initial perforate Latest H2S value: No data available for well SBHP/T: at perfs 9049' TVD 3425 psi/180F extrapolated from DH gage at 9552' MD NOTE: 403 Sundry approval required. Objectives The objective of this procedure is to stimulate the Wahoo interval in 04-350 and prepare the ✓ well for injection. Contacts for this work are: Matt Brown Megan Peltier 564-5874 (w) 564-5851 223-7072 (c) 240-8398 344-1130 (h) Well History Well 04-350i is a Lisburne water injector completed in Nov-2011 with 4-1/2" tubing and a 4- 1/2" liner. The initial post-rig drift indicated -400' of fill. A sample recovered green cement. A CTU mill job cleaned out the cement sheath with a 3.70" mill to 10209' CTM on Jan 21/22 this year. Coil left KCI in the well with a 2500' 60/40 FP cap. An SCMT was logged on Feb 17th. The Wahoo zone was perforated on Feb 18, 2012. An injectivity test was performed on Feb 24/25, 2012 and showed very low injectivity. The pump rate was only about 0.3 bpm at about 2000 psi WHP. About 10 bbls were pumped during the test and the WHP climbed almost continuously during the job. 04-350 Coil Acid Stimulation Page 1 of 6 The well has no integrity issues (new well) and passed an MITIA to 3000 psi on Feb 5, 2012. Job Notes Although the well was recently perforated and has significant rathole, a SL drift/tag is called for in the procedure. The post-pert injectivity was so low that the drift is included in the procedure to make sure that there is no debris (perf debris or cement sheath) that is blocking the perfs. Due to the very low injectivity, this procedure calls for stimulating the Wahoo using_CT N<`' instead of fullbore. The diesel/ KCL load will be circulated down the coil while taking returns then the backside will be shut in. There are no H2S measurements for 04-350 as it is a new injector. The following table & map show H2S values in the area: Well H2S, ppm Date L3-24 60 5/12/1997 L3-28 120 4/16/1993 L4-15 100 1/4/2012 L4-30 200 11/22/2011 L4-31 45 8/22/2007 L4-32 1000 10/2/1998 • L4-36 55 7/18/2008 Note that the L4-32 reading is old and the L4 area has shown decreasing H2S levels over time. Map of Lisburne in 04-350 area L4-30 5960000 L3-24 • • L4-15 • 5957500 L3-28 L4-31 ♦ ♦ 5955000 L4-32 (04350 L4-36 5952500 5950000 710000 712500 715000 717500 720000 722500 725000 727500 730000 04-350 Coil Acid Stimulation Page 2 of 6 Acid Design Basis 1. Stimulation Target Zones Depth Top Depth Bot Footage Liner 9876 9924 48 4-1/2" Liner 9942 9976 34 4-1/2" Liner Total 82 2. Design Total Footage 82 ft Acid Design 12% HCI Stimulation —40 gal/ft • Acid Volume 12% HCI —80 bbls Reservoir Pressure 3425 psi /180° @ 9120' TVD (bot pert) GLV's 2 mandrels, both dummied 3. Fluid Requirements & Specifications Fluid Type Vol Vol, gal 2% KCI + F103 180 bbls 8,400 gal 12% HCI 80 bbls 3,360 gal Diesel 60 bbls 2,520 gal HCI Acid Loading for: 12% HCI tot chemical Product Code: Function: Units: per Mgal in HCI A264 ACI gal/Mgal 6 20 gal A201 Inhibitor Aid gal/Mgal 15 50 gal F103 Flowback aid gal/Mgal 2 7 gal L058 Iron Control lb/Mgal 20 67 lb W054 Antiemulsifier gal/Mgal 5 17 gal 04-350 Coil Acid Stimulation Page 3 of 6 PROCEDURE Slickline 1. Drift & tag PBTD to ensure that there is no blockage around perfs Pre-Acid Stimulation 1. Obtain an oil sample from an L3 well or an L4 well. Preferred oil sample candidates (in order of preference) are L4-14, L3-30 or L3-22. Deliver oil sample to Schlumberger Well Services lab for pre-job emulsion/sludge testing at least 5 days prior to acid stim. Test both live and spent_acid with the crude_oihto ensure there is no sludge or emulsions. Adjust additive package as needed based on lab results. Send lab report to matt.brown(a�bp.com and deliver a copy to job location prior to execution. 2. Order out fluids per the table above. Coiled Tubing HCL Acid Treatment • Filter all fluids that will enter the perforations to 3 microns absolute. • 04-350 is completed with L-80 tubing and L-80 Liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. Rig up a bleed hose to the IA as necessary. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to matt.brownbp.com. 1. Hold PJSM. • Possible hazards on this job include H2S • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 2. Preheat filtered KCI and diesel to 90°F. • Do not heat the acid or acid mixture . 3. Mix/Circulate acid to ensure homogenous solution at pump time. Ensure acid is pumped within 24 hours of loading. 4. RIH with MHA + 2-1/2" jet/swirl nozzle, performing wt checks as needed. 04-350 Coil Acid Stimulation Page 4 of 6 5. RIH to top perf at 9876'. Pump the following down the coil: a. 50 bbls diesel - taking returns at surface. b. 70 bbls 2% KCI + F103 - taking returns at surface - SI returns after 70 bbls 2% KCI out the nozzle c. 20 bbls 2% KCI + F103 d. 80 bbls 12% HCL while reciprocating across perforations (9876-9976) e. 50 bbls 2% KCI + F103 while reciprocating across perforations (9876-9976) Notes: -If needed to establish injection, go to 3000 psi WHP. Once injectivity is established, drop to 1800 psi WHP as to not frac the well during the acid wash. 6. Do an injectivity test post acid stim by pumping —40 bbls diesel down the backside at 2000 psi WHP. Establish a stabilized rate and pressure to make certain of positive injection. POOH. FP coil as needed 7. RDMO. Well Integrity History New drill by Doyon 25 > 01/04/12: Set DGLV in st#2 > 01/06/12: Set OGLV in st#2 > 02/05/12: Set DGLV in st#2, MIT-IA Passed to 3000 psi 04-350 Coil Acid Stimulation Page 5 of 6 TREE= 4-1/16"CMV WELLHEAD= FMC 04-350 SAFETY NOTES: ACTUATOR= BAKER C ORIG.KB.ELEV= 70.08' ORIG.BF.ELEV= 29.48 I KOP= 240' Max Angle= 45"@ 9860' Datum MD= 10319' ' ' 2147' —j4-12"HES X NIP,ID=3.813" Datum TVD 9300' SS GAS LIFT MANDRELS 20"CONDUCTOR,154#,X-53,ID=18.500" —194 ST MD TVD DEV TYPE VLV LATCH R)RT DATE 13-3/8"CSG,68#,L-80 BTC,ID=12.415" H 3879' 2 3580 3504 20 KBG2 DMY BK 0 02/05/121 4983 4758 28 KBG2 DMY BK 0 11/18/11 9098' —9-5/8"X 7"BKR ZXPN LTP, TOP OF 7'LNR — 9098' 1. w/10'TIEBACK,ID=6.180" Minimum ID= 3.726"@ 9696' T 9114' H9-5/8"X 7"FLEX LOCK HGR,ID=6.220" 4-1/2" HES XN NIPPLE 9-5/8"CSG,40#,L-80 HYD 563,ID=8.835" — 9270' ' ' I 9521' —4-12"HES X NIP,ID=3.813" 11-1 9552' I--4-1/7'SGM-NDPG-CA SINGLE DROP SUB,ID=3.958" 9587' —7"X 4-1/2"HES TNT PKR,ID=3.856" I I 9624' —4-12"HES X NIP,ID=3.813" ' 9696' —4-12"HES XN NIP,ID=3.725" TOP OF 4-1/2'LNR — 9703' 9703' —7"X 4-1/7'BKR HRD-EZXPN LTP 4-12"TBG,12.6#,L-80 TO-11, — 9713' w/FLEX LOCK LNR HGR,ID=4.190" .0152 bpf,ID=3.958" 9713' —4-1/2"WLEG,ID=4.00" -jELMD NOT LOGGED 7"LNR,26#,L-80 VAMTOPHC, — 9866' 1-41 .0383 bpf,ID=6.276" PERFORATION SUMMARY REF LOG. SLB-HNGRS LOG(11/08/11) ANGLE AT TOP PERF:45°@ 9876' Note.Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9876-9924 0 02/19/12 3-3/8" 6 9942-9976 0 02/18/12 PBTD — 10234' I 11111 1111111111 614141416.0 4-12"LNR,12.6#,L-86IBT, 10322' .0152 bpf,ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11119/11 0.25 INITIAL COMPLETION 01/07/12 LEC/PJC GLV CI0(01/06/12) WELL. 04-350 12/04/11 PJC DRLG DRAFT CORRECTION 02/09/12 JLJ/JMD GLV CI0(02/05/12) PERNIT No:`1111060 12/06/11 COG/PJC FINAL DRLG CORRECTIONS 02/19/12 JTC/JMD ADPERFS(02/18-19/12) API No: 50-029-23453-00 12/17/11 DOKJ PJC TREE INFORMATION SEC 26,T11 N,R15E,237'FSL&397'FWL 01/06/12 LEG PJC GLV C/O(01/04/12) 01/06/12 LEC/PJC GLV G0(01/06/12) BP Exploration(Alaska) 04-350 Coil Acid Stimulation Page 6 of 6 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 0 Development 0 Exploratory 0 GINJ ®WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One gJesf,L®Service 0 Stratigraphic 2. Operator Name. 5.Date Comp.,Susp.,or Aband.: 9�`' 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 4-14-1-9/20f1- o2J/B/Zo /L- 211-106 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 10/2/2011✓ 50-029-23453-00-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 11/3/2011 PBU 04-350 237'FSL,4883'FEL, SEC.26,T11 N, R15E, UM 8. KB(ft above MSL): 70 08 15.Field/Pool(s): Top of Productive Horizon: 1872'FSL,2687'FEL, SEC.26,T11 N, R15E, UM GL(ft above MSL): 29.48' Prudhoe Bay Field/Lisburne Pool Total Depth: 9.Plug Back Depth(MD+TVD): 1808'FSL,2375'FEL, SEC.26,T11 N, R15E, UM 10234' 9306' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 713220 y- 5952120 Zone- ASP4 10323' 9373' ADL 028324 TPI: x- 715367 y- 5953818 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 715680 Y- 5953763 Zone- ASP4 None 18.Directional Survey: ®Yes 0 No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1846' 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: DIR/GR/RES/PWD/NEU/DEN/FPWD I NGS/FMI/Sonic Scanner/AIT/MCFL/ECS/XPT/USIT/Stethoscope N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 154# X-52 Surface 118' Surface 118' 42" —260 sx of Arctic Set 13-3/8" 68# L-80 Surface 3879' Surface 3779' , 16" 2831 sx DeeDCrete.581 sx Class'G' 9-5/8" 40# L-80 Surface 9270' Surface 8571' 12-1/4" 600 sx Class'G' 7" 26# L-80 9098' 9866' 8426' 9042' 8-3/4" 217 sx Class'G' 4-1/2" 12.6# L-80 9703' 10322' 8922' 9372' 6-1/8" 120 sx Class'G' 24. Open to production or injection? ® Yes 0 No 25. TUBING RECORD If Yes,list each interval open (MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3-3/8"Gun Diameter,6 spf 4-1/2", 12.6#, L-80 9713' 9587'/8832' MD TVD 1 9 —7\ l TVD 9884'-9904' 9055'-91,9' RECEIVE® 2 ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9904'-9924' 9069'-90:3' D PTH INTERVAL(MD)t AMOUNT AND KIND OF MATERIAL USED 9942'-9956' 9096'-910•' 5 9956'-9976' 9105'-9120' MART2012 2200' Freeze Protected w/160 bbls Diesel Alaska Oil astConS Comm+ssipn 27. I N TEST Date First Production: — Method of Operation(Flowing,Gas Lift,etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None 1 al= it, `RBDMS MAR 191Qdd 11 -',' -„ K `1)4) Form 10-407 Revised 12/2009 CONTINUED ON REVERSE /� -,%IL -I? Submit Original Only 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 1916' 1912' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 5300' 5038' None West Sak 6490' 6098' Coleville Mudstone 7417' 6941' HRZ 9033' 8370' Sadlerochit 9275' 8575' Kavik 9612' 8852' Wahoo 7.2 9861' 9038' Wahoo 7.1 9947' _ 9099' Wahoo 6.3 9982' 9124' Wahoo 6.2 10026' 9155' Wahoo 6.1.2 10093' 9203' Wahoo 6.1.1 10152' 9246' Wahoo 5.3 10160' 9252' Wahoo 5.2 10206' 9286' Wahoo 5.1.2 10258' 9324' Wahoo 5.1.1 10292' 9350' Wahoo 4.8 10305' 9360' Formation at Total Depth(Name): Wahoo 4.8 10305' 9360' 31.List of Attachments: Summary of Daily Drilling Reports and Post Rig Work,Well Schematic Diagram,Surveys 32.I hereby certify that the • -••ing is r an r ect to the best of my knowledge. Signed: Joe Lastufka \ l Title: Drilling Technologist Date:5/14l 9— PBU 04-350 211-106 Prepared By Name/Number. Joe Lastufka, 564-4091 Well Number Permit No./Approval No. Drilling Engineer: Frank Pugh, 564-4859 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE= 4-1/16"CAN WELLHEAD= FMC04-350�_�� S{ f NOTES:. ACTUATOR= BAKER C ORIG.KB.ELEV= 70.08' ORIG BF.ELEV= 29.48 I KOP= 240' Max Angle= 45 @ 9860' Datum MD- 10319' ' 2147' —14-1/2"HES X NIP, ID=3.813" Datum TV D= 9300' SS GAS LIFT MANDRELS 20"CONDUCTOR,154#,X-53, ID=18.500" — —194 ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,68#, L-80 BTC, ID=12.415" H 3879' ` 2 3580 3504 20 KBG2 DMY BK 0 02/05/121 4983 4758 28 KBG2 DMY BK 0 11/1E1/11 9098' 19-50 X 7"BKR ZXPN LTP, TOP OF 7'LNR H 9098' w 110'TIEBACK, ID=6.180" Lar Minimum ID = 3.726" i� 9696' T 9114' —{9-5/8"X7"FLEX LOCKHGR,ID=6.220" 4-1/2" HES XN NIPPLE 9-5/8"CSG,40#,L-80 HYD 563,ID=8.835" H 9270' 111. 9521' H4-1/2"HES X NIP, ID=3.813" F 9552' --4-1/2"SGM-NDPG-CA SINGLE DROP SUB,ID=3.958" g1 9587' HT X 4-1/2"FES TNT PKR, ID=3.856" ' ' 9624` H4-1/2"HES X NIP, ID=3.813" I 9696' --14-1/2"HES XN NIP, ID=3.725" TOP OF 4-1/7'LNR H 9703' 9703' —17"X 4-1/7'BKR HRD-EZXPN LTP 4-1/2"TBG, 12.6#,L-80 T0-11, H 9713' w/FLEX LOCK LNR HGR,ID=4.190" .0152 bpf,10=3,958" 9713' —I4-112 WLEG, ID=4.00" —I ELMD NOT LOGGED 7"LNR,26#,L-80 VAMTOP HC, — 9866' .0383 bpf, ID=6.276" PERFORATION SUMMARY REF LOG: SLB-HNGRS LOG(11/08/11) ANGLE AT TOP PERF:45'@ 9876' Note: Refer to Production DB for historical perf data SIZE SPE INTERVAL Opn/Sqz DATE pe 3-3/8" 6 9876-9924 0 02/19/12 3-3/8" 6 9942-9976 0 02/18/12 PBTD H 10234' ,44444 4444444444 4-1/2"LNR, 12.6#, L-80 IBT, H 10322' .0152 bpf,ID=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNFF 11119111 D-25 INITIAL COMPLETION 01/07/12 LEC/PJC GLV C/O(01/06/12) WELL: 04-350 12/04/11 PJC DRLG DRAFT CORRECTION 02/09112 JLJ/JMD GLV C/O(02/05/12) PERMIT No: 2111060 12/06/11 DDG/PJC FINAL DRLG CORRECTIONS 02/19/12 JTC/JMD ADPERFS(02/18-19/12) API No: 50-029-23453-00 12/17/11 DOK/PJC TREE INFORMATION SEC 26,T11 N, R15E 237'FSL&397'FWL 01/06/12 LEC/PJC GLV C/O(01/04/12) 01/06/12 LEC/PJC GLV C/O(01/06/12) BP Exploration(Alas ka) BP AMERICA Leak-Off Test Summary Well Name: 04-350 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 10/12/11 LOT 3,878.00 3,779.00 9.20 659.00 2,465.10 12.56 10/26/11 FIT 9,270.00 8,575.00 9.00 1,339.00 5,348.10 12.01 10/26/11 FIT 9,579.00 8,825.00 9.20 1,300.00 5,517.70 12.04 10/31/11 FIT 9,866.00 9,043.00 8.40 762.00 4,708.00 10.02 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 27,2013 Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 04-350 FROM: PRUDHOE BAY UN LIS 04-350 Petroleum Inspector Src: Operator NON-CONFIDENTIAL Well Name PRUDHOE BAY UN LIS 04-350 API Well Number 50-029-23453-00-00 Inspector Name: Permit Number: 211-106-0 Inspection Date: 2/5/2012 Insp Num: MITOP000004034 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type J _ Well 04-350 T e In' N TVD %832 IA 214 j 3020 2980 2966 – — I — t PTD!' 2111060 Type TestI SPT Test psi' 3000 1 OA 140 160 160 ' 160 Interval Other(describe in notes) PAF Pass ,Tubing 200 500 500 1 500 Notes: Initial injection MIT-IA Thursday,June 27,2013 Page I of 1 North America-ALASKA- BP Page 1 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-OOYXF-C: (10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/27/2011 06:00 - 19:30 13.50 MOB P PRE RIG DOWN FROM 18-12C. HAUL RIG ANCILLARY EQUIPMENT FROM 18-12C TO 04-3501. PREP FOR RIG MOVE TO DS-04 -SCOPE DOWN MAST AND PIN TOP DRIVE -FINISH SECURING WELL 18-12C -BLOW DOWN MUD LINES -SECURE IRON DERRICKMAN -RAISE C-SECTION WIND WALL -PREP RIG MODULES FOR MOVE. -DISCONNECT RIG COMPLEX INTERCONNECT POWER AND SERVICE UTILITY LINES. -SKID FLOOR AND PREP TO LAY MAST DOWN. 19:30 - 20:30 1.00 MOB P PRE LAY MAST DOWN ON HEADACHE. PREP MODULES FOR SEPARATION. SKID POWER AND PUMP COMPLEX AWAY FROM PIT MODULE. 20:30 - 00:00 3.50 MOB P PRE MOVE PUMP AND POWER COMPLEX FROM 18-12C TO DS-04 AND STAGE SAME ON DRILLSITE. -SKID PIT MODULE AWAY FROM SUB. -SKID CASING SHED AWAY FROM SUB. 9/28/2011 00:00 - 22:00 22.00 MOB P PRE MOVE RIG COMPLEXES AND COMPONENTS FROM 18-12C TO DS-04. 22:00 - 00:00 2.00 RIGU P PRE SPOT RIG SUBSTRUCTURE OVER 04-3501 WELL SLOT. STAGE RIG COMPLEXES. 9/29/2011 00:00 - 02:30 2.50 RIGU P 1.08 PRE SPOT PIPE SHED. LEVEL SUBSTRUCTURE. LEVELING JACK HYDRAULIC CYCLINDER ON OFF DRILLER SIDE AT FRONT OF SUBSTRUCTURE FAILED AND APPROXIMATELY TWO GALLONS HYDRAULIC FLUID LEAKED INTO SECONDARY CONTAINMENT. 02:30 - 10:30 8.00 RIGU N RREP 224.08 PRE REPLACE OFF DRILLERS SIDE LEVELING JACK HYDRAULIC CYLINDER. 10:30 - 00:00 13.50 RIGU P 1.08 PRE CONTINUE SPOTTING PIPE SHED,PIT,PUMP AND POWER COMPLEXES. RAISE MAST TO HALF-MAST POSITION. SKID FLOOR INTO DRILLING POSITION. SPOT CASING SHED. PRE-SPUD MEETING WITH ANCHORAGE MANAGEMENT/ENGINEERING VIA VT CONFERENCE CALL. MAKE SERVICE AND UTILITY CONNECTIONS BETWEEN RIG COMPLEXES. PREPARE TO SCOPE UPPER SECTION OF MAST INTO DRILLING POSITION. FUNCTION TEST#1,#2 AND#3 GENERATOR EMERGENCY SHUTDOWN(ESD). 9/30/2011 00:00 - 08:00 8.00 RIGU P PRE CONTINUE PREPARING TO SCOPE UPPER SECTION OF MAST INTO DRILLING POSITION. DEMOBE TOP SECTION OF CATTLE CHUTE FOR MODIFICATIONS TO ALLOW 13-3/8" CASING TO BE RAN. REPLACE MAN RIDER WINCH LINE. NIPPLE UP DIVERTER BLOOIE LINE. SCOPE UPPER SECTION OF MAST INTO DRILLING POSITION. ACCEPTED RIG FOR OPERATIONS AT 08:00 Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 2 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 12:00 4.00 RIGU P PRE NIPPLE UP 21-1/4"HYDRIL DIVERTER AND DIVERTER BLOOIE LINE. TAKE ON 8.8-PPG DRILPLEX MUD TO PITS. CONTINUE CONNECTING STEAM,WATER AND AIR SERVICE LINES. MEASURED ROTARY TABLE TO GROUND LEVEL=40.60'. 12:00 - 15:00 3.00 RIGU P PRE CONTINUE RIGGING UP SURFACE EQUIPMENT. 15:00 - 16:00 1.00 RIGU P PRE PJSM- LIFTING AND RIGGING. REMOVE TOP SECTION OF CATTLE CHUTE FROM SUBSTRUCTURE ROOF. 16:00 - 22:00 6.00 RIGU P PRE INSTALL 4"DUMP VALVES IN SURFACE CONDUCTOR IN CELLAR. RIG UP CELLAR HOUSE WITH H2S/METHANE SENSORS AND INSTALL FLOOR GRATING. RIG UP 5"DRILL PIPE HANDLING TOOLS TO RIG FLOOR. FUNCTION 21-1/4"HYDRIL DIVERTER AND VERIFY NO HYDRAULIC LEAKS. WELD FLOW LINE JET ON"JOE'S BOX". INSTALL SCHLUMBERGER SENSOR ON TOP OF STAND PIPE MUD LINE. LOAD 5"DRILL PIPE IN CASING SHED. 22:00 - 00:00 2.00 RIGU P PRE PTSM-CREW CHANGE-HAYES CREW FIRST TOUR. CONTINUE LOADING 5"DRILL PIPE IN CASING SHED. TALLY 5"DRILL PIPE. LOAD 20 JTS.OF 5"HWDP IN SHED AND TALLY SAME. CHANGE TOP DRIVE SAVER SUB FROM 4"XT-39 TO 4-1/2"IF THREAD(NEW SAVER SUB). NIPPLE DOWN AIR BOOT/FLANGE ASSEMBLY FROM TOP OF HYDRIL DIVERTER TO ALLOW FOR MEASUREMENTS TO FABRICATE FLOW NIPPLE. 10/1/2011 00:00 - 01:30 1.50 RIGU P PRE CONTINUE RIGGING UP FLOOR TO PICK UP 5"DP. CHANGE OUT SAVER SUB. 01:30 - 03:30 2.00 RIGU P PRE RIG UP PS-21 SLIPS WITH 9-5/8"CASING SEGMENTS TO HANG MOUSEHOLE. PULL PS-21 SLIP BOWL. NIPPLE UP AIR BOOT/FLANGE ASSEMBLY TO TOP OF HYDRIL DIVERTER. STAB FLOW NIPPLE, TAKE MEASUREMENTS TO CUT OUT FLOW OPENING. PULL AND LAY DOWN FLOW NIPPLE. SET PS-21 SLIP BOWL IN ROTARY TABLE OPENING. 03:30 - 04:00 0.50 DRILL P SURF RIG UP 5"PIPE AND 8"BHA HANDLING TOOLS. CHANGE PS-21 9-5/8"SLIP SEGMENTS TO HAND SLIP SEGMENTS TO ALLOW FOR PICKING UP 5"DP AND USING HAND SLIPS TO TAG BOTTOM IN 20" CONDUCTOR. PIN STABBING BOARD IN DRILLING POSITION. 04:00 - 04:30 0.50 DRILL P SURF PJSM-PICKING UP 5"DP. 04:30 - 12:00 7.50 DRILL P SURF PICK UP 5"HWDP AND TAG BOTTOM IN 20" CONDUCTOR. TAGGED AT 1.18'. IRSTALLED - FLOW NIPPLE. STAGED SURFACE BHA TOOLS AND XO SUBS TO RIG FLOOR. PRESSURE TESTED SURFACE LINES AND EQUIPMENT TO 3500-PSI. MOTOR OIL LEAK ON LIGHT PLANT-IR#3957463. Printed 11/28/2011 11:34:54AM Page 3 of42 Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 DRILL P SURF PTSM-CREW CHANGE. CONTINUE PICKING UP 5"DRILL PIPE FROM PIPE SHED 1 X 1 MAKING STANDS AND STANDING THEM IN THE DERRICK WITH IRON DERRICKMAN. t 13:00 - 14:00 1.00 BOPSUR P SURF PERFORM ACCUMULATOR/DIVERTER TEST ,� ) t PER BP/AOGCC REQUIREMENTS. TESTED PVT'S,GAS ALARMS AND FLOW PADDLE. / ANNULAR DIVERTER CLOSURE TIME=34 SECONDS. LOU GRIMALDI-AOGCC WITNESSED TESTING. 14:00 - 14:30 0.50 DRILL P SURF PERFORMED EVACUATION DRILL AND AAR. ALL CREW MEMBERS ACCOUNTED FOR AT PRIMARY MUSTER AREA IN 3.0 MINUTES. 14:30 - 17:00 2.50 DRILL P SURF RESUMED PICKING UP 5"DRILL PIPE FROM PIPE SHED 1 X 1 MAKING STANDS AND STANDING THEM IN THE DERRICK WITH IRON DERRICKMAN. PICKED UP AND STOOD BACK A TOTAL OF 18 JTS.5"50#, S-135 4.5"IF HEAVY WEIGHT DRILL PIPE AND 120-JTS.OF 5"19.5#,S-135 4.5 IF DRILL PIPE 17:00 - 20:00 3.00 DRILL P SURF HANG OFF TRAVELING BLOCK. SLIP AND CUT 120'OF DRILLING LINE. REMOVE TRAVELING BLOCK HANG-OFF SLING. CALIBRATE BLOCK HEIGHT FOR TOTCO AND SCHLUMBERGER MWD. 20:00 - 21:00 1.00 DRILL P SURF CALIBRATE AMPHION,TOTCO AND SCHLUMBERGER BLOCK HEIGHT AND WEIGHT INDICATORS. TEST CROWN SAVER AND FLOOR SAVER. 21:00 - 22:00 1.00 DRILL P SURF PJSM-RIGGING UP WIRELINE. MIRU HALLIBURTON GYRODATA TOOLS. 22:00 - 22:30 0.50 DRILL P SURF PJSM-REVIEWED PICKING UP BHA PROCEDURE WITH RIG CREW. REVIEWED PLAN FORWARD WITH ALL RIG CREW,HES WIRELINE,GYRODATA,M-I MUD ENGINEERS, DIRECTIONAL DRILLER,MWD,GEOLOGIST AND CH2 PERSONNEL. 22:30 - 00:00 1.50 DRILL P SURF PICK UP AND MAKE UP SURFACE HOLE SPUD BHA#1 AS FOLLOWS: -16"HUGHES VM-1 MILL TOOTH TRI-CONE BIT -SLB MUD MOTOR,3/4,4.5 STAGES,.22 REVS/GALLON,1.5 DEGREE BEND -8"NM UBHO -16"NM INTEGRAL BLADE STABILIZER -8"NM DRILL COLLAR -NM BOTTLE NECK XO -1 JT.5"50#,HW-95 HWDP TOTAL LENGTH=103.83' GYRODATA VERIFIED FULL ENGAGEMENT OF GYRO TOOL STRING ALIGNMENT PIN IN UBHO SUB. RIG UP GYRODATA UPPER SHEAVE TO DRILLERS SIDE COLLAR FINGER. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 4 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/2/2011 00:00 - 01:30 1.50 DRILL P SURF PTSM-CREW CHANGE. PJSM-PICKING UP BHA. PRE-SPUD MEETING WITH HAYES CREW. REVIEWED SURFACE HOLE SECTION GOALS, EXPECTATIONS AND DRILLING HAZARDS. REVIEWED PORE PRESSURE DETECTION PLAN. DESIGNATED SPILL CHAMPIONS TO MONITOR OFFSET WELLHOUSES FOR BROACHING. CONDUCTED TABLE TOP(D3)DIVERTER DRILL. QUADCO UPGRADE TOTCO SOFTWARE FROM VERSION 2.2 TO VERSION 3.0. 01:30 - 04:00 2.50 DRILL P SURF RESUME MAKING UP SURFACE HOLE DRILLING BHA#1 TO 103.83'. MAKE UP 1ST STAND 5"HWDP. CALIBRATE CROWN SAVER. CALIBRATE BIT DEPTH AND HOLE DEPTH FOR TOTCO. 04:00 - 04:30 0.50 DRILL P SURF FILL HOLE WITH 8.8-PPG DRILPLEX MUD. BREAK CIRCULATION AND FILL HOLE. CHECK FOR LEAKS AT DIVERTER KNIFE VALVE,WELL CELLAR.TATTLE TAIL AND BOP DECK. STAGE PUMPS UP TO DRILLING RATE t/ -500-GPM. OBTAINED RETURNS AT 38-BBLS. AWAY. RIH FROM 103'MD TO 118'. TAG BOTTOM AT 118'. P/U WT=55K, S/O WT.= 60K 04:30 - 05:00 0.50 DRILL P SURF PICK UP GYRODATA TOOL STRING TO RIG FLOOR. RIG UP WIRELINE LOWER SHEAVE TO PAD EYE IN RIG FLOOR. CALIBRATE TOTCO PVT'S AND FLOW MONITORS. 05:00 - 12:00 7.00 DRILL N SFAL 159.08 SURF SPUD WELL AT 07:30. DRILL DIRECTIONALLY FROM 118'MD TO 158'MD. FLOW LINE PACKED OFF WITH GRAVEL SETTLING IN LINE. ADDED TWO ADDITIONAL 2"FLOWLINE JETS TO AID IN CUTTINGS TRANSPORT. 