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206-141
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-16A NORTHSTAR UNIT NS-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/23/2025 NS-16A 50-029-23096-01-00 206-141-0 N SPT 10339 2061410 2500 911 2723 2668 2647 118 123 123 123 OTHER P Brian Bixby 3/17/2025 CMIT TxIA as per Sundry # 323-052 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-16A Inspection Date: Tubing OA Packer Depth 855 2659 2602 2575IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250318102030 BBL Pumped:5.2 BBL Returned:5 Wednesday, April 23, 2025 Page 1 of 1 9 9 9 9 9 9 999 999 9 9 9 9 9 2LOSURGXFHU James B. Regg Digitally signed by James B. Regg Date: 2025.04.23 12:40:51 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-16A NORTHSTAR UNIT NS-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/23/2025 NS-16A 50-029-23096-01-00 206-141-0 N SPT 10339 2061410 2500 230 2738 2637 2625 118 118 118 118 OTHER P Brian Bixby 3/17/2025 MIT-T as per Sundry # 323-052 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-16A Inspection Date: Tubing OA Packer Depth 789 874 880 878IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250318101751 BBL Pumped:2.8 BBL Returned:2.8 Wednesday, April 23, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 999 99 9 9 9 2LO3URGXFHU MIT-T James B. Regg Digitally signed by James B. Regg Date: 2025.04.23 12:38:10 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install K-valve SSSV Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,505 feet 13,370 feet true vertical 11,306 feet NA feet 12,178, 13,444, Effective Depth measured 14,408 feet 13,479 & 13,685 feet true vertical 11,212 feet 9,210, 10,339, 10,370 & 10,555 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 13Cr-80 13,522' 10,409' 9-5/8" x 7" ZXP LTP 7" x 4-1/2" Bkr Prem. ZXP Packers and SSSV (type, measured and true vertical depth)7" x 5" Bkr ZXP See Above 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:NORTHSTAR OIL, KUPARUK OIL 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 324-154 014472 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG NA Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 134 Gas-Mcf 0 18 9-5/8" 3,206' 12,574' measured true vertical Packer MD 156' Liner 1,672' 413' Casing 12,531' Surface Production Liner 20 1106 25993 7" 4-1/2" 10,702' 10,920' 13,850' 14,093' 4-1/2" TRM-4E SSSV 1,024MD / 1,024TVD Water-BblOil-Bbl 168 770 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-141 50-029-23096-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL NORTHSTAR UNIT NS-16A Plugs Junk measured measured Conductor 20"156' Size 156' Length 9,565' 7,020psi 7,500psi 5,020psi 6,870psi 8,160psi 8,430psi 4,760psi 2,993'13-3/8" Burst NA Collapse NA 2,260psi TVD 3,250' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:29 am, Apr 18, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.04.18 06:46:39 - 08'00' Sara Hannegan (2519) DSR-4/23/24 RBDMS JSB 041924 WCB 12-4-2024 Well Name Rig API Number Well Permit Number Start Date End Date NS-16A Slickline 50-029-23096-01-00 206-141 3/22/2024 Future 3/22/2024 - Friday SET 4-1/2 " X-LOCK W/ X-EQ-DEV & K-VLV SSSV IN TRM-4E SSSV @ 1,024' MD, (sn: K39A, oal = 42.5" 1 set std pkg, 2nd lkdwn installed, 8 x 1/8" eq ports). RAN 4-1/2" CHECK SET TO 4-1/2" K-VLV @ 1,024' MD (sheared). PERFORM PASSING CLOSURE TEST W/ OPS DOWN FLOWLINE. PRESSURE UP & EQ K-SSSV W/ GAS FROM NS-18 TURN WELL OVER TO OPS FOR FLOW TEST TO TEST SEPERATOR. WELL LEFT FLOWING ON DEPARTURE, TREE TAGGED. ~ K-VLV PARAMETERS ~ - TEST RACK SET PSI - 653 PSI @ 60 DEG - VLV SET TO CLOSE @ 866 PSI PWH - FLOWING TBG PSI @ 1024' MD = 964 PSI Hilcorp Alaska, LLC Weekly Operations Summary RAN 4-1/2" CHECK SET TO 4-1/2" K-VLV @ 1,024' MD (sheared). SET 4-1/2 " X-LOCK W/ X-EQ-DEV & K-VLV SSSV IN TRM-4E SSSV @ 1,024' MD, _____________________________________________________________________________________ Revised By: DH 4/17/2024 SCHEMATIC Northstar Unit Well: NS-16A Last Completed: 3/25/2008 PTD: 206-141 TD = 14,505’(MD) / TD =11,306’(TVD) 20” KBE = 55.92’/ GL = 16.1’ 7” Tubing Punch @ 13,343’ 3/7/23 1a 4 5 6 17 13 11, 12 7 Top of cement in IA ~ 7,827’ 9-5/8” 1 2 9 15, 16 8 Min ID= 2.387” @ 13,52 2’ 2-7/8” Composite Bridge Plug @ 13,370’ 3/7/23 13-3/8” Whipstock @ 3,250’ on 2/10/2008 13-3/8” TAM Port Collar @ 1,587’ PBTD =14,414’(MD) / PBTD =11,218’(TVD) 3 13-3/8” 10 14 4-1/2” 5 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169# / X-56 / N/A N/A Surface 201' N/A 13-3/8" Surface 68# / L-80 / BTC 12.415” Surface 3,274’ 0.1497 9-5/8" Intermediate 47# / L-80 / BTC-M 8.681” Surface 12,574’ 0.0732 7" Liner 29# / L-80 / Hydril 521 6.184” 12,178’ 13,850’ 0.0371 4-1/2” Liner 12.6#/L-80 / Hydril 521 3.958” 13,685’ 14,093’ 0.0152 2-7/8” Liner 6.4#/ L-80 / STL 2.441” 13,522’ 14,504’ 0.0058 4-1/2” Liner 12.6#/13Cr80/Vam Top 3.958” 13,516 13,522’ 0.0152 5” Liner 15#/13Cr/Vam Ace 4.408” 13,479’ 13,516’ 0.0189 TUBING DETAIL 4-1/2” Tubing 12.6#/13Cr80/Vam Top 3.958” Surface 13,497’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,024’ 4-1/2” TRM-4E SSSV, ID= 3.812” 1a 1,024’ K-valve surface closure pressure 866psig 2 4,569’ GLM ST 1: Camco, RK, Port= NA, Dev=50, Vlv=Dmy, TVD= 3,976’, Date= 3/27/2008 3 12,178’ 9-5/8” x 7” ZXP Liner Top Packer w/11’ PBR, ID = 6.200” 4 12,199’ 9-5/8” x 7” Baker Flex Lock Liner Hanger, ID = 6.200“ 5 13,398’ 4-1/2” Fiber Optic Transducer, ID = 3.958” 6 13,423’ 4-1/2” HES “X” Nipple, ID = 3.813” 7 13,444’ 7” x 4-1/2” Baker Premier Packer, ID = 3.875” 8 13,471’ 4-1/2” HES ‘X’ Nip, ID= 3.813” 9 13,479’ 7” x 5” HRD ZXP Liner Top Packer w/17’ PBR, ID= 4.450” 10 13,483’ 4-1/2” HES ‘XN’ Nipple, ID= 3.725” 11 13,494’ 4-1/2” Self Aligning Mule Shoe, ID = 3.850” 12 13,507’ 7” x 5” Baker Flex Lock Hanger, ID = 4.400” 13 13,516’ 5” x 4-1/2” Cross-over, ID= 3.940” 14 13,522’ 4-1/2” x 2-7/8” Cross-over, ID= 2.387” 15 13,685’ 7” x 5” “HR” ZXP Liner Top Packer w/12’ PBR, ID = 4.350” 16 13,709’ 7” x 5” Baker Flex Lock Liner Hanger, ID = 4.370” 17 13,718’ 5” x 4-1/2” Cross-over, ID= 3.930” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kuparuk 11,989’ 12,001’ 9,041’ 9,052’ 12’ 9/12/2023 Open 3.125” Kuparuk 12,031’ 12,081’ 9,079’ 9,123’ 50’ 5/4/2023 Open 2.75” Ivishak 14,274’ 14,304’ 11,085’ 11,113’ 30 6/12/08 Closed 2” Ivishak 14,274’ 14,339’ 11,085’ 11,146’ 65 7/27/08 Closed 2” Ivishak 14,276’ 14,296’ 11,087’ 11,106’ 20 7/4/08 Closed 2” Ivishak 14,289’ 14,339’ 11,099’ 11,146’ 50 5/2/08 Closed 2” Ivishak 14,295’ 14,340’ 11,105’ 11,147’ 45 5/7/13 Closed 2” Ivishak 14,304’ 14,339’ 11,113’ 11,146’ 35 4/5/08 Closed 2” Ivishak 14,280’ 14,320’ 11,091’ 11,128’ 40 7/11/16 Closed 2” Ivishak 14,320’ 14,340’ 11,128’ 11,147’ 20 7/10/16 Closed 2” Reference log: SWS-PDC on 4/3/2008. CASING / OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 618 sx Permafrost ‘L’, 470 sx Class ‘G’ in 16” hole 9-5/8" 872 sx Extended Slurry, 637 sx Class ‘G’ in 12-1/4” hole 7” 107 sx Class “G” in 8-1/2” hole 4-1/2” 119 sx Class “G” in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 53 deg. @ 7,169’ Max Angle at Top Perf: 20 Deg. @ 14,274’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23096-01-00 Initially Drilled - Nabors 33E – 7/15/2002 Initial Completion – Nabors 33E – 6/14/2003 Sidetracked (NS16A) – Nabors 33E – 3/25/2008 SAFETY NOTE Well requires a SSSV. Chrome Tubing & Liner. Note: BSEE well 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install K-valve SSSV 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,505'N/A Casing Collapse Structural Conductor N/A Surface 2,260psi Intermediate 4,760psi Liner 7,020psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): See Schematic 12,178MD/9,210TVD,13,479MD/10,370TVD, 13,444MD/10,339TVD,13,685MD/10,555TVD, 1,024MD/1,019TVD 14,408' 13,850' 12,574' 1,672' 4-1/2" See Schematic 12,531' 3,206' 907-748-8581 brenden.swensen@hilcorp.com Operations Manager March 15, 2024 14,093'413' 4-1/2" 10,920' 156' 3,250' 10,702'7" 20" 13-3/8" 156' 9-5/8" 6,870psi N/A 5,020psi 156' 2,993' 9,565' NORTHSTAR OIL, KUPARUK OIL Same 12.6# / 13Cr-80 TVD Burst 13,522 8,160psi MD 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23096-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 11,306' 14,408' 11,212' 2,050 Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 206-141 C.O. 739 NORTHSTAR UNIT NS-16A Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: NORTHSTAR 9-5/8"x7" ZXP, 7"x5" ZXP, 7"x4" Prem. Pkr, 7"x5" ZXP, 4-1/2" TRM-4E SSSV Brenden Swensen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 2:22 pm, Mar 08, 2024 324-154 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.03.08 12:58:29 - 09'00' Sara Hannegan (2519) * 48 hour notice to AOGCC to witness SSSV performance test within 5 days of production startup. 10-404 MGR11MAR24 DSR-3/11/24 2,050 A.Dewhurst 12MAR24 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.13 11:01:49 -08'00'03/13/24 RBDMS JSB 031324 Page 1 of 4 Install K-Valve SSSV Well: NS-16A PTD: 206-141 Well Name: NS-16A API Number: 50-029-23096-01-00 Current Status: Kuparuk Producer PTD # 206-141 Estimated Start Date: 3/15/2024 Rig: Slickline Reg.Approval Req’std? Yes Estimated Duration: 1 day Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure: 2461 psi @ 9,000’ TVD (SBHPS 2/25/2024) Maximum Expected BHP: 2950 psi @ 9,000’ TVD (est.) 6.31ppg EMW (NS23 SBHPS 4/23/2023) Max. Anticipated Surface Pressure: 2050 psi Gas Column Gradient (0.1 psi/ft) History NS16A was drilled and completed as an Ivishak producer in 2002. It was sidetracked in 2008 also as an Ivishak producer. In March of 2023, the well was recompleted to the Kuparuk formation by pumping a cement plug in the IA and tubing, and then perforating through the existing tubing and casing. The original Kuparuk perforations only targeted the C1 sand. The sand came in at a low GOR and produced ~150 BOPD with little water and ~4mmscf/d. The C1 sands stopped sustained flow in August of 2023 and the C2 was shot in September of 2023 bringing in a significant amount of gas that is capable of sustaining flow to surface. The well failed its February 2024 SVS test – the down hole TRSSSV failed to close. Slickline spent ~6 days attempting to function the TRSSSV without success. Due to the inability to move the sleeve, we will not pursue locking out the TRSSSV to set a surface controlled WRSSSV. After reviewing options, a mechanical operated / pressure operated SSSV will be required to put the well back on production. Objective Install mechanical operated / pressure operated SSSV also known as a K-valve or PB-valve. The valve will be set up with a closing pressure of 866psig at surface based on 109degF flowing well head temperature. The main production header at Northstar operates at 760psig, so this pressure is ~100psi above header pressure. To test the valve, the well choke will be opened to drop the wellhead pressure to main production pressure. To reset the valve, the well will be pressured up to above the trip pressure then gradually reopened to the normal operating range. Procedure Slickline 1. MIRU. Pressure test PCE low 250psi high 2500psi. 2. Set K-valve in TRSSSV. 3. Turn well over to production. 4. Conduct a SVS test within 5 days after stabilized flow. Page 2 of 4 Install K-Valve SSSV Well: NS-16A PTD: 206-141 Calculations "K" Valve Calculation Sheet NS16A Date: 03/07/24 Test Data Test Date 02/05/24 Gross Fluid Rate 188 BLPD Flowing Well Head Pressure 766 psi Flowing Well Head Temperature 109 deg F GOR 152,490 scf/bbl TGLR 136,808 scf/bbl Flowing Pressure Calculations Based on Ansari Multiphase Flow Correlation "K" Valve Setting Depth TVD 1,024 ft Flowing Tubing Pressure (Pwh) 866 psi Flowing Tubing Pressure @ 1024' md 964 psi Valve set to close at 866# Pwh Closing Tubing Pressure @ 1024' md 964 psi "K" Valve Test Rack Set Pressure at 60 deg F 653 psi Valve Size & Volume Ratio 4-1/2" 1.314 NOTE: Well needs to flow at > 866 psi Pwh Valve set to close @ < 866 psi Pwh _____________________________________________________________________________________ Revised By: DH 9/14/2023 Page 3 of 4 CURRENT SCHEMATIC Northstar Unit Well: NS-16A Last Completed: 3/25/2008 PTD: 206-141 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 169# / X-56 / N/A N/A Surface 201'N/A 13-3/8"Surface 68# / L-80 / BTC 12.415”Surface 3,274’0.1497 9-5/8"Intermediate 47# / L-80 / BTC-M 8.681”Surface 12,574’0.0732 7"Liner 29# / L-80 / Hydril 521 6.184”12,178’13,850’0.0371 4-1/2”Liner 12.6#/L-80 / Hydril 521 3.958”13,685’14,093’0.0152 2-7/8”Liner 6.4#/ L-80 / STL 2.441”13,522’14,504’0.0058 4-1/2”Liner 12.6#/13Cr80/Vam Top 3.958”13,516 13,522’0.0152 5”Liner 15#/13Cr/Vam Ace 4.408”13,479’13,516’0.0189 TUBING DETAIL 4-1/2”Tubing 12.6#/13Cr80/Vam Top 3.958”Surface 13,497’0.0152 JEWELRY DETAIL No Depth Item 1 1,024’4-1/2” TRM-4E SSSV, ID= 3.812” 2 4,569’GLM ST 1: Camco, RK, Port= NA, Dev=50, Vlv=Dmy, TVD= 3,976’, Date= 3/27/2008 3 12,178’9-5/8” x 7” ZXP Liner Top Packer w/11’ PBR, ID = 6.200” 4 12,199’9-5/8” x 7” Baker Flex Lock Liner Hanger, ID = 6.200“ 5 13,398’4-1/2” Fiber Optic Transducer, ID = 3.958” 6 13,423’4-1/2” HES “X” Nipple, ID = 3.813” 7 13,444’7” x 4-1/2” Baker Premier Packer, ID = 3.875” 8 13,471’4-1/2” HES ‘X’ Nip, ID= 3.813” 9 13,479’7” x 5” HRD ZXP Liner Top Packer w/17’ PBR, ID= 4.450” 10 13,483’4-1/2” HES ‘XN’ Nipple, ID= 3.725” 11 13,494’4-1/2” Self Aligning Mule Shoe, ID = 3.850” 12 13,507’7” x 5” Baker Flex Lock Hanger, ID = 4.400” 13 13,516’5” x 4-1/2” Cross-over, ID= 3.940” 14 13,522’4-1/2” x 2-7/8” Cross-over, ID= 2.387” 15 13,685’7” x 5” “HR” ZXP Liner Top Packer w/12’ PBR, ID = 4.350” 16 13,709’7” x 5” Baker Flex Lock Liner Hanger, ID = 4.370” 17 13,718’5” x 4-1/2” Cross-over, ID= 3.930” PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Size Kuparuk 11,989’12,001’9,041’9,052’12’9/12/2023 Open 3.125” Kuparuk 12,031’12,081’9,079’9,123’50’5/4/2023 Open 2.75” Ivishak 14,274’14,304’11,085’11,113’30 6/12/08 Closed 2” Ivishak 14,274’14,339’11,085’11,146’65 7/27/08 Closed 2” Ivishak 14,276’14,296’11,087’11,106’20 7/4/08 Closed 2” Ivishak 14,289’14,339’11,099’11,146’50 5/2/08 Closed 2” Ivishak 14,295’14,340’11,105’11,147’45 5/7/13 Closed 2” Ivishak 14,304’14,339’11,113’11,146’35 4/5/08 Closed 2” Ivishak 14,280’14,320’11,091’11,128’40 7/11/16 Closed 2” Ivishak 14,320’14,340’11,128’11,147’20 7/10/16 Closed 2” Reference log: SWS-PDC on 4/3/2008. CASING / OPEN HOLE / CEMENT DETAIL 20"Driven 13-3/8"618 sx Permafrost ‘L’, 470 sx Class ‘G’ in 16” hole 9-5/8"872 sx Extended Slurry, 637 sx Class ‘G’ in 12-1/4” hole 7”107 sx Class “G” in 8-1/2” hole 4-1/2”119 sx Class “G” in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 53 deg. @ 7,169’ Max Angle at Top Perf: 20 Deg. @ 14,274’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23096-01-00 Initially Drilled - Nabors 33E – 7/15/2002 Initial Completion – Nabors 33E – 6/14/2003 Sidetracked (NS16A) – Nabors 33E – 3/25/2008 SAFETY NOTE Well requires a SSSV. Chrome Tubing & Liner. Note: BSEE well _____________________________________________________________________________________ Page 4 of 4 PROPOSED SCHEMATIC Northstar Unit Well: NS-16A Last Completed: 3/25/2008 PTD: 206-141 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 169# / X-56 / N/A N/A Surface 201'N/A 13-3/8"Surface 68# / L-80 / BTC 12.415”Surface 3,274’0.1497 9-5/8"Intermediate 47# / L-80 / BTC-M 8.681”Surface 12,574’0.0732 7"Liner 29# / L-80 / Hydril 521 6.184”12,178’13,850’0.0371 4-1/2”Liner 12.6#/L-80 / Hydril 521 3.958”13,685’14,093’0.0152 2-7/8”Liner 6.4#/ L-80 / STL 2.441”13,522’14,504’0.0058 4-1/2”Liner 12.6#/13Cr80/Vam Top 3.958”13,516 13,522’0.0152 5”Liner 15#/13Cr/Vam Ace 4.408”13,479’13,516’0.0189 TUBING DETAIL 4-1/2”Tubing 12.6#/13Cr80/Vam Top 3.958”Surface 13,497’0.0152 JEWELRY DETAIL No Depth Item 1 1,024’4-1/2” TRM-4E SSSV, ID= 3.812” 1A 1,024’K-Valve surface closure pressure 866psig 2 4,569’GLM ST 1: Camco, RK, Port= NA, Dev=50, Vlv=Dmy, TVD= 3,976’, Date= 3/27/2008 3 12,178’9-5/8” x 7” ZXP Liner Top Packer w/11’ PBR, ID = 6.200” 4 12,199’9-5/8” x 7” Baker Flex Lock Liner Hanger, ID = 6.200“ 5 13,398’4-1/2” Fiber Optic Transducer, ID = 3.958” 6 13,423’4-1/2” HES “X” Nipple, ID = 3.813” 7 13,444’7” x 4-1/2” Baker Premier Packer, ID = 3.875” 8 13,471’4-1/2” HES ‘X’ Nip, ID= 3.813” 9 13,479’7” x 5” HRD ZXP Liner Top Packer w/17’ PBR, ID= 4.450” 10 13,483’4-1/2” HES ‘XN’ Nipple, ID= 3.725” 11 13,494’4-1/2” Self Aligning Mule Shoe, ID = 3.850” 12 13,507’7” x 5” Baker Flex Lock Hanger, ID = 4.400” 13 13,516’5” x 4-1/2” Cross-over, ID= 3.940” 14 13,522’4-1/2” x 2-7/8” Cross-over, ID= 2.387” 15 13,685’7” x 5” “HR” ZXP Liner Top Packer w/12’ PBR, ID = 4.350” 16 13,709’7” x 5” Baker Flex Lock Liner Hanger, ID = 4.370” 17 13,718’5” x 4-1/2” Cross-over, ID= 3.930” PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Size Kuparuk 11,989’12,001’9,041’9,052’12’9/12/2023 Open 3.125” Kuparuk 12,031’12,081’9,079’9,123’50’5/4/2023 Open 2.75” Ivishak 14,274’14,304’11,085’11,113’30 6/12/08 Closed 2” Ivishak 14,274’14,339’11,085’11,146’65 7/27/08 Closed 2” Ivishak 14,276’14,296’11,087’11,106’20 7/4/08 Closed 2” Ivishak 14,289’14,339’11,099’11,146’50 5/2/08 Closed 2” Ivishak 14,295’14,340’11,105’11,147’45 5/7/13 Closed 2” Ivishak 14,304’14,339’11,113’11,146’35 4/5/08 Closed 2” Ivishak 14,280’14,320’11,091’11,128’40 7/11/16 Closed 2” Ivishak 14,320’14,340’11,128’11,147’20 7/10/16 Closed 2” Reference log: SWS-PDC on 4/3/2008. CASING / OPEN HOLE / CEMENT DETAIL 20"Driven 13-3/8"618 sx Permafrost ‘L’, 470 sx Class ‘G’ in 16” hole 9-5/8"872 sx Extended Slurry, 637 sx Class ‘G’ in 12-1/4” hole 7”107 sx Class “G” in 8-1/2” hole 4-1/2”119 sx Class “G” in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 53 deg. @ 7,169’ Max Angle at Top Perf: 20 Deg. @ 14,274’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23096-01-00 Initially Drilled - Nabors 33E – 7/15/2002 Initial Completion – Nabors 33E – 6/14/2003 Sidetracked (NS16A) – Nabors 33E – 3/25/2008 SAFETY NOTE Well requires a SSSV. Chrome Tubing & Liner. Note: BSEE well Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/30/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231130 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 11/13/2023 YELLOW JACKET GPT BCU 13 50133205250000 203138 10/5/2023 YELLOW JACKET PERF KBU 13-08 50133203040000 177029 10/16/2023 YELLOW JACKET CALIPER KU 12-17 50133205770000 208089 10/4/2023 YELLOW JACKET CALIPER/TEMP KU 24-7RD 50133203520100 205099 10/4/2023 YELLOW JACKET CALIPER MPU B-32 50029235700000 216151 9/20/2023 YELLOW JACKET RCT MPU L-47 50029235500000 215117 10/25/2023 YELLOW JACKET CUT NS-05 50029232440000 205009 9/9/2023 YELLOW JACKET PERF NS-16A 50029230960100 206141 9/12/2023 YELLOW JACKET PERF NS-20 50029231180000 202188 9/11/2023 YELLOW JACKET PERF NS-24 50029231110000 202164 9/10/2023 YELLOW JACKET PATCH PTM P1-13 50029223720000 193074 10/24/2023 YELLOW JACKET PL Please include current contact information if different from above. T38164 T38164 T38165 T38166 T38167 T38168 T38169 T38170 T38171 T38172 T38173 T38174 12/1/2023 YELLOW NS-16A 50029230960100 206141 9/12/2023 JACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 10:42:44 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,505 feet 13,370 feet true vertical 11,306 feet NA feet 12,178, 13,444, Effective Depth measured 14,408 feet 13,479 & 13,685 feet true vertical 11,212 