12:00 - 13:00 1.00 DRILL P SURF PTSM-CREW CHANGE. COMPLETE PLUMBING IN 2"FLOWLINE JETS. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 5 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 23:00 10.00 DRILL P SURF WHILE CONTINUING DRILLING,FLOWLINE INTERMITTENTLY PLUGGING AND HOLE FILL PUMPS FEEDING FLOWLINE JETS BECOMING LOCKED WITH GRAVEL. CUTTINGS TANK OFFLOAD LINE INTERMITTENTLY PLUGGING NECESSITATING BLOW DOWN WITH AIR AND MIXING DRILPLEX MUD IN CUTTINGS TO AID IN TRANSPORT OF CUTTINGS IN OFFLOAD LINE AND GETTING TANK EVACUATED. ONCE TANK WAS EVACUATED,KEPT SUPERSUCKER ON CONTINUOUS VAC AND PERIODICALLY FLUSHED TANK AND LINE WITH WATER AND/OR MUD. DRILL 16" SURFACE HOLE DIRECTIONALLY FROM 158' MD TO 479'MD,479'ND. WIPING 30'ON CONNECTIONS. CIRCULATED 2X BOTTOMS UP. MUD WT. IN 8.7-PPG,OUT 8.6-PPG. -500-GPM @ 335-PSI ON,300-PSI OFF -40 RPM -WOB 1-4K-LBS. -TQ 1-2K FT.-LBS. -ROP=50-150 FT/HR. -P/U WT.=53K, S/0 WT.=59K -AST 1.82-HRS. -ART 0.5-HRS. -ADT 2.32-HRS. -BIT HRS.2.32-HRS. 23:00 - 23:30 0.50 DRILL P SURF RUN GYRO SURVEY TO UBHO SUB AT 449'. -INCLINATION=.86 DEGREES 23:30 - 00:00 0.50 DRILL P SURF POH FROM 465'MD STANDING BACK 5" HWDP IN DERRICK WITH IRON DERRICKMAN. NO INDICATORS OF SURFACE BROACHING IN OFFSET WELLHOUSES OR SURROUNDING AREA. 10/3/2011 00:00 - 01:00 1.00 DRILL P SURF POH WITH SURFACE HOLE BHA#1. DISCUSSED AND AGREED FORWARD PLAN WITH ODE TO CHANGE MOTOR BEND FROM 1.50 DEGREES TO 2.12 DEGREES DUE TO DIFFICULTY IN OBTAINING DESIRED DOGLEGS. WEEKLY HSE MEETING WITH MOSES CREW. REVIEWED SECTION 3 OF PETEX VIDEO"INTRODUCTION TO WELL CONTROL". 01:00 - 02:00 1.00 DRILL P SURF LAY DOWN ALL OF SURFACE HOLE BHA#1 EXCEPT FOR BIT AND MUD MOTOR. INSPECT BIT AND MUD MOTOR BOTTOM BEARING. ALL GOOD. SMALL AMOUNT OF BALLING ON BIT AND IN 16"STABILIZER WATER COURSES. 102:00 - 02:30 0.50 DRILL P SURF ADJUST MOTOR BEND FROM 1.50 DEGREES TO 2.12 DEGREES PER SLB DD. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 6 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 .X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 05:30 3.00 DRILL P SURF RESUME PICKING UP AND MAKING UP SURFACE HOLE BHA#2 AS FOLLOWS: -16"HUGHES VM-1 MILL TOOTH TRI-CONE BIT -SLB 9-1/2"MUD MOTOR,3/4,4.5 STAGES,.22 REVS/GALLON,2.12 DEGREE BEND -ARC8 -12-1/4"NM ILS STABILIZER -MWD -8"NM UBHO -16"NM INTEGRAL BLADE STABILIZER -NM DRILL COLLAR -NM FLOAT COLLAR -NM DRILL COLLAR -FLOAT SAVER SUB -8"SMITH INTNL.HYDRAULIC DRILLING JAR -NM XO -5"HWDP(20 JTS.) TOTAL LENGTH=844.25' 05:30 - 06:00 0.50 DRILL P SURF RIH FROM 185'TO 378'MD. MONITOR HOLE FILL ON PIT#2. MAKE TOP DRIVE CONNECTION AND WASH TO BOTTOM AT 500-GPM AND 800-PSI. 06:00 - 12:00 6.00 DRILL P SURF BREAK CIRCULATION AND DRILL DIRECTIONALLY FROM 479'TO 820'MD. 572-GPM @ 760-PSI ON,750-PSI OFF -40 RPM -WOB 10-20K-LBS. -TQ 1-2K FT.-LBS.ON BOTTOM -ROP=50-150 FT/HR. -P/U WT.=84K, S/O WT.=90K -AST 1.0-HRS. -ART 0.54-HRS. -ADT 1.54-HRS. -BIT HRS. 1.6-HRS. 12:00 - 00:00 12.00 DRILL P SURF PTSM-CREW CHANGE. WEEKLY HSE MEETING WITH HAYES CREW. SURFACE HOLE FROM 820'TO 1,406'MD. TOTAL FEET DRILLED TODAY-927'. TAKING GYRODATA SURVEYS AT EACH CONNECTION. CURRENTLY UNABLE TO OBTAIN CLEAN MWD SURVEYS. -MUD WT. IN-8.8-PPG,OUT-8.9-PPG -FLUID LOSSES TO HOLE TODAY-43-BBLS. -500-GPM @ 335-PSI ON,300-PSI OFF -40 RPM -WOB 10-20K-LBS. -TQ 4K FT.-LBS. -ROP=50-150 FT/HR. -P/U WT.=105K,S/O WT.=104K, ROT WT. = 103K -AST 4.47-HRS. -ART 3.58-HRS. -ADT 8.05-HRS. -BIT HRS.9.16-HRS. -CUM BIT HRS.-13.57 -JAR HRS.-8.05 TOTAL JAR HRS.-9.65 Printed 11/28/2011 11:34:54AM North America-ALASKA-BP Page 7 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/4/2011 00:00 - 11:00 11.00 DRILL P SURF DIRECTIONALLY DRILL 16"SURFACE HOLE FROM 1,406'TO BASE OF PERMAFROST AT 1,975'MD. HEAVY SAND,MINOR WOOD AND MODERATE AMOUNT OF GRAVEL IN MUD RETURNS. -600 GPM,1035 PSI ON/1024 PSI OFF, -MW 8.9 IN/8.9 OUT, ECD=9.74 PPG -40 RPM,4-5K TQ ON/2-3K TQ OFF -3K WOB -P/U= 116K,5/0=112K, ROT=114K -AST=5.12,ART=0.73,ADT=5.85 FLUID LOSSES-—4.0-BBLS./HR. 11:00 - 12:00 1.00 DRILL P SURF CIRCULATE BOTTOMS UP WHILE RECIPROCATING -596 GPM/1000 PSI MONITOR WELL-STATIC 12:00 - 16:00 4.00 DRILL P SURF POOH ON ELEVATORS TO SURFACE -MONITOR HOLE ON TRIP TANK 16:00 - 16:30 0.50 DRILL P SURF CLEAN AND CLEAR RIG FLOOR 16:30 - 18:30 2.00 DRILL P SURF CHECK BIT CONDITION-OKAY TO RE-RUN BIT GRADE 2-2-WT-A-E-I-NO-TD ADJUST MUD MOTOR BEND FROM 2.12 TO 1.83, P/U BHA TO 93'AND PLUG IN TO TEST MWD. 18:30 - 20:30 2.00 DRILL N HMAN SURF INADVERTENTLY GOT MUD INTO TEST PORT ON ARC TOOL. CHANGE OUT ARC TOOL IN BHA. 20:30 - 22:00 1.50 DRILL P SURF CONTINUE P/U BHA FROM 93'TO 284'. -SHALLOW PULSE TEST AT 600 GPM/620 PSI 22:00 - 00:00 2.00 DRILL P SURF RIH CLEAN FROM 284'TO 1316'ON ELEVATORS. -MONITOR HOLE ON TRIP TANK 10/5/2011 00:00 - 02:00 2.00 DRILL P SURF CONTINUE RIH WITH SURFACE DRILLING BHA#3 FROM 1316'TO 1960'MD. -P/U=120K, S/O= 116K 02:00 - 03:00 1.00 DRILL P SURF WASH DOWN FROM 1960'TO 1975'. -ENCOUNTER FILL ON BOTTOM -REAM HOLE TWICE FROM 1940'TO 1975' -593 GPM,1100 PSI -40 RPM,2-5K TQ 03:00 - 12:00 9.00 DRILL P SURF DIRECTIONALLY DRILL 16"SURFACE HOLE FROM 1,975'TO 2,487'MD. -700 GPM,1350 PSI ON/1200 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.74 PPG -40 RPM,4K TQ ON/2K TQ OFF -2K WOB -P/U= 135K, 5/0=135K, ROT= 125K -AST=3.06,ART=1.53,ADT=4.59 12:00 - 00:00 12.00 DRILL P SURF DRILL SURFACE HOLE FROM 2.487 TO 3.205' MD. -820 GPM,2100 PSI ON/1900 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=10.2 PPG -40 RPM,7K TQ ON/6K TQ OFF -5-20K WOB -P/U= 159K, S/0=124K, ROT= 127K -AST=2.56,ART=2.97,ADT=5.53 Printed 11/28/2011 11:34:54AM Page 8 of 42 Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/6/2011 00:00 - 11:00 11.00 DRILL P SURF DIRECTIONALLY DRILL 16"SURFACE HOLE FROM 3.205'TO TD OF 3.893'MD. '{ -900 GPM,2295 PSI ON/2215 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.77 PPG -40 RPM,9K TQ ON/8K TQ OFF -16KWOB -P/U= 173K,S/O=135K, ROT=153K -AST=2.27,ART=4.84,ADT=7.11 11:00 - 13:00 2.00 DRILL P SURF CIRCULATE 2 BOTTOMS UP WHILE ROTATING AND RECIPROCATING. -900 GPM,2240 PSI -40 RPM,7K TQ 13:00 - 22:00 9.00 DRILL P SURF WIPER TRIP TO 1880'MD. PULLING TIGHT/ SWABBING. -PUMP OUT OF HOLE AT 600 GPM,1175 PSI 22:00 - 00:00 2.00 DRILL P SURF RIH CLEAN ON ELEVATORS FROM 1880'TO BOTTOM. 10/7/2011 00:00 - 01:30 1.50 DRILL P SURF CIRCULATE 2 BOTTOMS UP WHILE ROTATING AND RECIPROCATING. -900 GPM,2350 PSI -40 RPM,8K TQ -P/U=165K, S/O= 120K,ROT=146K 01:30 - 07:00 5.50 DRILL P SURF POOH ON ELEVATORS TO 844' HOLE TAKING PROPER DISPLACEMENT 07:00 - 13:00 6.00 DRILL P SURF LAY DOWN SURFACE DRILLING BHA.BIT AND STABILIZERS BALLED UP WITH CLAY. -BIT GRADED 6-5-WT-A-E-1-BU-TD 13:00 - 16:00 3.00 CASING P SURF R/U FOR RUNNING 13-3/8"CASING -R/D BX ELEVATORS AND BAILS -P/U LONG BAILS AND 13-3/8"SIDE DOOR ELEVATORS -INSTALL 350 TON SLIPS 16:00 - 17:00 1.00 CASING P SURF MAKE DUMMY RUN WITH 13-3/8"HANGER WITH LANDING JOINT. 17:00 - 18:00 1.00 CASING P SURF M/U VOLANT CASING RUNNING TOOL TO TOP DRIVE AND TORQUE TO 34K FT-LBS. 18:00 - 19:00 1.00 CASING P SURF P/U 13-3/8"CASING SHOE TRACK AND BAKER-LOK.FILL PIPE AND CHECK FLOATS- FLOATS HOLDING. 19:00 - 00:00 5.00 CASING P SURF CONTINUE RUNNING 13-3/8"68#L-80 BTC CSG WITH TORQUE RINGS FROM 129'TO 613' WITH VOLANT CRT. -TORQUE EACH CONNECTION TO 23K FT-LBS. -FILL EACH JOINT AND WASH DOWN EVERY 10AT5BPM. -MONITOR DISPLACEMENT VIA PITS#6,7, AND8 10/8/2011 00:00 - 01:00 1.00 CASING P SURF CONTINUE RUNNING 13-3/8"68#L-80 BTC CSG WITH TORQUE RINGS FROM 613'TO 726' WITH VOLANT CRT. -TORQUE EACH CONNECTION TO 23K FT-LBS. 01:00 - 03:30 2.50 CASING N RREP SURF TROUBLE LATCHING AND GETTING SIDE DOOR ELEVATORS TO SLIDE ON PIPE. -STRAP O.D.OF 13-3/8"CASING,ACTUAL O.D.OF CASING AVG 13.50" -DRESS INSIDE OF SIDE DOOR ELEVATORS WITH SANDING DISK TO ALLOW TO LATCH AROUND CASING. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 9 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 22:00 18.50 CASING P SURF CONTINUE RUNNING 13-3/8"68#L-80 BTC CSG WITH TORQUE RINGS FROM 726'TO 3834'WITH VOLANT CRT. -TORQUE EACH CONNECTION TO 23K FT-LBS. -FILL EACH JOINT AND WASH DOWN EVERY 10AT3BPM. -MONITOR DISPLACEMENT VIA PITS#6,7, AND 8. -TOTAL OF 95 JOINTS RAN. -PUSHING AWAY MUD WHILE RUNNING CASING,LOST TOTAL OF 250 BBLS 22:00 - 23:00 1.00 CASING P SURF P/U&M/U LANDING JOINT&13-3/8"FLUTED HANGER TO TOP OF JOINT#95 -HANGER PUP NOT MAKING UP [COMPLETELY 23:00 - 00:00 1.00 CASING P SURF HANGER PUP NOT MAKING UP TO SPEC. -BACKOUT HANGER PUP -CLEAN,INSPECT,AND DRESS HANGER THREADS 10/9/2011 00:00 - 01:30 1.50 CASING P SURF CONTINUE RE-DRESSING THREADS ON HANGER PUP -REPLACE COLLAR ON JOINT#95 BAKER-LOK AND M/U HANGER PUP TO TOP✓ OF JOINT#95 01:30 - 04:00 2.50 CEMT P SURF CIRCULATE BOTTOMS UP WHILE CONDITIONING MUD FOR CEMENT JOB -STAGE PUMPS UP TO 7 BPM/250 PSI -RECIPROCATE PIPE 20'STROKES -LOST TOTAL OF 30 BBLS WHILE CBU 04:00 - 05:00 1.00 CEMT P SURF R/D VOLANT CRT AND M/U CEMENT HEAD 05:00 - 07:00 2.00 CEMT P SURF CONTINUE TO CIRCULATE WHILE CONDITIONING MUD. -STAGE PUMPS UP TO 5 BPM/245 PSI -RECIPROCATE PIPE 20'STROKES -LOST 20 BBLS DURING CIRCULATION Printed 11/28/2011 11:34:54AM North America-ALASKA- BP Page 10 of 42 ry , +. ir' ntevcetT,W Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 13:30 6.50 CEMT P SURF CEMENT 13-3/8"SURFACE CASING WITH RECIPROCATION AS FOLLOWS: U' -HOLD PJSM WITH RIG CREW,SLB CEMENT Sµ- CREW,AND CH2MHILL -PUMP 5 BBLS 10.2 PPG MUD PUSH II -PRESSURE TEST LINES TO 3,500 PSI- GOOD -PUMP 95 BBLS 10.2 PPG MUD PUSH II AT 5 BPM,190 PSI -DROP BOTTOM PLUG. POSITIVE INDICATION PLUG LEFT CEMENT HEAD -PUMP 948 BBLS(2867 SX) 11.0 PPG DEEP CRETE LEAD CEMENT.YIELD 1.88 CUFT/SK -LAND CASING HANGER ON LANDING RING WHEN LEAD CEMENT ROUNDS SHOE -PUMP 120 BBLS(610 SX) 15.8 PPG CLASS G, TAIL CEMENT.YIELD 1.16 CUFT/SK -DROP TOP PLUG. POSITIVE INDICATION PLUG LEFT CEMENT HEAD -CHASE PLUG W/10 BBLS WATER F/SLB WASHING UP LINES SWAP TO RIG AND DISPLACE WITH 8.9 PPG DRILPLEX MUD -BEGIN DISPLACEMENT AT 3.5 BPM,350 PSI -INCREASE RATE TO 7 BPM,700 PSI AT 2470 STKS(248.7 BBLS) -SLOW RATE TO 5 BPM,1500 PSI AT 5330 STKS(536.7 BBLS) -SLOW RATE TO 3 BPM,1427 PSI AT 5410 STKS(544.8 BBLS) -BUMP PLUG AT 5546 STKS(558.5 BBLS)AT 1528 PSI -PRESSURE UP 500 PSI OVER FCP, HOLD FOR 5 MIN -BLEED OFF PRESSURE AND CHECK FLOATS, FLOATS HOLDING CMT IN PLACE 13:15 HRS -626 BBLS OF CEMENT BACK TO SURFACE .--- -FULL RETURNS AND GOOD LIFT PRESSURE— THROUGHOUT RESSURETHROUGHOUT JOB LEAD CEMENT REACHES 500 PSI COMPRESSIVE STRENGTH IN 14 HRS 52 MIN TAIL CEMENT REACHES 500 PSI COMPRESSIVE STRENGTH IN 15 HRS 56 MIN 13:30 - 18:00 4.50 CEMT P SURF R/D CEMENT LINE AND CEMENT HEAD BACK OUT LANDING JOINT AND L/D FLUSH RISER, FLOWLINE,AND CELLAR BOX R/D DIVERTER PIPE 18:00 - 00:00 6.00 CEMT P SURF FUNCTION AND FLUSH HYDRIL ELEMENT -N/D HYDRIL BAG AND KNIFE VALVE -P/U SURFACE RISER AND DIVERTER TEE TO RIG FLOOR AND L/D THROUGH BEAVER SLIDE 10/10/2011 00:00 - 09:30 9.50 CEMT P SURF INSTALL FMC 13-5/8"BIG BORE WELLHEAD N/U HIGH PRESSURE RISER AND BOPE -INSTALL DUTCH RISER NIPPLE,CHOKE AND KILL LINES,AND HOLE FILL LINE INSTALL SECONDARY ANNULUS VALVES Printed 11/28/2011 11:34:54AM North America -ALASBP KA- _ 42 of Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 'X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual©70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 11:30 2.00 BOPSUR P SURF RIG UP BOP TEST EQUIPMENT. -M/U TIW AND DART VALVES -INSTALL TEST PLUG,FILL SURFACE EQUIPMENT AND CHECK FOR LEAKS 11:30 - 16:30 5.00 BOPSUR P SURF TEST BOPE TO 250 PSI LOW,4000 PSI HIGH AS PER AOGCC AND BP POLICY.TEST ANNULAR PREVENTER TO 250 PSI LOW,2500 PSI HIGH.EACH TEST 5 CHARTED MINUTES. TEST THE ANNULAR, UPPER VARIABLES, AND LOWER VARIABLES WITH 5 IN TEST JOINT. 1 FAILED TEST ON LOWER IBOP.TEST WITNESSED BY JEFF JONES WITH AOGCC. D`' TEST WITNESSED BY WSL MIKE DINGER AND TOOLPUSHER MIKE MEADOWS. PERFORMED ACCUMULATOR TEST:SYSTEM PRESSURE 3,140 PSI,PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,800 PSI.RECOVERED 1ST 200 PSI-30 SECONDS.FULL RECOVERY 109 SEC WITH 2 ELECTRIC AND 2 AIR PUMPS.6 NITROGEN BOTTLES,AVERAGE PRESSURE= 2,316-PSI. CLOSING TIMES -ANNULAR=23 SECONDS -UPPER VBR=18 SECONDS -BLIND/SHEARS=16 SECONDS -LOWER VBR= 16 SECONDS -CHOKE HCR=2 SECONDS -KILL HCR=2 SECONDS 16:30 - 18:30 2.00 BOPSUR P SURF UD TEST PLUG, P/U AND INSTALL WEAR BUSHING, R/D LONG BAILS. 18:30 - 21:30 3.00 BOPSUR N RREP SURF CHANGE OUT LOWER IBOP 21:30 - 22:00 0.50 BOPSUR N HMAN SURF PULL WEAR BUSHING 22:00 - 23:00 1.00 BOPSUR N HMAN SURF MAKE-UP 10'PUP AND SINGLE FOR 5"TEST JOINT AND INSTALL TEST PLUG,R/U TO RE-TEST ANNULAR. 23:00 - 00:00 1.00 BOPSUR N HMAN SURF FILL STACK AND BLEED AIR. RE-TEST ANNULAR TO 250 PSI LOW,3500 PSI HIGH FOR 5 MIN EACH PER BP POLICY.TEST LOWER IBOP TO 250 PSI LOW,4000 PSI HIGH FOR 5 MIN EACH.TEST WITNESSED BY WSL GARRET STAUDINGER AND TOURPUSHER JOHN NEWMAN. 10/11/2011 00:00 - 01:30 1.50 BOPSUR N HMAN SURF PULL TEST PLUG AND INSTALL WEAR RING. -R/D TESTING EQUIPMENT. 01:30 - 05:30 4.00 CASING P SURF R/U TO RUN 5"DRILLPIPE SINGLES FROM PIPESHED. -R/U MEDIUM BAILS, BX ELEVATORS, ROTATING ARM,AND BELL GUIDE. -MOVE 5"HWDP STANDS FROM OFF-DRILLERS SIDE TO DRILLERS SIDE. -CHANGE OUT SLIP INSERTS. -REMOVE STRIP-O-MATIC&SECURE FLOW BOX. -CLEAN CLEAR&RIG FLOOR. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 12 of 42 Operation Summary Report Common Well Name.04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30.00AM Rig Release. Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 11:00 5.50 CASING P SURF PJSM.SINGLE IN THE HOLE WITH 117 JOINTS OF 5"DP ON MULE SHOE TO 3,652'-MD -P/U=118K,S/O=120K -MONITOR DISPLACEMENT ON TRIP TANK 11:00 - 12:00 1.00 CASING P SURF CIRCULATE 1-1/2 BOTTOMS UP -545 GPM,450 PSI BLOW DOWN TD,MONITOR WELL-STATIC 12:00 - 15:00 3.00 CASING P SURF POOH FROM 3652'-MD TO SURFACE, RACKING BACK 5"DP. -MONITOR DISPLACEMENT ON TRIP TANK. 15:00 - 16:30 1.50 CASING P SURF P/U BIT&STABILIZERS THROUGH BEAVERSLIDE. -SERVICE RIG,LUBRICATE ROTARY TABLE. 16:30 - 18:00 1.50 CASING P SURF PRESSURE TEST 13-3/8"CSG T0250 PSI FOR 5 MIN AND 3500 PSI FOR 30 MIN-TEST PASSED-WTL APPROVAL TO CONTINUE OPERATIONS -8 BBLS TO REACH TEST PRESSURE -LOST 37 PSI IN FIRST 15 MIN -LOST 0 PSI IN SECOND 15 MIN -8 BBLS RETURNED 18:00 - 20:00 2.00 CASING P SURF PJSM. M/U 12-1/4"ROTARY STEERABLE DRILLING BHA AS PER SLB D.D. 20:00 - 20:30 0.50 CASING P SURF TEST SLB POWER DRIVE RSS AT ROTARY TABLE -300 GPM,80 PSI AND 623 GPM,465 PSI. 20:30 - 22:30 2.00 CASING P SURF UD JOINT OF HWDP FOR RSS TEST& CONTINUE TO M/U BHA AS PER SLB D.D. 22:30 - 23:00 0.50 CASING P SURF INSTALL 5"SLIP INSERTS&CENTERING GUIDE. 23:00 - 00:00 1.00 CASING P SURF RIH HWDP TO 849'-MD -MONITOR WELL ON TRIP TANK(STATIC) 10/12/2011 00:00 - 01:00 1.00 CEMT P SURF RIH WITH 12-1/4"DRILLING BHA ON 5" SINGLES FROM PIPE SHED FROM 849'MD TO 938'MD. -LUBE AND ADJUST LINK TILT AND ROTATOR ON BX ELEVATORS. 01:00 - 01:30 0.50 CEMT P SURF SHALLOW PULSE TEST MWD @ 938'MD -674 GPM,1130 PSI 01:30 - 04:00 2.50 CEMT P SURF RIH ON 5"FROM SINGLES IN PIPE SHED FROM 938'MD TO 2538'MD -MONITOR DISPLACEMENT ON TRIP TANK 04:00 - 06:30 2.50 CEMT P SURF CONTINUE RIH FROM 2538'MD TO 3766'MD ON STANDS -TAG CEMENT 21'MD ABOVE FLOAT COLLAR 06:30 - 10:00 3.50 CEMT P SURF DRILL OUT CEMENT&FLOAT EQUIPMENT FROM 3766'MD TO 3865'MD -P/U=170K,S/0=145K, ROT=152K -600 GPM,1350 PSI ON,1275 PSI OFF -50 RPM,8-10K TQ -WOB 5-12K TAG FLOAT COLLAR ON DEPTH 10:00 - 11:30 1.50 CEMT P SURF DISPLACE WELL TO 9.2 PPG LSND MUD -515 GPM,670 PSI -50 RPM,7-8K TQ Printed 11/28/2011 11:34.54AM North America -ALASKA- BP Page 13 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 14:30 3.00 CEMT P SURF CONTINUE DRILLING SHOE TRACK FROM 3865'MD TO 3870'MD&20'OF NEW FORMATION TO 3914'MD -P/U=170K, S/O= 145K,ROT=152K -600 GPM,950 PSI -50 RPM,10-11K TQ ON,6-8K TQ OFF -WOB 5-12K SPR'S @ 3865'MD,3775'TVD-MW=9.2 PPG, TIME=11:30 #1 MP-20/30 SPM=110/130 PSI #2 MP-20/30 SPM=110/140 PSI 14:30 - 15:30 1.00 CEMT P SURF CIRCULATE BOTTOMS UP ✓ -MW 9.2 IN/ 9.2 OUT -OBTAIN CLEAN HOLE ECD @ 800 GPM,1520 PSI=9.56 PPG 15:30 - 16:30 1.00 CEMT P SURF PULL UP INTO CASING AND PERFORM LOT L C� -12.5 PPG EMW LEAK OFF PRESSURE -ODE APPROVAL TO CONTINUE OPERATIONS WITH A GREATER THAN 50 BBL KICK TOLERANCE 16:30 - 19:00 2.50 DRILL P INTI 'DRILL 12-1/4"INTERMEDIATE HOLE FROM 3914'MD TO 4054'MD. -843 GPM,1675 PSI ON/1600 PSI OFF -MW 9.2 IN/9.2 OUT, ECD=9.76 PPG -120 RPM,12-13K TQ -15K WOB -P/U=157K,S/O= 145K,ROT=153K -ADT= 1.36 SPR'S @ 3914 MD,3811'TVD-MW=9.2 PPG, TIME= 17:00 #1 MP-20/30 SPM= 120/140 PSI #2 MP-20/30 SPM=120/140 PSI 19:00 - 21:30 2.50 DRILL N SFAL INTI SCHLUMBERGER MWD COMPUTER PROGRAMMING ISSUES STAND BACK 2 STANDS TO CASING SHOE 21:30 - 22:00 0.50 DRILL P INTI SERVICE IRON DERRICKMAN 22:00 - 00:00 2.00 DRILL N RREP INTI REPAIR HYDRAULIC CONNECTION ON IRON DERRICKMAN 10/13/2011 00:00 - 00:30 0.50 DRILL N RREP INTI REPLACE HYDRAULIC FITTING ON IRON DERRICKMAN -CIRC AT 84 GPM,110 PSI 00:30 - 01:00 0.50 DRILL P INTI SERVICE TOP DRIVE AND TRAVELING EQUIPMENT -CIRC AT 84 GPM,110 PSI 01:00 - 02:30 1.50 DRILL N SFAL INTI MAD PASS FROM 3880'MD T04055'MD -847 GPM,1730 PSI -50 RPM,6-7K TQ 02:30 - 12:00 9.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 4054'MD TO 5185'MD -880 GPM,2265 PSI ON/2260 PSI OFF -MW 9.4 IN/9.4 OUT -160 RPM,TQ=10-12K ON/7K OFF -P/U= 187K,S/O=153K, ROT=172K -25K WOB,ADT=6.26 SPR'S @ 5185'MD,4935'TVD-MW=9.5 PPG, TIME=12:00 #1 MP-20/30 SPM=150/190 PSI #2 MP-20/30 SPM=150/190 PSI Printed 11/28/2011 11:34:54AM Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 00:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 5185'MD TO 6602'MD -880 GPM,2750 PSI ON/2700 PSI OFF -MW 9.6 IN/9.6 OUT, ECD=10.15 PPG -160 RPM,TQ=10-20K ON/12-14K OFF -P/U=228K,S/O= 174K,ROT=196K -25K WOB,ADT=6.73 SPR'S @ 6130'MD,5773'TVD-MW=9.6 PPG, TIME= 19:30 #1 MP-20/30 SPM= 190/220 PSI #2 MP-20/30 SPM=190/220 PSI 10/14/2011 00:00 - 12:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 6602'MD to 7361'MD(6890'TVD) -880 GPM,3080 PSI ON/3050 PSI OFF -MW 10.2 IN/10.2 OUT, ECD=10.54 PPG -80 RPM,TQ=8-11K ON/6-7K OFF -P/U=213K, S/O= 194K,ROT=201K -12K WOB,ADT=6.65 SPR'S @ 7265'MD,6801'TVD-MW= 10.2 PPG,TIME=09:00 #1 MP-20/30 SPM=200/240 PSI #2 MP-20/30 SPM=190/200 PSI 12:00 - 00:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 7361'MD to 8113'MD(7569'TVD) -880 GPM,3370 PSI ON/3350 PSI OFF -MW 10.4 IN/10.4 OUT, ECD=10.75 PPG -160 RPM,TQ=11-16K ON/8-9K OFF -P/U=222K,S/O=205K, ROT=212K -25K WOB,ADT=8.96 SPR'S @ 7730'MD SPR'S @ 8043'MD,7478'TVD-MW=10.45 PPG,TIME=22:30 #1 MP-20/30 SPM=240/300 PSI #2 MP-20/30 SPM=240/300 PSI 10/15/2011 00:00 - 12:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 8113'MD to 8675'MD -880 GPM,3600 PSI ON/3550 PSI OFF -MW 10.4 IN/10.4 OUT, ECD= 10.78 PPG -140 RPM,TQ=8-23K ON/8-10K OFF -P/U=234K, S/O=209K, ROT=225K -32K WOB,ADT=9.4 SPR'S @ 8589'MD,7961'TVD-MW=10.4 PPG,TIME=09:15 #1 MP-20/30 SPM=200/240 PSI #2 MP-20/30 SPM=210/200 PSI 12:00 - 00:00 12.00 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 8675'MD to 8967'MD(8314'TVD) -880 GPM,3440 PSI ON/3530 PSI OFF MW 10.4 IN/10.4 OUT, ECD=10.78 PPG -80-160 RPM,TQ=9-16K ON/9-10K OFF -P/U=240K,S/O=212K, ROT=226K -8-28K WOB,ADT=10.39 Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 15 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/16/2011 00:00 - 09:30 9.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 8967'MD TO 9265'MD -880 GPM,3570 PSI ON/3550 PSI OFF -MW 10.4 IN/10.4 OUT, ECD=10.73 PPG -130 RPM,TQ=11-16K ON/9-11K OFF -P/U=254K,5/0=214K, ROT=235K -20K WOB,ADT=7.09 CIRC B/U AT 9270'LOOKING FOR TSAD CASING PICK SPR'S @ 9145'MD,8467'ND-MW=10.45 PPG,TIME=05:20 #1 MP 20/30 SPM=200/240 PSI #2 MP-20/30 SPM=200/230 PSI 09:30 - 11:00 1.50 DRILL P INTI CIRC B/U AT 9265'MD LOOKING FOR TSAD CASING PICK -880 GPM,3630 PSI -MW 10.4 IN/10.4 OUT, ECD= 10.66 PPG 11:00 - 12:30 1.