feet 9,210, 10,339, 10,370 & 10,555 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 13Cr-80 13,522 10,409 Tubing (size, grade, measured and true vertical depth) 2-7/8" 13Cr-80 14,504' 11,305' 9-5/8" x 7" ZXP LTP 7" x 4-1/2" Bkr Prem. ZXP Packers and SSSV (type, measured and true vertical depth)7" x 5" Bkr ZXP See Above 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:NORTHSTAR OIL, KUPARUK OIL 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Engineer Contact Phone: 4-1/2" TRM-4E SSSV 1,024MD / 1,024TVD Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 323-496 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG NA measured true vertical Packer MD 156' Size 156' 2,993' Length Liner 1,672' 413' Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 135 Gas-Mcf 0 14 031663 133 7269 777 1215 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-141 50-029-23096-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC CBL results emailed to bryan.mclellan@aogcc.gov on 4/2/2023 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL NORTHSTAR UNIT NS-16A Plugs Junk measured measured Conductor 10,702' 10,920' 13,850' 14,093' 12,531' 3,250'Surface Production Liner 20" 9-5/8" 156' 3,206' 12,574' 9,565' 7,020psi 7,500psi 5,020psi 6,870psi 8,160psi 8,430psi 4,760psi 13-3/8" Burst NA Collapse NA 2,260psi TVD Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 1:19 pm, Sep 22, 2023 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.09.21 15:43:47 - 08'00' Sara Hannegan (2519) RBDMS JSB 092623 WCB 12-5-2024 DSR-9/23/25 Well Name Rig API Number Well Permit Number Start Date End Date NS-16A Slickline 50-029-23096-01-00 206-141 9/7/2023 9/12/2023 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 850/6/91 INTERVAL = 11989 - 12001 FT. 3-1/8" 6 SPF, 12' LOADED, CCL - TOP SHOT = 8.8 FT., CCL STOP = 11980.2 FT. ALL SHOTS FIRED, WHP 850 PSI, NO CHANGE. ELINE COMPLETE. DSO NOTIFIED. *** WELL SI ON DEPARTURE *** 9/12/2023 - Tuesday 9/8/2023 - Friday ***CONT WSR FROM 9/7/23*** (perforating) TAGGED TD W/ 12' x 3.62" DRIFT @ 12,403' SLM (sticky) PERFORMED WELL CONTROL/H2S DRILL W/ WSL, CRANE OP AND CREW ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Hilcorp Alaska, LLC Weekly Operations Summary 9/7/2023 - Thursday ***WELL S/I UPON ARRIVAL*** (perforating) R/U HES 766 SLICKLINE UNIT ***CONT WSR ON 9/8/23 INTERVAL = 11989 - 12001 FT. 3-1/8" 6 SPF, 12' LOADED, CCL - TOP SHOT = 8.8 FT., CCL STOP = 11980.2 FT. ALL SHOTS FIRED _____________________________________________________________________________________ Revised By: DH 9/14/2023 SCHEMATIC Northstar Unit Well: NS-16A Last Completed: 3/25/2008 PTD: 206-141 TD = 14,505’(MD) / TD =11,306’(TVD) 20” KBE = 55.92’/ GL = 16.1’ 7” Tubing Punch @ 13,343’ 3/7/23 4 5 6 17 13 11, 12 7 Top of cement in IA ~ 7,827’ 9-5/8” 1 2 9 15, 16 8 Min ID= 2.387” @ 13,52 2’ 2-7/8” Composite Bridge Plug @ 13,370’ 3/7/23 13-3/8” Whipstock @ 3,250’ on 2/10/2008 13-3/8” TAM Port Collar @ 1,587’ PBTD =14,414’(MD) / PBTD =11,218’(TVD) 3 13-3/8” 10 14 4-1/2” 5 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169# / X-56 / N/A N/A Surface 201' N/A 13-3/8" Surface 68# / L-80 / BTC 12.415” Surface 3,274’ 0.1497 9-5/8" Intermediate 47# / L-80 / BTC-M 8.681” Surface 12,574’ 0.0732 7" Liner 29# / L-80 / Hydril 521 6.184” 12,178’ 13,850’ 0.0371 4-1/2” Liner 12.6#/L-80 / Hydril 521 3.958” 13,685’ 14,093’ 0.0152 2-7/8” Liner 6.4#/ L-80 / STL 2.441” 13,522’ 14,504’ 0.0058 4-1/2” Liner 12.6#/13Cr80/Vam Top 3.958” 13,516 13,522’ 0.0152 5” Liner 15#/13Cr/Vam Ace 4.408” 13,479’ 13,516’ 0.0189 TUBING DETAIL 4-1/2” Tubing 12.6#/13Cr80/Vam Top 3.958” Surface 13,497’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,024’ 4-1/2” TRM-4E SSSV, ID= 3.812” 2 4,569’ GLM ST 1: Camco, RK, Port= NA, Dev=50, Vlv=Dmy, TVD= 3,976’, Date= 3/27/2008 3 12,178’ 9-5/8” x 7” ZXP Liner Top Packer w/11’ PBR, ID = 6.200” 4 12,199’ 9-5/8” x 7” Baker Flex Lock Liner Hanger, ID = 6.200“ 5 13,398’ 4-1/2” Fiber Optic Transducer, ID = 3.958” 6 13,423’ 4-1/2” HES “X” Nipple, ID = 3.813” 7 13,444’ 7” x 4-1/2” Baker Premier Packer, ID = 3.875” 8 13,471’ 4-1/2” HES ‘X’ Nip, ID= 3.813” 9 13,479’ 7” x 5” HRD ZXP Liner Top Packer w/17’ PBR, ID= 4.450” 10 13,483’ 4-1/2” HES ‘XN’ Nipple, ID= 3.725” 11 13,494’ 4-1/2” Self Aligning Mule Shoe, ID = 3.850” 12 13,507’ 7” x 5” Baker Flex Lock Hanger, ID = 4.400” 13 13,516’ 5” x 4-1/2” Cross-over, ID= 3.940” 14 13,522’ 4-1/2” x 2-7/8” Cross-over, ID= 2.387” 15 13,685’ 7” x 5” “HR” ZXP Liner Top Packer w/12’ PBR, ID = 4.350” 16 13,709’ 7” x 5” Baker Flex Lock Liner Hanger, ID = 4.370” 17 13,718’ 5” x 4-1/2” Cross-over, ID= 3.930” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kuparuk 11,989’ 12,001’ 9,041’ 9,052’ 12’ 9/12/2023 Open 3.125” Kuparuk 12,031’ 12,081’ 9,079’ 9,123’ 50’ 5/4/2023 Open 2.75” Ivishak 14,274’ 14,304’ 11,085’ 11,113’ 30 6/12/08 Closed 2” Ivishak 14,274’ 14,339’ 11,085’ 11,146’ 65 7/27/08 Closed 2” Ivishak 14,276’ 14,296’ 11,087’ 11,106’ 20 7/4/08 Closed 2” Ivishak 14,289’ 14,339’ 11,099’ 11,146’ 50 5/2/08 Closed 2” Ivishak 14,295’ 14,340’ 11,105’ 11,147’ 45 5/7/13 Closed 2” Ivishak 14,304’ 14,339’ 11,113’ 11,146’ 35 4/5/08 Closed 2” Ivishak 14,280’ 14,320’ 11,091’ 11,128’ 40 7/11/16 Closed 2” Ivishak 14,320’ 14,340’ 11,128’ 11,147’ 20 7/10/16 Closed 2” Reference log: SWS-PDC on 4/3/2008. CASING / OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 618 sx Permafrost ‘L’, 470 sx Class ‘G’ in 16” hole 9-5/8" 872 sx Extended Slurry, 637 sx Class ‘G’ in 12-1/4” hole 7” 107 sx Class “G” in 8-1/2” hole 4-1/2” 119 sx Class “G” in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 53 deg. @ 7,169’ Max Angle at Top Perf: 20 Deg. @ 14,274’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23096-01-00 Initially Drilled - Nabors 33E – 7/15/2002 Initial Completion – Nabors 33E – 6/14/2003 Sidetracked (NS16A) – Nabors 33E – 3/25/2008 SAFETY NOTE Well requires a SSSV. Chrome Tubing & Liner. Note: BSEE well 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,505'N/A Casing Collapse Structural Conductor N/A Surface 2,260psi Intermediate 4,760psi Liner 7,020psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NORTHSTAR 9-5/8"x7" ZXP, 7"x5" ZXP, 7"x4" Prem. Pkr, 7"x5" ZXP, 4-1/2" TRM-4E SSSV Brenden Swensen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 206-141 C.O. 739 NORTHSTAR UNIT NS-16A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23096-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 11,306' 14,408' 11,212' 2,050 NORTHSTAR OIL, KUPARUK OIL Same 12.6# / 13Cr-80 TVD Burst 13,522 8,160psi MD 6,870psi N/A 5,020psi 156' 2,993' 9,565' 156' 3,250' 10,702'7" 20" 13-3/8" 156' 9-5/8"12,531' 3,206' 907-748-8581 brenden.swensen@hilcorp.com Operations Manager September 15, 2023 14,093'413' 4-1/2" 10,920' Perforation Depth MD (ft): See Schematic 12,178MD/9,210TVD,13,479MD/10,370TVD, 13,444MD/10,339TVD,13,685MD/10,555TVD, 1,024MD/1,019TVD 14,408' 13,850' 12,574' 1,672' 4-1/2" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:12 pm, Aug 30, 2023 323-496 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.08.30 15:00:04 - 08'00' Sara Hannegan (2519) 2,050 DSR-8/31/23MGR01SEP23 10-404 MDG 9/6/2023 *&: 09/06/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.06 16:07:02 -08'00' RBDMS JBS 090823 Page 1 of 4 Add Perf Well: NS-16A PTD: 206-141 Well Name: NS-16A API Number: 50-029-23096-01-00 Current Status: Kuparuk Producer PTD # 206-141 Estimated Start Date: 9/15/2023 Rig: E-Line or Slickline Reg.Approval Req’std? Yes Estimated Duration: 1 day Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure: 2950 psi @ 9,000’ TVD (NS23 SBHPS 4/23/2023) Maximum Expected BHP: 2950 psi @ 9,000’ TVD (est.) 6.31ppg EMW Max. Anticipated Surface Pressure: 2050 psi Gas Column Gradient (0.1 psi/ft) History NS16A was drilled and completed as an Ivishak producer in 2002. It was sidetracked in 2008 also as an Ivishak producer. In March of 2023, the well was recompleted to the Kuparuk formation by pumping a cement plug in the IA and tubing, and then perforating through the existing tubing and casing. The original Kuparuk perforations only targeted the C1 sand. The sand came in at a low GOR and produced ~150 BOPD with little water and ~4mmscf/d. Since the C2 sands are expected to be a significantly higher GOR, the perforations were deferred to attempt to drain as much of the C1 as possible prior to the C2 – expecting the C2 to dominate flow and the C1 to become a minor contributor once the C2 is perforated. The C1 is showing signs of struggling to sustain flow with the latest well test flowing around 1.2mmscf/d. The well also has recently been shut in for the 2023 facility turnaround and is difficult to kick off. Objective Perforate 12’ of the C2 Kuparuk sand. Procedure Slickline 1. MIRU. Pressure test PCE low 250psi high 2500psi. 2. Drift to top of milled cement at 12,410’. a. Coil milled out the cement sheath with a 3.76” junk mill on 8/14/2023 to 12,410’ MD. b. Recommend drifting with 3.5” gage or larger. WSL discretion. 3. Drift with dummy 2-7/8” guns. Slickline or Eline 4. MIRU. Pressure test PCE low 250psi high 2500psi. 5. Perforate ±12’ from ±11,989’ to ±12,001’ MD. a. Use reference log Perforation Depth Control Log dated April 3 2008. b. Ensure deep penetrating charges. Shooting through 4.5” tubing and 7” casing. c. Contact town Geo and OE for final tie in correlation. i. Geo - Brock Rust, brust@hilcorp.com, 907-777-8394 ii. OE - Brenden Swensen, brenden.swensen@hilcorp.com, 907-748-8581 Page 2 of 4 Add Perf Well: NS-16A PTD: 206-141 Reference Log Title Page Page 3 of 4 Add Perf Well: NS-16A PTD: 206-141 Reference Log Gamma Signature Perf Interval: ± 11,989’ to ± 12,001’ Page 4 of 4 Add Perf Well: NS-16A PTD: 206-141 Kuparuk Perf Add ± 11,989’ to ± 12,001’ Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Brenden Swensen To:McLellan, Bryan J (OGC); Davies, Stephen F (OGC) Cc:Rixse, Melvin G (OGC); Torin Roschinger Subject:RE: [EXTERNAL] RE: Northstar NS-16A IA Cement CBL PTD 206-141 Sundry 323-052 Date:Tuesday, April 4, 2023 7:05:19 AM You don't often get email from brenden.swensen@hilcorp.com. Learn why this is important Good morning Bryan, Thank you for the quick response. AOGCC witnessed passing MIT-T and CMIT TxIA to 2500 psi on 3/26/23. AOGCC also witnessed drift and tag TOC in tubing @ 13,310' SLM on 3/29/23. I should have included that in my previous email. We will proceed with perforating today. Thanks, ~Brenden Swensen From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, April 3, 2023 4:46 PM To: Brenden Swensen <Brenden.Swensen@hilcorp.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] RE: Northstar NS-16A IA Cement CBL PTD 206-141 Sundry 323-052 Brenden, Hilcorp has approval to proceed with perforating the Kuparuk on the condition that the MIT-T and CMIT TxIA to 2500 psi pass, with opportunity for AOGCC witness. On my first look at the CBL, I don’t agree with your pick for top of good cement. Although 7840’ is the first hint of patchy cement, I would call good cement top at 10165’ MD. A TOC at 10165’ MD still provides sufficient cement to isolate the proposed Kuparuk perfs at 11989’ MD. Happy to discuss if you want to. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brenden Swensen <Brenden.Swensen@hilcorp.com> Sent: Monday, April 3, 2023 4:28 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Northstar NS-16A IA Cement CBL PTD 206-141 Sundry 323-052 Good afternoon Bryan, Please see attached cement bond log for NS-16A. Top of cement pick is at 7840’ MD. TOC proposed in the sundry is 8000’ MD. Let us know if we are approved to proceed with perforating the Kuparuk. Thanks, Brenden Swensen 907-748-8581 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:11 Township:13N Range:13E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:14505 ft MD Lease No.:ADL0312799 Operator Rep:Suspend:P&A: Conductor:20"O.D. Shoe@ 156 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 3250 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9 5/8"O.D. Shoe@ 12574 Feet Csg Cut@ Feet Liner1:7"O.D. Shoe@ 13850 Feet Csg Cut@ Feet Liner2:4 1/2"O.D. Shoe@ 14093 Feet Csg Cut@ Feet Tubing:4 1/2"O.D. Tail@ 13522 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 13370 ft 13310 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Verification of cement across the Kuparuk formation prior to perforating the Kuparuk formation. MIT's were completed on 03-26- 2023 by Austin McLeod - both passing. Top of cement tag was a good at 13310 ft MD with a good cement sample from the bailer. A cement bond log will be run in a few days to verify cement in IA. March 29, 2023 Kam StJohn Well Bore Plug & Abandonment Northstar NS-16A Hilcorp Alaska LLC PTD 2061410; Sundry 323-052 none Test Data: Casing Removal: Nathan Williams Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0329_Plug_Verification_Northstar_NS-16A_ksj MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-16A NORTHSTAR UNIT NS-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 NS-16A 50-029-23096-01-00 206-141-0 N SPT 10339 2061410 2500 1844 2728 2699 2692 74 75 75 75 OTHER P Austin McLeod 3/26/2023 Producer. CMIT-TxIA to 2500psi. Sundry 323-052. Retainer @ 13,325 ft MD. TOC in IA @ ~ 8000 ft MD (CBL not done yet to verify) 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-16A Inspection Date: Tubing OA Packer Depth 1844 2695 2631 2603IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230326180722 BBL Pumped:2 BBL Returned:2.3 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Producer CMIT-TxIA Sundry 323-052. James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:29:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-16A NORTHSTAR UNIT NS-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 NS-16A 50-029-23096-01-00 206-141-0 N SPT 10339 2061410 2500 2140 2710 2653 2636 74 74 74 74 OTHER P Austin McLeod 3/26/2023 Producer. MITT to 2500psi. Sundry 323-052. Retainer @ 13,325 ft MD. No tag done. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-16A Inspection Date: Tubing OA Packer Depth 1647 1665 1666 1666IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230326180123 BBL Pumped:0.6 BBL Returned:0.6 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 99 9 9 9 9 9 9 9 Producer. Sundry 323-052. James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:26:21 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Kuparuk Recomplete Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,505 feet 13,370 feet true vertical 11,306 feet NA feet 12,178, 13,444, Effective Depth measured 14,408 feet 13,479 & 13,685 feet true vertical 11,212 feet 9,210, 10,339, 10,370 & 10,555 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 13Cr-80 13,522 10,409 Tubing (size, grade, measured and true vertical depth) 2-7/8" 13Cr-80 14,504' 11,305' 9-5/8" x 7" ZXP LTP 7" x 4-1/2" Bkr Prem. 7" x 5" HRD ZXP Packers and SSSV (type, measured and true vertical depth)7" x 5" Bkr ZXP 4-1/2" TRM-4E SSSV See Above 1,024MD / 1,024TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:NORTHSTAR OIL, KUPARUK OIL 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Engineer Contact Phone: 13-3/8" Burst NA Collapse NA 2,260psi 7,020psi 7,500psi 5,020psi 6,870psi 8,160psi 8,430psi 4,760psi Conductor 10,702' 10,920' 13,850' 14,093' 12,531' 3,250'Surface Production Liner 20" 9-5/8" 156' 3,206' 12,574' 9,565' NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL NORTHSTAR UNIT NS-16A Plugs Junk measured measured TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-141 50-029-23096-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC CBL results emailed to bryan.mclellan@aogcc.gov on 4/2/2023 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 199 Gas-Mcf 1031 18 05314 117 3076207 771 NA measured true vertical Packer MD 156' Size 156' 2,993' Length Liner 1,672' 413' Casing 323-052 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 35152 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:08 pm, May 25, 2023 Digitally signed by Brenden Swensen (005774) Date: 5/25/23 3:50:09 PM Brenden Swensen (005774) RBDMS JSB 071923 X DSR-5/26/23 X WCB 12-5-2024 KUPARUK OIL Well Name Rig API Number Well Permit Number Start Date End Date NS-16A Slickline 50-029-23096-01-00 206-141 3/5/2023 5/4/2023 Hilcorp Alaska, LLC Weekly Operations Summary LRS LOADED TUBING W/ 250bbls DEAD CRUDE. RAN KJ, 3.78" CENT, HES PRESSURE / TEMP TOOL TAG XN @ 13,447' SLM. (12,483' MD) FOR 36' COR, PUH TO 13,334' SLM (13,370' MD) & FLAG WIRE. SET CBP @ 13,334' SLM (13,370' MD), LRS TESTED TUBING TO 1500psi (pass). RAN KJ, HES MAXFIRE W/ TUBING PUNCH (21 - .45" holes) & PUNCH HOLES FROM 13,308' SLM (13,343' MD) TO 13,312' SLM (13,348' MD), ALL SHOTS FIRED. CONTINUE ON 3-8-23 WSR. MISU UNIT & EQUIP, RIG UP ON WELL, LAY EQUIP DOWN DUE TO LRS HAVING ISSUES LOADING TANKS. CONTINUE ON 3-7-23 WSR. 3/7/2023 - Tuesday 3/5/2023 - Sunday TRAVEL / JOB PREP. TRAVEL FROM ENDICOTT TO NORTHSTAR. PREP UNIT & TOOLS FOR JOB. STBY FOR WELL SUPPORT TO FINISH PAD SET UP. CONTINUE ON 3-6-23 WSR. 3/6/2023 - Monday 3/11/2022 - Saturday Transfer 385 bbls crude from WCT to OTT / Heat Fresh Water Upright to 100* / Pump 67 bbls from flowback tank to NS 33 3/12/2023 - Sunday IA cement job for Kuparuk re-complete: Pump 246bbl 14ppg class G with HES offshore skid. Displace cement with 5bbl FW +198 NS crude to Tbg punches at 13348'. Trap 3000psi on tbg. TOC in IA ~8022'. Transfer 395 bbls crude from WCT to OTT / Assist with Cement. Pump 198 bbls crude to spot cement. Freeze protct hardline and NS 19 flowline. 3/8/2023 - Wednesday Transfer 150 bbls crude from WCT to OTT. / CIRC OUT--Verify micro motion and flowpaths with 14 bbls diesel. Pump 677 bbls crude down tbg taking returns up IA to NS19 flowline. Flush hardline legs with 4 bbls diesel & 5 bbls neat meth / Transfer 288 bbls crude from WCT to OTTs 3/9/2023 - Thursday Transfer crude from WCT to OTT / Freeze Protect IA with 45 bbls crude & 5 bbls neat meth. 3/29/2023 - Wednesday WELL S/I ON ARRIVAL. (d&t toc, state witness). RAN 2.83" CENT, 5' x 2.5" PUMP BAILER, TAG TOC @ 13,310' SLM. (recover approx 1/4 cup of hardened cement). WELL LEFT S/I ON DEPARTURE. 4/3/2023 - Monday WELL S/I ON ARRIVAL, DSO NOTIFIED. RAN HES CBL TOOL DOWN TO TD @ 13,316' SLM & LOGGED UP TO 6000' SLM AS PER PROGRAM (good data), FLAGGED WIRE @ 12,200' SLM. CONTINUE ON 4-3-23 WSR. 4/4/2023 - Tuesday AOGCC witnessing of tagging TOC is a COA on Sundry 323-052. -WCB SET CBP @ 13,334' SLM (13,370' MD), (d&t toc, state witness). RAN 2.83" CENT, 5' x 2.5" PUMP BAILER, TAG TOC @ 13,310' SLM Per email dated 4-4-23, AOGCC witnessed passing MIT-T and combo to 2500 psi on 3-26-2023. This was a COA on Sundry 323-052. -WCB Email correspondence from Bryan McLellan to Brenden Swensen (Hilcorp) on 4-3-2023 gave approval, based on the CBL results, for Hilcorp to perforate the Kuparuk. -WCB RAN HES CBL TOOL DOWN TO TD @ 13,316' SLM & LOGGED UP TO 6000' SLM AS PER PROGRAM Pump 246bbl 14ppg class G with HES offshore skid. Displace cement with 5bbl FW +198 NS crude to Tbg punches at 13348'. Trap 3000psi on tbg. TOC in IA ~8022'. TUBING PUNCH (21 - .45" holes) & PUNCH HOLES FROM 13,308' SLM (13,343' MD) TO 13,312' SLM (13,348' MD), ALL SHOTS FIRED Well Name Rig API Number Well Permit Number Start Date End Date NS-16A Slickline 50-029-23096-01-00 206-141 3/5/2023 5/4/2023 Hilcorp Alaska, LLC Weekly Operations Summary ATTEMPTED TO RUN 22'x3-1/8" PERF GUNS SAT DOWN HIGH @ 10,568' SLM, UNABLE TO WORK PAST. RAN KJ, 2'x1-7/8" STEM, 4-1/2" BLB, 3.70" GAUGE RING, S/D @ 9,800' SLM WORK TOOLS TO 10,546' SLM, UNABLE TO WORK PAST, RECOVERED LARGE PIECE OF CEMENT IN GAUGE RING. RAN KJ, 2'x1-7/8" STEM, 4-1/2" BLB, 3.25" GAUGE RING, S/D @ 10,554' SLM, WORK TOOLS DOWN TO 13,294' SLM. RAN KJ, 20'x3-1/8" DUMMY GUNS, HES GAMMA / CCL / TEMP TOOL, TAG CEMENT @ 13,290' SLM, LOGGED FROM TD TO 11,000' SLM (good data), FLAGGED WIRE @ 12,200' SLM. CONTINUE ON 4-5-23 WSR. 4/5/2023 - Wednesday PERFORATE TBG W/ HES MAXFIRE & 3 1/8" GEORAZOR 6 SPF, 60* PHASE, 12,061' TO 12,081' ELMD. Correlated to SLB Perforation Depth Log dated 3-Apr-2008. HUNG UP W/ SPENT GUN @ 10944' SLM, LOST SPANGS & OJs. PRESSURE UP ON WELL W/ GAS TO PUSH FLUID DOWN HOLE. ATTEMPT TO FLOW TOOLS OUT BY BRINGING WELL ONLINE. 