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM 9265'MD TO 9270'MD CIRC B/U AT 9265'MD LOOKING FOR TSAD CASING PICK 12:30 - 13:00 0.50 DRILL P INTI DRILL 12-1/4"INTERMEDIATE HOLE FROM `o 9270'MD TO 9275'MD(8575'TVD) -880 GPM,3630 PSI ON/3500 PSI OFF -MW 10.4 IN/10.4 OUT, ECD=10.66 PPG -130 RPM,TQ=7-20K ON/9-10K OFF -P/U=245K,S/O=212K,ROT=235K -20K WOB,ADT=0.17 13:00 - 14:30 1.50 DRILL P INTI CIRC B/U AT 9275'MD LOOKING FOR TSAD CASING PICK -880 GPM,3630 PSI -MW 10.4 IN/10.4 OUT, ECD= 10.66 PPG 12-1/4"INTERMEDIATE TD CALLED BY GEOLOGY AT 9275'MD(8575'ND) -TOTAL BIT HRS=56.61,TOTAL JAR HRS= 87.5 14:30 - 16:00 1.50 DRILL P INTI PUMP 30 BBL HI-VIS SWEEP AROUND -40%INCREASE IN CUTTINGS UPON SWEEP RETURN 16:00 - 16:30 0.50 DRILL P INTI MONITOR WELL FOR 10 MIN-STATIC -MW 10.4 IN/10.4 OUT -INSTALL 5"SLIP INSERTS SPR'S @ 9275'MD,8575'ND-MW=10.4 PPG,TIME=16:00 #1 MP-20/30 SPM=180/220 PSI #2 MP-20/30 SPM=180/220 PSI 16:30 - 18:30 2.00 DRILL P INTI PUMP OUT OF HOLE FROM 9275'MD TO 8210' MD -126 GPM,400 PSI -P/U=250K 18:30 - 19:00 0.50 DRILL P INTI MONITOR WELL FOR 10 MIN-STATIC -MW 10.4 IN/10.4 OUT PUMP DRY JOB AND BLOW DOWN TOP DRIVE 19:00 - 00:00 5.00 DRILL P INTI POOH ON ELEVATORS FROM 8210'MD TO 3871'MD MONITOR HOLE ON TRIP TANK Printed 11/28/2011 11:34:54AM Page 16 of 42 Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/17/2011 00:00 - 01:00 1.00 DRILL P INTI CIRCULATE 2 BOTTOMS UP AT THE SHOE. -840 GPM,2200 PSI -160 RPM,4K TQ 01:00 - 02:00 1.00 DRILL P INTI PJSM FOR CUT AND SLIP DRILLING LINE. TROUBLE SHOOT SLB DRAWWORKS ENCODER 02:00 - 05:00 3.00 DRILL P INTI CUT AND SLIP DRILLING LINE. SERVICE TOP DRIVE,BLOCKS,AND CROWN SHEAVES -INSPECT SAVER SUB -C/O AIR BOOT ON FLOW LINE -C/O DIES ON TOP DRIVE -CALIBRATE SLB BLOCK HEIGHT 05:00 - 11:00 6.00 DRILL P INTI RIH ON ELEVATORS FROM 3871'MD TO 9159' MD WASH AND REAM TO 9275'MD. 11:00 - 14:00 3.00 DRILL P INTI CIRC WHILE ROT AND RECIP FROM 9275'MD TO 9180'MD -845 GPM,3520 PSI -MW 10.4 IN/10.4 OUT -100 RPM,TQ=10-11K -P/U=268K, S/O=210K 14:00 - 14:30 0.50 DRILL P INTI MONITOR WELL FOR 10 MIN-STATIC -MW=10.4PPGINANDOUT L/D SINGLE TO 9244'MD AND SPOT 35 BBL LCM 40 PPG PILL ON BTM -380 GPM,870 PSI 14:30 - 17:00 2.50 DRILL P INTI POOH FROM 9244'MD TO 8306'MD -105 GPM,250 PSI ENCOUNTERED TIGHT SPOTS W/25K+ OVERPULL -FROM 9100'MD TO 9000'MD -FROM 8800'MD TO 8700'MD -S/O AND PULL BACK THROUGH WITHOUT PROBLEM -MW=10.4 PPG IN AND OUT 17:00 - 17:30 0.50 DRILL P INTI MONITOR WELL FOR 10 MIN-STATIC -MW= 10.4 PPG IN AND OUT -PUMP DRY JOB AND BLOW DOWN TOP DRIVE 17:30 - 20:30 3.00 DRILL P INTI POOH ON ELEVATORS FROM 8306'MD TO 5865'MD -MONITOR WELL ON TRIP TANK 20:30 - 21:00 0.50 DRILL P INTI DROPPED OBOE T_7,EINGER RETAIN SPRING FELL FROM DERRICK-SEE REMARKS -INSPECT ALL RACKING FINGERS AND SPRINGS 21:00 - 23:00 2.00 DRILL P INTI POOH ON ELEVATORS FROM 5865'MD TO 3871'MD -MONITOR WELL ON TRIP TANK 23:00 - 00:00 1.00 DRILL P INTI CIRC B/U INSIDE 13-3/8"CASING SHOE -800 GPM,2215 PSI 10/18/2011 00:00 - 01:00 1.00 DRILL P INTI MONITOR WELL FOR 10 MIN-STATIC -MW=10.4 PPG IN AND OUT PUMP DRY JOB AND B/D TOP DRIVE 01:00 - 02:00 1.00 DRILL P INTI POOH RACKING BACK 5"DP FROM 3871'MD TO 1980'MD -MONITOR WELL ON TRIP TANK -L/D GHOST REAMER AT 2263'MD Printed 11/28/2011 11:34:54AM North America-ALASKA-BP Page iWf12 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 04:00 2.00 DRILL N RREP INTI INSTALL SAFETY CABLE ON DRILL PIPE FINGER RETENTION SPRING B/D CHOKE LINE AND CONDUCT KICK WHILE TRIPPING DRILL 04:00 - 04:30 0.50 DRILL P INTI POOH RACKING BACK 5"DP FROM 1980'MD TO 849'MD -MONITOR WELL ON TRIP TANK 04:30 - 05:00 0.50 DRILL P INTI PJSM WITH DDI,SLB AND BPXA ON LID BHA PROCEDURE. -MONITOR WELL ON TRIP TANK 05:00 - 07:30 2.50 DRILL P INTI L/D BHA PER SLB REP MONITOR WELL ON TRIP TANK 07:30 - 09:00 1.50 DRILL P INTI CLEAN AND CLEAR RIG FLOOR, PULL WEAR BUSHING,PERFORM AAR WITH SLB. 09:00 - 11:00 2.00 BOPSUR P INTI CIO UPPER PIPE RAMS TO 9-5/8"FOR CASING RUN AND FUNCTION TEST BOPE. R/U TEST EQUIPMENT. 11:00 - 12:00 1.00 BOPSUR P INTI PRESSURE TEST UPPER 9-5/8"PIPE RAMS- CHARTED -250 PSI LOW/4000 PSI HIGH -5 MIN LOW/5 MIN HIGH -GOOD TEST,WITNESSED BY WSL(DAVE NEWLON) R/D TEST EQUIPMENT 12:00 - 15:00 3.00 CASING P INTI R/U TO RUN 9-5/8"CSG -R/D BX ELEVATORS,MEDIUM LENGTH BAILS AND BELL GUIDE -R/U VOLANT TOOL, LONG BAILS,SIDE DOOR ELEVATORS AND LINK TILT 15:00 - 15:30 0.50 CASING P INTI PERFORM DUMMY RUN WITH LANDING JT AND HANGER 15:30 - 16:30 1.00 CASING P INTI P/U BAKERLOK FLOAT SHOE,COLLAR AND LANDING COLLAR -FLOAT CHECK-GOOD -MW=10.4 PPG IN AND OUT 16:30 - 00:00 7.50 CASING P INTI RIH WITH 9-5/8"L-80.40#.HYF1563 (.SG. USING VOLANT CSG RUNNING TOOL TO 2006' MD. MAKING UP CONNECTIONS TO 13,000 FT-LBS.TORQUE. VERIFIED TOP DRIVE MAKE UP TORQUE VALUE WITH RIG TONGS. -FILLING EVERY JT,CIRC DOWN EVERY 10 JTS -148 GPM,30 PSI -P/U= 108K,S/O=105K 10/19/2011 00:00 - 06:00 6.00 CASING P INTI RIH WITH 9-5/8"L-80,40#, HYD563,CSG USING VOLANT CSG RUNNING TOOL FROM 2006'MD TO 3875'MD -FILLING EVERY JT,CIRC DOWN EVERY 10 JTS 06:00 - 07:00 1.00 CASING P INTI CIRC B/U WHILE RECIP FROM 3875'MD TO 3835'MD -210 GPM,170 PSI 07:00 - 08:30 1.50 CASING N RREP INTI REPAIR PIPE SKATE -CIRC AND RECIP AT 210 GPM,170 PSI 08:30 - 20:30 12.00 CASING P INTI RIH WITH 9-5/8"L-80,40#, HYD563,CSG USING VOLANT CSG RUNNING TOOL FROM 3875'MD TO 8477'MD -FILLING EVERY JT,CIRC DOWN EVERY 10 JTS Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 18 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type. DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 22:30 2.00 CASING P INTI CIRC B/U WHILE RECIP BEFORE ENTERING HRZ -294 GPM,340 PSI -MW=10.4 PPG IN AND OUT 22:30 - 00:00 1.50 CASING P INTI RIH WITH 9-5/8"L-80,40#,HYD563,CSG USING VOLANT CSG RUNNING TOOL FROM 8477'MD TO 9153'MD -FILLING EVERY JT,CIRC DOWN EVERY 10 JTS 10/20/2011 00:00 - 01:00 1.00 CASING P INTI RIH WITH 9-5/8"L-80,40#, HYD563,CSG USING VOLANT CSG RUNNING TOOL FROM 9153'MD TO 9269'MD, LAND CASING ON HANGER. -FILLING EVERY JT,CIRC DOWN EVERY 10 JTS -WASH DOWN LANDING JT 01:00 - 04:00 3.00 CASING P INTI CIRCULATE 2X BOTTOMS UP WHILE CONDITIONING MUD FOR CEMENT JOB -STAGE PUMPS UP FROM 2 BPM TO 7 BPM/ 370 PSI -LOST TOTAL OF 0 BBLS WHILE CBU -CASING LANDED ON HANGER,NO RECIPROCATION OF PIPE 04:00 - 04:30 0.50 CEMT P INTI R/D VOLANT CRT AND M/U CEMENT HEAD AND CEMENT LINE 04:30 - 05:00 0.50 CEMT P 1NT1 PJSM WITH RIG CREW,NIGHT SLB CEMENT CREW,CH2MHILL,BPXA ON 9-5/8"CEMENT JOB 05:00 - 06:00 1.00 CEMT N SFAL INTI CIRC THROUGH CEMENT HEAD WHILE SLB TROUBLE SHOOT CEMENT COMPUTER SYSTEM -7 BPM,480 PSI -C/O CEMENT TRUCK FOR NEW COMPUTER SYSTEM Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 19 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 10:30 4.50 CEMT P INTI CEMENT 9-5/8"INTERMEDIATE CASING WITH OUT RECIPROCATION AS FOLLOWS: ,�f -HOLD PJSM WITH RIG CREW,DAY SLB �1 CEMENT CREW AND BPXA p� -CASING LANDED ON HANGER FOR ENTIRE (Anr�r CEMENT JOB CEMENT PUMPING UNIT -PUMP 10 BBLS 13 PPG MUD PUSH AT 4 BPM, 530 PSI -PRESSURE TEST LINES TO 4,000 PSI- GOOD -PUMP 40 BBLS 13 PPG MUD PUSH AT 5 BPM, 480 PSI -DROP BOTTOM PLUG.POSITIVE INDICATION PLUG LEFT CEMENT HEAD -PUMP 124 BBLS(600 SX)15.8 PPG CLASS G TAIL CEMENT.YIELD 1.16 CUFT/SK.5 BPM, 230 PSI. -DROP TOP PLUG.POSITIVE INDICATION PLUG LEFT CEMENT HEAD -CHASE PLUG W/10 BBLS,WATER TO FLUSH CEMENT LINES.5.7 BPM,250 PSI. SWAP TO RIG AND DISPLACE WITH 10.4 PPG LSND MUD -DISPLACEMENT RATE 7 BPM,165 PSI AT 443 BBLS -SLOW RATE TO 5 BPM,285 PSI AT 564 BBLS (CEMENT AT SHOE) -SLOW RATE TO 3 BPM,870 PSI AT 690 BBLS (10 BBL FROM PLUG BUMP) -BUMP PLUG AT 696 BBLS AT 900 PSI __ -CONTINUE TO PUMP AT 3 BPM PLUG NOT BUILDING PRESSURE OVER 1500 PSI -STOPPED PUMPING AT 704 BBLS -HOLD 700 PSI ON CASING CMT IN PLACE 10:30 HRS -124 BBLS OF CEMENT IN PLACE -LOST 28 BBLS WHILE DISPLACING CEMENT -GOOD LIFT PRESSURE THROUGHOUT JOB, FINAL CEMENT LIFT PRESSURE 900 PSI TAIL CEMENT REACHES 500 PSI COMPRESSIVE STRENGTH IN 4 HRS 24 MIN 10:30 - 11:30 1.00 CEMT P INTI BLEED OFF PRESSURE AND CHECK FLOATS, FLOATS NOT HOLDING. -SHUT IN CASING AND PLACE PRESSURE GAUGE ON CEMENT HEAD -PRESSURE INCREASE TO 500 PSI -ROCK FLOATS,BLEED BACK 4 BBLS AND SHUT IN CASING -FLOATS STILL NOT HOLDING 11:30 - 12:00 0.50 CEMT P INTI R/D AND B/D CEMENT LINE,OFFLOAD PITS, SERVICE RIG FLOOR EQUIPMENT Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 20 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 14:30 2.50 CEMT P INTI SAFETY STAND DOWN MEETING WITH DAY CREW, FOCUSING ON IMPROVING SAFETY AWARENESS WITH GOOD GROUP DISCUSSION AND QUESTIONS FOLLOWED BY CHECK SIX PRESENTATION ON SITUATIONAL AWARENESS AND COMPLACENCY. 14:30 - 15:30 1.00 CEMT P INTI BLEED APPROXAMANTLY 10 GALLONS FROM CASING, RIG DOWN CEMENT HEAD,LANDING JOINT, LONG BAILS AND SIDE DOORS. 15:30 - 18:00 2.50 CEMT P INTI RIG UP MEDIUM BAILS,BX ELEVATORS, ROTATING ARM AND LINK TILT 18:00 - 19:00 1.00 WHSUR P INTI Mill RUNNING TOOL ON 5"HWDP,RUN IN AND SET PACK OFF,RILDS AND FMC TEST -250/5000 PSI,5/30 MINUTE TEST -GOOD TEST WITNESSED BY WSL MIKE HEFLEY 19:00 - 19:30 0.50 WHSUR P INTI P/U NEW TEST PLUG AND WEAR BUSHING 19:30 - 20:30 1.00 BOPSUR P INTI C/O TOP PIPE RAMS TO 2-7/8"X 5-1/2"VBR'S, INSPECT DOOR SEALS,C/O ONE SEAL ON PALFINGER SIDE 20:30 - 22:00 1.50 BOPSUR P INTI INSTALL TEST PLUG,OPEN AND INSPECT ALL DOOR SEALS ON ALL RAM DOORS-ALL GOOD AND CLEAN,GREASE AND BUTTON UP 22:00 - 22:30 0.50 BOPSUR - P INTI SERVICE RIG,PULL POWER SLIPS TO CLEAN AND GREASE. 22:30 - 00:00 1.50 CASING P INTI R/U AND TEST LINES TO 3500 PSI AND PERFORM INJECTIVITY TEST ON 9-5/8"X 13-3/8"ANNULUS. -ANNULUS PRUSSURED UP TO 930 PSI BEFORE BREAKING OVER -INJECT 10.8 PPG MUD DOWN O.A.AT 127 GPM,830 PSI 10/21/2011 100:00 - 02:30 2.50 WHSUR P INTI FREEZE PROTECT 9-5/8"X 13-3/8"ANNULUS -PUMP 283 BBLS OF 10.8 PPG MUD AT 126 GPM,830 PSI -PUMP 132 BBLS OF 80 DEG,6.8 PPG ARCTIC GRADE DIESEL AT 126 GPM,1030 PSI -R/D CIRC EQUIPMENT 02:30 - 03:00 0.50 BOPSUR P INTI PRESSURE TEST BOP 2-7/8"X 5-1/2"PIPE RAMS -250/4000 PSI,5/5 MIN CHARTED TEST -GOOD TEST 03:00 - 04:30 1.50 CASING P INTI PRESSURE TEST 9-5/8"CASING �+ -250/4000 PSI,5/30 MIN CHARTED TEST _ FAILFD TFST CIRCULATE FOR 5 MIN RE-PRESSURE TEST 9-5/8"CASING -250/4000 PSI,5/30 MIN CHARTED TEST -FAILED TEST 04:30 - 05:00 0.50 BOPSUR N DFAL INTI PRESSURE TEST BOP BLIND RAMS -250/4000 PSI,5/5 MIN -GOOD TEST 05:00 - 06:30 1.50 CASING N DFAL INTI R/D TEST EQUIPMENT,CLOSE BLIND RAMS, SECURE WELL. WAIT ON ORDERS 06:30 - 08:00 1.50 CASING P INTI SAFETY STAND DOWN WITH NIGHT RIG CREW.DISCUSS SAFETY AWARENESS. Printed 11/28/2011 11:34:54AM North America -ALASKA BP Page 21 of 42 Operation Summary Report a Common Well Name:04-350 AFE No Event Type:DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 CASING N DFAL INTI INSTALL BELL GUIDE.SERVICE RIG FLOOR EQUIPMENT WHILE WAITING ON RTTS PACKER. 08:30 - 09:00 0.50 CASING N DFAL INTI PJSM FOR RUNNING RTTS, LOAD RTTS. 09:00 - 09:30 0.50 CASING N DFAL INTI INSTALL WEAR BUSHING 09:30 - 10:00 0.50 CASING N DFAL INTI M/U RTTS PACKER PER HALLIBURTON.C/O SLIP INSERTS. 10:00 - 12:00 2.00 CASING N DFAL INTI RIH WITH RTTS PACKER ON 5"DP STANDS TO 2374'MD -MONITOR WELL ON TRIP TANK 12:00 - 14:00 2.00 CASING P INTI SAFETY STAND DOWN WITH DAY RIG CREW. DISCUSS SAFETY AWARENESS. 14:00 - 14:30 0.50 CASING N DFAL INTI PJSM FOR RUNNING RTTS. 14:30 - 15:30 1.00 CASING N DFAL INTI INSPECT IRON DERRICK MAN AND TOP DRIVE 15:30 - 16:00 0.50 CASING '`N DFAL INTI RIH WITH RTTS PACKER ON 5"DP STANDS FROM 2374'MD TO 3317'MD MONITOR WELL ON TRIP TANK 16:00 - 16:30 0.50 CASING N DFAL INTI SERVICE TOP DRIVE 16:30 - 17:00 0.50 CASING N RREP INTI SECURE GUIDE DOLLY ASSEMBLY RETAINING PINS 17:00 - 22:00 5.00 "" CASING N DFAL INTI RIH WITH RTTS PACKER ON 5"DP STANDS FROM 3317'MD TO 9077'MD -MONITOR WELL ON TRIP TANK 22:00 - 23:00 1.00 CASING N DFAL INTI CIRC DP VOL,163 BBLS -394 GPM,700 PSI 23:00 - 00:00 1.00 CASING N DFAL INTI SET 9-5/8"HES RTTS AT 9163'MD,ATTEMPT TO TEST,CIRC VALVE ON RTTS NOT HOLDING RE-SET RTTS AND TRY 4X 10/22/2011 00:00 - 00:30 0.50 CASING N. DFAL INTI SET 9-5/8"HES RTTS AT 9163'MD, CONFIRMED CIRC VALVE HOLDING ON RTTS. 00:30 - 03:00 2.50 CASING N DFAL INTI PRESSURE TEST 9-5/8",CASING AT 9163'...MD -250/4000 PSI,5/30 MIN CHARTED TEST -FAILED TEST RE-SET RTTS RE-PRESSURE TEST 9-5/8"CASING AT 9163' MD -250/4000 PSI,5/30 MIN CHARTED TEST -FAILED TEST 03:00 - 04:30 1.50 CASING N DFAL INTI CIRC SURFACE TO SURFACE,645 BBLS -294 GPM,570 PSI 04:30 - 08:00 3.50 CASING N DFAL INTI PULL UP TO 9070'MD AND SET RTTS PRESSURE TEST 9-5/8"CASING AT 9070'MD -250/4000 PSI,5/30 MIN CHARTED TEST -FAILED TEST ELIMINATE SURFACE EQUIPMENT RE-PRESSURE TEST 9-5/8"CASING AT 9070' MD -250/4000 PSI,5/30 MIN CHARTED TEST -RETEST FAILED 08:00 - 09:00 1.00 CASING N DFAL INTI PRESSURE TEST BELOW RTTS AT 9070'MD -250/4000 PSI -TEST FAILED 09:00 - 10:30 1.50 CASING N DFAL INTI PUMP OUT OF HOLE FROM 9070'MD TO 8881' MD AND SET RTTS -252 GPM,520 PSI Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 22 of 42? Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 8881'MD -250/4000 PSI,5/30 MIN CHARTED TEST -FAILED TEST RELEASE RTTS PACKER,BLOW DOWN TOP DRIVE AND KILL LINE 11:30 - 12:00 0.50 CASING N DFAL INTI MONITOR WELL FOR 10 MINUTES-STATIC -MW 10.4 PPG IN AND OUT PUMP DRY JOB, BLOW DOWN TOP DRIVE AND KILL LINE 12:00 - 12:30 0.50 CASING N DFAL INTI INSPECT IRON DERRICKMAN AND TOP DRIVE 12:30 - 16:00 3.50 CASING N DFAL INTI POOH STANDING BACK 5"DP FROM 8881'MD TO 5011'MD, -MONITORING WELL ON TRIP TANK 16:00 - 16:30 0.50 CASING N DFAL INTI CIRCULATE AND RECIPROCATE PIPE ACROSS PACKER SETTING DEPTH -PUW=154K,SOW= 132K -168 GPM,170 PSI SET RTTS AT 5005'MD,BLOW DOWN TOP DRIVE 16:30 - 17:30 1.00 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 500SMD -250/4000 PSI,5/30 MIN CHARTED TEST -FAILEIITFST BLOW DOWN AND RELEASE RTTS 17:30 - 18:30 1.00 CASING N DFAL INTI MONITOR WELL FOR 10 MIN-STATIC -MW 10.4 PPG IN AND OUT PUMP DRY JOB,BLOW DOWN TOP DRIVE 18:30 - 21:00 2.50 ' CASING N DFAL INTI POOH FROM 5011'MD TO 1804'MD -MONITOR WELL ON TRIP TANK 21:00 - 21:30 0.50 CASING N DFAL INTI KICK WHILE TRIPPING DRILL,CONDUCT AAR WITH WSL,TOOL PUSHER AND CREW 21:30 - 22:30 1.00 CASING _ N DFAL INTI POOH STANDING BACK 5"DP FROM 1804'MD TO 672'MD -MONITOR WELL ON TRIP TANK 22:30 - 23:30 1.00 CASING N DFAL INTI MONITOR WELL FOR 10 MIN-STATIC -MW 10.4 PPG IN AND OUT PJSM FOR TESTING CASING WHILE CIRCULATING -PUW= 67K,SOW=73K -252 GPM,100 PSI 23:30 - 00:00 0.50 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 663'MD 'V -75n/4000 PSI,5/30 MIN CHARTFD TFT _ -GOOD TEST 10/23/2011 00:00 - 01:00 1.00 CASING N DFAL INTI POOH AND UD RTTS PACKER 01:00 - 02:30 1.50 CASING N DFAL INTI RIH WITH NEW RTTS PACKER ON 5"DP STANDS TO 1040'MD 02:30 - 03:00 0.50 CASING N DFAL INTI CIRCULATE DRILL PIPE VOLUME AND RECIPROCATE THROUGH SETTING DEPTH -252 GPM,110 PSI 03:00 - 04:00 1.00 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 1040'MD -250/4000 PSI,5/30 MIN CHARTED TEST -PASSING TEST 04:00 - 06:00 2.00 CASING N DFAL INTI RIH WITH NEW RTTS PACKER ON 5"DP STANDS FROM 1040'TO 2553'MD , / 06:00 - 07:30 1.50 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 2553'MD X -250/4000 PSI,5/30 MIN CHARTED TEST -PASSING TEST 07:30 - 08:00 0.50 CASING N DFAL INTI SERVICE IRON DERRICKMAN, BX ELEVATORS AND SLIPS Printed 11/28/2011 11:34:54AM North America-ALASKA-BP Page 23 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 14:00 6.00 CASING N RREP INTI TROUBLE SHOOT IRON DERRICKMAN, REPAIR HYDRAULIC HOSES AND C/O ENCODER CABLE AND ENCODER ON IDM. 14:00 - 14:30 0.50 CASING N DFAL INTI RIH WITH NEW RTTS PACKER ON 5"DP STANDS FROM 2553'MD TO 2751'MD -MONITOR WELL ON TRIP TANK 14:30 - 15:00 0.50 CASING N DFAL INTI MONITOR WELL FOR 10 MIN-STATIC -MW=10.5 PPG IN AND OUT 15:00 - 16:30 1.50 CASING N DFAL INTI RIH FROM 2751'MD TO 5011'MD MONITOR WELL ON TRIP TANK 16:30 - 17:00 0.50 CASING N DFAL INTI CIRCULATE AND RECIPROCATE PIPE ACROSS PACKER SETTING DEPTH -PUW=156K,SOW=132K -252 GPM,340 PSI SET RTTS AT 5001'MD,BLOW DOWN TOP DRIVE 17:00 - 17:30 0.50 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 5001'MD -250/4000 PSI,5/30 MIN CHARTED TEST -PASSING TEST 17:30 - 18:30 1.00 CASING N DFAL INTI TEST SURFACE EQUIPMENT,SERVICE TOP DRIVE, IRON DERRICKMAN, BLOW DOWN INJECTION LINE,RELEASE RTTS 18:30 - 21:30 3.00 CASING N DFAL INTI RIH FROM 5001'MD TO 8888'MD -MONITOR WELL ON TRIP TANK 21:30 - 22:30 1.00 CASING N DFAL INTI CIRCULATE AND RECIPROCATE PIPE ACROSS PACKER SETTING DEPTH -PUW=240K,SOW=180K -252 GPM,480 PSI PUMP 30 BBL CITRIC ACID PILL -252 GPM,480 PSI PUMP 134 BBL 10.3 PPG MUD -126 GPM,380 PSI PUMP 20 BBLS OF 10.3 PPG MUD AND RECIPROCATE PIPE 15'STROKES 22:30 - 00:00 1.50 CASING N DFAL INTI SET 9 5/8"RTTS PACKER AT 8876'MD,BLOW DOWN TOP DRIVE 10/24/2011 00:00 - 00:30 0.50 CASING N DFAL INTI SET RTTS AT 8876'MD AND BLOW DOWN TOP DRIVE 00:30 - 01:30 1.00 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 8876'MD -250/4000 PSI,5/30 MIN CHARTED TEST -PASSING TEST 01:30 - 02:00 0.50 CASING N DFAL INTI RIH WITH RTTS FROM 8876'MD TO 9171'MD -P/U=236K,S/O=183K 02:00 - 02:30 0.50 CASING N DFAL INTI CIRCULATE AND RECIPROCATE AT 9160'MD -252 GPM,580 PSI -15'STROKES 02:30 - 03:30 1.00 CASING N DFAL INTI PRESSURE TEST 9-5/8"CASING AT 9160'MD -250/4000 PSI,5/30 MIN CHARTED TEST -� -PASSING TEST -80 PSI DROP IN FIRST 15 MIN -10 PSI DROP IN SECOND 15 MIN WTL APPROVAL TO PROCEED 03:30 - 04:00 0.50 CASING N DFAL INTI RELEASE RTTS, B/D INJECTION LINE, INSPECT IDM AND DERRICK PRIOR TO POOH MONITOR WELL FOR 10 MIN-STATIC -MW 10.5 PPG IN AND OUT 04:00 - 08:30 4.50 CASING N DFAL INTI POOH WITH RTTS STANDING BACK 5"DP FROM 9160'MD TO 4160'MD -MONITOR WELL ON TRIP TANK Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 24 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 11:30 3.00 CASING N RREP INTI DROPPED OBJECT-BROKEN PIPE RETAINER SPRING FELL FROM DERRICK RACKING BOARD. CLEARED FLOOR AND SECURED AREA. SAFETY INVESTIGATION CONDUCTED AND A PLAN FORWARD WAS AGREED UPON. REMOVED MOST OF THE END LOADING SPRINGS(PIPE NEEDS TO BE MOVED TO REPLACE ALL). INSPECTED REMAINING SPRINGS AND RACKING BOARD, CLEARED TO CONTINUE OPERATIONS. 11:30 - 13:30 2.00 CASING N DFAL INTI POOH WITH RTTS STANDING BACK 5"DP FROM 4160'MD TO 578'MD -MONITOR WELL ON TRIP TANK 13:30 - 14:00 0.50 CASING N DFAL INTI MONITOR WELL FOR 10 MIN-STATIC -MW 10.5 PPG IN AND OUT 14:00 - 15:00 1.00 CASING N DFAL INTI POOH FROM 578'MD TO SURFACE AND L/D RTTS AS PER HALLIBURTON REP -MONITOR WELL ON TRIP TANK 15:00 - 15:30 0.50 CASING P INTI CLEAN AND CLEAR RIG FLOOR, DRAIN BOP STACK,PULL WEAR RING. 15:30 - 17:00 1.50 BOPSUR P INTI PJSM, INSTALL TEST PLUG,RIG UP TO TEST BOPE. CONDUCT WELL KILL DRILL 17:00 - 00:00 7.00 BOPSUR P INTI TEST BOPE TO 250 PSI LOW,4000 PSI HIGH AS PER AOGCC AND BP POLICY.TEST THE a, UPPER AND LOWER VARIABLES WITH 5"AND VA 4"TEST JOINTS.TEST ANNULAR PREVENTER WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH.EACH TEST 5 CHARTED MINUTES. -64 AOGCC,BOB NOBLE WAIVED WITNESS TO TEST AT 08:00 HRS ON 10/23/2011.TEST WITNESSED BY WSL MIKE HEFLEY AND TOOLPUSHER JOHN(ERIC)RODLAND. PERFORMED ACCUMULATOR TEST:SYSTEM PRESSURE 3050 PSI,PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1700 PSI.RECOVERED 1ST 200 PSI-24 SECONDS.FULL RECOVERY 124 SEC WITH 2 ELECTRIC AND 2 AIR PUMPS.6 NITROGEN BOTTLES,AVERAGE PRESSURE= 2241 PSI. CLOSING TIMES -ANNULAR=28 SECONDS WITH 4"DP -UPPER VBR= 18 SECONDS WITH 4"DP,19 SECONDS WITH 5"DP -BLIND/SHEARS=28 SECONDS -LOWER VBR=19 SECONDS WITH 4"DP,19 SECONDS WITH 5"DP -CHOKE HCR=2 SECONDS -KILL HCR=2 SECONDS 10/25/2011 00:00 - 04:00 4.00 CASING N RREP INTI REMOVE REMAINING PIPE RETAINING SPRINGS ON THE END OF THE DERRICK FINGERS. REPLACED SAFETY WIRES ON SPRINGS WITH NEW 1/8"GALVANIZED SAFETY CABLES. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 25 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual©70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:30 0.50 CASING P INTI PJSM WITH RIG CREW,SLB,AND BPXA. 04:30 - 05:30 1.00 DRILL P INT2 M/U 8-3/4"BIT TO POWERDRIVE. SHALLOW TEST AS PER D.D.@ 410-GPM @ 320-PSI. BLEW DOWN TOP DRIVE. 05:30 - 06:30 1.00 DRILL P INT2 CONTINUE PICKING UP BHA#5 COMPONENTS AS FOLLOWS: -8-3/4"HYCALOG PDC BIT -POWERDRIVE RSS -ARC6 -MWD -ADN6 -6-3/4"NMDC FLEX COLLAR -6-3/4"NMDC FLEX COLLAR -6-3/4"NMDC FLEX COLLAR -PORTED FLOAT SUB -MI BALL CATCHER -MI WELL COMMANDER CIRC.SUB -1 JT.5"50.5#/FT. HWDP -6-3/4"SMITH HYDRAULIC JAR -19 JTS.5"50.5#/FT.HWDP TOTAL LENGTH-862.12' 06:30 - 07:00 0.50 DRILL P INT2 PJSM-DDI,SLB&BPX. LOADING AND HANDLING NUKE SOURCES. 07:00 - 09:00 2.00 DRILL P INT2 COMPLETE PICKING UP AND MAKING UP BHA #5. ✓ 09:00 - 10:00 1.00 DRILL P INT2 CHANGED OUT PS-21 SLIP INSERTS. SHALLOW TEST MWD @ 550-GPM @ 1251-PSI. 10:00 - 12:00 2.00 DRILL P INT2 RIH WITH BHA#5 ON 5"DP FROM DERRICK FROM 862'TO 3702'. MONITOR HOLE FILL VIA PIT#2. 12:00 - 16:30 4.50 DRILL P INTI CONTINUE RIH WITH 5"DP FROM DERRICK FROM 3702'TO 9077'. FILLED PIPE EVERY 20 STANDS. MONITORED HOLE FILL VIA PIT#2. 16:30 - 18:30 2.00 DRILL P INT2 OBTAIN PARAMETERS: -PUW=253K -SOW= 189K -ROT WT.=225K -RPM=40 -FREE TQ.=18-19K FT-LBS. -GPM=350 @ 1075-PSI WASH DOWN FROM 9077'TO 9191'MD. TAG FLOAT COLLAR AT 9184'. DRILL FLOAT EQPT. AT 40-RPM WITH 1-8K WOB,18-19K TQ.AT 450-GPM AND 1290-PSI. WASH DOWN TO 9255'. MONITOR WELL FOR 10-MINUTES. MUD RETURNS SEVERELY AIRED UP. OBTAIN SPR'S IN PREPARATION FOR MUD SWAP. SPR'S @ 9168'MD: PUMP#1 20-SPM=300-PSI,30-PSM= 400-PSI PUMP#2 20-SPM=300-PSI,30-PSM= 360-PSI Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 26 of 42 Operation Summary Report,. Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 21:00 2.50 DRILL P INT2 PJSM-DISPLACE WELL TO 9.0-PPG LSND MUD. PUMPED 40-BBLS.WATER,40-BBL. HI-VIS SPACER FOLLOWED BY 676-BBLS. 9.0-PPG LSND MUD @ 440-GPM AND 1560-PSI ICP. OBTAIN SPR'S @ 9168'MD: PUMP#1 20-SPM=200-PSI,30-PSM=280-PSI PUMP#2 20-SPM=200-PSI,30-PSM= 260-PSI 21:00 - 22:00 1.00 DRILL P INT2 RE-LOG FROM 9165'TO 9267'MD. 22:00 - 23:30 1.50 DRILL P INT2 DRILL OUT SHOE TRACK AND 13'OF NEW HOLE FROM 9267'TO 9288'MD. -480 GPM @ 1340-PSI -60-RPM -18-22K TQ.ON 16K TQ OFF REPLACING CABLE TETHERS ON FINGER SPRINGS ON DERRICK BOARD. 23:30 - 00:00 0.50 DRILL P INT2 CBU 482-BBLS.@ 480--GPM @ 1340-PSI AND 40-RPM @ 13-16K TQ. 10/26/2011 00:00 - 01:00 1.00 DRILL N HMAN 9,287.00 INT2 CONTINUE CBU. CORRECTED HOLE DEPTH VIA CORRECTED PIPE TALLY DEPTH. RECIP FROM 9258'MD TO 9287'MD -480 GPM,1340 PSI 01:00 - 01:30 0.50 DRILL P INT2 DRILL ADDITIONAL NEW HOLE FROM 9288' TO 9295'TO OBTAIN 20'MINIMUM OF NEW HOLE BEFORE PERFORMING FIT. -40-RPM -480-GPM @ 1376-PSI -11K TQ.OFF -18-19K ON -11-18K WOB 01:30 - 02:00 0.50 DRILL P INT2 CBU IN PREPARATION FOR F.I.T. 02:00 - 03:00 1.00 DRILL P INT2 PERFORM F.I.T.TO 12.0-PPG EMW PER ADWOP SOP AND DDI PROCEDURE. -CASING SHOE @ 9275'MD,8575'TVD -MW=9.0-PPG -SURFACE PSI=1339-PSI -BH ..t.PSI - MW=12.0-PPG'. 03:00 - 04:00 1.00 DRILL P INT2 ESTABLISH BILINE ECD OF 9.65-PPG AT 580-GPM AT 1820-PSI AT 9295'. 04:00 - 08:00 1 4.00 DRILL P INT2 DRILLING AHEAD FROM 9287'TO 9579' TOWARD STOPPING POINT AT 20'ABOVE KAVIK. -596 GPM,1990 PSI ON/1990PS1 OFF -MW 9.2 IN/9.1 OUT, ECD=9.96-PPG -120 RPM,TQ= 19-21K ON/13-14K OFF -P/U=261K,S/O=206K, ROT=233K -20K WOB SUSTAINED HIGH WIND SPEEDS OF 40+MPH WITH GUSTS TO 60+MPH DURING THE NIGHT. SEVERE AMOUNT OF WIND BORNE SAND AND DIRT. Printed 11/28/2011 11:34:54AM 1:,4111gr' 'ACECommon Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 10:00 2.00 DRILL P INT2 CBU X 2 WHILE ROTATING AND RECIPROCATING @ 580-GPM,1930-PSI, 120-RPM,12-14K TQ. PUMPED 11000 STROKES(1100-BBLS.) SPOTTED 15.0-BBL. LCM PILL IN IVISHAK. BLEW DOWN TOP DRIVE. 