4/6/2023 - Thursday DROP CUTTER BAR IN ATTEMPT TO CUT WIRE, CUTTER BAR DID NOT CUT. LRS 106BBLS OF SEAWATER TO TRY AND FREE UP TOOLSTRING LRS PUMP 15BBLS FOR METH/DIESEL FOR FREEZE PROTECT. DROPPED KINLEY CUTTER, KINLEY CUT HIGH. APPROX 700' OF .125ss WIRE LEFT IN HOLE PLUS TOOLSTRING. HES UNIT 767 SWAP TO BRAIDEDLINE. 4/7/2023 - 4/27/2023 Continued Fishing. 4/28/2023 - Friday Slickline: RAN 8' x 3.0" PUMP BAILER TO JAR DOWN/BAIL ON TOOLSTRING (jar down 40min, bailer empty). JARRED UP ON TOOLSTRING FOR 1hr @ 10,915' BLM. FLOW WELL FOR 6hrs. RAN 8' x 3.0" PUMP BAILER TO TOP OF TOOLSTRING @ 10,578' BLM. RAN 2 1/2" JDC, PULLED TOOLSTRING FROM 10,582' BLM (everything looks good/recovered). 4/29/2023 - Saturday Slickline: RAN LOOSE 4 1/2" BRUSH, 3.50" GAUGE RING, SD @ 10,631' BLM (not sticky). RAN 8' x 3.0" PUMP BAILER TO 10,631' BLM (recovered 1.5gal cement). BRING WELL O/L & FLOW, MOVE TO NS-25. 4/30/2023 - Sunday Slickline: RAN 4 1/2" BRUSH, 3.70" GAUGE RING TO TOP OF CEMENT @ 10,041' SLM (unable to make deeper) MADE 2 RUNS W/ 8' x 3.0" PUMP BAILER FROM 10,037' SLM TO 11,168' SLM (break through several bridges, recovered 1.5gal chunks/cement) 5/1/2023 - Monday PERFORATE TBG W/ HES MAXFIRE & 3 1/8" GEORAZOR 6 SPF, 60* PHASE, 12,061' TO 12,081' ELMD Well Name Rig API Number Well Permit Number Start Date End Date NS-16A Slickline 50-029-23096-01-00 206-141 3/5/2023 5/4/2023 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: RAN 8' x 3.0" PUMP BAILER TO 11,165' SLM (recovered 1/4gal hard packed cement in bailer bottom) RAN KJ, 2' x 1 7/8" STEM, 2.70" CENT, 12 PRONG SPEAR (86" oal). SD @ 11,161' SLM. MAKE IT DOWN TO 11,165' SLM. RAN 3"x8' PUMP BAILER W/ SHARK TOOTH FLAPPER 4 TIMES, MAKE IT FROM 11,170' SLM DOWN TO 12,136' SLM, RECOVERED TOTAL OF 1.5gal OF CEMENT. RAN KJ, 2'x1-7/8" STEM, 4-1/2" BLB, 3.25" GAUGE RING, S/D @ 12,137' SLM (clean) RAN 4 1/2" BRUSH, 3.50" GAUGE RING TO 11,176' SLM (sticks, unable to pass) RAN 8' x 3.0" PUMP BAILER AND BREAK SEVERAL BRIDGES FROM 11,213' SLM TO 11,295' SLM (recovered 1/4gal, hard packed cement in bailer bottom) 5/2/2023 - Tuesday Slickline: MADE SEVERAL RUNS W/ 3.0" PUMP BAILER TO KEEP TUBING CLEAR AFTER GAUGE RINGS RAN 4 1/2" BRUSH, 3.25" GAUGE RING TO 12,050' SLM (several tight spots). RAN 4 1/2" BRUSH (extra stiff), 3.50" GAUGE RING DOWN TO 12,050' SLM (cement starts @ 1,200', heavy resistance from 11,500' TO 12,050' slm) 5/3/2023 - Wednesday Slickline: RAN 4 1/2" BRUSH (stiff), 3.70" GAUGE RING TO 11,514' SLM (unable to pass) RAN 3.62" GAUGE RING TO 11,647' SLM, UNABLE TO PASS THROUGH. RAN 3" x 8' PUMP BAILER TO 12,400' SLM, RECOVERED 1 CUP OF CEMENT RAN 3.62" G-RING TO 11,648' SLM WORK TOOLS FOR 15min AND UNABLE TO MAKE ANY HOLE RAN 4-1/2" BRUSH, 3.50" G-RING TO 11,500' SLM DOWN TO 12,100' SLM RAN 4-1/2" BRUSH, 3.62" G-RING TO 11,655' SLM WORK TOOLS FOR 45min DOWN TO 11,859' SLM RAN 3" x 8' PUMP BAILER TO 12,200' SLM (empty blr) MAKE MULTIPLE OTHER 3.62" G-RING RUNS & WORK TOOLS FROM 11,873 DOWN TO 11,886' & CANT MAKE ANY MORE HOLE 5/4/2023 - Thursday Slickline: RAN 3"x8' PUMP BAILER W/ SHARK TOOTH FLAPPER & S/D @ 12,400' SLM, RECOVERED 2 CUPS OF CEMENT. RAN KJ, 2'x1-7/8" STEM, XO, 4-1/2" BLB, XO, 3.62" GAUGE RING & S/D @ 12,886' SLM, UNABLE TO WORK PAST. RAN KJ, 2'x1-7/8" STEM, XO, 4-1/2" BLB, XO, 3.50" GAUGE RING & S/D @ 12,356' SLM. RAN HES MAXFIRE W/ 20' 2.75" GUN (6 SPF, 60deg PHASE) & SHOT FROM 12,026' SLM (12,041' MD), 12,046' SLM (12,061' MD), ALL SHOTS FIRED. RAN KJ, 2' x 1-7/8" STEM, XO, 4-1/2" BLB, XO, 3.50" G-RING, SD 12,042' SLM & WORK DOWN TO 12,120' SLM, MAKE MULTIPLE PASSES TO CLEAR UP TIGHT SPOT RAN HES MAXFIRE W/ 10' x 2.75" GUN (6 SPF, 60 deg PHASE) & SHOT FROM 12,006' SLM (12,031' -12,041' MD) ALL SHOTS FIRED Hilcorp Alaska, LLC 2" 2"6 6 14280 - 14320 14320 - 14340 0 0 7/11/16 7/10/16 COMPOSITE BRIDGE PLUG TUBING PUNCH KUPARUK PERFS 12,031-12,081' MD 13,370' 13,343' TOP OF CEMENT 7,840', COMPETENT CEMENT @ 10,165' PER HAL CBL ON 4/2/2023 CEMENT SHEATH IN TUBING - 10,041' (~3.62"), 11,886' (~3.50") CEMENT TOP TAGGED AT 13,310' (SLM) 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Kuparuk Recomp 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?C.O. 739 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,505'N/A Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Liner 7,020psi Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-440-7692 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Aras Worthington aras.worthington@hilcorp.com Tubing Grade:Tubing MD (ft): 12,178MD/9,210TVD,13,479MD/10,370TVD, 13,444MD/10,339TVD,13,685MD/10,555TVD , 1,024MD/1,019TVD Perforation Depth TVD (ft):Tubing Size: 12.6# 13Cr-80 13,522 3/15/2023 9-5/8"x7" ZXP, 7"x5" ZXP, 7"x4" Prem. Pkr, 7"x5" ZXP, 4-1/2" TRM-4E SSSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 206-141 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23096-01-00 Hilcorp Alaska, LLC NORTHSTAR UNIT NS-16A Length Size Proposed Pools: 156'156' TVD Burst 11,306'14,408'11,212'4,000 14,408' NORTHSTAR / NORTHSTAR OIL PRESENT WELL CONDITION SUMMARY MD N/A 8,160psi 5,020psi 6,870psi 2,993' 9,565' 10,702' 3,250' 12,574' 156'20" 13-3/8" 9-5/8" 3,206' 12,531' 8,430psi Perforation Depth MD (ft): 13,850' See Attached Schematic 413' See Attached Schematic 4-1/2" 4-1/2" 7"1,672' 10,920'14,093' m n P s 2 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 11:07 am, Jan 27, 2023 323-052 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.01.27 10:11:43 -09'00' Torin Roschinger (4662) DSR-1/30/23 X * AOGCC to witness slickline tag of (TOC ~13,325' MD) and MIT-T and CMIT- TxIA to 2500 psi. * CBL results to AOGCC email: melvin.rixse@alaska.gov DLB 02/03/2023 10-404 MGR09FEB23 Northstar, Kuparuk Oil DLB 4,000 GCW 02/10/23JLC 2/10/2023 2/10/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 12:04:31 -09'00' RBDMS JSB 021423 Re-complete to Kuparuk Well: NS16A PTD: 206-141 Well Name:NS16A API Number:50-029-23096-01 Current Status:Operable Ivishak Producer Rig:N/A Estimated Start Date:March 15, 2023 Estimated Duration:2 weeks Reg.Approval Req’d?Yes Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Torin Roschinger 406-570-9630 (M) Current Bottom Hole Pressure (Ivishak):5435 psi @ 11,100’ TVD (ca. 2019) Maximum Expected BHP (Ivishak):5500 psi @ 11,100’ TVD Max. Anticipated Surface Pressure (Ivishak):4325 psi Gas Column Gradient (0.1 psi/ft) Current Bottom Hole Pressure (Kuparuk):2375 psi @ 9000’ ssTVD (est.) Maximum Expected BHP (Kuparuk):2475 psi @ 9000’ ssTVD Max. Anticipated Surface Pressure (Kuparuk):1575 psi Gas Column Gradient (0.1 psi/ft) History NS16A was drilled and completed as an Ivishak producer in 2002. It was rotary sidetracked in 2008 also as an Ivishak producer. The Ivishak production has depleted to the point where a Kuparuk re-complete is proposed. Objective Execute an IA cement job to get cement across the Kuparuk interval. Perforate and produce the Kuparuk. The proposed TOC the IA is ~8000’ MD which is ~3107’ TVD below the sidetrack/whipstock set depth in the surface casing. A full reservoir abandonment of the Ivishak is not proposed at this time because there may be a future desire to either go back to the Ivishak perforations or perform a CTD sidetrack to another Ivishak target. Post-job Evaluation o MIT-T and CMIT-TxIA o CBL to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily I concur. The well produces~120 BOPD with a GOR ~50% higher than the field wide average, . re-completing the well in the Kuparuk should improve ultimate recovery from the field. DSR-1/30/23 -00 DLB Re-complete to Kuparuk Well: NS16A PTD: 206-141 Procedural steps Slickline & Fullbore 1. Pull SSSV. 2. Drift for CBP/Cement retainer to ~13,500’ MD. CBP and Retainer are both 3.57” max OD. 3. Tag the 3.725” XN nipple @ 13,483’ MD w/ appropriate sized drift (3.80” – 3.725”). Flag wire and correct depth to tubing tally. 4. Set 4-1/2” CBP in the middle of the first full joint of tubing above the production packer (~13,370 MD*). 5. PT of tubing/CBP to 1500 psi to verify CBP set. Five-minute test, no more than 10% pressure loss. 6. Punch tubing in the middle of the first collar above the CBP. (~13,343’ – 13,348’ MD*). 7. Pump diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel. (~870 bbls diesel surface-to-surface). 