10:00 - 11:00 1.00 DRILL P INT2 POH ON ELEVATORS FROM 9579'TO 9258. FILL HOLE AND MONITOR DISPLACEMENT ON TRIP TANK. 11:00 - 11:30 0.50 DRILL P INT2 RIG UP AND PERFORM F.I.T. PERADWOP SOP AND DDI PROCEDURE. PRESSURE UP AT 5.0-SPM TO 1285-PSI. TOTAL STROKES PUMPED=37. EMW=12.0-PPG. BLEW DOWN KILL LINE 11:30 - 12:00 0.50 DRILL P INT2 RIH ON ELEVATORS FROM 9258'TO 9545'MD. P/U SINGLE 12:00 - 13:00 1.00 DRILL P INT2 CBU AT 580 GPM 1960 PSI 13:00 - 15:00 2.00 DRILL P INT2 SPIKE MUD WIEGHT FROM 9 PPG TO 10.4 PPG -580 GPM,1990 PSI MONITOR WELL FOR 10 MIN 15:00 - 18:00 3.00 DRILL P INT2' " DRILLING AHEAD FROM 9579'MD TO 9750'MD 2060 GPM,2060 PSI ON/2090 PSI OFF -ECD=11.04-PPG -120 RPM,TQ=17-19K ON/13-15K OFF -P/U=255K,S/O=205K,ROT=209K -PUMP 2OBBL LCM PILL AT 9637'MD 18:00 - 19:30 1.50 DRILL P INT2 CIRC OUT CUTTINGS SAMLPES AT 9750'MD ✓Y -570 GPM,2185 PSI 19:30 - 22:00 2.50 DRILL P INT2 DRILL 8 3/4"INTERMEDIATE 2 HOLE FROM 9750'MD to 9866'MD(9043 TVD) -570 GPM,2220 PSI ON/2230 PSI OFF -MW 10.4 IN/10.4 OUT, ECD=11.22 PPG -120 RPM,TQ=14-18K ON/13-17K OFF -P/U=255K, 5/0=208K, ROT=213K -10-20K WOB,ADT=6.74 22:00 - 00:00 2.00 DRILL P INT2 CIRCULATE HOLE CLEAN -570 GPM,2190 PSI CIRCULATE 30 BBL HI-VIS SWEEP,DISPLACE WITH 10.4 LSND MUD. -570 GPM,2260 PSI MONITOR WELL RECOVERED SWEEP TO CUTTINGS TANK. NO INCREASE IN CUTTINGS WHEN SWEEP RECOVERED. 10/27/2011 00:00 - 00:30 0.50 DRILL P INT2 MONITOR WELL FOR FLOW FOR 10-MINUTES. NO FLOW. BLEW DOWN TOP DRIVE. 00:30 - 01:00 0.50 DRILL P INT2 POH ON ELEVATORS FROM 9866'MD TO 9-5/8"SHOE. MONITOR HOLE FILL FOR PROPER DISPLACEMENT VIA TRIP TANK. 01:00 - 02:30 1.50 DRILL P INT2 CLEAN RIG DUE TO SEVERE BLOWING SAND. CLEAN FILTERS ON EQUIPMENT. 02:30 - 04:30 2.00 DRILL P INT2 RIH FROM 9257'ON ELEVATORS.WASH LAST STAND DOWN TO TD AT 9866'MD. CIRCULATE SURFACE TO SURFACE TO CONDITION HOLE AND MUD. RECIPROCATE AND ROTATE PIPE. SWAB FAILED ON#2 MUD PUMP. 04:30 - 05:00 0.50 DRILL P INT2 MONITOR WELL FOR FLOW-10 MINUTES. WELL STABLE. Printed 11/28/2011 11:34:54AM North America -ALASKA BP Page 28 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project: Prudhoe Bay Site:PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 DRILL P INT2 POH ON ELEVATORS TO 9100'MD. 05:30 - 06:30 1.00 DRILL P INT2 WORK PIPE AND CIRCULATE ACROSS LINER TOP PACKER SETTING DEPTH FROM 9161' TO 9066'MD @ 600-GPM @ 2130-PSI. ROTATTED PIPE AT 120-RPM WITH 12-13K TQ. TOTAL STROKES PUMPED=7280. 06:30 - 07:00 0.50 DRILL P INT2 MONITOR WELL. STATIC. MIXED AND PUMPED 25-BBLS.OF 12.4-PPG DRY JOB @ 4.5-BBLS./MIN.@ 440 PSI. BLEW DOWN TOP DRIVE. 07:00 - 12:00 5.00 DRILL P INT2 POH FROM 9161'TO 2470'MD. MONITOR DISPLACEMENT VIA TRIP TANK. 12:00 - 14:00 2.00 DRILL P INT2 RESUME POH FROM 2470'TO 1997'MD. HOLE NOT TAKING CORRECT DISPLACEMENT. FLOW CHECKED WELL FOR 20-MINUTES. HOLE IS STATIC. RESUME POH FROM 1997'TO 862'MD. MONITORED WELL FOR 10-MINUTES FOR FLOW. HOLE IS STATIC. PJSM-LAYING DOWN 5"HWDP. 14:00 - 14:30 0.50 DRILL P INT2 POH FROM 862'TO 330'LAYING DOWN 18 JOINTS OF 5"HWDP. CHANGE OUT PS-21 SLIP INSERTS TO HAND SLIP BUSHINGS. CONTINUE LAYING DOWN BHA#5 COMPONENTS. 14:30 - 18:00 3.50 DRILL P INT2 CONTINUE POH LAYING DOWN BHA#5. PJSM-HANDLING NUKE SOURCES. REMOVE NUKE SOURCES TO TRANSPORTATION SHIELD PER SLB PROCEDURE. 18:00 - 19:30 1.50 DRILL P INT2 MONITOR WELL FOR 10-MINUTES. PJSM- CHANGING PIPE RAMS. DRAIN BOP STACK. PULL WEAR BUSHING AND SET TEST PLUG. CLEAN AND CLEAR RIG FLOOR. 19:30 - 00:00 4.50 DRILL P INT2 SWAP UPPER PIPE RAMS FROM 2-7/8"X 5-1/2"VBR'S TO 4-1/2"X 7"VBR'S. TEST UPPER PIPE RAMS WITH 5"AND 7"TEST JOINTS. UNABLE TO GET ACCEPTABLE TEST WITH 7"TEST JOINT. SCREWED FOSV ON BOTTOM OF 7"TEST JOINT tTO RAISE JOINT AND MOVE RAM CLOSING AREA ON JOINT DOWN. OBTAINED PASSING PRESSURE TEST WITH BOTH 5"AND 7"TEST JOINTS. TESTED RAMS TO 250-PSI LO/4000-PSI HI FOR 5/5 CHARTED MINUTES. RAM CLOSING TIME ON 5"TEST JOINT=19 SEC. RAM CLOSING TIME ON 7"TEST JOINT= 15 SEC. 10/28/2011 00:00 - 01:30 1.50 CASING P INT2 SET WEAR BUSHING I.D. =9-1/16". RIG UP 7" DOUBLE STACK HYDRAULIC POWER TONGS WITH TORQUE TURN EQUIPMENT. INSTALL 7"INSERTS IN BX ELEVATORS AND 7"SLIP INSERTS IN PS-21 SLIP BOWL. PJSM- PICKING UP AND RUNNING CASING. 01:30 - 02:30 1.00 CASING P INT2 TROUBLESHOOT HYDRAULIC POWER TONG OPERATION. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 29 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type:DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 05:30 3.00 CASING P INT2 PICKED UP AND MADE UP 7"#1 CASING SHOE JOINT WITH DAVIS-LYNCH REAM MASTER SHOE,7"HES FLOAT COLLAR BAKER-LOK'D TO#2 JOINT AND#3 JOINT WITH BAKER INSERT LANDING COLLAR INSTALLED. APPLIED BAKER-LOK TO BOTH COUPLED THREAD JOINTS AND TORQUE TURNED CONNECTIONS TO OPTIMUM TORQUE OF 11,950 FT-LBS. FILLED SHOE TRACK WITH MUD. PULLED SHOE TRACK OUT OF HOLE TO ALLOW MUD TO DRAIN. OBSERVED FLUID LEVEL HAD DROPPED. RAN SHOE TRACK BACK IN HOLE AND CHECKED FLOATS. FLOATS ARE HOLDING. RIH WITH 7"26#,L-80 VAMTOP HC INTERMEDIATE 2 LINER FROM PIPE SHED. TORQUE TURNING EACH CONNECTION TO 11,950 FT-LBS.OPTIMUM TORQUE. USED JET LUBE SEAL GUARD THREAD COMPOUND AND STABBING GUIDE. USED DOG COLLAR ON FIRST 10 JOINTS. 05:30 - 06:00 0.50 CASING P INT2 CIRCULATE 1-1/2 LINER VOLUMES(40-BBLS.) @ 5.0-BPM @ 85-PSI. 06:00 - 08:00 2.00 CASING P INT2 RIH WITH 7"LINER ON 5"DP FROM DERRICK FROM 767'TO 2570'MD. MONITOR DISPLACEMENT VIA PIT#2. FILLED PIPE EVERY 15 STANDS. 08:00 - 12:00 4.00 CASING P INT2 CONTINUE RIH WITH 5"DP FROM 2570'TO 6337'MD. MONITORING DISPLACEMENT VIA PIT#2. FILLING PIPE EVERY 15 STANDS WHILE RIH. 12:00 - 15:00 3.00 CASING P INT2 CONTINUE RIH FROM 6337'TO 9173'MD. MONITORING DISPLACEMENT VIA PIT#2. FILLING PIPE EVERY 15 STANDS WHILE RIH. 15:00 - 15:30 0.50 CASING P INT2 PICK UP AND MAKE UP BAKER CEMENT HEAD WITH SINGLE JOINT OF DP AND 10' PUP. LAY SAME BACK DOWN ON PIPE SKATE. 15:30 - 17:00 1.50 CASING P INT2 CIRCULATE BOTTOMS UP @0 9137'. WASH DOWN TO 9268'@ 6.0-BPM @ 530-PSI. PUW =224K,SOW=187K. ROTATED STRING AT 20-RPM WITH 9K FT-LBS. FREE TQ. BLEW DOWN TOP DRIVE. 17:00 - 18:30 1.50 CASING P INT2 RIH FROM 9268'TO 9835'MD. MONITOR DISPLACEMENT VIA PIT#2. MAKE UP BAKER CEMENT HEAD. CONTINUE RIH FROM 9835' TO TAG AT 9867'MD WITH 4k DOWNWEIGHT. PUW=233K,SOW=187K. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 30 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 19:00 0.50 CASING P INT2 ESTABLISH CIRCULATION @ 1.OBPM. STAGE PUMP UP TO 5.0-BPM @ 495-PSI. AT 89-BBLS (867 STROKES)AWAY,TOTCO PVT'S INDICATED A PIT GAIN. SHUT DOWN PUMP TO FLOW CHECK WELL. WELL APPEARED TO BE FLOWING WITH LARGE AMOUNT OF PERCOLATION AT FLOW RISER. SHUT IN WELL WITH ANNULAR PREVENTER AGAINST CLOSED CHOKE. MANUAL TANK STRAP INDICATED A 2.0-BBL.GAIN. INSTANT SICP= 0-PSI, SIDPP=0-PSI. MADE NOTIFICATIONS TO ADW BASE OPERATIONS DRILLING SUPERINTENDENT AND DAY WELLSITE LEADER. 19:00 - 20:00 1.00 CASING N DPRB 9,867.00 INT2 MONITOR WELL. FILL MUD/GAS SEPARATOR. TESTED CEMENT LINE TO 4000-PSI. MONITOR SIDPP AND SICP. SIDPP =0-PSI,SICP=0-PSI. OPENED ANNULAR PREVENTER AND MONITORED WELL. WELL IS STATIC. DISCUSSED AND AGREED PATH FORWARD WITH ADW BASE OPERATIONS SUPERINTENDENT. 20:00 - 22:00 2.00 CASING N DPRB 9,867.00 INT2 CLOSED ANNULAR PREVENTER AND CIRCULATED @ 1.0-BPM @ 200-PSI,1.5-BPM @ 260-PSI. AT 1500 STROKES PUMPED OPENED SUPER CHOKE BYPASS TO REDUCE BACKPRESSURE ON ANNULUS AND CONTINUED CIRCULATING TAKING RETURNS THROUGH SUPER CHOKE AND BYPASS AND THROUGH MUD/GAS SEPARATOR. ✓ INCREASED CIRCULATION RATE TO 3.5-BPM @ 425-PSI. MUD WT. IN=10.4-PPG,OUT= 10.4-PPG. 22:00 - 00:00 2.00 CASING N DPRB 9,867.00 INT2 CIRCULATING BOTTOMS UP THROUGH CHOKE MANIFOLD AT 3.5-BPM @ 425-PSI. 10/29/2011 00:00 - 01:00 1.00 CASING N DPRB 9,867.00 INT2 COMPLETED CIRCULATING BOTTOMS UP AT 3.5-BPM AT 425-PSI THROUGH CHOKE. SHUT DOWN PUMPING AND MONITORED WELL FOR FLOW FOR 15-MINUTES. NO FLOW OBSERVED. CLOSED ANNULAR PREVENTER AND SHUT IN WELL. BLED OFF 100-PSI FROM DRILLPIPE. MONITORED SICP AND SIDPP FOR 30-MINUTES. 0-PSI BUILDUP NOTED. CONTACTED ADW BASE OPERATIONS SUPERINTENDENT AND AGREED PLAN FORWARD TO OPEN WELL AND MONITOR WELL FOR FLOW. OPENED SUPER CHOKE AND ANNULAR PREVENTER. MONITORED WELL FOR 30-MINUTES WITH NO FLOW OBSERVED. 01:00 - 01:30 0.50 CASING P INT2 PJSM-REVIEWED CEMENTING 7"LINER PROCEDURE WITH DDI,SLB,CH2,SCS AND BPXA PERSONNEL. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 31 of 42 Operation Summary Report Common Well Name:04-350 'AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 06:00 4.50 CASING P INT2 CEMENT 7"LINER WITHOUT RECIPROCATION AS FOLLOWS: -HOLD PJSM WITH RIG CREW,DAY SLB CEMENT CREW AND BPXA -CASING LANDED ON BOTTOM AT 9866'MD FOR ENTIRE CEMENT JOB. CEMENT PUMPING: 1" . -PUMP 5 BBLS 13.0-PPG MUD PUSH AT 3.0-BPM,614-PSI C41 4, -PRESSURE TEST LINES TO 4,609-PSI. GOOD TEST -PUMP 30.0-BBLS 13.0-PPG MUD PUSH AT 6.0-BPM AND 1086-PSI -PUMP 45.2-BBLS,YIELD 1 17(218 SX) _ 15.8-PPG CLASS G TAIL CEMENT WITH GAS-BLOK AT 6.0-BPM AND 230-PSI. -DROP DRILL PIPE WIPER DART.POSITIVE INDICATION DART LEFT CEMENT HEAD. -CHASE PLUG W/10.0-BBLS.FRESH WATER TO FLUSH CEMENT LINES AT 6.0-BPM AND 270-PSI. -SWAP TO RIG AND DISPLACE WITH 10.4-PPG LSND MUD AT 6.0-BPM. -SLOW RATE TO 3.0-BPM AT 125-BBLS. AWAY TO LATCH UP WIPER PLUG. -LATCH UP WIPER PLUG WITH 1106-PSI.AND 138-BBLS.AWAY. -DISPLACEMENT RATE 6 BPM AT 0-PSI AT 150.0-BBLS -SLOW RATE TO 3.0-BPM,0-PSI AT 160.0-BBLS -BUMP PLUG AT 162.4-BBLS ATI 117-PS1 -PRESSURED UP ON PLUG TO 3006-PSI TO SET LINER HANGER. -PRESSURED UP TO 4000-PSI AND HELD FOR 5-MINUTES. -BLED OFF PRESSURE AND CHECKED FLOATS. FLOATS HOLDING. -SET 75K DOWNWEIGHT ON PACKER. PICKED UP TO PICKUP WEIGHT AND ROTATED STRING AT 15-RPM. SLACKED OFF TO 75K DOWNWEIGHT. GOOD SET ON PACKER. -BLEW DOWN AND RIGGED DOWN 2" CEMENT HOSE. -PRESSURED UP DP TO 1000-PSI. PICKED UP UNTIL PRESSURE DROPPED AND THEN PUMPED 30-BBLS.TO CLEAN OUT LINER TIE-BACK RECEPTACLE. PICKED UP 30'AND STAGED PUMP UP TO 10-BPM @ 730-PSI. CIRCULATE EXCESS CEMENT OUT AT 10-BPM @ 735-PSI. • -RECOVERED AN ESTIMATED 6.0-BBLS.OF NEAT CEMENT. MW IN= 10.4-PPG,MW OUT= 10.3-PPG. -CEMENT IN PLACE AT 02:33-HRS. -LOST 0.0-BBLS WHILE DISPLACING CEMENT GOOD LIFT PRESSURE THROUGHOUT JOB, FINAL CEMENT LIFT PRESSURE 1074-PSI Printed 11/28/2011 11:34:54AM _ Page 32 of 42 rJ, 11 ! tkArate- Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site:PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum_:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 12:00 6.00 CASING P INT2 MONITOR WELL FOR FLOW. WELL IS STATIC. POH ON ELEVATORS WITH BAKER 7"LINER RUNNING TOOL FROM 9098'MD (LINER TOP). BROKE OUT AND LAYED BAKER CEMENT HEAD DOWN. CONTINUE POH TO 8230'. MONITOR WELL FOR FLOW. WELL IS STATIC. PUMPED 25-BBL. 12.2-PPG SLUG. POH FROM 8230'ON ELEVATORS TO 4188'MD. PUW= 129K,SOW=125K. 12:00 - 15:00 3.00 CASING P INT2 CONTINUE POH FROM 4188'MD TO 110'. MONITOR HOLE FILL VIA TRIP TANK. MONITOR WELL FOR FLOW. NO FLOW. LAYED DOWN 7"LINER RUNNING TOOL. 15:00 - 16:00 1.00 CASING P INT2 CLEAR AND CLEAN RIG FLOOR. PULLED PS-21 SLIP INSERTS. DRAINED BOP STACK. PULLED WEAR BUSHING AND SET UPPER TEST PLUG. PULLED TEST JOINT AND FUNCTIONED BLIND RAMS. 16:00 - 20:00 4.00 BOPSUR P INT2 PJSM-C/O UPPER PIPF RAMS_CHANGED OUT UPPER PIPE RAMS FROM 4-1/2"X 7" VBR'S TO 2-7/8"X 5-1/2"VBR'S. TESTED UPPER PIPE RAMS WITH 2-7/8"AND 5"TEST JTS.TO 250-PSI LO/4000-PSI HI FOR 5/5 CHARTED MINUTES. TESTED ANNULAR WITH 2-7/8"AND 5"TEST JOINTS TO 250-PSV3500-PSI FOR 5/5 CHARTED MINUTES. TESTED LOWER RAMS WITH 2-7/8" TEST JT.TO 250-PSI LO/4000-PSI HI FOR 5/5 CHARTED MINUTES. 20:00 - 22:00 2.00 CASING P INT2 PRESSURE TEST 9-5/8"X 7"CASING,LINER_ PER BPXA STP WELLBORE INTEGRITY TESTING CRITERIA. TESTED CASING TO 250-PSI LO/4000-PSI FOR 5/30 CHARTED MINUTES. PRESSURE DROP IN 1ST 15 MINUTES=20-PSI, PRESSURE DROP IN 2ND 15 MINUTES= 10-PSI. E-MAILED TEST DATA TO ADW BASE OPERATIONS SUPERINTENDENT FOR REVIEW AND RECEIVED APPROVAL TO PROCEED WITH PLANNED FORWARD OPERATIONS. BLEW DOWN MUD LINES FROM VA TO MUD PUMP. RIGGED DOWN TEST EQUIPMENT. 22:00 - 23:30 1.50 DRILL P PROD1 CHANGE OUT BX ELEVATOR INSERTS TO 4" DP INSERTS. INSTALLED HAND SLIP BUSHINGS IN PS-21 SLIP BOWL. BRING BHA #6 COMPONENTS TO RIG FLOOR. INSPECT IRON DERRICKMAN AND RACKING BOARD FINGER SPRINGS. SERVICE AND INSPECT TOP DRIVE. CHANGE OUT HAND SLIP HANDLES ON 3-1/2",4"AND 4-3/4"DRILL COLLAR SLIPS. 23:30 - 00:00 0.50 DRILL P PROD1 PJSM-PICKING UP BHA#6-6-1/8"DRILLING BHA. 10/30/2011 00:00 - 04:30 4.50 DRILL P PROD1 PICK UP,MAKE UP AND RIH 6-1/8"LISBURNE PRODUCTION HOLE DRILLING BHA#6 AND RIH TO 1425'PICKING UP 4"DP DOUBLES FROM PIPE SHED. PERFORMED SHALLOW MWD TEST AT 1425'MD. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 33 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 12:00 7.50 DRILL P PROD1 RIH WITH BHA#6 ON 5"DP FROM DERRICK FROM 1425'MD TO 5671'MD FILLING PIPE EVERY 20 STANDS. MONITORED PIPE DISPLACEMENT ON TRIP TANK. PUW=153K, SOW= 126K. 12:00 - 16:00 4.00 DRILL P PROD1 CONTINUE RIH FROM 5671'TO 9068'MD. PUW=223K,SOW=163K. RIH FROM 9068' TO 9634'AND TAG WITH 12K WOB. PUW= 20K OVERPULL. 16:00 - 17:00 1.00 DRILL P PROD1 WASH DOWN FROM 9634'MD TO 9728'MD. -240 GPM @ 1770-PSI OFF AND 2200-PSI ON -40-RPM -12-13K TQ.ON -2-7K WOB POH TO 9634'AND MONITOR WELL FOR 10-MINUTES. BLEW DOWN TOP DRIVE. 17:00 - 18:30 1.50 DRILL P PROD1 PJSM-CHANGE OUT SAVER SUB. CHANGED OUT WORN 6-5/8"REG X 4-1/2"IF SAVER SUB TO NEW SAVER SUB. LIKE FOR LIKE SWAP. 18:30 - 19:00 0.50 DRILL P PROD1 SERVICE AND INSPECT IRON DERRICKMAN, DERRICK FINGER BOARD AND TOP DRIVE. 19:00 - 21:00 2.00 DRILL P PROD1 SLIP AND CUT DRILLING LINE 64'. MONITOR WELL VIA TRIP TANK#1. 21:00 - 22:00 1.00 DRILL P PROD1 WASH FROM 9634'MD TO TAG INSERT LANDING COLLAR/LINER WIPER PLUG AT 9778'MD. -200-GPM @ 1420-PSI -250-GPM @ 1880-PSI OFF AND 2382-PSI ON -50-RPM -13K TQ OFF,13K TQ ON -PUW=230K,SOW= 170K,ROT WT=200K 4KTO7KWOB 22:00 - 23:00 1.00 DRILL P PROD1 CBU 480-BBLS.AT 250-GPM AT 1880-PSI WITH 50-RPM AND 13K TQ. 23:00 - 00:00 1.00 DRILL P PROD1 DISPLACE 10-4-PPG LSND MUD TO 8.5-PPG FLO-PRO MUD. PUMPED 32-BBLS. FRESH WATER AND 36-BBL. HI-VIS SPACER PILL. DISPLACED WITH 8.5-PPG FLO-PRO MUD AT 250-GPM @ 1859-PSI. ROTATED PIPE AT 50-RPM WITH 10-11K TQ. 10/31/2011 00:00 - 01:30 1.50 DRILL P PROD1 CONTINUE DISPLACING HOLE TO 8.5-PPG FLO-PRO MUD AT 250-GPM @ 1400-PSI. ROTATED PIPE AT 50-RPM WITH 6-8K TQ. SPR'S @ 9730'MD 01:15-HRS.: -MP#1 20-SPM=380-PSI 30-SPM=540-PSI -MP#2 20-SPM=370-PSI 30-SPM=530-PSI 01:30 - 02:30 1.00 DRILL P PROD1 PERFORMED NEGATIVE PRESSURE TEST ON WELL FOR 30-CHARTED MINUTES. 0-PSI PRESSURE BUILDUP OBSERVED. OBSERVED WELL VISUALLY FOR FLOW FOR 15-MINUTES AND WELL WAS STATIC. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 34 of 42 ," . Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 10:00 7.50 DRILL P PROD1 WASH AND REAM TO TOP OF INSERT LANDING COLLAR AT 9778'MD. DRILL OUT WIPER PLUGS AND LANDING COLLAR. CLEAN OUT SHOE TRACK FROM 9778'TO 7" CASING SHOE AT 9866'MD. -4K WOB -253 GPM,1580-PSI ON--1470-PSI OFF 5-6K TQ ON,6K TQ OFF -50 RPM PUW=218K,SOW=197K ROT WT=21K 10:00 - 12:00 2.00 DRILL P PROD1 DIRECTIONALLY DRILL FROM 9866'MD TO 9888'MD. -4-5K WOB -253 GPM,1580 PSI ON,1410 PSI OFF -50 RPM -6-7K TQ ON.6K TQ OFF -PUW=218K,SOW=197K,ROT WT=211K -TOTAL JAR HRS.-91.52(NOTE:JARS ARE USED FROM PREVIOUS WELL) -ADT=1.52 -ART=1.52 12:00 - 13:30 1.50 DRILL ""P PROD1 CIRCULATE BOTTOMS UP AT 9823'. -245-GPM @ 1475-PSI -50-RPM -5-6K TQ -PUW=218K,SOW=197K,ROT WT. =211K -FLOW CHECKED WELL FOR 10-MINUTES- STATIC -BLEW DOWN TOP DRIVE 13:30 - 15:00 1.50 DRILL P PROD1 PJSM. RIG UP TO PERFORM F I T PUMPED DOWN KILL LINE AND DRILL PIPE. CLOSED UPPER PIPE RAMS. PUMPED AT 0.4-BPM TO 755-PSI AND 10-PPG EMW. CHARTED TEST FOR 10-MINUTES. BLED OFF PRESSURE AND RIGGED DOWN TEST EQUIPMENT. BLEW DOWN KILL LINE. -MW 8.3-PPG IN,8.4-PPG OUT -PUMPED 1.8-BBLS. -BLED BACK 1.6-BBLS. 15:00 - 19:30 4.50 DRILL P PROD1 DRILL AHEAD FROM 9888'MD TO 9944'MD. -250-GPM -1430-PSI OFF,1725-PSI ON -50-RPM -6-8K TQ OFF,7-9K TQ ON -PUW=215K,SOW= 194K,ROT WT=210K -4-5K WOB TOOK DRILLING BREAK AT 9930'. ROP AVERAGE INCREASED FROM 12.5 FT/HR.TO 25 FT./HR.OVER A 25-MINUTE PERIOD. SHUT DOWN PUMPS, PICKED UP OFF BOTTOM AND FLOW CHECKED WELL. WELL IS STATIC. Printed 11/28/2011 11:34:54AM E E '� o- � �° �` olisefar7,agep5 of,4 ,4" ,titzittt:&t del*, lfirrAni t iH €� 414 414r7f ° ',.`. *Ilk:.+ 6' Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C:(10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 DRILL N DPRB 9,944.00 PROD1 PER UNPLANNED CHANGE IN WELL PLAN AND IN ANTICIPATION OF MOST LIKELY PORE PRESSURE OF 9.0-PPG IN LISBURNE ZONE 6/5,WEIGHT UP FLO-PRO MUD SYSTEM FROM 8.4-PPG IN TO 8.7-PPG OUT WITH SALT. CIRCULATING AT 249-GPM @ 1442-PSI. 50-RPM,5-7K TQ,216K ROT WT. SPR'S @ 9920'MD 23:50-HRS.: -MP#1 20-SPM=450-PSI 30-SPM=600-PSI -MP#2 20-SPM=420-PSI 30-SPM=580-PSI DRILL 6-1/8"LISBURNE PRODUCTION HOLF FROM 9866'MD TO 9944'MD(9095'TVD) -570 GPM,1800 PSI ON!1600 PSI OFF -MW 8.4 IN/8.4 OUT,ECD=8.8 PPG -300 RPM,TQ=8K ON/8K OFF -P/U=215K, S/0=194K, ROT=210K -5K WOB,ADT=4.55 -JAR HRS.=94.55 11/1/2011 00:00 - 03:00 3.00 DRILL N DPRB 9,944.00 PROD1 CONTINUE WEIGHTING UP FLO-PRO MUD SYSTEM FROM 8.4-PPG TO 9.0-PPG WITH SALT. CIRCULATING AT 249-GPM @ 1442-PSI. 50-RPM,5-7K TQ,216K ROT WT WHILE WEIGHTING UP. -MW IN=9.0-PPG,OUT=9.0-PPG. 03:00 - 03:30 0.50 DRILL P PROD1 OBTAIN SPR'S: 9930'MD @ 03:15-HRS. #1-MP: 20-SPM=420-PSI, 30-SPM=580-PSI #2 MP: 20-SPM=410-PSI, 30-SPM=570-PSI MONITOR WELL FOR 10-MINUTES. NO FLOW. 03:30 - 09:00 5.50 DRILL-. P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,944' MD to 10,010'MD -250 GPM,1770 PSI ON/1600 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.56 PPG -60 RPM,TQ=8-9K ON/6-8K OFF -P/U=230K,S/O=202K, ROT=215K -7K WOB,ADT=4.92 PERFORM PLANNED FLOW CHECK AT 9972' MD(PROJECTED TOP OF LISBURNE ZONE 6) -STATIC 09:00 - 11:30 2.50 DRILL P PROD1 RE-LOG GR/RES FROM 10,009'TO 9,919'. TAKE STETHOSCOPE PRESSURE SAMPLES AT THE FOLLOWING DEPTHS WHILE ff PUMPING AT 250 GPM: -9872'(9046'TVD); DRY -9874'(9047'TVD); DRY 11:30 - 23:00 11.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,010'MD to 10,105'MD -275 GPM,1965 PSI ON/1835 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.56 PPG -60 RPM,TQ=8-9K ON/6-7K OFF -P/U=236K, S/0=197K, ROT=215K -7-10K WOB,ADT=8.85 HELD UNANNOUNCED KICK WHILE DRILLING DRILL Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 36 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P PROD1 RE-LOG GR/RES FROM 10,004'TO 9979'.TAKE STETHOSCOPE PRESSURE SAMPLES AT THE FOLLOWING DEPTHS WHILE PUMPING AT 250 GPM: -9907'(9072'TVD);3298 PSI -9896'(9063'TVD); DRY SPR'S @ 9978'MD,9121'TVD-MW=9.0 PPG, TIME=23:45 #1 MP-20/30 SPM=460/600 PSI #2 MP-20/30 SPM=440/600 PSI 11/2/2011 00:00 - 06:30 6.50 DRILL P PROD1 CONTINUE TAKING STETHOSCOPE PRESSURE SAMPLES AT THE FOLLOWING DEPTHS: SAMPLE WHILE PUMPING AT 253 GPM -9,897'MD(9,064'TVD); DRY -9,908'MD(9,072'TVD);3,301 PSI -9,975'MD(9,119'TVD); DRY 9,959'MD(9,108'TVD);3,592 PSI -9,955'MD(9,105'TVD);QUESTIONABLE -9,957'MD(9,106'ND);QUESTIONABLE -9,939'MD(9,093'ND);QUESTIONABLE SAMPLE WITH PUMPS OFF -9,937'(9,092'TVD);3,339 PSI -9,956'(9,106'ND); DRY 06:30 - 12:30 6.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,105'MD TO 10,202'MD -254 GPM,1910 PSI ON/1750 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.58 PPG -60 RPM,TQ=9-10K ON/6-7K OFF -P/U=239K,S/O=198K, ROT=215K -15-16K WOB,ADT=5.31 SPR'S @ 10,195'MD,9,275'ND-MW=9.0 PPG,TIME=11:47 #1 MP-20/30 SPM=460/610 PSI #2 MP-20/30 SPM=450/600 PSI 12:30 - 14:30 2.00 DRILL P PROD1 ACQUIRE STETHOSCOPE PRESSURE SAMPLES AT THE FOLLOWING DEPTHS WHILE PUMPING AT 254 GPM: -10,042'MD(9,167'ND); DRY -10,070'MD(9,187'ND);SUPERCHARGED WITH MUD FILTRATE 14:30 - 00:00 9.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,202'MD TO 10,305'MD -274 GPM,2100 PSI ON/1810 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.60 PPG -60 RPM,TQ=9-10K ON/6-8K OFF -P/U=244K, S/O=202K, ROT=220K -9-15K WOB,ADT=5.31 SPR'S @ 10,289'MD,9,345'ND-MW=9.0 PPG,TIME=20:45 #1 MP-20/30 SPM=460/600 PSI #2 MP-20/30 SPM=460/600 PSI Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 37 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/3/2011 00:00 - 02:30 2.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 10,305'MD TO TD OF 10,323'MD -273 GPM,2030 PSI ON/1810 PSI OFF -MW 9.0 IN/9.0 OUT, ECD=9.60 PPG -60 RPM,TQ=8-10K ON/7K OFF -P/U=228K,S/O=200K, ROT=218K -9-15K WOB,ADT= 1.5 02:30 - 10:30 8.00 DRILL P PROD1 ACQUIRE STETHOSCOPE PRESSURE SAMPLES AT THE FOLLOWING DEPTHS WHILE PUMPING AT 253 GPM: -10,227'MD(9,301'TVD);3932 PSI -10,209'MD(9,288'TVD); DRY -10,232'MD(9,305'TVD);4250 PSI (SUPERCHARGED W/MUD FILTRATE) -10,147'MD(9,242'TVD); DRY -10,132'MD(9,231'TVD); DRY -10,120'MD(9,222'TVD); DRY -10,120'MD(9,222'TVD); DRY -10,120'MD(9,222'TVD); DRY -10,101'MD(9,209'TVD); DRY -10,101'MD(9,209'TVD); DRY 10:30 - 15:00 4.50 DRILL P PROD1 BACK REAM TO 7"SHOE WHILE CIRCULATING TWO BOTTOMS UP FROM 10,323'MD TO 9,823'MD -275 GPM,1780 PSI OFF MW 9.O IN/9.0 OUT -60 RPM,TQ=7K OFF MONITOR WELL FOR 10 MIN-STATIC v SPR'S @ 10,323'MD,TIME=11:30 #1 MP-20/30 SPM=450/620 PSI #2 MP-20/30 SPM=400/600 PSI 15:00 - 15:30 0.50 DRILL P PROD1 RIH FROM 9,823'MD TO 10,323'MD -MONITOR WELL DISPLACEMENT ON TRIP TANK 15:30 - 19:30 4.00 DRILL P PROD1 BACK REAM TO 7"SHOE WHILE CIRCULATING TWO BOTTOMS UP FROM 10,323'MD TO 9,918'MD. -275 GPM,1770 PSI OFF -MW 9.0 IN/9.0 OUT -60 RPM,TQ=7K OFF -ADD 290 BBLS OF NEW MUD TO SYSTEM DURING CIRCULATION -CLEAN DITCH MAGNETS AFTER CIRCULATING;VERY LITTLE METAL RECOVERED. 19:30 - 20:00 0.50 DRILL P PROD1 ROTATE AND RECIPROCATE ACROSS 4 1/2" LINER PACKER SETTING DEPTH WHILE CIRCULATING -275 GPM,1,715 PSI -40 RPM,TQ=6K OFF MONITOR WELL-STATIC 20:00 - 20:30 0.50 DRILL P PROD1 POOH FROM 9,634'MD TO 9,351'MD -MONITOR DISPLACEMENT ON TRIP TANK 20:30 - 21:00 0.50 DRILL P PROD1 DROP 1.78"OD BALL -PUMP BALL TO SEAT AT 63 GPM,315 PSI - PRESSURE UP TO 2,300 PSI TO OPEN WELL COMMANDER CIRC SUB. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 38 of 42 f . Operation Summary Report Common Well Name:04-350 I AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:30 1.50 DRILL P PROD1 CBU AT 350 GPM,520 PSI -ROTATE AND RECIPROCATE ACROSS 7" LINER TOP(9,098'MD) -40 RPM,TQ=5-6K OFF MONTIOR WELL 10 MIN-STATIC 22:30 - 00:00 1.50 DRILL P PROD1 POOH ON ELEVATORS FROM 9,255'MD TO 7,838'MD -MONITOR WELL ON TRIP TANK. 11/4/2011 00:00 - 07:00 7.00 DRILL P PROD1 POOH ON ELEVATORS FROM 7,838'MD TO 280'MD -FOUND WASHOUT ON STAND#67(5"DRILL PIPE);CHANGEOUT JOINT. -MONITOR DISPLACEMENT ON TRIP TANK. 07:00 - 10:30 3.50 DRILL P PROD1 LAY DOWN PRODUCTION DRILLING BHA -MONITOR WELL PRIOR TO L/D BHA (STATIC). -L/D PRODUCTION DRILLING BHA& RADIOACTIVE SOURCES. -BIT GRADE 4-2-BT-N-X-I-PN-TD 10:30 - 11:30 1.00 BOPSUR P PROD1 RIG UP TO TEST BOPE -DRAIN STACK. -PULL WEAR BUSHING. SET UPPER TEST PLUG AND FILL STACK. 11:30 - 20:00 8.50 BOPSUR P PROD1 TEST BOPE TO 250 PSI LOW,4000 PSI HIGH AS PER AOGCC AND BP POLICY.TEST ANNULAR PREVENTER TO 250 PSI LOW,3500 PSI HIGH.EACH TEST 5 CHARTED MINUTES. TEST THE UPPER VARIABLES AND LOWER VARIABLES WITH 2-7/8 IN AND 5 IN TEST JOINTS.TEST THE ANNULAR PREVENTER WITH 2-7/8 IN TEST JOINT.NO FAILED TESTS. CHANGED OUT DOOR SEAL ON UPPER VARIABLE RAMS.TEST WITNESS WAIVED BY CHUCK SCHEVE WITH AOGCC.TEST WITNESSED BY WSL MIKE DINGER AND TOOLPUSHER SAM DYE. PERFORMED ACCUMULATOR TEST:SYSTEM PRESSURE 3,000 PSI,PRESSURE AFTER CLOSING ALL RAMS AND ANNULAR PREVENTER 1,820 PSI.RECOVERED 1ST 200 PSI-17 SECONDS. FULL RECOVERY 96 SEC WITH 2 ELECTRIC AND 2 AIR PUMPS.6 NITROGEN BOTTLES,AVERAGE PRESSURE= 2,408-PSI. CLOSING TIMES -ANNULAR=23 SECONDS -UPPER VBR=18 SECONDS -BLIND/SHEARS=16 SECONDS -LOWER VBR=16 SECONDS -CHOKE HCR=2 SECONDS -KILL HCR=2 SECONDS 20:00 - 21:00 1.00 BOPSUR P PROD1 RIG DOWN BOP TEST EQUIPMENT. -PULL TEST PLUG&INSTALL WEAR BUSHING. -B/D TOP DRIVE,CHOKE MANIFOLD,CHOKE &KILL LINES. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 39 of 42 Operation Summary Report Common Well Name:04-350 'AFE No Event Type: DRL-ONSHORE(DON) Start Date: 9/27/2011 End Date. 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time:10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 EVAL N WAIT PROD1 WAIT ON SLB E-LINE UNIT WITH OPEN HOLE LOGGING TOOLS. -PERFORM RIG HOUSEKEEPING&CLEAN WINDWALLS 11/5/2011 00:00 - 02:30 2.50 EVAL N WAIT PROD1 CONTINUE TO WAIT FOR SLB E-LINE UNIT TO ARRIVE WITH OPENHOLE LOGGING TOOLS. -SERVICE AND CLEAN RIG 02:30 - 08:30 6.00 EVAL P PROD1 RIG UP SLB E-LINE UNIT -R/U SHEAVES AND M/U LOGGING BHA#1 WITH HNGS/SONIC SCANNER/FMI -TEST TOOLS 08:30 - 12:00 3.50 EVAL P PROD1 RIH WITH OPENHOLE LOGGING BHA#1 ON E-LINE. -COULD NOT GET LOGGING TOOLS PAST OBSTRUCTION AT 10,075'WLM IN OPEN HOLE. 12:00 - 00:00 12.00 EVAL P PROD1 LOG WITH E-LINE FROM 10,075'WLM TO 1,200'WLM AT 750-900 FPH. -PERFORM RIG MAINTENANCE&CLEANING. 11/6/2011 00:00 - 01:00 2.00 EVAL P PROD1 CONTINUE LOGGING WITH E-LINE FROM 1,200'WLM TO SURFACE. NOTE: DAYLIGHT SAVINGS TIME AT 02:00 HRS 01:00 - 02:00 1.00 EVAL P PROD1 LAY DOWN E-LINE LOGGING BHA#1 02:00 - 03:30 1.50 EVAL P PROD1 M/U CLEANOUT BHA WITH USED 6-1/8" HUGHES TRI-CONE BIT(FULL GAUGE), STABILIZER,4-3/4"DRILL COLLARS,AND JARS. 03:30 - 14:30 11.00 EVAL P PROD1 RIH WITH CLEANOUT ASSEMBLY TO 7,882' MD -FILL PIPE EVERY 20 STANDS. -MONITOR DISPLACEMENT ON TRIP TANK. 14:30 15:30 1.00 EVAL N RREP PROD1 TROUBLE SHOOT IRON DERRICK MAN ENCODER. 15:30 - 17:30 2.00 EVAL P PROD1 RIH WITH CLEANOUT ASSEMBLY FROM 7,882' MD TO 10,050'MD -FILL PIPE EVERY 20 STANDS. -MONITOR DISPLACEMENT ON TRIP TANK. 17:30 - 18:00 0.50 EVAL P PROD1 ENCOUNTER OBSTRUCTION @ 10,092'MD, SET DOWN 10K LBS -REAM FROM 10,090 TO 10,145'MD THREE TIMES -WASH&REAM TO TD @ 10,323'MD -275 GPM,1,000 PSI -80 RPM,TQ=7-9K -P/U=240K,S/O=185K,ROT=215K 18:00 - 18:30 0.50 EVAL P PROD1 PUMP 30 BBL HI VIS SWEEP TO BIT WHILE ROTATING AND RECIPROCATING Printed 11/28/2011 11:34:54AM North America ALASKA- BP Page 40 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 21:30 3.00 EVAL P PROD1 BACKREAM FROM 10,323'MD TO 7"SHOE -275 GPM,970 PSI -80 RPM,TQ=7-9K -NO INCREASE IN CUTTINGS OBSERVED WITH HIGH VIS SWEEP -CLEAN DITCH MAGNETS AFTER CIRCULATING;VERY LITTLE METAL RECOVERED. SPR'S @ 9,765'MD,TIME=21:30 #1 MP-20/30 SPM=320/460 PSI #2 MP-20/30 SPM=320/460 PSI 21:30 - 22:00 0.50 EVAL P PROD1 MONITOR WELL PRIOR TO PUMPING DRY JOB. -BLOW DOWN TOP DRIVE 22:00 - 00:00 2.00 EVAL P PROD1 POOH ON ELEVATORS FROM 9,866'MD TO 7,693'MD -MONITOR DISPLACEMENT ON TRIP TANK. 11/7/2011 00:00 - 08:00 8.00 EVAL P PROD1 POOH WITH CLEANOUT ASSEMBLY ON ELEVATORS FROM 7,693'MD TO SURFACE. -MONITOR DISPLACEMENT ON TRIP TANK. 08:00 - 09:00 1.00 EVAL P PROD1 L/D CLEANOUT BHA -BIT IN GAUGE 09:00 - 16:30 7.50 EVAL P PROD1 M/U&RIH WITH OPEN HOLE LOGGING ASSEMBLY RUN#2 ON E-LINE. -COULD NOT GET LOGGING TOOLS PAST LEDGE AT 9,967'WLM IN OPEN HOLE. -POOH WITH E-LINE FROM 9,967'WLM TO SURFACE. 16:30 - 17:30 1.00 EVAL ' P PROD1 MODIFY LOGGING ASSEMBLY. -L/D FMI&M/U NON-MAGNETIC HOUSING, GPIT&HOLE FINDER. 17:30 - 20:00 2.50 EVAL P PROD1 RIH WITH OPEN HOLE LOGGING ASSEMBLY RUN#3 ON E-LINE. -COULD NOT GET LOGGING TOOLS PAST LEDGE AT 9,967'WLM IN OPEN HOLE. 20:00 - 23:00 3.00 EVAL P PROD1 POOH FROM 9,967'WLM TO SURFACE WITH E-LINE TO MODIFY LOGGING ASSEMBLY. -L/D NON-MAGNETIC HOUSING,GPIT,HOLE FINDER&SONIC SCANNER. -M/U FMI,HNGS, EDTC&WEIGHT BAR LOGGING ASSEMBLY. -TEST FMI 23:00 - 00:00 1.00 EVAL P PROD1 RIH WITH OPENHOLE LOGGING ASSEMBLY RUN#4 ON E-LINE TO 9,967'WLM. 11/8/2011 00:00 - 01:00 1.00 EVAL P PROD1 CONTINUE RIH W/E-LINE OPENHOLE LOGGING ASSEMBLY RUN#4 -WORK PAST LEDGE AT 9,967'WLM. -UNABLE TO GET PAST OBSTRUCTION AT 10,075'WLM. 01:00 - 03:00 2.00 EVAL P PROD1 POH WITH E-LINE LOGGING ASSEMBLY RUN #4 -DISCUSS WITH TOWN CONFIGURATION FOR NEXT ASSEMBLY 03:00 - 03:30 0.50 EVAL P PROD1 LAY DOWN LOGGING ASSEMBLY RUN#4 03:30 - 06:00 2.50 EVAL P PROD1 M/U E-LINE OPENHOLE LOGGING ASSEMBLY RUN#5 -P/U HNGS, ECS,MCFL, SONIC SCANNER, NON-MAG HOUSING,GPIT Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 41 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) Start Date:9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163 00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 13:30 7.50 EVAL P PROD1 RIH WITH E-LINE LOGGING RUN#5. -UNABLE TO GET PAST OBSTRUCTION AT 10,280'WLM -POOH FROM 10,280'WLM TO SURFACE, LOGGING ON TRIP OUT. 13:30 - 14:30 1.00 EVAL P PROD1 LAY DOWN LOGGING ASSEMBLY RUN#5 14:30 - 16:30 2.00 EVAL P PROD1 . M/U E-LINE OPENHOLE LOGGING ASSEMBLY RUN#6 -P/U HNGS,ECS,HRLA,SONIC SCANNER, FMI&HOLE FINDER. 16:30 - 18:00 1.50 EVAL P PROD1 CALIBRATE&SURFACE TEST OPENHOLE LOGGING TOOLS. 18:00 - 00:00 6.00 EVAL P PROD1 RIH WITH E-LINE LOGGING RUN#6 TO 10,280' WLM. -POOH FROM 10,280'WLM TO 9,868 WLM, LOGGING ON TRIP OUT. 11/9/2011 00:00 - 01:30 1.50 EVAL P PROD1 POOH WITH E-LINE LOGGING RUN#6 FROM 9868'WLM TO SURFACE. 01:30 - 03:00 1.50 EVAL P PROD1 LAY DOWN LOGGING BHA -MISSING ONE OF SLEEVE STABILIZERS ON TOOLSTRING 03:00 - 06:00 3.00 EVAL N DFAL PROD1 DISCUSS PLAN FOWARD WITH TOWN. -DECISION TO MAKE DRILLPIPE CLEANOUT RUN. -LOAD AND STRAP BHA COMPONENTS -PREPARE EQUIPMENT FOR RUNNING 4 1/2" PRODUCTION LINER 06:00 - 08:00 2.00 EVAL N DFAL PROD1 M/U 6 1/8"CLEANOUT ASSEMBLY TO 324'MD 08:00 - 18:30 10.50 EVAL N DFAL PROD1 RIH ON ELEVATORS WITH 6 1/8"CLEANOUT ASSEMBLY FROM 324'MD TO 9,864'MD -MONITOR DISPLACEMENT ON TRIP TANK. 1 18:30 - 19:00 0.50 EVAL N DFAL PROD1 CIRCULATE DRILLSTRING VOLUME AT 7" SHOE -252 GPM,460 PSI. -P/U=236K,S/O=197K 19:00 - 20:00 1.00 EVAL N DFAL PROD1 RIH ON ELEVATORS WITH 6 1/8"CLEANOUT ASSEMBLY FROM 9,864'MD TO 10,243'MD -MONITOR DISPLACEMENT ON TRIP TANK. SPR'S @ 9,850'MD,TIME= 19:00 M.W.=9.0 PPG #1 MP-20/30 SPM=260/320 PSI #2 MP-20/30 SPM=260/320 PSI 20:00 - 21:00 1.00 EVAL N DFAL PROD1 WASH DOWN FROM 10,243'MD TO 10,287'MD -TOOK WEIGHT AT 10,287'MD,REAM DOWN WITH 10-15K WOB FOR 10' -REAM FROM 10,297'TO 10,323'MD WITH NO SIGN OF OBSTRUCTION. -P/U&REAM PAST OBSTRUCTION AREA SEVERAL TIMES CLEAN TO BOTTOM. -275 GPM,550 PSI -40 RPM,TQ=9-10K -P/U=246K,5/0=195K,ROT=215K 21:00 - 23:00 2.00 EVAL N DFAL PROD1 PUMP HIGH VIS SWEEP WHILE ROTATING AND RECIPROCATING -275 GPM,600 PSI -80 RPM,TQ=8-10K -METAL SHAVINGS,RUBBER,AND FABRIC TAPE FROM LOGGING TOOL CENTRALIZER RETURNED TO SURFACE. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 42 of 42 Operation Summary Report Common Well Name:04-350 AFE No Event Type: DRL-ONSHORE(DON) I Start Date: 9/27/2011 End Date: 11/19/2011 X3-00YXF-C: (10,795,163.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 EVAL N DFAL PROD1 PUMP OUT OF HOLE FROM 10,323'MD TO 9,961'MD -2 BPM,260 PSI -P/U=245K,S/O=195K 11/10/2011 00:00 - 00:30 0.50 EVAL N DFAL PROD1 PUMP OUT OF HOLE FROM 9961'MD AT 2 BPM -P/U=245K, S/O= 195K 00:30 - 01:00 0.50 EVAL N DFAL PROD1 MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT. -PUMP DRY JOB. 01:00 - 03:00 2.00 EVAL N DFAL PROD1 INSPECT DRILLING LINE-FOUND WEAR SPOT AND DECIDED TO SLIP AND CUT. 03:00 - 08:30 5.50 EVAL N DFAL PROD1 SLIP AND CUT DRILLING LINE -CUT 616'OF DRILLING LINE. -CALIBRATED BLOCK HEIGHT. 08:30 - 16:30 8.00 EVAL N DFAL PROD1 POOH ON ELEVATORS WITH 6 1/8" CLEANOUT ASSEMBLY FROM 9,772'MD TO 324'MD. -MONITOR HOLE FILL ON TRIP TANK. 16:30 - 18:30 2.00 EVAL N DFAL PROD1 LAY DOWN 6 1/8"CLEANOUT ASSEMBLY -BIT WAS IN GAUGE WITH NO SIGNS OF ABNORMAL WEAR. Printed 11/28/2011 11:34:54AM North America -ALASKA- BP Page 1 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/10/2011 18:30 - 20:30 2.00 CASING P RUNPRD RIG UP TO RUN 4 1/2"PRODUCTION LINER. -R/U SLIP INSERT,ELEVATOR INSERTS& POWER TONGS. 20:30 - 00:00 3.50 CASING P RUNPRD RUN 14 JOINTS TOTAL OF 4 1/2"12.6#L-80 IBT LINER WITH TORQUE RINGS TO 620'MD -CHECK FLOAT EQUIPMENT -FILL EACH JOINT OF LINER BEGIN M/U 4 1/2"X 7"LINER HANGER/ PACKER ASSEMBLY 11/11/2011 00:00 - 02:00 2.00 CASING P RUNPRD FINISH M/U 4-1/2"X 7"LINER HANGER/ PACKER ASSEMBLY. -FROM 620'MD TO 715'MD -CIRC ONE LINER VOLUME AT 5 BPM,50 PSI 02:00 - 03:00 1.00 CASING P RUNPRD RIH WITH 4-1/2"LINER ON 4"DRILLPIPE FROM 715'MD TO 1760'MD -FILL PIPE EVERY 10 STANDS -CHECK P/U,S/O AND ROTATING TQ AT 20 RPM EVERY 10 STANDS 03:00 - 08:00 5.00 CASING P RUNPRD R/U 5"DP HANDLING EQUIPMENT RIH WITH 4-1/2"LINER ON 5"DRILLPIPE FROM 1760'MD TO 6289'MD -FILL PIPE EVERY 10 STANDS -CHECK P/U, S/O AND ROTATING TQ AT 20 RPM EVERY 10 STANDS 08:00 - 09:00 1.00 CASING P RUNPRD CIRCULATE BOTTOMS UP -8 BPM,430 PSI -P/U= 150 K, S/O=140 K, ROT= 141 K RTTQAT20RPM=4.5KFT/LBS 09:00 - 12:30 3.50 CASING P RUNPRD RIH WITH 4-1/2"LINER ON 5"DRILLPIPE FROM 6289'MD TO 9688'MD -FILL PIPE EVERY 10 STANDS -CHECK P/U,3/0 AND ROTATING TQ AT 20 RPM EVERY 10 STANDS -P/U=205 K, S/O=180 K, ROT=193 K -RT TQ AT 20 RPM=7-8 K FT/LBS 12:30 - 14:00 1.50 CASING P RUNPRD CIRCULATE BOTTOMS UP -6 BPM,430 PSI -P/U=221 K, S/O= 193 K, ROT=203 K -RT TQ AT 20 RPM=7-8 K FT/LBS 14:00 - 16:00 2.00 CASING P RUNPRD RIH WITH 4-1/2"LINER ON 5"DRILLPIPE FROM 9688'MD TO 10322'MD -M/U CEMENT HEAD AND WASH DOWN LAST 15' -2 BPM,340 PSI -P/U=234 K,S/O=190 K -RT TQ AT 20 RPM=7-8 K FT/LBS 16:00 - 17:30 1.50 CEMT P RUNPRD CIRC STAGING THE PUMPS UP -2 BPM,290 PSI -3 BPM,350 PSI -4 BPM,410 PSI -5 BPM,500 PSI -6 BPM,650 PSI -P/U=234 K, S/O= 190 K 17:30 - 18:00 0.50 CEMT P RUNPRD PJSM FOR 4-1/2"PRODUCTION LINER CEMENT JOB WITH SLB,RIG CREW,BP, BAKER,AND CH2MHILL. Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 2 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 21:00 3.00 CEMT N DPRB RUNPRD CEMENT 4-1/2"PRODUCTION LINER WITH ��/� ROTATION AND WITH OUT RECIPROCATION AS FOLLOWS: CEMENT PUMPING UNIT -PUMP 20 BBLS 12.3 PPG MUD PUSH AT 3.7 BPM,400 PSI PRESSURE TEST LINES TO 4,400 PSI- GOOD -PUMP 25 BBLS(120 SX)15.8 PPG CLASS G TAIL CEMENT.YIELD 1.17 CUFT/SK.4.5 BPM, /)) 350 PSI. � ' -BLOW DOWN AND DISCONNECT CEMENT LINE. SWAP TO RIG FOR DISPLACEMENT -DROP DP WIPER DART, POSITIVE INDICATION DART LEFT CEMENT HEAD -CHASE DART WITH 15 BBL PERF PILL AT 4 BPM,0 PSI -FOLLOW PERF PILL WITH 9.0 PPG FLOPRO MUD -DISPLACEMENT RATE 6 BPM,60 PSI -BEGIN ROTATING 20 RPM/9K TQ,3 BBL PRIOR TO MUD PUSH AT SHOE -PRESSURE BEGINS TO CLIMB RAPIDLY WHEN CEMENT IS AT SHOE -BRING PUMPS DOWN AS PRESSURE REACHES 2500 PSI -AFTER HOLDING 2500 PSI FOR 1 MIN, PRESSURE DROPS TO 300 PSI -CONTINUE DISPLACEMENT AT 2 BPM,850 PSI FOR 5 BBLS -SLOW RATE TO 1 BPM,750 PSI -OBSERVE 150 PSI PRESSURE INCREASE AT 159 BBLS(CALCULATED DART LATCHING WITH WIPER PLUG) -CONTINUE TO DISPLACE AT 1 BPM, OBSERVE 730 PSI LIFT PRESSURE(1550 PSI TOTAL) -Pt UG DID NOT BUMP ,STOP PUMPING AT 1 BBL OVER CALCULATED DISPLACEMENT CONSULT TOWN -PUMP 2 MORE BBLS TO ATTEMPT TO BUMP PLUG, UNSUCCESSFUL -ATTEMPT TO MECHANICALLY RELEASE FROM LINER WITH WEIGHT AND LEFT HAND TORQUE 21:00 - 22:30 1.50 CEMT N DPRB RUNPRD P/U 15'OBSERVE 5000 LB WEIGHT DROP -P/U ADDITIONAL 12'STAGING PUMPS TO 7 BPM -INCREASE RATE TO 10 BPM PRESSURE DROP TO 3400 PSI -P/U 30'UNABLE TO RECIPROCATE -CIRCULATE BOTTOMS UP -CIRCULATE OUT 130 BBLS OF CEMENT CONTAMINATED MUD k 22:30 - 00:00 1.50 CEMT N DPRB RUNPRD DISCUSS PLAN FOR R/D CEMENT HEAD. -BACK OUT CEMENT HEAD ON DOUBLE AND RACK BACK IN DERRICK COLLAR FINGER. Printed 11/28/2011 11:35:17AM North America-ALASKA- BP Page 3 of 10 Operation Summary Report Common Well Name:04-350 1 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/12/2011 00:00 - 01:00 1.00 CEMT N DPRB RUNPRD BACK OUT CEMENT HEAD ON DOUBLE AND RACK BACK IN DERRICK COLLAR FINGER. 01:00 - 03:00 2.00 CEMT N DPRB RUNPRD PUMP OUT OF HOLE FROM 10,223'MD TO IJ' 9025'MD STANDING BACK 13 STANDS OF 5" DP TO 7"LINER TOP ! �� -2 BPM,450 PSI 03:00 - 04:30 1.50 CEMT N DPRB RUNPRD CIRCULATE BOTTOMS UP WHILE RECIPROCATING -6.5 BPM,1950 PSI P/U=218K,S/O=180K 04:30 - 05:00 0.50 CEMT N DPRB RUNPRD MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT PUMP DRY JOB,BLOW DOWN TOP DRIVE AND UD CEMENT HEAD 05:00 - 14:00 9.00 CEMT N DPRB RUNPRD POOH ON ELEVATORS FROM 8930'MD TO 620'MD -MONITOR WELL ON TRIP TANK CONFIRMATION THAT 4-1/2"LINER ASSEMBLY AND LINER STILL ATTACHED 14:00 - 15:30 1.50 CEMT N DPRB RUNPRD PJSM,R/U 4-1/2"HANDLING EQUIPMENT,P/U WACHS COLD CUTTER AND BAKER TOOLS FOR SCRAPER RUN -MONITOR HOLE ON TRIP TANK MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT 15:30 - 21:30 6.00 CEMT N DPRB RUNPRD UD PACKER.LINER HANGER AND LINER RUNNING TOOL -FLUID LEAKAGE OBSERVED FROM LINER HANGER BELOW SLIPS L/D LINER JTS 14-4 -CONTAMINATED CEMENT AND PERF PILL FOUND IN LINER JTS 10-4 -RECOVERED 2"X 3"PIECE OF METAL FROM E-LINE LOGGING TOOL CENTRALIZER LODGED IN 4-1/2"LINER CENTRALIZER UD SHOE TRACK -COLD CUT JT 3 ABOVE LANDING COLLAR- DRILL PIPE DART AND LINER WIPER PLUG LATCHED IN LANDING COLLAR -COLD CUT JT 2 ABOVE FLOAT COLLAR- HARD CEMENT OBSERVED IN SHOE TRACK 21:30 - 00:00 2.50 CEMT N DPRB RUNPRD PULL WEAR BUSHING,CLEAN CEMENT FROM SURFACE EQUIPMENT, REMOVE STRIP-O-MATIC TO SERVICE, PICK UP SUBS FOR CLEAN OUT/SCRAPER BHA,M/U STACK WASHER. 11/13/2011 00:00 - 05:00 5.00 CEMT N DPRB RUNPRD CONTINUE TO CLEAN CEMENT FROM SURFACE EQUIPMENT -CHANGE OUT STRIP-O-MATIC INSERTS -CLEAN OUT CEMENT DEBRIS FROM FLOW BOX -FLUSH STACK,BOPE,WELLHEAD,CHOKE LINE/MANIFOLD,AND KILL LINE WITH STACK WASHER PERFORM WEEKLY BOP FUNCTION TEST -INSTALL WEAR RING Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 4 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 07:30 2.50 CONDHL N DPRB RUNPRD M/U CLEANOUT BHA TO 519'MD -6-1/8"USED HUGHES TRI-CONE BIT(IN GAUGE) -NEAR BIT STABILIZER -4-3/4"SPIRAL DRILL COLLARS -JARS -3-1/2"DRILL PIPE -7"CASING SCRAPER MONITOR WELL ON TRIP TANK 07:30 - 17:00 9.50 CONDHL N DPRB RUNPRD RIH ON DP FROM 519'MD TO 9114'MD -MONITOR WELL ON TRIP TANK -FILL PIPE EVERY 20 STANDS 17:00 - 00:00 7.00 CONDHL N DPRB RUNPRD WASH AND REAM DOWN FROM 9114'MD TO 10,216'MD -275 GPM,600 PSI -60 RPM,TQ=10K,WOB=7K -P/U=249K,S/O=190K -BEGAN DRILLING CEMENT IN OPEN HOLE AT 10,070'MD SPR'S @ 9866'MD,9043'TVD-MW=9.1 PPG, TIME=19:50 #1 MP-20/30 SPM=220/260 PSI #2 MP-20/30 SPM=200/260 PSI 11/14/2011 00:00 - 01:00 1.00 CONDHL N DPRB RUNPRD WASH AND REAM DOWN FROM 10,216'MD TO 10,323'MD -340 GPM,680 PSI -60 RPM,TQ=9K,WOB=7K -P/U=232K, S/O=205K, ROT=214K 01:00 - 04:00 3.00 CONDHL N DPRB RUNPRD PUMP 3X BCU WHILE RECIPROCATING AND ROTATING -PUMP HI-VIS SWEEP SURFACE TO SURFACE -SIGNIFICANT INCREASE IN CEMENT CUTTINGS AND RUBBER WITH BOTTOMS UP -340 GPM,650 PSI -60 RPM,TQ=6.5K -P/U=232K,S/O=205K, ROT=214K -RETURNS CLEANED UP AFTER 3X B/U SPR'S @ 10323'MD,9371'TVD-MW=9.1 PPG,TIME=04:00 #1 MP-20/30 SPM=220/260 PSI #2 MP-20/30 SPM=200/260 PSI 04:00 - 05:00 1.00 CONDHL N DPRB RUNPRD MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT PUMP OUT OF HOLE FROM 10323'MD TO 9775'MD(INSIDE 7"SHOE) -2 BPM,180 PSI 05:00 - 05:30 0.50 CONDHL N DPRB RUNPRD MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT PUMP DRY JOB AND BLOW DOWN TOP DRIVE 05:30 - 06:30 1.00 CONDHL N DPRB RUNPRD POOH ON ELEVATORS FROM 9775'MD TO 8827'MD -MONITOR WELL ON TRIP TANK 06:30 - 07:00 0.50 CONDHL N DPRB RUNPRD SERVICE TOP DRIVE BLOCKS AND CROWN SHEAVES. PERFORM PM'S ON BLOCKS,TOP DRIVE AND CROWN. Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 5 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project: Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 10:00 3.00 CONDHL N RREP RUNPRD TROUBLESHOOT IRON DERRICK MAN.C/O ELECTRONIC VALVE ON IDM.CONT PM'S ON TOP DRIVE,CROWN, IDM AND MUD PUMPS. 10:00 - 14:30 4.50 CONDHL N DPRB RUNPRD POOH ON ELEVATORS FROM 8827'MD TO 614'MD -MONITOR WELL ON TRIP TANK 14:30 - 17:00 2.50 CONDHL N DPRB RUNPRD MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT LAY DOWN CLEAN OUT/SCRAPER BHA -BIT AND SCRAPER IN GAUGE -MONITOR WELL ON TRIP TANK 17:00 - 18:30 1.50 CONDHL N DPRB RUNPRD CLEAN AND CLEAR RIG FLOOR.R/U TO RUN 4-1/2"LINER, R/U POWER TONGS,ELEVATOR INSERTS, FILL UP HOSE,TIW CROSS OVERS. 18:30 - 21:00 2.50 CASING N DPRB RUNPRD PJSM, P/U AND RUN 4-1/2"12.6#L-80 IBT PRODUCTION LINER -CHECK FLOATS -MONITOR WELL ON TRIP TANK 21:00 - 21:30 0.50 CASING N DPRB RUNPRD MAKE UP LINER TOP PACKER AND LINER HANGER. 21:30 - 22:00 0.50 CASING N DPRB RUNPRD CIRC 1.5 LINER VOLUMES AT 3 BPM -P/U=44K,SAN=56K 22:00 - 00:00 2.00 CASING N DPRB RUNPRD RIH WITH 4-1/2"PRODUCTION LINER ON DRILL PIPE TO 1856'MD -MONITOR WELL ON TRIP TANK 11/15/2011 00:00 - 06:30 6.50 CASING N DPRB RUNPRD RIH WITH 4-1/2"PRODUCTION LINER ON DP FROM 1856'MD TO 9865'MD -MONITOR WELL ON PIT#2 06:30 - 08:00 1.50 CASING N DPRB RUNPRD CIRC B/U AT 7"LINER SHOE -6 BPM,430 PSI 08:00 - 09:00 1.00 CASING N DPRB RUNPRD RIH WITH 4-1/2"PRODUCTION LINER ON DP FROM 9865'MD TO 10,323'MD -M/U CEMENT HEAD AND TAG ON DEPTH AT 10,323'MD -MONITOR WELL ON PIT#2 09:00 - 11:30 2.50 CEMT N DFAL RUNPRD CIRC 2X BOTTOMS UP -6 BPM,570 PSI -P/U=238K, 3/0= 196K -RECIPROCATE PIPE 15'STROKES 11:30 - 12:00 0.50 CEMT N DFAL RUNPRD PJSM FOR 4-1/2"PRODUCTION LINER CEMENT JOB WITH SLB, RIG CREW, CH2MHILL, MI,AND BP. -CIRCULATE AND RECIPROCATE AT 6 BPM Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 6 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 15:00 3.00 CEMT P RUNPRD CEMENT 4-1/2"PRODUCTION LINER AS FOLLOWS: -RECIPROCATE IN 15'STROKES FROM 10,307'MD TO 10,322'MD. CEMENT PUMPING UNIT: -PUMP 20 BBLS 12.2 PPG MUD PUSH AT 5 BPM,650 PSI a I/ -PRESSURE TEST LINES TO 4400 PSI. GOOD ti L TEST -PUMP 25 RBLS 15.8 PPG CLASS G CEMENT WITH GASBLOK,YIELD 1.17 X120 SX) AT 6 BPM AND 230 PSI SWAP TO RIG PUMPS: I% p): -PUMP FRESH WATER BACK TO SLB NPTO ,, FLUSH LINES OF CEMENT �l -BLOW AIR BACK TO SLB TO CLEAN LINES -DISCONNECT CEMENT HOSE FROM CEMENT HEAD -RELEASE DP WIPER DART,POSITIVE INDICATION DART RELEASED -BEGIN RECIPROCATING 15'STROKES CEMENT DISPLACEMENT WITH RIG: -DISPLACE WITH 15 BBL PERF PILL AT 6 BPM,60 PSI -DISPLACE WITH 9.0 PPG FLOPRO AT 6 BPM, 90 PSI -MUD PUSH AT SHOE AT 6 BPM,400 PSI -STOP RECIP WHEN CEMENT REACHES SHOE AT 6 BPM,830 PSI -LATCH UP WIPER PLUG AND SHEAR AT 6 BPM,1700 PSI -SLOW DISPLACEMENT RATE FOR PLUG BUMP TO 3 BPM,845 PSI -BUMP PLUG AT 3 BPM,850 PSI STOP CIRCULATING: -PRESSURE UP ON PLUG TO SET HANGER, 2900 PSI -SET DOWN TO CONFIRM HANGER SET,70K -PRESSURE UP TO RELEASE HRD-E RUNNING TOOL,4200 PSI -P/U 5'ABOVE SET DEPTH AND BLEED OFF PRESSURE -S/O AND ROTATE TO SET PACKER,70K,20 RPM,7.5 TQ -REPEAT TO CONFIRM PACKER SET,GOOD SET ON PACKER -PRESSURE UP AND PICK UP UNTIL PRESSURE DROPS,1000 PSI TO 230 PSI -CIRCULATED AT 3 BPM TO CLEAN OUT LINER TIE-BACK RECEPTACLE CIRCULATE OUT EXCESS CEMENT WITH RIG: -PICK UP OUT OF TIE-BACK RECEPTACLE AND STAGE PUMPS UP TO 16 BPM,1360 PSI �I -UNABLE TO DETERMINE EXACT AMOUNT \ OF CEMENT RETURNED.RECOVERED 103 BBLS OF CEMENT CONTAMINATED FLOPRO Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 7 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) CEMENT IN PLACE AT 13:30 HRS: ✓ -LOST 0 BBLS WHILE DISPLACING CEMENT -GOOD LIFT PRESSURE THROUGHOUT JOB --INITIAL CIRCULATING PRESSURE AT 6 BPM,650 PSI --FINAL CEMENT LIFT PRESSURE AT 3 BPM, 850 PSI. 15:00 - 17:00 2.00 CEMT P RUNPRD UD CEMENT HEAD WITH SINGLE,B/D TD, PREP PITS TO DISPLACE WELL,CLEAN CEMENT CONTAMINATED SURFACE LINES AND EQUIPMENT. MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT 17:00 - 18:00 1.00 CEMT P RUNPRD DISPLACE WELL TO 9.0 PPG BRINE -675 GPM,1320 PSI -MW=9.0 PPG IN AND OUT 18:00 - 18:30 0.50 CEMT P RUNPRD MONITOR WELL FOR 10 MIN-STATIC -MW=9.0 PPG IN AND OUT B/D TD, P/U CEMENT HEAD, B/O AND UD SINGLE AND CEMENT HEAD. 18:30 - 00:00 5.50 CASING P RUNPRD POOH ON ELEVATORS WITH LINER RUNNING TOOL FROM 10,236'MD TO 6648'MD LAYING DOWN 5"DP TO PIPE SHED. -MONITOR WELL ON TRIP TANK 11/16/2011 00:00 - 08:30 8.50 CASING P RUNPRD POOH ON ELEVATORS WITH LINER RUNNING TOOL FROM 6648'MD TO SURFACE LAYING DOWN DP TO PIPE SHED. -MONITOR WELL ON TRIP TANK -UD BAKER RUNNING TOOL 08:30 - 10:00 1.50 CASING P RUNPRD RIH WITH 5"DP FROM DERRICK AND UD IN SINGLES TO PIPE SHED. 10:00 - 12:00 2.00 CEMT P RUNPRD RIG UP E-LINE PER SLB REP 12:00 - 15:00 3.00 CEMT P RUNPRD RIH WITH USIT LOGGING TOOLS ON E-LINE TO 10,020'MD -CANNOT GET PAST 10,020'MD -LOG UP FROM 10,020'MD TO 9700'MD -MONITOR WELL ON TRIP TANK 15:00 - 17:00 2.00 CEMT P RUNPRD POOH AND UD USIT LOGGING TOOLS -MONITOR WELL ON TRIP TANK 17:00 - 20:30 3.50 CEMT P RUNPRD M/U AND RIH WITH 3.6"GRJB ON E-LINE. -MONITOR WELL ON TRIP TANK -CAN NOT GET PAST 10,030'MD 20:30 - 22:30 2.00 CEMT P RUNPRD POOH WITH 3.6"GRJB ON E-LINE -JUNK BASKET FULL OF CEMENT CURRENT USIT LOG DEEMED ACCEPTABLE, APPROVAL FROM ODE AND TOWN GEOLOGIST TO PROCEED WITH OPERATIONS. 