8. Set 4-1/2” Northern Solutions ball-drop-composite cement retainer in the middle of the first full joint above the tubing punch (~13,325’ MD*) *Note: All depths reference tubing tally of 3/24/2008. Fullbore Cement 9. Pump down production tubing with returns from the IA: ¾10 bbls FW + Surfactant ¾244 bbls 14-15.8 ppg Class G cement ¾Chase w/phenolic landing ball & two foam wiper balls ¾Chase balls w/ ~202 bbls diesel and look for indication of ball landing on-seat ¾Pump no more than 204 bbls total displacement after cement ¾If ball seats, apply no more than 2900 psi tbg pressure to verify seating (~500 psi over lift-pressure) ¾Bleed-off tubing pressure. Bleed no more than 1-bbl to see if retainer poppet holds pressure from IA to tubing (lift pressure). If it does not hold pressure, bump tubing pressure back up to lift pressure and lock in pressure w/ tree valves Note: expected lift pressure is ~2400 psi Cement Calculations ¾7” x 4-1/2” volume from 12,178’ – 13,343’ MD:20 bbls ¾9-5/8” x 4-1/2” volume from 12,178’ – 8000’ MD:224 bbls Total Cement to pump: 244 bbls Slickline & Fullbore 10. D&T TOC. 11. Log Memory CBL from tag of TOC in tubing to ~6000’ MD to identify TOC. 12. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 2500 psi. Ensure 24-hour notice provided for AOGCC. 13. Leave CBP, cement, and cement retainer in tubing to isolate Ivishak from Kuparuk perforations. E-Line 14. Perforate the Kuparuk per attached proposed schematic. email to AOGCC. AOGCC to witness tag of TOC. email CBL to melvin.rixse@alaska.gov upon completion. Re-complete to Kuparuk Well: NS16A PTD: 206-141 Slickline 15. Set SSSV. Well Diagnostics & WIE 16. Update AKIMS and add biennial MIT-T and CMIT TxIA. Re-complete to Kuparuk Well: NS16A PTD: 206-141 NS16 Current Schematic 7” Casing Annular TOC @ ~13,350’ MD (w/ 30% washout) 9-5/8” Casing Annular TOC @ ~5580’ MD (w/ 30% washout) Confining Shales between Kuparuk and Ivishak: 12,296’ – 14,038’ MD Re-complete to Kuparuk Well: NS16A PTD: 206-141 Perforations into Kuparuk: 11,989’–12,001’MD 12,031’ – 12,081’ MD TOC in IA ~8000’MD NS16 Proposed Schematic Cement Retainer @ ~13,325’ MD CBP @ ~13,370’ MD Tubing Punch @ ~13,343’ MD Re-complete to Kuparuk Well: NS16A PTD: 206-141 iY ISP � } I V STATE OF ALASKA AICA OIL AND GAS CONSERVATION COMOSION JUL 2 6 2016 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Re-Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory❑ 206-141 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23096-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-16A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/ NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 14,505 feet Plugs measured 14,408 feet true vertical 11,306 feet Junk measured N/A feet 12,178, 13,444, Effective Depth measured 14,408 feet Packer measured 13,479&13,685 feet 9,210,10,339, true vertical 11,212 feet true vertical 10,370, 10,555 feet Casing Length Size MD TVD Burst Collapse Conductor 156' 20" 156' 156' N/A N/A Surface 3,206' 13-3/8" 3,250' 2,993' 5,020psi 2,260psi Production 12,531' 9-5/8" 12,574' 9,565' 6,870psi 4,760psi Liner 1,672' 7" 13,850' 10,702' 8,160psi 7,020psi Liner 413' 4-1/2" 14,093' 10,920' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-7/8" 6.4#/CR-80/Vam Top 14,408' 11,212' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80/STL 14,504' 11,305' 9-5/8"x 7"ZXP LTP 7"x 4-1/2"Bkr Prem. 7"x5"HRDZXP �'+'"" Packers and SSSV(type,measured and true vertical depth) 7"x 5"Bkr ZXP 4-1/2"TRM-4E SSSV See Above 1,024MD/1,024TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A ` g Treatment descriptions including volumes used and final pressure: N/A SCANNED OCT 1 2016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 568 38,073 742 205 789 Subsequent to operation: 549 28,696 595 328 788 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: °��`4. c To,/ Contact Taylor Wellman Email twellman anhilcorp.com Printed Name Mike Du Title Operations Manager .74c/ Signature Phone 777-8382 Date 7/25/2016 Form 10-404 Revised 5/2015 4-2 -16 RBDMS LU4'.. 2 9 2016 Submit Original Only TREE= ' ABB-VG]5-1/8"SKSI LtEAD= 135/8"MULTIBOVVL SKSI N S 'I 6A S•YONOTES: TBG&ELLt'"REQUIRES A SSSV. ACTUATOR= BAKER INMAL KB.81 56.46' BF ELEV= 40.56'(CB 15.9') IliI4' rp Alatker...i.t.r: 1024' 14-112"TRIM-4E SSSV NP,E)=3.812" KOP= 100' Max Angie= ... . ............_ 53 @ 7169' Datum MD= 13686' — { 1587' {13-318"TAM PORT COLLAR I Datum TVD= 10500'SS 20"CONDUCTOR 1 ? 13-3/8"WHIPSTOCK(02/10/08) 1 3250' 13-3/8"CSG,68#,L-80 BTC,ID=12.415" 1 —3274 MILLOUT WINDOW(NS-16A) 3250'-3274' Minimum ID =2.387" @ 13522' / GAS LIFT MANDRELS 4-1/2" X 2-7/8" XU ST M? TVD DEV TYPE VLV LATCH PORT DATE 4569 3976 50 MMIC DMY RK 0 03/27/08 9-5/8"CSG,47#,L-80 513 HY DRI.. 1 6831' `—X >< XO TO L-80 BTC 1. 12178' —9-5/8"X 7"BKR ZXP LTP w/11'FBR,ID=6.200" I 12199' Hr x 5"BKR FLEX LOCK HGR,ID=6.200" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" 1 12574' ® L 13398' —14-1/2"FIBER OPTIC TRANSDUCER,10=3.958" ' ' 13423' 14-1/2"HES X NP,to=3.813" -2 X. 13444` --{7"X 4-1/2"BKR PREME2 PKR,ID=3.875" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, — 13497' ' 13471' —{4-1/2"HES X NP,1=3.813" .0152 bpf,ID=3.958" 13479' --17"X 5"HRD ZXP LIP w/17'PBR,E=4.450" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, — 13522' ' 13483' —4-1/2"HES XN NIP,E=3.725" .0152 bpf,0=3.958" 13497 —14-112"SELF ALIGNiJC MULE SHOE,10=3.850' PERFORATION SUMMARY \ 13507' —7"X 5"BKR FLEX LOCK HGR,ID=4.40" REF LOG: SWS-FDC ON 04/03/08 13516' —15"X 4-1/2"XO PUP,ID=3.94" ANGLE AT TOP PERE:20"@ 14274' 13522' 14-1/2"X 2-7/8"XO,ID=2.387" Nate:Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL(MD) Opn/Sqz SHOT SOZ 2" 6 14274-14304 0 06/12/08i 0 13885' —°{7"X 5"BKR ZXP LTP w/12'PBR D=4.350' 2" 6 14274-14339 0 07/27/08 2" 6 14276-14296 O 07/04/08 \ 13709' --17"X 5"BKR FLEX LOCK HGR,ID=4.370" 2" 6 14289-14339 0 05/02/08 13718' 15"X 4-1/2"XO PUP,D=3.930" 2^ 6 14295-14340 0 05/07/13 2" 6 14304-14339 0 04/05/08 2" 6 14280-14320 0❑ 7/10/2016 2" 6 14320-14340 0 17/9/20161 7"LNR,29#,L-80 521 HYDRA-, 1 13850' , .0371 bpf,El=6.184' — 4-1/2"LNR,12.6#,L-80 521 HYDRA.., 1 14093' 0152 bpf, =3.958" PBTD —{ 14408' 2-7/8"LNR,6.4#,13CR 80,.0058 bpf,ID=2.441" H 14504" ,.•�•.4 - DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/15/02 JAS 1NIT COMPLETION 03/29/09 ?/PJC LNR CORRECTION WELL: NS16A 03/21/03 FM FINAL COMPLETION 02/17/11 MB/JMD ADDED SSSV SAFETY NOTE PERMT No:'2061410 03/25/08 N33E SIDETRACK(NS-16A) 03/03/11 PJC DRAVVI IG CORRECTIONS AR No: 50-029-23096-01 07/09/08 WWR/TLH ADPE F&2-7/8"LNR CORRECT 05/22/13 SET/JMD ADPERFS(05/07/13) SEC 11,T13N,R13E, 1199'FSL&645 FEL 07/26/08 WWR/PJC DRLG DRAFT CORRECTIONS • 09/05/08 VVRR/PJC PEWS(07/27/08) Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS 16 SlickLine 50-029-23096-00-00 206-141 7/9/16 7/10/16 Daily Operations: 7/6/2016-Wednesday No activity to report. 7/7/2016-Thursday No activity to report. 7/8/2016- Friday No activity to report. 7/9/2016-Saturday ***WELL FLOWING ON ARRIVAL*** (SLB ELINE - PERF). PJSM. RU/PT ELINE. S/I WELL. LPT 300 PSI. HPT 4,800PSI. RUN 1: RIH W/GEODYNAMIC 2" GUN. OAL=48'/OAW=450LB/ MAXOD=2.2". PERFORATE INTERVAL 14,320'-14,340'. CCL TO TOP SHOT=3.83' CCL STOP DEPTH = 14,316.17' TD TAGGED 14,375'. CORRELATED TO SLB PRODUCTION PROFILE DATED 26-MAY-2016. 7/10/2016-Sunday PJSM. RU/PT ELINE. LPT 300 PSI. HPT 4,800PSI. RUN 2: PERFORATE INTERVAL 14,300'-14,320'. CCL TO TOP SHOT=3.83' CCL STOP DEPTH = 14296.17'. RUN 3: RIH W/GEODYNAMIC 2" GUN. PERFORATE INTERVAL 14,280'-14,300'. CCL TO TOP SHOT= 3.83' CCL STOP DEPTH = 14,276.17'. ALL LOGS CORRELATED TO SLB PRODUCTION PROFILE DATED 26-MAY-2016. 7/11/2016- Monday No activity to report. 7/12/2016-Tuesday No activity to report. • •• y of r„ ewP,\\�yyy� THE STATE Alaska Oil and Gas t„, j o ALAsKA.. Conservation Commission 333 West Seventh Avenue Ir C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 P ALAFax: 907.276.7542 S www.aogcc.alaska.gov Mike Dunn Operations Manager Hilcorp Alaska, LLC SCANNED JAN 0 9 201ZJ 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Northstar Field,Northstar Oil Pool,NU NS-16A Permit to Drill Number: 206-141 Sundry Number: 316-323 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this' day of June, 2016. RBDMS JUN 1 3 2016 • •• STATE OF ALASKA • ¢. F C E I ALASKA JUN 0 7 °6 OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS O� �� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend ❑ ,....—Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Cl 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ • 206-141 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23096-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No 0 NORTHSTAR UNIT NS-16A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 . NORTHSTAR/NORTHSTAR 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): 14,505' • 11,306' • 14,408' 11,212' 4,000 14,408' N/A Casing Length Size MD TVD Burst Collapse Conductor 156' 20" 156' 156' N/A N/A Surface 3,206' 13-3/8" 3,250' 2,993' 5,020psi 2,260psi Production 12,531' 9-5/8" 12,574' 9,565' 6,870psi 4,760psi Liner 1,672' 7" 13,850' 10,702' 8,160psi 7,020psi Liner 413' 4-1/2" 14,093' 10,920' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2-7/8" 6.4#/CR-80/Vam Top 14,408' See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80/STL 14,504' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): . 9-5/8"x 7"ZXP LTP,7"x 5"ZXP LTP,7"xd 4"Prem.Pkr & 12,178MD/9,210TVD, 13,479MD/10,370TVD, 13,444MD/10,339TVD & 7"x 5"ZXP LTP and 4-1/2"TRM-4E SSSV 13,685MD/10,555TVD and 1,024MD/1,019TVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/22/2016 OIL Q WINJ ❑ WDSPL r• /�..Yj'eSuspended El16.Verbal Approval: Date: GAS ❑ SPLUG CICommission Representative: £ 4. .1 INJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved Slit ',4 �ir •A herein will not be deviated from without prior written approval. Contact Taylor Wellman rtoe Email twellmanahilcorD.com Printed Name ,fit/Dunn Title Operations Manager / Signature Phone 777-8382 Date 6/7/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3kL2 - 323 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 �/ RBDMS Y'-JUN 1 3 2016 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q"�Y i APPROVED BY Approved by: / f f a .'