22:30 - 23:30 1.00 CEMT P RUNPRD PJSM,RIG DOWN E-LINE. 23:30 - 00:00 0.50 CASING P RUNPRD PULL WEAR RING,R/U TO TEST 4-1/2" PRODUCTION LINER. 11/17/2011 00:00 - 01:00 1.00 CASING P RUNPRD PRESSURE_TEST4-1/2"PRODUCTION LINER -250 PSI(5 MIN)LOW,4000 PSI(30 MIN)HIGH -GOOD TEST WTL APPROVAL TO PROCEED WITH OPERATIONS Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 8 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C: (1,805,044.00) Project:Prudhoe Bay Site:PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:04-350 actual©70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 02:00 1.00 RUNCOM P RUNCMP R/U FOR RUNNING 4-1/2"COMPLETION -HANGER DUMMY RUN -RIG UP I-WIRE 02:00 - 02:30 0.50 RUNCOM P RUNCMP PJSM FOR RUNNING 4-1/2"COMPLETION WITH RIG CREW, DOYON CASING,SLB,HES, AND BP. 02:30 - 21:30 19.00 RUNCOM P RUNCMP RIH 4-1/2"L-80 TCII COMPLETION WITH I-WIRE FROM SURFACE TO 9714'MD,TAG NO-GO TBR. -WLEG -XN NIPPLE -X NIPPLE -HES TNT PACKER -SGM-NDPG-CA(WITH I-WIRE TO SURFACE) -X NIPPLE -.GLM(DUMMY) GLM(DCK SHEAR) -X NIPPLE MONITOR WELL ON TRIP TANK 21:30 - 22:30 1.00 RUNCOM P RUNCMP SPACE OUT LANDING HANGER 22:30 - 23:30 1.00 RUNCOM P RUNCMP FEED I-WIRE THROUGH HANGER AND TEST I-WIRE SWEDGE FITTING TO 5000 PSI FOR 5 MIN.GOOD TEST. 23:30 - 00:00 0.50 RUNCOM P RUNCMP LAND TUBING AT 9709'MD(HALFWAY IN TBR),RUN IN LOCK DOWN SCEWS PER FMC REP. 11/18/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR,R/D I-WIRE AND CASING RUNNING TOOLS. 00:30 - 01:00 0.50 RUNCOM P RUNCMP R/U TO REVERSE CIRCULATE CORROSION INHIBITED BRINE DOWN ANNULUS. 01:00 - 05:00 4.00 RUNCOM P RUNCMP REVERSE CIRCULATE DOWN ANNULUS -150 BBL,9.0 PPG BRINE 3%KCL -319 BBL,9.0 PPG BRINE 3%KCL WITH CORROSION INHIBITOR -201 BBL,9.0 PPG BRINE 3%KCL -4 BPM,500 PSI 05:00 - 07:30 2.50 RUNCOM P RUNCMP DROP BALL AND ROD,PRESSURE UP TO SET HES TNT COMPLETION PACKER. 1/ PRESSURE TEST 4-1/2"COMPLETION TUBING -250 PSI(5 MIN) LOW,4000 PSI(30 MIN)HIGH -FAILED TEST 07:30 - 08:00 0.50 RUNCOM N DFAL RUNCMP R/D REVERSE CIRC EQUIPMENT AND PULL LANDING JOINT. 08:00 - 10:30 2.50 RUNCOM N DFAL RUNCMP R/U REVERSE CIRC EQUIPMENT WHILE WAITING ON SLICKLINE. 10:30 - 11:30 1.00 RUNCOM N DFAL RUNCMP R/U SLICKLINE PER SLB. 11:30 - 14:00 2.50 RUNCOM N DFAL RUNCMP RIH WITH SLB SLICKLINE,RETRIEVE BALL AND ROD,AND POOH. -MONITOR WELL ON PIT#4 14:00 - 15:00 1.00 RUNCOM N DFAL RUNCMP PJSM ON PRESSURE TESTING TUBING PRESSURE TEST 4-1/2"COMPLETION TUBING -250 PSI(5 MIN)LOW,4000 PSI(30 MIN)HIGH -CHARTED,GOOD TEST WTL APPROVAL TO PROCEED WITH OPERATIONS 15:00 - 15:30 0.50 RUNCOM P RUNCMP R/D SLB SLICKLINE Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 9 of 10 Operation Summary 'Report Common Well Name:04-350 AFE No Event Type:COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C:(1,805,044.00) Project:Prudhoe BaySite: PB DS 04 Rig Name/No.: DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 17:00 1.50 RUNCOM P RUNCMP PRESSURE UP TUBING TO 1500 PSI AND HOLD. PRESSURE TEST IA(4-1/2"X 7"&9-5/8" ANNULUS) 250 PSI(5 MIN)LOW,4000 PSI(30 MIN)HIGH CHARTED,GOOD TEST WTL APPROVAL TO PROCEED WITH OPERATIONS SHEAR UPPER GLM SHEAR VALVE: -BLEED IA AND TBG TO 0 PSI -PRESSURE UP IA TO 3200 PSI -BLEED IA AND TBG TO 0 PSI ESTABLISH COMMUNICATION BETWEEN IA AND TBG: -CIRC DOWN IA AT 3 BPM,2350 PSI -CIRC DOWN TBG AT 3 BPM,2500 PSI 17:00 - 18:00 1.00 BOPSUR P RUNCMP PJSM AND SET FMC 4"H TYPE TWC TEST TWC FROM BELOW: -250 PSI(5 MIN)LOW,2000 PSI(10 MIN)HIGH -CHARTED,GOOD TEST TEST TWC FROM ABOVE: -250 PSI(5 MIN)LOW,3500 PSI(10 MIN)HIGH -CHARTED,GOOD TEST 18:00 - 23:30 5.50 BOPSUR P RUNCMP PJSM, WD BOP,DRAIN BOP STACK,REMOVE PS-21 SLIPS, B/D CHOKE AND KILL, REMOVE STRIP-O-MATIC, N/D BOP, N/D 13-5/8"RISER. 23:30 - 00:00 0.50 WHSUR P RUNCMP PJSM FOR N/U DRY HOLE TREE TO ADAPTER FLANGE AND PLACING ON WELLHEAD. 11/19/2011 00:00 - 05:30 5.50 WHSUR P RUNCMP N/U DRY HOLE TREE AND ADAPTOR FLANGE TO WELLHEAD, RUN I-WIRE THROUGH AND TEST I-WIRE.GOOD TEST. 05:30 - 07:00 1.50 WHSUR P RUNCMP R/U AND PRESSURE TEST TREE -250 PSI(5 MIN)LOW,5000 PSI(10 MIN)HIGH -CHARTED,GOOD TEST R/D TEST EQUIPMENT 07:00 - 10:00 3.00 WHSUR P RUNCMP R/U LUBRICATOR AND PRESSURE TEST -250 PSI(5 MIN)LOW,3500 PSI(5 MIN)HIGH -GOOD TEST PULL TWC AND R/D LUBRICATOR 10:00 - 11:00 1.00 WHSUR P RUNCMP RU/U CIRC EQUIPMENT, HEAT DIESEL TO 70 DEG F. 11:00 - 12:30 1.50 WHSUR P RUNCMP CONDUCTED DROPPED OBJECT PREVENTION ENGAGEMENT MEETING WITH BOTH CREWS. 12:30 - 15:00 2.50 RUNCOM P RUNCMP PJSM-FREEZE PROTECT WELL. HEAT DIESEL TO 70F. PIT LINES TO 3200-PSI. REVERSE CIRCULATE 160-BBLS.DIESEL AT 1.0-BPM AT 2640-PSI. 15:00 - 17:30 2.50 RUNCOM P RUNCMP SWAP VALVES ON SQUEEZE MANIFOLD AND ALLOW DIESEL TO U-TUBE IA X T. Printed 11/28/2011 11:35:17AM North America -ALASKA- BP Page 10 of 10 Operation Summary Report Common Well Name:04-350 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/10/2011 End Date: 11/19/2011 X3-00YXF-C:(1,805,044.00) Project:Prudhoe Bay Site: PB DS 04 Rig Name/No.:DOYON 25 Spud Date/Time: 10/2/2011 7:30:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:04-350 actual @70.08ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 22:00 4.50 WHSUR P RUNCMP PJSM-INSTALL AND TEST TWC. DRAIN TREE. RIG UP DSM LUBRICATOR AND TEST TO 500-PSI LO/3500-PSI HI FOR 5/5 CHARTED MINUTES. SET TWC. RIG DOWN DSM LUBRICATOR. TEST TWC FROM BELOW TO 250-PSI LO/2000-PSI HI FOR 5/5 CHARTED MINUTES. RIGGED DOWN TEST EQUIPMENT. BLEW DOWN LINES AND SECURED WELL. REMOVED WORKING VALVES FROM IA AND OA. INSTALLED TAPPED BLIND FLANGES ON IA AND OA WITH PRESSURE GAUGES. PERFORMED HOUSEKEEPING IN WELL CELLAR AND BOP DECK. 22:00 - 00:00 2.00 RIGD P RUNCMP PJSM-LOWER IRON DERRICKMAN TO FLOOR LEVEL. CLEAN RIG AND CLEAR FLOOR. DRAIN CHARGE PUMPS AND MUD LINES IN PUMP ROOM. RELEASED RIG AT 00:00-HRS. Printed 11/28/2011 11:35:17AM 04-350, Well History (Post Rig) Date Summary 01/21/12 MIRU. RIH w/BTT 3.70" mill/motor assy to set down at 10020'. Mill assumed cement sheath easily to 10181'. 01/22/12 Continue milling easily an assumed cement sheath from 10181'to probable wiper plug at 10209'CTD. Pump 25 bbl biozan sweep and chase to surface w/KCI. FP wellbore w/60/40 from 2500'. RDMO. Job complete. 02/02/12 T/I/O=0/VAC/130.Temp=32°.T& IA FL. (Slickline Request). AL=SI.TBG FL near surface, unable to qet IA FL due to VAC. 02/05/12 SET 4 1/2" SLIP STOP CATCHER @ 3701'SLM. LRS PUMPED 3 BBLS DOWN IA. PULL S/O FROM STA#2 @ 3553' SLM(3580' MD). SET 1" BK DGLV IN STA#2 3553' SLM. LRS MIT-IA TO 3000#- PASSED. 02/06/12 PULLED 4 1/2" SLIP STOP CATCHER @ 3700' SLM. DRIFTED W/20'X 3 3/8" DUMMY GUN W/SAMPLE BAILER TO 10,207' SLM,TARGET DEPTH 9971' MD- BAILER HAD SAMPLE OF MILLED CEMENT& RIG DEBRIS. TURN WELL OVER TO PAD OP. LEFT WELL SHUT IN. 02/17/12 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O=0/75/100 PSI. TD TAGGED AT 10236'. RECORD STATION LOG WITH PRESS/TEMP SENSOR AT 10211' FOR 5 MIN. 1700 PSI ON TUBING WHILE LOGGING DUE TO CABLE FLUID DISPLACEMENT. MAIN PASS LOGGED FROM TD-9650' UP AT 30 FPM,TEMP/PRESS DATA RECORDED ACROSS SAME INTERVAL. REPEAT PASS LOGGED FROM TD-9275'AT 30 FPM. UNABLE TO DETERMINE ACCURATE FIELD PICK TOC DUE TO PATCHY CEMENT BELOW THE LINER HANGER. 02/18/12 INITIAL T/I/O=0/75/100 PSI. RUN#1 - PERFORATED INTERVAL @ 9956'-9976'WITH 20' x 3-3/8" HSD PJ 3406 HMX GUN. RUN#2- PERFORATED INTERVAL @ 9942'-9956'WITH 14'x 3-3/8" HSD PJ 3406 HMX GUN. RUN #3- PERFORATED INTERVAL @ 9904'-9924'WITH 20'x 3-3/8" HSD PJ 3406 HMX GUN. UNIT SHUT DOWN FOR THE NIGHT,WELL SHUT IN ON DEPARTURE. 02/19/12 INITIAL T/I/O=0/40/100 PSI RUN#4- PERFORATE 9884'-9904'WITH 20' (FULL LOADED)X 3-3/8" HSD PJ 3406 HMX. RUN#5- PERFORATE 9876' -9884'WITH 10' (8' LOADED)3-3/8" HSD PJ 3406 HMX. FINAL T/I/O=0/40/100 PSI. JOB COMPLETE. 02/24/12 T/I/O=0/68/140 Temp=S/I. Step Rate Injectivity Test(New Well Post). Attempted to pump 60/40 meth spear down Tbg. Tbg pressured up to 800 psi max pressure. Monitor Tbg pressure and repeatedly bumped up Tbg pressure to 800 psi with 60/40 meth. (2.4 bbls total) Still in progress. 02/25/12 Step Rate Injectivity Test(New Well Post). Pumping in progress. Continued to monitor Tbg pressure and repeatedly bumped up Tbg pressure with 60/40 meth to 800 psi. (5.7 bbls pumped) Increased pressure to 2000 psi with an additional 4 bbls of 60/40 meth @ 0.3-0.4 bpm. Monitored pressure fall off to 255 psi in 45 min. FWHP=0/60/100. 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Dispatched To: Christine Mahnken Well No 04-350 Date Dispatched: 10-Nov-11 Installation/Rig Doyon 25 Dispatched By: Brian Muzny Data No Of Prints No of CDs Surveys 2 1 Received By: Zin Please sign and return to: Drilling&Measurements LWD Division 2525 Cambell Street,Suite 400 Anchorage,Alaska 99501 muznyl @slb.com Fax:907-561-8317 LWD Log Delivery V1.0,01/22/2010 • • o „ n 00„0,...„ O O O M O 1 m 0 0 0 } . C N M 3 o.m a y 2 2 ae 'm r. , §72713 0 co O m mo'zr,t6pooi oZi m m ci' o' o' m o`•" m o 5 o mo m° Og N.) m� o . 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Z W WJj' mWWWW mO'Dmm W O N JAmmm JomN JNWA mmJNmaz OAi ` 22.,-till' mm LA0 OJ(Nbd't A' V(D mN,p J 1:::::1J-J, JJJ J N -2:14,J J J J N m m mU,011 (n(n wmm . .,,,4=.tn a Utm m T a 2 m A A W W W W O O_m w o A N m A m 822,25 24">2482 NOoo N NN b wOmONJWW mmm 5 m- -.Iowa- W NOON 0OWN0 _ J N VO V V J V J J J V V N ‘-i-j2 -.' 8,'W.?,'V V N J O O O O O O O O O O O0 0 0 0 0 N N V V N V N N NNN N N N N V V Mn,V V V V V V J V J N V J J J V N V r m m� mmm�m mm m 0m O A 0 A)m m m m(O O V V J W m W A mt m J O_�W W� N OH O Nm -' O m m?N W J J A O W W m m S O C CO m AJ Nm- Ommo,, Oo N(AO— Jmmm V D m mAmmAAt mtttV8 AmmAmAmm mm'mmt IV N m N N IVIV N IV N IV IV N NNN(V r P) m W Nmmm 0(0IVN NN N NIV CC00 ((000000 (0 O Am—<J AmONm amONO Am W,m .2, m N +y m N N VA-,AN A m V V A .N.-.01 OV m NRi W"m M m',INN WWWW, mmmOV Om,N _C W "---"'J WV AmVnON mNomW .g O_ W • Drilling&Measurements 2525 Gambell Street.Suite 400 Anchorage AK 99503 Schlumberger Tel(907)273-1700 Fax(907)561-8317 t� lS CI Date: Well Name: 04-350 Company: BP Exploration Alaska API Number: 50-029-23453-0000 AFE Number: 000008092 Location: X=713,219.7 US Feet;Y=5,952,119.880 US Feet Field: Lisburne Rig: Doyon 25 Drilling and Measurements Field Support: Operations Manager, Mario Pepe Field Service Manager, Brian Muzny Drilling and Measurements Field Crew: Cell Manager, Jessica Dake Cell Engineer, Joe Cavataio SERVICES PROVIDED Services Services Dates Depth Intervals Directional Survey Service 01-Oct-11 to 03-Nov-11 0.00 feet to 10,323 feet PowerDrive*Rotary Steerable 11-Oct-11 to 27-Oct-11 3,893 feet to 9,866 feet VISION*(Resistivity,Gamma Ray) 03-Oct-11 to 03-Nov-11 479 feet to 10,323 feet VISION*(Neutron,Density Azimuthal) 22-Oct-11 to 03-Nov-11 9,275 feet to 10,323 feet StethoScope* (FPWD) 30-Oct-11 to 03-Nov-11 9,866 feet to 10,323 feet OPERATING STATISTICS Total MWD Pumping Time: 303.2 hours Total LWD Pumping Time: 303.2 hours Total MWD Time Below Rotary: 456 hours Total LWD Time Below Rotary: 456 hours Total MWD Depth Interval: 9,753 feet Total LWD Depth Interval: 9,753 feet Total MWD Runs: 5 Total LWD Runs: 5 JOB PERFORMANCE Directional The final MWD survey point was located at 10,268.32 feet with an inclination of 41.57 degrees and an azimuth of 104.22 degrees. This direction and inclination was projected from the final survey point to TD, which resulted in the following bottom hole coordinates. Measured Depth: 10,323 feet True Vertical Depth: 9372.97 feet Displacement at Azimuth: 53.88 feet at 104.22 degrees 1 Formation Evaluation Schlumberger 16 inch surface Section The surface section was drilled from 0 to 3,893 feet in three runs.A motor was used for directional control during all runs. From 479 to 3,898 feet,Resistivity,Gamma Ray,and APWD were supplied in real-time and from memory once the tools were retrieved. After the surface hole was drilled, 13 3/8 inch casing was set.The final measured bottom hole temperature was 68 degrees Fahrenheit. 12-1/4 inch Intermediate Section The intermediate section was drilled from 3,893 to 9,275 feet in one run.PowerDrive*rotary steerable tool was used for directional control during this run and provided inclination at bit and Gamma Ray at bit. Resistivity,Gamma Ray,APWD(for ECD and hole cleaning)were supplied in real-time and from memory once the tools were retrieved.After completing this run,9 5/8 inch casing was set.The final measured bottom hole temperature was 150 degrees Fahrenheit. 8-3/4 inch Intermediate Section: This section of the well was drilled from 9,275 feet to 9,866 feet MD. PowerDrive*rotary steerable tool was used for directional control during this hole section,and provided inclination at bit and Gamma Ray at bit.Resistivity,Gamma Ray,APWD,Azimuthal Density,and Neutron data were supplied in real-time and from memory once the tools were retrieved. 6-1/8 inch Intermediate Section: The production section of the well was drilled from 9,866 feet to 10,323 ft. MD.A motor was used for directional control during this run.Resistivity,Gamma Ray,Azimuthal Density,and Neutron data were supplied in real-time and from memory once the tools were retrieved. StethoScope*was used to measure APWD and FPWD during this run. Innovation The Schlumberger MWD team was able to successfully run Stethoscope*in the Lisburne formation for pressure testing. Schlumberger Oilfield Services—Drilling&Measurements appreciates the opportunity to provide BP Exploration(Alaska)with MWD and LWD services. Sincerely, Jessica Dake MWD/LWD Engineer Schlumberger Drilling&Measurements 2 BOPE usage report: Doyon Rig 25 1104-350' Page 1 of 1 Regg, James B (DOA) s�D z,11- From: ,11_From: Rall, John R [RalIJR2@BP.com] Sent: Saturday, October 29, 2011 10:51 AM L C 11I4" To: DOA AOGCC Prudhoe Bay Cc: Daniel, Ryan; Kilfoyle, Jeffery A; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Schultz, Mikel; Willingham, James M; Allen, Kenneth W; Egbejimba, Uchenna J; AK, D&C Rig 25 Well Site Leader Subject: BOPE usage report: Doyon Rig 25 well 04-350i Attachments: 04-350i BOP Usage Form 10-28-2011.doc <<04-3501 BOP Usage Form 10-28-2011.doc» John Rall Wells Operations Superintendent Office: 659-4618 Cell: 907-980-2589 11/4/2011 Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. N, � Field Superintendent Name: John Rall Wellsite Leader Name: Mike Hefley Contact Number: 659-4618 Contact Number: 659-5856 Harmony#5380 Traction Number: IR-3978503 Well Location & Name: DS 04-350i Permit To Drill (PTD) Number: 2111060 Date and Time of Incident: 10/28/2011 19:00-hrs. Original Scope of Work: Run and cement 767' of 7" liner to intermediate hole TD of 9866' MD, at the top of the Lisburne forma Operational Description Leading up to Well Control Event: While circulating bottoms up with 7" liner casing shoe on bottom, a pit gain was observed on the PVT monitoring system. Circulation was stopped and the well was observed for flow. The well was flowing with percolation of mud at the flow nipple. The well was shut in using the annular preventer. Instant SICP = 0-psi, instant SIDPP = 0-psi. BOPE Used and Reason: The 13-5/8" 5M annular preventer was closed to shut in the well. Approximately 2-bbls of pit gain was calculated. SICP = 0-psi. SIDPP = 0-psi. The well was circulated thru the choke for bottoms up and observed for flow through the choke. No flow was observed. The choke was shut in and the well was observed for pressure buildup for 30-minutes. SICP = 0-psi., SIDPP= 0-psi. Opened choke and annu preventer and confirmed well was not flowing. Is a BOPE Test Required after use ( Yes / No): Yes, the annular preventer will be tested once the liner running tool is pulled out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Resumed normal rig operations and cemented 7" liner in place. POH and test annular preventer. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bay(a,alaska.gov BOPE Usage Report for AOGCC August 2, 2010 HRE 1 v Email CC List Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 2 Page l of l Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, September 02, 2011 9:33 AM To: Schwartz, Guy L(DOA); 'Hubble, Terrie L' Cc: 'Pugh, Frank'; 'Kimmet, Megan'; Saltmarsh, Arthur C (DOA) Subject: RE: PTD#211-106, Name Correction OH... I just read that you already received the PTD. We will change the original copy here only then and the name will be changed in our database (RBDMS) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Friday,September 02, 2011 9:30 AM To: 'Hubble,Terrie L' Cc: Pugh, Frank; Kimmet, Megan; Saltmarsh,Arthur C(DOA) Subject: RE: PTD # 211-106, Name Correction OK ...We can change the name fairly easily. I'll change the 401 and other documents before sending back the approved PTD. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent:Thursday, September 01, 2011 5:09 PM To: Schwartz, Guy L (DOA) Cc: Pugh, Frank; Kimmet, Megan Subject: PTD # 211-106, Name Correction Hi Guy, We just got the approved Permit to Drill back today for this well and have learned that we had submitted it with an incorrect name. It is listed as L04-350 which would indicate (kind of) that this well was to be drilled from Lisburne Pad 4. However, this well is going to be drilled from Drill Site (EOA)04. The correct well name should be PBU 04-350. Would you mind hand correcting on your copies and we'll do the same here. Then, when we submit the Completion Report it will be correctly submitted. Please let me know if this is acceptable. Have a great weekend! Terrie 9/2/2011 r's ,LP ' !�, SEAN PARNELL, GOVERNOR f ' ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Pool, PBU L04-350 BP Exploration (Alaska), Inc. Permit No: 211-106 Surface Location: 236' FSL, 4883' FEL, SEC. 26, T11N, R15E, UM Bottomhole Location: 1767' FSL, 2376' FEL, SEC. 26, Ti1 N, R15E, UM Dear Mr. Egbejimba: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel . Seamount, Jr. S� Chair DATED this e day of September, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA �� ALAS "AL AND GAS CONSERVATION COMM' ON ED PERMIT TO DRILL AUG 2 4 2011 20 AAC 25.005 1 a.Type of work: 1 b.Proposed Well Class: 0 Development Oil ®Service-Winj 0 Single ZoneC �SiOn ® Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone Coalbed _ LJ g Ga Gas Hydrates 0 Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU L04-350 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10313' TVD 9369' Prudhoe Bay Field/Lisburne 4a. Location of Well(Govemmental Section): 7. Property Designation(Lease Number): Pool Surface: ADL 028324 236'FSL,4883'FEL, SEC.26,T11 N, R15E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1894'FSL,2847'FEL, SEC.26,T11 N, R15E, UM September 23,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1767'FSL,2376'FEL,SEC.26,T11 N,R15E, UM 2560 23,760' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 69 feet 15.Distance to Nearest Well Open Surface: x- 713220 y-5952120 Zone- ASP4 GL Elevation above MSL: 29.48 feet to Same Pool: 5,220' 16.Deviated Wells: Kickoff Depth: 240 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 42 degrees Downhole: 4809 Surface: 3911 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 154# X-52 WELD 154' Surface Surface 223' 223' —260 sx of Arctic Set • 16" 13-3/8" 68# _ L-80 BTC 3902' •Surface Surface 3902' 3809' 599 bbls DeepCRETE;111 bbls Class'G' • 12-1/4" 9-5/8" 40# _ L-80 Hydril563 9251' ,Surface Surface 9251' 8559' 123 bbls Class'G' . 