� I IAIISSIONER THE COMMISSION Date: —�— Ru mi4 Fnrm nr1 Form 10-403 R ised 11/2015 a pIc rd for 12 months from the date of approval. / Attachments in Duplicate d"OrMfg;;' ! /h 4•-£3-f4, • Re Pert • Well: NS-16A PTD: 206-141 Hikorp Alaska,LLQ API: 50-029-23096-01 Well Name: NS-16A API Number: 50-029-23096-01 Current Status: Online Rig: EL Estimated Start Date: June 22, 2016 Estimated Duration: 2 days Reg.Approval Req'std? N/A Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 206-141 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: Well EZ Inputs Required: Yes Current Bottom Hole Pressure: 5100 psi @ 11,100'TVD(Based on Ivishak BHP Trend on 9/24/15) Maximum Expected BHP: 5100 psi @ 11,100'TVD (Based on Ivishak BHP Trend on 9/24/15) Max.Anticipated Surface Pressure: 4000 psi (Based on 0.1 psi/ft.gas gradient) Last SI WHP: 3835 psi (Taken on 05/15/16) Min ID: 2.387" ID 4-1/2" x 2-7/8"XO at 13,522' MD Reference Log: Perforation Depth Control Log dated April 3, 2008 Brief Well Summary: The well was previously reperfed for scale in 2013 over the 14295'-14340' interval with good results but has since decreased roughly 1,000 bfpd.A production profile log run on May 26, 2016 confirmed low fluid rates from the interval suggesting it has scaled off again.A Slickline drift on 5/15/16 with a 2.30" OD centralizer found a restriction at^'14013' MD but was able to tap through it and drift to "14,350'MD then POOH with#100 overpull at the restriction. Objective: Using Eline, re-perforate the following Ivishak intervals for increased oil production. Proposed gun runs must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir" Engineer: Gun Run# Perf Top Perf Bottom Perf Length 1 ±14,320' ±14,340' 20 2 ±14,300' ±14,320' 20 3 ±14,280' ±14,300' 20 Total 60 Table 1: NS-16A Proposed Re-Perf Gun Runs Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 4,000psi high. 2. MU perforating tool string with 2", 6spf, 60 deg phasing guns with deep penetrating charges. 3. RIH and correlate 1st gun run to reference log Perforation Depth Control Log dated April 3, 2008. Contact OE Taylor Wellman at 1(907) 947-9533 or Wyatt Rivard 1(509) 670-8001 prior to perforating for final approval of tie in. 4. Perforate 1st gun run as per Table 1: NS-16A Proposed Re-Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. Repeat steps 2-4 for gun runs 2 & 3 as per Table 1: NS-16A Proposed Re-Perf Gun Runs. 6. RD Eline. Attachments: As-built/Well Schematic " T AB&VGI SKSI N S 1 6A "*C ROM E TBG 8 INF.'"'WE1taLF EAD= 13-5/8"MULTiBOIM_OVVL SKSI S NOTES:WELL REQUIRES A SSSV. ACTUATOR= BAKER 11t1AL KB.Ell 5646' I BE ET-EV= -40.56'(CB 15.0') Ililcurp Ala-{,xi.1.1.1; I 1024' H4-112"TRM-4E SSSV NP,D=3.812" KOP= 100' Max • Angle- 53"@ 7169' Datum M)= 13686' — -- 1587' -113-3/8"TAM PORT COLLAR Datum TD V = 10500'SS 20"CONDUCTOR H ? 13-318"WHPSTOC K(02/10/08) -{ 3250' 13-3/8"CSG,68#,L-80 BTC,ID=12.415" ---j -3274 FALLOUT WNDOW(NS-16A) 3250'-3274' Minimum ID =2"387" @ 13522` ! GAS LFT MANDRELS 4-1/2" X 2-7/8" XO ST MD TVD DEV TYPE VLV LATCH FORT DATE 4569 3976 50 MMG OMY RK 0 03/27/08 9-5/8"CSG,47#,L-80 513 HYDRA- -I 6831' }—X ?G XO TO L-80 BTC4 12178' --I 12199' H 7"X 5"BKR FLEX LOCK HGR,ID=6.200" 9-5/8"CSG,47#,L-80 BTC,D=8.681" H 12574' A O II I 13398' H4-1/2"FIBER OPTIC TRANSDUCER,D=3.958' , 13423' H 4-1/2"HES X NP,D=3.813" _2 X 13444' -17"X 4-1/2"BKR FREMER FKR,ID=3.875" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 13497' ' 13471' H4-1/2"I(2 X NP,D=3.813' .0152 bpf,ID=1958" 13479' -17"X 5"I-RD ZXP LTP w 117'PER,D=4.450" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, 13522' ' " 13483' H4-112"HES XN EVP,D=3.725" .0152 bpf,D=3.958" 1.---7-,3,7-8-F-1-14-1/2-SELF ALIGNNG MULE SHOE,ID 3.850" PERFORATION SUMMARY 13507' -I 7"X 5"BKR FLEXLOCK HGR,ID=4.40" RE=LOG: SWS-PDC ON 04/03/08 / 13516' H5"X 4-1/T X9 RP,ID=3.94" ANGLE AT TOP FERE:20'©14274' 13522' -14-112"X 2-7/8"XO,D=2.387" Note;Refer to Production DB for historical perf data SIZE SPF INTERVAL(M7) OpnlSgz SHOT SOZ 2" 6 14274-14304 0 06/12/084 H._ i 13685' -{7"X 5"BKR ZXP LTP w 1 12'RD=4.350" 2" 6 14274-14339 0 07/27/08 2" 6 14276-14296 0 07/04/08 13709' -j 7"X 5"BKR FLEX LOC K Hs D=4.370 2" 6 14289-14339 O 05/02/08 13718' H5"X 4-1/2"XO PLP,D=3.930" 2" 6 14295-14340 O 05/07/13 2" 6 14304-14339 0 04/05/08 7"LNR 29#,L-80 521 HY DRL, H 13850' .0371 bpf,D=6.184" , - 4-1/2"LNR 12.6#,L-80 521 HYDRL, -{ 14093' 0152 bpf,D=3.958" pBTD -1 14408' 2-7/8"LM 6.4#,13CR-80,.0058 bpf,ID=2.441" H14504' ..•A. DATE REV BY COMM3NTS DATE REV BY COMMENTS NORTHSTAR 07115/02 JAS IMT COMPLETION 03/29/09 ?/PJC UR CORRECTION WELL: NS16A 03/21/03 FM FiNAL COMPLETION 02/17/11 M3/JM7 ADDED SSSV SAFETY NOTE F MT No:'2061410 03/25/08 N33E SIDETRACK(NS-16A) 03/03/11 PJC DRAWNG CORRECTIONS API Na: 50-029-23096-01 07/09/08 W/VR(11H ADFERF&2-7/8"LNR CORRECT 05/22/13 SET/JM3 ADFERFS(05/07/13) SEC 11,T13N,R13E,1199'FSL&645'FEL 07/26/08 WWR/PJC DRLG DRAFT CORRECTIONS 09/05/08 WRWPJC PEES(07/27/08) STATE OF ALASKA . • ' _' ; ry ,' KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS ., d 1. Operations Abandon U Repair Well U Plug Perforations LJ Perforate U Other U M✓ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 1511 Exploratory ❑ 206 -141 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23096 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0312799 NSTR NS16A ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted NORTHSTAR, NORTHSTAR OIL • 11. Present Well Condition Summary: Total Depth measured 14505 feet ' Plugs measured None feet true vertical 11305.92 feet Junk measured None feet Effective Depth measured 14408 feet Packer measured See Attachment feet true vertical 11212.24 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 156 20" 169# X -56 45 - 201 45 - 200.92 4260 2590 Surface 3206 13 -3/8" 68# L -80 44 - 3250 44 - 2992.58 5020 2260 Intermediate None None None None None None Production 12531 9 -5/8" 47# L -80 43 - 12574 43 - 9564.6 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment ' f See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED JUL 0 3 20 True Vertical depth See Attachment feet I I Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 40 - 13522 40 - 10408.94 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" TRM -4E SSV 1024 1019.49 SSSV 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: 641 32595 877 0 751 Subsequent to operation: 653 34711 911 0 756 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorE❑ Development 0 ' Service ❑ Stratigraphic El Daily Report of Well Operations X 16. Well Status after work: Oil Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 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: 313 -017 Contact Nita Summerhays Email Nita.Summerha s • BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician /w/ Sig f i . Phone 564 -4035 Date 5/30/2013 1 --- 25 / RBDMS MAY 3 1 201. Form 10 -404 Revised 10/2012 Submit Original ` • • Daily Report of Well Operations ADL0312799 ** *WELL S/I ON ARRIVAL * ** (pre adperf) RIG UP SWCP DSL -1 SLICKLINE 3/13/2013 ** *CONTINUED ON 3/14/13 WSR * ** ** *JOB CONTINUED FROM 3/13/13 WSR * ** (pre adperf) ATTEMPTED SURFACE EQUIPMENT PRESSURE TEST - FAILING HIGH PRESSURE TEST LAID DOWN EQUIPMENT ON LOCATION TO HEAD HOME FOR HITCH AND C/O W/ INCOMING CREW FOR THE HITCH GREASE CREW TO SERVICE VALVES DURING DAY AND NEW CREW WILL RETURN IN PM TO DO DRIFT RUN ARRIVE BACK ON LOCATION - WINDS AT +45 MPH SO STANDBY FOR WINDS TO LET UP BEFORE PROCEEDING WITH JOB 3/14/2013 ** *WELL STILL FLOWING - CONT ON 3/15/13 WSR * ** ** *WELL FLOWING ON ARRIVAL*** (pre ELINE adperf) CURRENTLY RIGGING UP DSL #1 TO RUN DRIFT 3/16/2013 * * *CONT ON 03/17/13 WSR * ** * * *CONT FROM 03/16/13 WSR * ** (pre adperfs) DRIFTED W/ 11' x 2" DMY PERF GUN & 1 -1/2" S. BAILER TAG HARD BOTTOM @ 14,351' SLM. (no sample) (targeted depth = 14,340' MD) (NO ISSUES) 3/17/2013 ** *WELL LEFT S /I, WELL TENDER NOTIFIED * ** * ** JOB CONTINUED FROM 6- MAY - 2013 * ** (ELINE REPERF) GUN # 1 - 25' X 2" PJ 2006 HSD -- PERFORATED INTERVAL © 14,315' - 14,340' GUN # 2 - 20' X 2" PJ 2006 HSD -- PERFORATED INTERVAL @ 14,295' - 14,315' ALL DEPTHS REFERENCED TO SLB PDC LOG DATED 3- APR -08. TAGGED TD AT 14381. WALK THRU W/ DSO PRIOR TO DEPARTURE, VALVE CREW TO REMOVE AUX SWAB AFTER E -LINE MOVED OFF WELLAND OUT OF WAY. WELL LEFT SHUT IN UNTIL AFTER VALVE CREW DOES REPAIRS ON SSV FINAL T /I /O = 3800/0/0 5/7/2013 ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL Perforation Attachment ADL0312799 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NS16A 7/27/2008 RPF 14274 14276 11084.93 11086.8 NS16A 7/27/2008 RPF 14276 14279 11086.8 11089.62 NS16A 7/27/2008 RPF 14279 14289 11089.62 11099.02 NS16A 5/7/2013 RPF 14289 14295 11099.02 11104.67 NS16A 5/7/2013 APF 14295 14296 11104.67 11105.62 NS16A 5/7/2013 APF 14296 14299 11105.62 11108.44 NS16A 5/7/2013 APF 14299 14304 11108.44 11113.16 • NS16A 5/7/2013 APF 14304 14315 11113.16 11123.56 NS16A 5/7/2013 APF 14315 14319 11123.56 11127.34 NS16A 5/7/2013 APF 14319 14339 11127.34 11146.31 NS16A 5/7/2013 APF 14339 14340 11146.31 11147.26 BPS BRIDGE PLUG SET OH OPEN HOLE FCC FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • 1 Casing / Tubing Attachment ADL0312799 Casing Length Size MD TVD Burst Collapse CONDUCTOR 156 20" 169# X -56 45 - 201 45 - 200.92 4260 2590 LINER 1672 7" 26# L -80 12178 - 13850 9209.9 - 10702.1 7240 5410 LINER 982 2 -7/8" 6.4# 13CR80 13522 - 14504 10408.94 - 11305 10570 11160 LINER 408 4 -1/2" 12.6# L -80 13685 - 14093 10554.69 - 10919.6 8430 7500 PRODUCTION 12531 9 -5/8" 47# L -80 43 - 12574 43 - 9564.6 6870 4760 SURFACE 3206 13 -3/8" 68# L -80 44 - 3250 44 - 2992.58 5020 2260 TUBING 13482 4 -1/2" 12.6# 13Cr80 40 - 13522 40 - 10408.9 8430 7500 • 1111 • • • Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS16A SSSV 1024 963.57 4 -1/2" TRM-4E SSV NS16A PACKER 12178 9153.98 7" Baker ZXP Top Packer NS16A PACKER 13444 10283.27 4 -1/2" Baker Premier Packer NS16A PACKER 13479 10314.56 5" Baker ZXP Top Packer NS16A PACKER 13685 10498.77 5" Baker ZXP Top Packer W _ = / " MULT SKS 3OVVL I N S 16 A . WELLHEAD _ 13,.518• � �c S NOTES: WELL REQUIRES A SSSV. ACTUATOR = BAKER TBG 8 LNR""" INITIAL KB. ELE _ 56.46' I I BF ELEV = _.._ 40.56 (CB 159') 1 1024' H4 -112' Tt�M -4E SSSV NP, D = 3.812" I KOP - -- __ 100 Max Angle = 51° 7169' Datum ND= 13686' — — I 1587' H13-3/8" TAM POW COLLAR I Datum TVD = 10500' SS 1 H ? 