8-3/4" 7" 26# L-80 VamTop 687' 9101' 8345' 9788' 8979' 41 bbls Class'G' • 6-1/8" 4-1/2" 12.6# L-80 IBT-M 675' 9638' 8867' 10313' 9369' 22 bbls Class'G' • 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redriil and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Frank Pugh,564-4859 Printed Name John Egbe'imba Title Engineering Team Leader + ^� //1 Prepared By Signature " `, Phone 564-5859 Date 1 Elizabeth Barker,564-5674 / Commission Use Only Permit To Drill API Nu ber: Permit rov l Date: See cover letter for Number: x/110,6 50- q�?3�S 'eGws I ' I I other requirements Conditions of Anoroval: If box is checked,well mayy n t used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: 11 Other: 0� ,0S . £3 ' '_S- �� , Samples Req'd: ❑ es CI No Mud Log Req'd: ❑�s Ila No *25� rs,, 1T b1 .v /eSf 6.. H2S Measures: Yes 0 No Directional Survey Req'd: Pr Yes 0 No 19ae(i, e.,,,,,, ' cccc.e,A.3.4.. </Doe, ' ZO AAC. Z S: 033 (�j) yr M l T i re i,r a Ai,. a 14-',, o pe r0-4-:0.1 I r. 4.c""i w� A-/O y 7/1 _9 /� APPROVED BY THE COMMISSION Date ` ,COMMISSIONER Form 10-401 evised 07/2009 This permit is valid for 24 months from date of approval(20 AAC 25.005(g)) Submit In Duplicate ORIGINAL / '4 by 0 To: Alaska Oil & Gas Conservation Commission From: Frank Pugh, Operations Drilling Engineer Date: August 18, 2011 Re: Prudhoe Bay Field, Lisburne Pool — Request for Permit to Drill 04-350i A permit to drill is requested for a new grassroots well to be named 04-350i. The primary target for this directional water injection well is the Lisburne — Wahoo Formation Z7 & Z6. There is an additional objective of appraising a target in the Ivishak reservoir for future potential. The well will utilize a cemented and perforated 4-1/2" liner for intra- zonal isolation of the reservoir injection interval. The planned spud date is September 23, 2011 and will utilize the Doyon 25 rig. Summary of Drilling Plan: A 20" surface conductor will be installed prior to the rig arriving on location. The surface interval will be a 16" hole drilled from the 20" conductor to the SV3 where 13-3/8" casing will be run and cemented to surface. The first intermediate section will be a 12-1/4" hole drilled to the base of the HRZ followed by installation of 9-5/8" casing which will be cemented to a minimum of 1,000 ft above the shoe. The second intermediate section will be an 8-3/4" hole drilled to the base of the Kavik where a 7" liner will be installed and fully cemented. The reservoir section will be a 6-1/8" hole drilled into the Lisburne — Wahoo Formation Z7 & Z6 which will be isolated by a fully cemented 4-1/2" production liner that will be perforated. The production tubing will be a full string of 4-1/2" tubing made up to a 7" x 4-1/2" production packer. Additional information as required is provided in the following sections and attachments for your review. Please contact me at 907-564-4859 should you have any questions or require additional information. Sincerely, 4 Frank Pugh Operations Drilling Engineer BP Exploration (Alaska), Inc. 04-350i Permit Application Page 1 TREE= CNV 4-1116"SM SAFETY NOTES: WELLHEAD= FMC BB PROPOSE^ 04-3501 ACTUATOR= Hyd. KB ELEV= 69 00' BF EL EV= 29.48' Waif—AngleK L 240' , . 20"COPD,154#,X-52,F)=18.500 '4 —223' = 42'09569.- DatumMD= 10313' DatumTVlk 9300.ss 13-318-CSG.68#.L-80.I0=12 415 -{ -3902' I---411 SV3 HRZ I9-5/8"CSG.40#.L-80,1 8.835 IH —9251' IVISHAK SLB SAPHIRE DHP Gauge —i —9538' , r J NIXKAV I K 4-1/2"TBG,12.68,L-80.10=3 958 Fi —9636' •, 7"LNR.26#.L-80.113=6.276 ' REIRFORATION SIA/MARY iTBD} ' REF LOG: ANGLE AT TOP PEFf: I Note:Ret sr to Production U8 for historical pert data LISBURNE SIZE SEE INTERVAL Opn/Sqz DATE 14-1/7'LNR.12.6#,L-80.13.958I� —10,313' I '1'EEVECC, DATE REV BY C,OMMFNrs IIA TI REV BY COMM, PRUDHOE BAY UNIT 01/17/11 CRR Original Dralt WELL. 04-3SOi 08/15/11 FDP Revised Depths R.Casing PERMRNo: API No SEC 26.T11 N,RI5E,23T FSL 8 4883'FEL BP Exploration(Alaska) 04-350i Permit Application Page 3 Drill and Complete Plan Summary Well Name: 04-350i Well Type: Water Injector Target Objective: Lisburne — Wahoo Z7 & Z6 Estimated Start Date: 23-Sep-2011 Time to complete: 39.2 days API NUMBER: N/A Rig: Doyon 25 Planned TD: 10,313' MD 9,369' TVD RT/GL: 39.52' / 29.48' RTE: 69.00' Surface Northing (Y) Easting (X) Section Offsets TRS Location 5,952,119.88' 713,219.70' 237' FSL /4,883' FEL 11N, 15E, 26 Northing (Y) Easting (X) TVDss Section Offsets TRS Locagens et 5,953,836' 715,206' -8,754' 1,895' FSL / 2,847' FEL 11 N, 15E, 26 ti5,953,804' 715,342' -8,910' 1,859' FSL / 2,712' FEL 11N, 15E, 26 Bottom Northing (Y) Easting (X) TVDss Section Offsets TRS Hole 5,953,722' 715,683' -9,300' 1,767' FSL / 2,373' FEL 11 N, 15E, 26 Location Well Design: 4-String, Big Bore w/ Cemented & Perforated Completion Directional Plan (attachment included): KOP: 240' MD, build 1.0°/100ft Plan Version: Schlumberger Plan 04-350 (P8) Maximum Hole Angle: 42.0° @ 9,569 ft MD Survey Program: MWD Standard + IFR + Multi-Station Close Approach Wells: All wells pass Major Risk criteria. Reference anti- collision report in the directional well plan for detail. Nearest well within Pool: 5,220' horizontal distance to L3-24 in Lisburne Pool. Distance to Nearest Property Line: 23,760' to PBU boundary. BP Contact Personnel: Name Position Office Cell e-mail Frank Pugh Drilling Engineer 564-4859 382-6260 Frank.Pugh2@bp.com Mike McTeague Geologist 564-4640 928-607-9386 Mike.McTeague@bp.com Megan Kimmet Petroleum Engineer 564-5851 240-8398 Megan.Kimmet@bp.com 04-350i Permit Application Page 2 Formation Markers & Pore Pressure: SoR Formation Top and Estimated Pore Pressure Predictions Tops Based on Well Plan#: 04-350_wp6 Estimated Depth Hydrocarbon Pore Pressure Formation Formation Top Uncertainty Bearing (TVDss) (+/-TVD ft) (Yes/No) Minimum Most Likely Maximum (PP9) (PPM (PIN) BPRF 1,899 +/-50' No 8.35 8.35 8.9 SV5 3,054 +/-50' No 8.35 8.9 8.9 SV4 3,274 +/-50' No 8.35 8.8 8.8 SV3 3,756 +/-50' No 8.35 9.03 9.03 SV2 3,936 +/-50' No 8.35 9.0 9.0 SV1 4,367 +/-50' No 8.35 8.9 8.9 UG4 4,943 +/-50' No 8.35 8.85 8.85 UG3 5,139 +/-50' No 8.35 8.94 8.94 UG1 5,870 +/-50' No 9.13 9.33 9.33 WS2 6,421 +/-50' No 9.13 9.33 9.33 WS1 6,632 +/-50' No 9.13 9.33 9.33 CM3 6,882 +/-50' No 8.45 9.8 10.1 CM2 7,348 +/-50' No 9.2 10.2 10.6 CM1 7,864 +/-50' No 9.8 10.2 10.6 THRZ 8,299 +/-20' No 10.1 10.4 10.6 TSAD 8,490 +/-20' Yes 7.2 7.36 7.52 TKVK 8,754 +/-20' No 9.3 9.8 10.3 TLSB g 910 30 shUeleo�w/20 Yes 5.1 7.56 7.85 TD 9,300 5.1 7.56 7.85 Wells within 1/4 mile of this injection well: Well Name Dist, Ft. Annulus Integrity Comments None N/A N/A 04-350i Permit Application Page 4 1 sil a 1 a 0 \\\ , m O ti> ,A' O LU SAV- 547.. CO \\ ``ry \•J ` Q 6 O O m L. \ \ .1.'1 , • . CU \ ��TT g_�_ c \ , -0a3 ililikkih1/4 a .. MIIIWs' : 4\\ .4v S iii 0_ 7 • .4 1%, ,, iii\‘414 *. _‘..i 0 c ,... ____ ,..„ _c .„.. -A Ilk .41 . • , y ,, 7 \ 0 Ii ` 0.. (13a O P.` ,. 1 ,.// A • / ,A C, 1 A. - : a` CI a 0 Well Control: Equipment capable of controlling the maximum potential surface pressures will be installed on each section. The 16" surface hole will be drilled with 21-1/4" diverter equipment rated to 2,000 psi. The 12-1/4" intermediate hole and subsequent hole sections will use 13-5/8" BOPE consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. 13-5/8" BOP Stack: 21-1/4" Diverter: • 5,000 psi Annular Preventer • 2,000 psi Diverter Annular • 5,000 psi Pipe Rams (2) • 5,000 psi Blind Shear/Rams The BOP will be tested on a 14 day cycle, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period will not be requested. Diverter, BOPE, and general arrangement drilling fluid system schematics of Doyon 25 are attached to this permit to drill. BOPE test pressures are based on the data below: Maximum Surface Pressure —Assumes Full Column of Gas to Surface (Formation Pore Pressures represent the maximum predicted values) 12-1/4" Hole TVD Formation Gas Maximum Maximum (1S`Intermediate Section) (ft) Pore Press. Gradient Anticipated BHP Surface Pressure (ppg) (psi/ft) (psi) (psi) Ugnu &West Sak 5,939 9.33 0.10 2,881 2,287 lvishak 8,559 7.52 0.10 3,347 2,491 13-5/8" BOP planned test pressures: • Annular Preventer 250 psi/3,500 psi • Rams 250 psi/3,500 psi 8-3/4" Hole TVD Formation Gas Maximum Maximum (2"d Intermediate Section) (ft) Pore Press. Gradient Anticipated BHP Surface Pressure (ppg) (psi/ft) (psi) (psi) Kavik 8,979 10.3 0.10 4,809 3,911 Lisburne 8,979 7.85 0.10 3,665 2,767 13-5/8" BOP planned test pressures: • Annular Preventer 250 psi/3,500 psi • Rams 250 psi/4,000 psi 6-1/8" Hole TVD Formation Gas Maximum Maximum (Production Section) (ft) Pore Press. Gradient Anticipated BHP Surface Pressure (ppg) (psi/ft) (psi) (psi) • Well Total Depth 9,369 7.85 0.10 3,824 2,888 13-5/8" BOP planned test pressures: • Annular Preventer 250 psi/3,500 psi • Rams 250 psi /3,500 psi Planned completion fluid: 8.5 ppg seawater/6.8 ppg diesel to 2,200 ft ND 04-350i Permit Application Page 5 ilt f 8 1 1 1 1 8 ; i311g a I 8 I I 1 ' 11 ton° iii 9 8 8 , 8 1 9 8 8 1 Ia) �, 0 a 0 i , cc Q r r: C r�_ry 1 %1 L : � O :' `'`' �_-� [ q("1/4E vi �� a' n �- . �� v Q i i iju k a r I o II t LisN �I A t cf iii 1 iii•� >+ i _ lit =E 0 3 Ii:� ; 1 1 i r s 1 l ` +► \ _— V`. • �� ' Ir ''. \\,._c_ir ,% � t"-' I ma III 3 /--Tho 6 i U - Q a- Q E a) a. O coLo O -01.0.1.4......‘,....-Agetavord--, L! . I , = ell dVi9"Pl. 1 .II:= '"----- -- 1 E El t 2r A 2 2 "-- —1-li=i i El'.. 2 2-----.1 • iMi..- :: , ti Mow . .. 1 1.e 1.1tori, .....w.korida.-- ii..---ol- ii..-Ritiirsigji• gi[lit:0 R 4 ill u iltibil:f: M 11111111 g‘ !Phil ,ill'ic,tr!._ i ....—_,, .. .11111MI IIIIIIIID 4, 11111111!Z i 111111. •;ti, lail --.:!: ' :i! ,trs 12,1 a) a) .L. fAilp,,..-. x co - MANI ..:' I 1 . r. -—..---- „ri . 11111111t 1 (,) tr 1 I --- - '---7 .7:: .ss.‘ 11:3 aais.;!1 t',i..i.0•1'E' I a_ 1 ...... 1 15 i i5 E El tt—F_All :11•iug,'17 5.1.7.t4-,--e'\V\:1'e=:/i-,E-I0.l--w''::7N.:.,1:,.,..,4:t,s,:74:e.:7 i N f1IHIIpmI. . 1 T Ce°;t C.2.4 i I 14 4 1 ' a r 0 .,, ... , 1 ,.._ .- • : li .7,,... I , 1.10111' . - 1 1Mmol - =MIMEO IV* i '.rtv I mil_ 01 , istrias , .i..... ±.:.,1 i 7-----_r, i 1 III ' 7 , lis a , '! 1 Li -1 j .E:: i 1, ,_•.,. lEi , . : . 0 ...,... . .- i -, __..„, , _, „._ , 0 , a , 111 • i', '-I -0.-:— L .,-„. 0_ ALI i < :.- E iii :- - MIII 0- alit, 6 Int in c? ct cm Casing/Tubing Program: Casing Hole Casing &Tubing Description Top Bottom String SizeSize lb/ft Grade Conn. Length , , <. ` Conductor 42 & 20" 154 X-52 WELD 154' Surface 223' 223' Driven Surface 16" 13-3/8" 68 L-80 BTC 3902' Surface 3902' 3809' Inter./Prod. 12-1/4" 9-5/8" 40 L-80 H YD9251' Surface 9251' 8559' Inter./Prod. 8-3/4" 7" 26 L-80 VAM 687' 9101' 8345' 9788' 8979' LinerTOP HC Production 6-1/8" 4-1/2" 12.6 L-80 IBT-M 675' 9638' 8867' 10313' 9369' Liner Tubing Tubing 4-1/2" 12.6 L-80 TC-II 9638' Surface 9638' 8867' Comments: Tubing crossover to 4-1/2"just below tree. Casing & Tubing Specifications % Rating Burst Collapse Tensile ID Make-up Torque Surface Casing: 13-3/8", 68 ppf, L-80, BTC 100% 5020 psi 2260 psi 1,556,000 lb 12.415" ID To Position 80% 4016 psi 1808 psi 1,244,800 lb 12.259" Drift Intermediate/Production Casing: 9-5/8",40 ppf, L-80, Hydril 563 100% 5750 psi 3090 psi 916,000 lb 8.835" ID 13,000 ft-lb (opt) 80% 4600 psi 2472 psi 732,800 lb 8.75" Drift 10,800 ft-lb (min) Intermediate/Production Liner: 7", 26 ppf, L-80, VAM Top HC 100% 7240 psi 5410 psi 604,000 lb 6.276" ID 17,000 ft-lb (opt) 80% 5792 psi 4328 psi 483,200 lb 6.151" Drift 14,000 ft-lb (min) Production Liner: 4-1/2", 12.6 ppf, L-80, IBT-M 100% 8430 psi 7500 psi 288,000 lb 3.958" ID To Position 80% 6744 psi 6000 psi 230,400 lb 3.833" Drift Completion Tubing: 4-1/2", 12.6 ppf, L-80,TC-II 100% 8430 psi 7500 psi 288,000 lb 3.958" ID 4200 (max) 80% 6744 psi 6000 psi 230,400 lb 3.833" Drift 3500 (min) 04-350i Permit Application Page 8 Formation & Casing Integrity Testing: Formation & Casing Integrity Testing Summary Shoe Test Shoe Minimum Minimum Casing Test Casing Test Test Point Depth Test FIT/LOT Expected Pressure Pressure Type (ECD) FG (Drilling) (Completion) 13-3/8" Surface 20-50 ft LOT 11.8 ppg 12.6 ppg 3,500 psi N/A Casing Shoe below shoe 9-5/8" Intermediate/ 20-50 ft LOT 11.8 ppg 12.7 ppg 4,000 psi 3,500 psi Prod. Casing Shoe below shoe 7" Intermediate/ 20-50 ft FIT 9.7 ppg 11.7 ppg 3,500 psi 3,500 psi Production Liner Shoe below shoe 4-1/2" Prod. Liner Lap TOL LNR Lap N/A N/A N/A 3,500 psi Mud Program: 16" Surface Hole: Freshwater Mixed-Metal Oxide or H droxide MMO or MMH Depth Interval Density Funnel Viscosity (2x 3rpm— Yield Point Flu d Loss pH (ft) (ppg) (seconds) 6rpm) (Ib/100ft ) (m1/30min) 223—3,902 60-120(for reference Surface—SV3 8.8—9.5 only. Fluid should be 30—60 30—80 NC 10.3— 11.0 run off LSYP 12-1/4" Intermediate Hole: Low-Solids/Non-Dis•ersed LSND Poi mer Plastic Yield API HPHT Drill Depth Interval Density Viscosity Point Fluid Loss Fluid Loss pH Solids MBT (ft) (ppg) (cP) (Ib/100ft2) (ml/30min) @ BHCT (%) (ppb) (ml/30min) 3,902-9,251 9.2- 10.6 12-22 17-28 <6.0 < 10.0 9.0-10.0 <6.0 <20 SV3—TSAD 8-3/4" Intermediate Hole: Low-Solids/Non-Dis•ersed LSND Poi mer Plastic Yield API HPHT Drill Depth Interval Density Viscosity Point Fluid Loss Fluid Loss pH Solids MB (ft) (ppg) (cP) (Ib/100ft2) (ml/30min) @ BHCT (%) (ppb); (m1/30min) 9,251 -9,788 90- 10.8 <22 17-28 <6.0 < 10.0 9.0-10.0 <6.0 < 20 TSAD—TLSB 6-1/8" Production Hole: Po/ mer-Based RDF Plastic Yield API HPHT Drill Depth Interval Density Viscosity Point Fluid Loss Fluid Loss pH Solids MBT` (ft) (ppg) (cP) (Ib/100ft2) (m1/30min) @ BHCT (%) (ppb}r (m1/30min) 9,788-10,313 85-9.0 0- 12 20-28 6.0-8.0 N/A 9.0-9.5 < 3.0 <4 TLSB—TD 04-350i Permit Application Page 9 Cement Calculations: PERMAFROST: The 13-3/8" surface casing will be run approximately 1,871' TVD below Base Permafrost and may use a port collar, if deemed necessary. The casing will be cemented to surface with light weight Arctic grade (DeepCRETE) lead slurry and class `G' tail slurry. Surface Casin•: Casing 13-3/8", 68 ppf, L-80, BTC Lead: Open-hole volume>250% excess in permafrost and 40% excess below permafrost, final volume to be based on hole condition. Use Port collar as required. Basis: Lead TOC: Surface. Tail: Open-hole volume> 250%excess in permafrost and 40% excess below permafrost+40' shoe track, final volume to be based on hole condition. Tail TOC: 1,000' MD above the 13-3/8" casing shoe. Total Cement Volume: 710 bbl Lead 599 bbl of DeepCRETE 11.0 ppg Tail 111 bbl of Class 'G' 15.8 ppg Intermediate/Production Casin•: Casing 9-5/8",40 ppf, L-80, Hyd-563 Basis: Tail: Open-hole volume 40% excess+80' shoe track, final volume to be based on hole condition. Tail TOC: 1,500' MD above the 9-5/8" liner shoe. Total Cement Volume: 123 bbl Lead None Tail 123 bbl of Class'G' 15.8 ppg Intermediate/Production Liner: Liner#1 7", 26 ppf, L-80, VAM Top HC Basis: Tail: Open-hole volume 40% excess+80' shoe track, unless otherwise determined by caliper logs. Tail TOC: 200' above 7" liner top. Total Cement Volume: 41 bbl Lead None Tail 41 bbl of Class `G' 15.8 ppg Production Liner: Liner#2 4-1/2", 12.6 ppf, L-80, IBT-M Basis: Tail: Open-hole volume 40% excess+80' shoe track, unless otherwise determined by caliper logs. Tail TOC: 200' above 4-1/2" liner top. Total Cement Volume: 22 bbl Lead None Tail 22 bbl of Class `G' 15.8 ppg 04-350i Permit Application Page 10 Logging Program: Logging Program Summary s° Drilling-MWD/LWD: DIR/GR/RES/PWD 16" Surface Hole Section Open Hole WL: None Cased Hole WL: None Drilling-MWD/LWD: DIR/GR/RES/PWD 12-1/4" 1st Intermediate Section Open Hole WL: None Cased Hole WL: Sonic Scanner 8-3/4" 2"d Intermediate/ Drilling-MWD/LWD: DIR/GR/RES/PWD/NEU/DEN Production Section (Ivishak) Open Hole WL: None Cased Hole WL: Sonic Scanner Drilling-MWD/LWD: DIR/GR/RES/PWD/NEU/DEN/FPWD 6-1/8" Production Section Open Hole WL: NGS/FMI/Sonic Scanner/AIT/MCFL/ECS/ (Lisburne) XPT formation pressures (contingency) NMR (optional) Cased Hole WL: USIT Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I waste to Pad 3 for disposal. Variance Request: To avoid the risk of plugging the flow line with large rocks and wood fragments encountered - while drilling surface hole, it is requested to drill without a flow paddle for approximately the first b.K 1,000 ft. After drilling past the larger cobbles and wood sections, the flow paddle will be placed back in the flow line. 04-350i Permit Application Page 11 Summary of Drilling Hazards WeII# 04-350i POST THIS NOTICE IN THE DOGHOUSE I. Well Collision Potential &Close Approach: A. All wells pass Major Risk criteria. Reference anti-collision report in the directional well plan for detail. Shut-in adjacent wells 04-11Ai & 04-25i which may fail close approach tolerances while drilling the surface hole. II. Hydrates and Shallow gas: A. No history of being present at the DS-04 pad area. III. Well Control Formation Pressures: A. Formation pressure estimates below are based on offset well pressures, drilling record mud weights, and PPFG analysis. Formation Pore Pressure TVDss MD Hydrocarbon Bearing Ugnu &West Sak 9.13—9.33 ppg 5,870'—6,882' 6,303'—7,410' No Sadlerochit(Ivishak) 7.20—7.52 ppg 8,490'—8,754' 9,251'—9,578' Yes Kavik 9.30— 10.30 ppg 8,754'—8,910' 9,578'—9,788' Yes Lisburne 5.10—7.85 ppg 8,910'—9,300' 9,788'—10,313' Yes IV. Kick Tolerance Minimum Formation Integrity Requirements: A. The computed kick tolerances below were determined by using the minimum planned mud weights together with pore pressures +0.5 ppg greater than the maximum predicted pore pressures in exposed permeable zones or potentially permeable zones for each section. Kick Tolerance Minimum Formation Integrity Requirements Summary Maximum Minimum Maximum Minimum Minimum Casing and Interval Influx Mud Predicted FIT/LOT Expected Volume Weight Pore Pressure (Kick Tol.) FG 13-3/8" Surface Casing > 50 bbls 9.6 ppg 9.33 ppg 11.7 ppg 12.6 ppg 9-5/8" Intermediate/ Infinite 9.0 10.3 11.6 12.7 Production Casing ppg ppg ppg ppg 7" Intermediate/ Infinite 8.5 7.85 9.0 11.7 Production Liner ppg ppg ppg ppg 4-1/2" Production Liner N/A N/A N/A N/A N/A V. Surface Broaching: A. Monitor adjacent wells for indications of broaching while drilling surface hole. 04-350i Permit Application Page 12 VI. Running Gravels: A. Surface Hole: Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede building angle and running casing through the permafrost. Boulders and/or cobbles could cause BHA deflection and create excessive doglegs. Build rates through the permafrost should be kept low (1°/100ft). Maintain low flowrates to minimize hole washout. Hazards include wood & cobbles, lost circulation, and tight-hole problems while drilling and running casing. Use best practices for drilling and casing the surface hole interval. See DS-04 Pad Data Sheet for additional detail. VII. Faults: Fault Crossings & Intersect Intersect Est.Throw Throw Direction Uncertainty Associated Formations MD TVDss None expected N/A N/A N/A N/A N/A VIII. Lost Circulation/ Breathing: A. Potential losses to the Ivishak due to low PP & FG, if drilled into with the higher weight required for the Colville and HRZ. B. Potential losses in the Lisburne—Wahoo Formation ranging from minor to severe, though most likely to be low-moderate, if drilled into with the higher weight required for the Kavik. Faults are not expected to be present and fracturing should be minimal. Follow the LCM decision tree; keep mud weight as low as safely permissible. IX. Heavy Oil: A. Not present in the DS-04 pad area. X. Hydrogen Sulfide: A. DS-04 Pad is designated as an H25 site. Follow Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: H2S Data Well Name Fl Level Date of Reading Parent Well (if sidetrack) N/A N/A N/A #1 Closest SHL Well H25 Level 04-11i N/A- Injector N/A #2 Closest SHL Well H25 Level 04-25i N/A- Injector N/A #1 Closest BHL Well H2S Level (Ivishak) 04-02A 550 ppm 10/28/2010 #2 Closest BHL Well H2S Level (Ivishak) 04-08i N/A- Injector N/A #1 Closest BHL Well H2S Level (Lisburne) L3-28 120 ppm 4/16/1993 #2 Closest BHL Well H2S Level (Lisburne) L4-31 45 ppm 8/22/2007 Max. Recorded H2S on Pad/Facility 04-39 1950 ppm 7/1/2001 DS4 is an H2S pad Other Relevant H2S Data Note: L4 Pad has had some high H2S (L4-15 and L4-30 as (H2S alarms from rigs, etc.) high as 2100 ppm). Recent H2S samples have been below 400 ppm. 0 Review the DS-04 Pad Data Sheet and the Well Plan for additional information. 04-350i Permit Application Page 13 04-350i — Drill and Complete Operations Summary Current Condition & Well History: 1. This is a grassroots well. Preliminary (Pre-Rig) Operations: 1. Install 20" conductor. 2. Weld an FMC landing ring for the FMC Big Bore wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Shut-in nearby wells, bleed-off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Doyon 25: a. Survey conductor with rig over it to ensure rig is centered over the hole. b. R/U diverter system and test. '/ 2. Drill 16" Surface Hole Section: a. Prepare enough 5"drill pipe to drill the surface hole. b. Make-up 16" directional drilling assembly with MWD/LWD tool string. c. Cleanout 20" conductor, spud well & directionally drill surface hole to the base of the permafrost. p Gyro data is needed to about 1,100 ft where it's estimated that clean surveys can be taken. d. At base permafrost circulate hole clean and condition mud as required prior to making wiper trip " to the top of the HWDP. e. RIH &drill remainder of surface hole to planned casing point in the shale above the SV3. f. Circulate hole clean &condition mud as required prior to making wiper trip to base of permafrost. - g. Trip back to TD, circulate hole clean and condition mud for running 13-3/8"casing. h. POOH and L/D BHA. 3. Run &Cement 13-3/8" Surface Casing: a. Run 13-3/8", 68 ppf, L-80, BTC surface casing. b. R/D casing equipment. c. Cement with 1,000 ft of 15.8 ppg Class G tail cement& 11.0 ppg DeepCRETE cement to surface. d. Pressure test casing to 3,500 psi for 5 minutes on plug bump. e. R/D cementing equipment and flush diverter system. f. N/D diverter system. g. N/U FMC 13-5/8" 5M New Standard Big Bore wellhead system and test as required. h. N/U & pressure test 13-5/8" 5J\A BOPE: /4x— 23.31.4 40 Ps,'/ Test rams to 250 psi/,3, ff psi P Test annular to 250 psi/3,500 psi L7 0 Svv 04-350i Permit Application Page 14 4. Drill 12-1/4" 1st Intermediate Hole Section: a. Prepare enough 5" drill pipe to drill the 12-1/4" 1st intermediate hole. b. Test 13-3/8" casing to 250 psi for 5 minutes / 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 12-1/4"drilling assembly with MWD/LWD tool string. d. RIH &tag float collar or TOC. Displace to 9.2 ppg LSND mud while drilling the shoe track. e. Drill at least 20 ft but no more than 50 ft of new formation for the LOT and CBU. • f. Pull inside casing and perform the LOT. g. Drill ahead following the directional plan. Ensure mud weight is increased to 10.2 ppg at least 100 ft above the HRZ, according to the HRZ polar plot. h. Continue drilling to the 1st intermediate casing point which is the HRZ/Ivishak interface. CBU as needed for cutting samples to properly identify Ivishak boundary. . i. At casing point, circulate hole clean &condition the mud as needed prior to performing wiper trip. j. Run back to bottom, circulate hole clean and condition mud for running 9-5/8" casing. k. POOH and lay down the BHA. 5. Run &Cement 9-5/8" Intermediate/Production Casing: s./Ooc) l a. Change upper VBR's to 9-5/8" casing rams and test to 250 psi/psi. b. Run 9-5/8", 40 ppf, L-80, Hyd-563 intermediate/production casing. - c. R/D casing equipment. • d. Cement with 1,500 ft of 15.8 ppg Class G cement. e. Pressure test casing to 4 psi for 5 minutes on plug bump. f. Install casing pack-off and test per FMC representative procedures/instructions. g. Confirm that OA is open by pumping small volumes of mud down annulus as soon as possible. h. R/D cementing equipment and flush stack. i. Freeze-protect the 13-3/8" x 9-5/8" annulus, once the cement has reached 500 psi compressive strength. Ensure that the diesel/brine/mud in the OA is overbalanced to formation at 9-5/8" shoe. j. Change 9-5/8" casing rams to VBR's and test to 250 psi/4,000 psi. 6. Drill 8-3/4" 2"d Intermediate Hole Section: a. Pick-up additional 5" drill pipe as required to drill the 8-3/4" 2nd intermediate hole. b. Test 9-5/8" casing to 250 psi for 5 minutes / 4 QQO psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength. c. Make-up 8-3/4" drilling assembly with MWD/LWD tool string. d. RIH &tag float collar or TOC. Displace to 9.0 ppg LSND mud while drilling the shoe track. e. Drill out shoe track&at least 20 ft but no more than 50 ft of new formation for the FIT and CBU. f. Pull inside casing and perform the FIT. g. Drill ahead according to the directional plan and gradually weight up to a minimum of 9.8 ppg before entering the Kavik. A combination of background LCM and LCM sweeps will be used proactively to build formation integrity while drilling the lvishak. h. Continue drilling to the 2nd intermediate casing point which is the Kavik/Lisburne interface. CBU as needed for cutting samples to properly identify Lisburne boundary. i. At casing point, circulate hole clean and condition the mud as needed prior to performing wiper trip to the shoe. j. Run back to bottom, circulate hole clean and condition mud for running the 7" liner. 04-350i Permit Application Page 15 k. POOH and lay down the BHA. 7. Run &Cement 7" Intermediate/Production Liner: a. Change upper VBR's to 7"casing rams and test to 250 psi/4,000 psi. b. Run 7", 26 ppf, L-80, VAM Top HC intermediate/production liner with 150 ft lap into the 9-5/8" casing shoe. c. Cement to the TOL with 15.8 ppg Class G cement. • d. Set the liner hanger& liner top packer. • e. CBU and pressure test liner to 3,500 psi for 5 minutes. f. R/D cementing equipment. g. POOH, UD liner running tool (LRT). N) h. Change 7" casing rams to VBR's and test to 250 psi si. 8. Drill 6-1/8" Production Hole Section: a. Pick-up enough 4"drill pipe to drill the 6-1/8" production hole. b. Test 7" liner to 250 psi for 5 minutes/ 3,500 psi for 30 minutes after cement reaches a minimum of 500 psi compressive strength, provided mud weight is 10.5 ppg or less. c. Negative pressure test 7" liner lap to 250 psi below the 8.5 ppg completion fluid BHP equivalent to test freeze protection integrity. d. Make-up 6-1/8" drilling assembly with MWD/LWD tool string. e. RIH &tag landing collar or TOC. Displace liner to 8.5 ppg Flo-Pro SF fluid while drilling the shoe track. f. Drill at least 20 ft but no more than 50 ft of new formation for the FIT and CBU. ' g. Pull inside casing and perform the FIT. h. Drill ahead, as bit performance allows, according to directional plan and rig site geologist to well ` TD. POOH to replace bit if required. i. At casing point, circulate hole clean and condition the mud as needed prior to performing wiper trip to the casing shoe. j. Run back to bottom, circulate hole clean and condition mud for running casing. k. POOH, L/D excess 4" drill pipe and the BHA. R/U E-line and run Spectral GR, Resistivity Imager, Sonic Scanner, using Sonic Scanner to a 8L- obtain a CBL through the 7" liner and 9-5/8" casing. Run Array induction tool, Micro-Cylindrically focused log, and Spectral Neutron. Perform wiper trips as required. m. R/D E-line. 9. Run &Cement 4-1/2" Production Liner: a. Notify the state 24 hours in advance of casing pressure test for witnessing. b. Run 4-1/2", 12.6 ppf, L-80, IBT-M production liner with 150 ft lap into the 7" liner shoe. c. Cement to the TOL with 15,8 ppq Class G cement.,A Hi-Vis perforation pill will be spotted inside the 4-1/2" liner during the cement job. d. Set the liner hanger& liner top packer. Displace well to clean seawater above the liner top. e. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner to 4,000 psi for 5 minutes. f. R/D cementing equipment. g. POOH, UD liner running tool (LRT). h. Test 9-5/8" casing x 7" liner x 4-1/2" liner to 250 psi for 5 minutes/4,000 psi for 30 minutes after cement reaches a minimum of 1,000 psi compressive strength. ✓ 04-350i Permit Application Page 16 10. Perforate: a. P/U & RIH with DPC perforating assembly. Perforating intervals to be determined from logs. b. Space-out guns and confirm position prior to firing. _ c. Immediately after firing, POOH, lay down guns, and verify shots fired. 11. Run 4-1/2" Completion: (/d- '7" a. Notify the state 24 hours in advance of tubing & IA pressure test for witnessing. �,L✓' b. R/U and run a 4-1/2", 12.6 ppf, L-80, TCII completion with SLB sapphire gauge mandrel above the production packer and iWire to surface. Space out and land the tubing with the tubing tail inserted into the liner tie back sleeve. Run in lock down screws (RILDS). c. R/D tubing running equipment. d. Displace well to seawater completion fluid through the IA, topping off the IA with corrosion inhibited seawater. e. Pump enough diesel freeze protect fluid into the IA to protect to 2,200 ft TVD on both tubing & IA. f. R/U jumper line between tubing & IA to allow diesel to U-tube into tubing. g. Drop ball & rod assembly to RHC plug. h. Test tubing to 250 psi for 5 minutes and then set production packer with 3,500 psi. i. Hold 3,500 psi for 30 minutes for tubing pressure test. j. Bleed tubing pressure down to 1,500 psi. - -f l k. Pressure test IA to 250 psi for 5 minutes/3,500 psi for 30 minutes. I_Q`� I. Bleed tubing & IA pressures to 0 psi and lay down the landing joint. 12. Nipple Down BOPE/Nipple Up Production Tree& Freeze Protect: a. Install TWC and test. Nipple down BOPE. b. N/U the tubing head adapter flange and production tree. c. Test tubing head adapter flange &tree to 250 psi for 5 minutes/5,000 psi for 30 minutes.. d. Pull TWC with a lubricator. - e. Install BPV in tubing hanger&test. • f. Install VR plugs in the annulus valves and secure the well. Ensure that both IA & OA are protected by two barriers. 13. Release Rig: a. Rig down and move off location. Post-Rig Operations: 1. MIRU slick line. Pull BPV. 2. Pull ball & rod /RHC plug from landing nipple below production packer. 3. Step-Rate test to determine injectivity. Follow post well steps based on test results. 4. Install the well house, instrumentation, and injection line. 04-350i Permit Application Page 17 M 0 C H 4nM40 4mn327OQM N 0 Q nNMO MQPmN 2423R N N 2' 916001:6 6e-n6n NQO6n pmmmO mmm mvoa 00.0 ,00.,,—.4. 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'gpi NN COUNDmWO1-�O DNN- M N omO OOOm mNNM - m ON mmmN., Nnm mm tptptpm La-n Omm M Z 0 0 O c m a uz O O C O M N CD m N.))t 7 t D 7 N 00)N.0 oD oimp CCp0 NtC0M) MMMM f/) N NNNNN NNNNN NNNN 0 0 W CC tmpp 22$88 0000Ooc� NMbOp,66Mmmm mmgm mmnm4ppW NMMMOWW °) 0 3 0_ yNp M000 - SOm O'-OW' O0 O ,i666 NOONR6 O ^^^f-mm mm00000 2 W m m v n0000 08=00 0008 �w o O0000 00000 0000 zM -z N^ mC J N W LL °• � W 00UNNpp00000 C 0 M m pp m m f+)t'O,m, ,mmm0 Q V NV 4N J J LL LL tri M I� C N� O 6 N Va ngO N O V O yON ? mOO ‘-,g2.666 p00mmO ml-Nm m0 pmW0 m..mm mapW6 mmm0 :w 0 O 3 N U o Z U -13 o) E 0 No 2'4m Y�up0i m o c v O WUI=-{�- am W IY-i.ti-o 0 by 0 Schlumberger WELL 04-350(P8) FIELD Prudhoe Bay Unit-BOA STRUCTURE DS-04 Magceb Parameter 5,340.Lacatnn 346227 Alasaa State Plane,Zone 04.US Feet Mw.Yneaus Model: 9GGM 2011 Dip: 81.032' Date September 20.2011 tat N 701619.785 Northing'. 5952119 85 305 God Cmv'.1.62352752• Sot'. 04-350 ND Rat: Rotary Ta9e(698 above MSLI Meg Dec'. 21.552• FS: 57670 2n Lon: W 148 16 31 080 Eas919 713219.70 BUS Scale Fact 0.989951655 Pen'. 04-350108) Sny ate.July 26,2011 0 1000 2000 • 0 RTE • 0 KOP Cry 1/100 0 1000 2000 14-350(P8) Cry11100 1000 > 1000 cr.1.5/100 Cry 1/100 6000 _ _.._.._.. i.._.._.._.._.._..y.._.._.._.._.._.._.._.._..!.._.._.._ 6000 End Cry 2000 _.-_.-_.._.._.. :_..Perm._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._ 2000 _.._.._.._.._.._.._.._.._ Cry 1/100 _.._.._..q.._.._.._ 1 .._.._.._..y.._.._.._.._.._._._.._.. 0 0 7000 _.._.._....._.._.._.. a._.._.._..y.._.._.._.._._.._.._.._..,.._.._.._ 7000 C o 11 3000 • 3000 co C _.._.._.._.._..*.._.._ ,_.._.._.._.._..r.._.._.._.._.._.._.._.._..r.._ fco End Cry • ry 1/100 8000 • _.._.._.._.._. _. 7 i.._.._.._.._.._. 8000 m 13-3/87 Csg 9-518"Csg 4000 II''`^' 4000 _'�2 sid'a100 _.._.._.._.._.._.._.._.._.._.._.._.._.._. p-••E;;e aid 7"CS'g 9000 T.._.._..TVRf:.!:•.T.::".:•.!:.�:•.!.VTAtTlJT.._..!:l.!:::� .'�.l::.TJ.!.L!.L! 9000 50004 5000 TO 4-1/2"Csg 04-350(°8) 0 1000 2000 or.1.5/E00 Vertical Section(ft)Azim=105°,Scale=1(in):1000(ft) Origin=0 N/-S,0 E/-V • 6000 ""_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._. ,di.._._.._ 6000 t4-450(P8) 0 1000 2000 Vertical Section(ft)Azim=30°,Scale=1(in):1000(ft) Origin=0 NI-S,0 El-V by 0 Schlumberger WELL FIELD STRUCTURE 04-350 (P8) Prudhoe Bay Unit-BOA DS-04 Ma9rv8[Panmelan Slalace Location NA027 Alaska Stale Plane,Zore 04.US Feet Maceltane0ua Mod.) BOOM2011 Dip: 81 0321 Cele: September 20,2011 Lat. N 701819.785 Northing 5952119.886US G.00,011 1173527521 Sot 00.350 NO Red: Rotary Table)698 above MSL) May Doc: 21.552' FS 57674.201 Lon: W 14818 31.080 Easerp: 713219.708115 Scale Fac[0.99995165 Man, 04-350(P8) Srry Dale:July 26,2011 0 500 1000 1500 2000 2500 2500 2500 N sa I�,,e 2000 2000 End Cry 9-5/8"Cesg Bid 4/100 End Bid see-:;;;;Ear°""0111N TO ' 4-1/2"Csg 1500 CR/44/100••••;••• 04-350?9t1 1500 04-350(P8) A L095%Confidenc_.__...._...._____1 e A c 1000 1000 d1 co End Cry V /! V 500 44-311"-Cog- 500 Cry 1/100 Cry 1/100 End Cry 0 •••• 0 Cry 1/100 RTE Cry 1/100 KOP Cry 1/100 -500 -500 0 500 1000 1500 2000 2500 «< W Scale=1(in):500(ft) E >>> 7,4 a Project: Prudhoe Bay Well: Site: Plan B DS 03 50 0q 24/04.24 °�g5ae44, v Wellbore: Plan 04-350 ,058 ' a Design: Plan #8 04-350 0 i. 93Sb43S DP. a <�qC' S �. fS 4500— 55 1O 4200-' / CI; 3900— a v 50 0'0-7 j 3? 7,, '4? c 85 3600— ! f SS / 80 it'0/ �a= r _/ B3. o 3300— / 6S 8 . ! �� 1 45 75 // Sa 9a 3000— / /70 /'1.S 2700— 11910119A ! yr yS r,0 80 / t1 0 75 / //'1.0 1 .2400— 04.20i0Q.20 '1® /65 jJ 9 10 !.-�.. h Q ,Y Z 65. 60 o v o T.,„_' ^2100 oA.zlio4 21 �'_, s cn a_, 0 v zro co 1800 1 5.5 2 °9 5/8" wq�,��`qmi, 35 `, 's : C Lam' N' 6 ' / ° 441/2" 1500 O 0A.1a% �' I i/` cr • I , 0 . 44 v 1200 25 O L..,,,\ :j /77 ' 50 I Sa o azo 900 ? o n V °.0 4S srt 600 _ h r,, 9 -r 300 • 0p S.• O T C CP b V W 7 O \. , 0 0o- $ 3i 300 .:0, -s: ' _,-a Y v y> .,p v�0` OpA� .;v �.p�� `� Z o -600 % ..'''-'4;88,1" 29/04- AL/ 1 1 i I I I ' I I I t I f I l r i I I I i I I t .' k�- I I 1 �' I I ' I I = I -600 -300 0 '34300 9j0 0O`4i� i�00 1200 1500 1800 2100 2400 2700 3000 3300 3600 'o'Q� �Q 1 7PaPest(-)/East(+)(600 ft/in) 4"a c. , Project: Prudhoe Bay —11 040 y� 9A a `� Site: PB DS 04 •�f::� i�a> '04. 7/04.1j p.o- " 04, Well: Plan 04-350 s oy Wellbore: Plan 04-350 3� A�� 0 3s o Design: Plan #8 04-350 �s D 35 -9 v _ _ m - \ S \..' 4n 1100— 0 1 �, 0Q1000— 2�, '-: j - 15 ash / 1� 900— h 45 J. '0 4p 800— 25 / (Jr: /// 700— i 35 �S n g. •)„.' )� ,94L4,1. 10 v < v 5X5 ^ o 13 318" /'�Vn5 _ / 6 ^ . s J 500— �o- Q o is, o �0 o N y Os r \ ' '6 o + 400— o •- cn 0 Q. O O - Z $o' L 300 3p O .. ,At) ;-.)2. � 3i S _ 30 I i (A - - ._s 200— ,.,./- — =- 0 for 1 ?S v, 7, �~ o „di . 0 100- 20 r .2r 35 / �/' O^ J h :/ -100— ` 3 ^, 0< -- -200— N., , r �p :_ _ N, -400— \ cn O 0 j - \ s _ o\ 1,,,, 50, ti' /S o 30N A9`ory AAO 20 o9So Vgiall1111111111ft..--% -�• •i-;.=-•. 'Or' •. 600 -500 -400 -300 -200 -100 0 ‘04, zoo 300 -744 74 500 600 49• 00 800 West(-)/East(- 0 ft/in) 'pe, e, Mrs Pim riOI.33O(PIrO-33OP O1433O) �oo I � 2( 00 3°°C o o� 500 o 60c 1000 I r go 00 q000 000 0 o Doeo 000 i000 - Plan 414114.391 7-- 1 li ,,- /11-1 m —N- co �i n Q ,-' DRILL SITE 4 idry- .-,. i o I I 0 . ////7 0_ �!' o � Y � :O il ■35 Air '34 / ., . i ,� OIC■21 ', ■ , ® . .4/� • ■22 res. ■23 — JJ / 1�'�PROJECT ■24 ge 4/ / A 44 •▪17 ■ ��'' _ „• , ®� 7/ / ■16 — I�1� 4 �1 / / 10• 47.33 w• �o ' LSO� ,..===..._ 38• / 46:36 s• VICINITY MAP NTS 8• S=7 41 • ( 49139 ��```O F,q44,v11 lll/i sa — _ 48+12 04-350 P(E, " ..(.9S 1�I • _.,3 woe 49 i\ • 40o • / 43i:27� _ SC. P6 ••• I ■14 SE 5 - _/11 � 772:2 Cr �4i•1540 40 JI .29 i e• Leonard J. (Manley 42i• •30 N.62;411386 •. \ 6 :45i i ■32 q��,'_' %` / ■37 ��I��fl""�ESSIOW-`` 4■ / SURVEYOR'S CERTIFICATE 0I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE 3 . LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR 2 • UNDER MY DIRECT SUPERVISION AND THAT 40■ L ALL DIMENSIONS AND OTHER DETAILS ARE 1 ■ CORRECT AS OF JULY 15, 2011. /( IV LEGEND • EXISTING WELL CONDUCTOR / + AS-BUILT WELL CONDUCTOR NOTES: 1. DATE OF SURVEY: JULY 15, 2011. GRAPHIC SCALE 2. FIELD BOOK: NS11-49 PGS. 42-45. 3. COORDINATES ARE ALASKA STATE PLANE ZONE 4, NAG 27. 0 250 500 1000 4. GEODETIC POSITIONS ARE NAD 27. 1 5. PAD AVERAGE SCALE FACTOR:0.9999512 ( IN FEET ) 6. HORIZONTAL CONTROL BASED ON BPXA OPERATOR MONUMENTS 1 inch = 500 ft. 4A AND 48. 7. VERTICAL CONTROL BASED ON BPXA OPERATOR MONUMENTS M.L.L.W. (MEAN LOWER LOW WATER). LOCATED WITHIN PROTRACTED SEC. 26, T. 11 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 04-350 Y= 5,952,119.88 N (—)1,581.09 7016'19.785" 70.2721625' 29.48' 237' FSL X= 713,219.70 E 1658.89 148'16 31.080" 148.2753000' 4883' FEL DRAWN: F. Robert „ BARNHART �ht4� (k= i CHECKED: �•�11��%� {� HACKEWAN J =.it bN 1/74 � DATE: ��Vi' 11!, 7/17/11 ��1\ DRAWING. _b IL: FR8I1 DS4 es DRILL SITE 4 ISHEET Q aSSOC. roe No. AS—BUILT CONDUCTOR of 1 KM 7/17/11 ISSUED FOR INFORMATION TFB K ■c�.ms SCALE: 1 en MST MEMO LAW1• = 500' WELL 04-350 NO. DATE REVISION BY CHK manna[. .uw pow Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907)273-1766 Fax(907) 561-8367 Wednesday August 18, 2011 Frank Pugh Lisburne 04-350 (P8) BP Exploration (Alaska) Inc. Doyon 25 Close Approach Analysis We have examined the potential intersections of the subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Tool Code Instrument Type Start Depth End Depth GYD-GC-SS Gyrodata NSG SS Gyro 0' and 1100' and MWD PowerPulse 1100' and 2600' and MWD+IFR+MS PowerPulse 1100' and 3902' and MWD PowerPulse 3902' and 5400' and MWD+IFR+MS PowerPulse 3902' and 9251' and MWD PowerPulse 9251' and 9788' and MWD+IFR+MS PowerPulse 9251' and 9758' and MWD PowerPulse 9788' and 10313' and MWD+IFR+MS PowerPulse 9788' and 10313' and Survey Interval Surface hole: 1 per stand - 93 ft Intermediate hole 1: 1 per stand - 93 ft Intermediate hole 2: 1 per stand -93 ft Production Hole: 1 per stand - 93 ft Close Approach Analysis results: Under method (2), note: All wells pass major risk. There is the potential for magnetic interference coming out of the conductor. A single shot gyro is planned to be run for up to 1100'md. All data documenting these procedures is available for inspection at the Drilling & Measurements Drilling Engineering Center(DEC). Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Nate Beck 08/18/2011 0 —o o0 —o m 0 _o n 0 _O O O —0 O L >, lh 0 m _o m OchQ a) MO Tr LUJOOU _ "O0 C C C O Q.Q.Q_Q.Q. —M U a>= a) C iv p b o c c NS O g g $ N - oL_ O a - CD O> o J —o N ° m a> 0 —o 0 0 —o n m g e to 0 —o O N r O O .: k0 { 0 Lo 0 v m f m 0 U <`9 d 2 O C —O -CT, y N 7 ,O} N Q 0 CD 0 O w cli :r N —O` RQ •t 7 4 I ' " I I r " I " I I I I l I I I I I I I un o 4) o ,n o ,r, - o o Lc; o o o kl> o Lc) Q 7 n !- o 0 Lo t :h h N N .- e- (w,pi.)uolleJedag aJ1Ua3 01 a11ua3 BPPASSPORT Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan 04-350 Project: Prudhoe Bay TVD Reference: 04-350 plan new @ 69.00ft(Doyon 25 estimate) Reference Site: PB DS 04 MD Reference: 04-350 plan new @ 69.00ft(Doyon 25 estimate) Site Error: 0.00ft North Reference: True Reference Well: Plan 04-350 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 04-350 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#8 04-350 Offset TVD Reference: Offset Datum Reference Plan#8 04-350 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refers Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,227.36ft Error Surface: Elliptical Conic Survey Tool Program Date 7/26/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 39.52 1,100.00 Plan#8 04-350(Plan 04-350) GYD-GC-SS Gyrodata gyro single shots 1,100.00 2,600.00 Plan#8 04-350(Plan 04-350) MWD MWD-Standard 1,100.00 3,901.68 Plan#8 04-350(Plan 04-350) MWD+IFR+MS MWD+IFR+ Multi Station 3.901.68 5,400.00 Plan#8 04-350(Plan 04-350) MWD MWD-Standard 3,901.68 9,251.47 Plan#8 04-350(Plan 04-350) MWD+IFR+MS MWD+ IFR+ Multi Station 9,251.47 9,788.37 Plan#8 04-350(Plan 04-350) MWD MWD-Standard 9,251.47 9,788.37 Plan#8 04-350(Plan 04-350) MWD+IFR+MS MWD+IFR+Multi Station 9,788.37 10,313.14 Plan#8 04-350(Plan 04-350) MWD MWD-Standard 9,788.37 10.313.14 Plan#8 04-350(Plan 04-350) MWD+IFR+MS MWD+IFR+Multi Station Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB DS 04 =-. 04-11-04-11-04-11 686.77 675.00 33.06 18.38 14.69 Pass-Major Risk 04-11A-04-11A-04-11A 686.77 675.00 33.06 18.38 14.69 Pass-Major Risk 04-12-04-12-04-12 399.41 395.00 89.03 9.89 79.14 Pass-Major Risk 04-13-04-13-04-13 631.31 630.00 212.10 11.47 200.63 Pass-Major Risk 04-17-04-17-04-17 4,515.51 4,390.00 251.10 108.66 149.98 Pass-Major Risk 04-19-04-19-04-19 3,826.07 3,735.00 298.53 48.11 250.50 Pass-Major Risk 04-19-04-19A-04-19A 3,829.80 3,730.00 298.55 48.13 250.51 Pass-Major Risk 04-19-04-19A-04-19a wp08 3,894.73 3,800.00 300.34 47.21 253.14 Pass-Major Risk 04-23-04-23-04-23 3,653.88 3,450.00 553.62 56.24 499.28 Pass-Major Risk 04-23A-04-23A-04-23A 3,653.88 3,450.00 553.62 56.24 499.28 Pass-Major Risk 04-24-04-24-04-24 3,320.10 3,175.00 445.15 52.86 394.30 Pass-Major Risk 04-25-04-25-04-25 513.56 510.00` 32.06 10.57 21.49 Pass-Major Risk 04-25-04-25PB1-04-25PB1 513.56 510.00- 32.06 10.57 21.49 Pass-Major Risk 04-26-04-26-04-26 437.95 435.00-. 152.63 8.16 144.48 Pass-Major Risk 04-27-04-27-04-27 540.82 540.00- 271.50 10.42 261.07 Pass-Major Risk 04-39-04-39-04-39 189.77 790.00- 85.37 16.92 68.44 Pass-Major Risk 04-46-04-46-04-46 2,915.08 2,885.00 82.99 42.62 40.38 Pass-Major Risk 04-47-04-47-04-47 2,560.29 2,545.00 198.97 52.23 147.18 Pass-Major Risk 04-48-04-48-04-48 403.25 400.00 60.98 7.06 53.94 Pass-Major Risk 04-49-04-49-04-49 909.08 905.00 69.71 14.04 55.83 Pass-Major Risk 7/26/2011 4:31:21PM Page 2 of 3 COMPASS 2003.16 Build 73 Project: Prudhoe Bay Site: PB DS 04 Well: Plan 04-350 Wellbore: Plan 04-350 From Colour To MD Design Plan #8 04-350 40 500 500 1000 1000 1500 From Surface to TD 1500 2000 Scan interval 50 ft Scale 1 : 100 2000 3000 All wells pass major risk ,, 0 3000 5000 o° 175 5000 — 8000 =.I ; 8000 11000 330 .r' a 30 Alt ir '_ 12 y/vv i a 1 6 300 2749-- � ,0 60 ,! ? 701 800 o- " 89"e 9g ,,:t\ F } '�- ' 8 3 Q\y vo\1197 4110120 12 5 1308140 '',j "/' ' I , 2840 - A \ Q .b 1810 o-°j� �a4 1 11 0o- 1813 0, �'`^ ^� \ \ 191 ,',3 ,; 2214 / c 41E12811 1 �^" 1112 \ '\ \/ 7 2 121 1 12 cj '29'8 1 ' 270 QQi I op13 . = 90 h ` 4 y 1613 co ti ' OpA licl"o-"°4.C380 'b\ 1714 o°p14 o17Ppx JO 00 118 ^Y 541 Pmi1199 I, e',e ,:';'r 602 1298z. st;, �.. ^ 79� ,� ry• c. -Y.;s028, 900 ' 215„597 \\o°t 240 3'� ��1097 / 1088��/ 120 3098 10s i9}�6QQ��'�� ,r�, / w cp93 / 12 ti° do /9? 759 i �o �,o, 4?395 403`� 1 .� � v ti 210 13c43891"of 3150 175 _.....- 180 180 Travelling Cylinder Azimuth (TFO+AZI)[°]vs Centre to Centre Separation [50 ftfin] 0 0 0 j o CO O to M O M o i O o CV ' • o O O ti ti "Cr LI . LL V O ro co 0 CN 1 EH 0 0 - CI. U N,- 0 • 0 LLI 0 L O CD O Q • a CL 0 W o 0 0 0 0 0 0 0 00 Co O 0 0 0 0 0 0 Alaska Department of Natural Resources Land Administration System Page 1 of 1 ' 'Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Hata 'I "j` <' A' `'` tine Alaska DNR Case Summary File Type: ADL File Number: 28324 '4a+'Printable Case File Summary See Township,Range,Section and Acreage? Yes No I New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28324 maP Search for Status Plat Updates As of 08/29/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type: 784_ OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 015E Section: 25 Section Acres:640 Search Plats Meridian: U Township: OlIN Range: 015E Section: 26 Section Acres:640 Meridian: U Township: O11N Range: 015E Section: 35 Section Acres:640 Meridian: U Township: 01IN Range: 015E Section: 36 Section Acres:640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-154 TIIN-RISE-UM 25,26,35,36 2560.00 U-3- 7 End of Case Summary Last updated on 08/29/2011. Not sure who to contact?Have a question about DNR?Visit the Report technical problems with this page to the Site optimized for Netscape 7, IE 6 or above. This site also requires that all must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System Status http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=283 2... 8/29/2011 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME .a'i/ / ,—c_374.1-0 PTD# cam?fIVO,6 Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: 7, �l6/4 ,X4)/ POOL: //�5AV.44/ '2 O/Z Circle Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 -o 0 $ co 0 -a 3 o m C) - 0 -0 3' CO 7 4t r 30 CD 0 "r 3.0 oO co - Lou 0) 0 N co ca N _. 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