1 113 -3/8" WHPSTOCK (02/10/08) H 3250' 113 -3/8" CSG, 681, L-80 BTC, 0= 1 2415' H - 3274 WILLOUT W ( 16A) 3250' - 3274' Minimum ID = 2.387" @ 13622' / GAS LIFT MANDRELS 4 -112" X 2-7/8" XO ST WD TVD DEV TYPE VLV LATCH FORT GATE 1 4569 3976 50 MMG 01W RK 0 03/27/18 9-5/8' CSG, 47#, L -80 513 WORK. --{ 6831' 1•-)G X XO TO L-80 BTC 12178' H9 -5/8" X 7' BKR ZXP LW 111' PBR, D = 62100° 1 12199' H 7' X 5" BKR FLEX LOCK HGR, D = 6.200' I 19 -518' CSG, 47 #, L -80 BTC, D = 8.681" H 12674 I a • 1 13398' H4 -1/2" FI3ER OPTIC TRANSDUCER, 13= 3.958" 1 1 13423' H4 -1/2" F EE X NP, D= 3.813" 1 1 1 C 13444" HT X 4-112' BKR PREMER FKR, D = 3.875' 1 4-1/2' TBG, 12.6 #,13CR -80 VAM TOP, H 1349T [ 13471' 4 I BS X N D = 3.813" .0152 bpf, D = 3.958" 13479' HT' X 5° HRD ZXP LIP w / 17' PBR, D = 4.450° I 4 TBG, 12.6 5, 13C1180 VAM TOP, -1 13522' I 13483' H4 -1/2" HES XN NP, D = 3.725' 1 .0152 bpf, D = 3.958' 13497' -{4 -112" SELF ALIGNING Mt1LE SHOE, D= 3.850' I St1MtiMRY 1350T HT X 5° BKR FLEX LOCK HGR, D = 4.40° 1 PEFFORAIDN REF LOG: SWS- PDC ON 04/03/08 13516' H 5" X 4-1/2" XO P. P, 0= 3.94' I ANGLE AT TOP PERF: 20" ',' 14274' 13522 H4 -1/2" X 2 -7/8' XO, D = 2.387" 1 Note: Refer to Reduction DB for historical pert data SIZE SW INTERVAL (MD) Opn/Sqz SHOT SOZ 2' 6 14274 - 14304 0 06/12/08 I 13685" Hr X 5" BKR ZXP LTP w / 12' PBR, D = 4.350" 1 2" 6 14274 - 14339 O 07/27/08 2" 6 14276 - 14296 O 07/04/08 13709 H 7' X 5- FLEX LOCK HGR, D = 4.370" I 2" 6 14289 -14339 0 05/02/08 13718 I-{5" x 4 -112 " XO PUP D = 3.930" 1 2" 6 14295 -14340 0 05/07/13 2" 6 14304 - 14339 0 04/05/08 ■ 7" LM , 29 5, 1-80 521 HY DRL, -{ 13850' • .0371 bpf, D = 6.184° 4-1/2' LNG 12.6 #, L-80 521 HYDRL, -1 14093' .0152 bpf, D = 3.958' PSTD 14408' I 12 -7/8" LNR, 6.4#, 13CR -80, .0058 bpf, D =2.441" H 14504' I ∎••�•�• GATE REV BY COMMENTS DATE REV BY COM :NTS NORTHSTAR 07/15/02 JAS IMT COMPLETION 03/29/09 ?/ PJC UR CORRECTION WELL: NS16A 03/21/03 FM RNAL COMPLETION 02/17/11 M3/JMD ADDED SSSV SAFETY NOTE PERMIT No: "2061410 03/25108 N33E SIDETRACK (NS -18A) 03/03/11 PJC DRAWING CORRECTIONS AR No: 50-029-23096-01 07/09/08 WWRITLH ADFB & 2 -7/8' LNR CORRECT 05/22/13 SET /JWD ADMITS (05/07/13) SEC 11, T13N, R13E, 1199' FSL & 645' FE. 07/26/08 VVWR/PJC DRLG DRAFT CORRECTIONS 09505/08 WRR/PJC PERFS (07/27/08) BP Exploration (Alaska) e,`",1// s THE STATE Alaska Oil Gas N'i ° f AA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O S / Anchorage, Alaska 99501 -3572 F ALAS Main: 907.279.1433 Fax: 907.276.7542 Mark Sauve SCANNED FEB 2 6 2013 Petroleum Engineer BP Exploration (Alaska), Inc. D ` / P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 313-017 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 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, al-e- Cathy . Foerster 4.---- Chair . DATED this da y of January, 2013. Encl. • • RECEIVED STATE OF ALASKA ,JA.J\1 .[ 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION / I // 3 07-j APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ p, Suspend ❑ Plug Perforations❑ Perforate 0 ' Pull Tubing ❑ Time Extension j� n., Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ , o 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development 0 Exploratory ❑ 206 -141-0 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23096 -01 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 458A �. t'-z NSTR NS16A . Will planned perforations require a spacing exception? Yes ❑ No Q %y rLI 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312799 • NORTHSTAR, NORTHSTAR OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 - 11306 • 14414 11218 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 156 20" Conductor 45 - 201 45 - 200.92 Surface 3206 13 -3/8" 68# L -80 44 - 3250 44 - 2992.58 5020 2260 Intermediate None None None None None None Production 12531 9 -5/8" 47# L -80 43 - 12574 43 - 9564.6 6870 4760 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# 13Cr80 13Cr80 40 -13522 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 4 -1/2" TRM-4E SSV 1024', 1019.49' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil 0 ' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark Sauve.@BP.Com Printed Name Mark Sauve Title PE Signature Phone 564 -4660 Date 1/14/2013 e? COMMISSION USE ONLY �7 Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 f, CJ t Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: ` 4- 0 2 -1- 4.,,e4v41., APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: f ,. 2.2 ' 3 0 Fini.,61 e / 10 Approved application is valid for 12 months f rom e d a I JAN t Submit in Duplicate t �`� A 1 1 /111/3 'ra,/) ' • • PERFORATING PROCEDURE Ver 4 0 06/04/01 ROW 1,11110411111111111111111111 Well: NS16A API #: 50- 029 - 23096 -01 Date: 1/10/13 Prod Engr Mark Sauve Office Ph: 564 -4660 H2S Level: Home Ph: 336 -6128 None Anticipated Cell Ph: 748 -2865 CC or AFC: ANSPERFS Detail Code: Description: Drift to TD & Re- Perforate 45' ✓ WBL Entries IOR Type Work Description 75 S Drift to TD with 2" Dummy Gun 75 E Re -pert 45' per the below procedure. Well Obiectives and Logging Notes: NS16A was sidetracked from the original wellbore in 2008 and had an initial rate of -2500 bopd. The well has a long history of successful stimulations & re -perfs. This program is part of an ongoing effort to stimulate various Northstar wells that appear to be suffering a loss of PI. . Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Attachment: Reference Log with annotated perforations. Reference Log Tie in Log Add /Subtract feet Log: PDC GR /CCL to the tie -in log to be on Date: 4/3/2008 depth with the reference log. Company: Schlumberger Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re /lperf 14,295' - 14,340' - 45' 6 60° 0 Ivishak Re 0 0 - 0 Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2" Charge: 2006 PJ Desired Penetration: 21.8 Entry Hole Diam: 0.22 Is Drawdown Necessary/Desired /Unnecessary During Perforating NA Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie into GR from annotated reference log Tie in using: Schlum PDC log GR/CCL dated 4/4/08 Minimum ID: 2.400 in Min ID Type: 4.5" x 2.875" crossover @ 13527' 'MD 2 -7/8" Liner Top: 13505' ft MD Casing Size: 2.441 in 2 -7/8" Liner Est Res. Pres. @ 14,350 MD 11100' SS 5,121 psi Last Tag: 14330' SLMD ft 11/16/2011 with static pressure gauges Well: NS16A Perforation Summary Date: API #: 50- 029 - 23096 -01 On -Site Prod Engr: PBTD General Comments: Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf 0/B/U - 0 0/B/U - O ............. 0/B/U - O ................ 0/B/U - O 0/B/U - • • Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS16A 7/27/08 RPF 14274 14276 11085 11087 NS16A 7/27/08 RPF 14276 14279 11087 11090 NS16A 7/27/08 RPF 14279 14289 11090 11099 NS16A 7/27/08 RPF 14289 , 14296 11099 11106 NS16A 7/27/08 RPF 14296 14299 11106 11108 NS16A 7/27/08 RPF 14299 14304 11108 11113 NS16A 7/27/08 RPF 14304 14319 11113 11127 NS16A 7/27/08 RPF 14319 , 14339 11127 11146 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF ' • 0 Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS16A SSSV 1024 4 -1/2" TRM -4E SSV 1019 NS16A PACKER 12178 7" Baker ZXP Top Packer 9210 NS16A PACKER 13444 4 -1/2" Baker Premier Packer 10339 NS16A PACKER 13479 5" Baker ZXP Top Packer 10370 NS16A PACKER 13685 5" Baker ZXP Top Packer 10555 ' r Casing Summary ADLO312799 Casing Length Size MD Top MD Base TVD Top ND Base Burst Collapse Grade CONDUCTOR 156 20" Conductor 45 201 45 201 LINER 1672 7" 26# L -80 12178 13850 9210 10702 7240 5410 L -80 LINER 408 4 -1/2" 12.6# L -80 13685 14093 10555 10920 8430 7500 L -80 LINER 982 2 -7/8" 6.4# 13CR8C 13522 14504 10409 11305 10570 11160 13CR80 PRODUCTION 12531 9 -5/8" 47# L -80 43 12574 43 9565 6870 4760 L -80 SURFACE 3206 13 -3/8" 68# L -80 44 3250 44 2993 5020 2260 L -80 TUBING 13482 4 -1/2" 12.6# 13Cr8C 40 13522 40 10409 8430 7500 13Cr80 III • ■ TREE = , ABB-VGI 5-1/8" 5KSI • SOY NOTES: WELL 1 " ' WELLHEAD = 13-5/8" MULTIBOWL 5KSI N S 16A mCHROMETBG & LNR"** REQUIRES A SSSV. ACTUATOR = BAKER KB. ELEV = 56.46' I BF. ELEV = 40.56' (CB 15.9') • I 1024' 1� 4 -1/2" TRM-4E SSSV NIP, ID = 3.812" 1 KOP = 100' Max Angle = 53° @ 7169' Datum MD = 13686' I 1587' H 13 -3/8" TAM PORT COLLAR Datum TVD = 10500' SS 120" CONDUCTOR I ? 113 -3/8" WHIPSTOCK (02/10/08) H 3250' 13 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H -3274 I MILLOUT WINDOW (NS -16A) 3250' - 3274' Minimum ID = 2.387" @ 13522' GAS LIFT MANDRELS 4 -1/2" X 2 -7 /8" XO ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4569 3976 50 MMG DMY RK 0 03/27/08 9 -5/8" CSG, 47 #, L -80 513 HYDRIL -I 6831' 1- X XO TO L -80 BTC 12178' (-I -5/8" X 7" BKR ZXP LW w / 11' PBR, ID = 6.200" I 12199' H 7" X 5" BKR FLEX LOCK HGR, ID = 6.200" I 19 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" H 12574' I IL ` 13398' H 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I ' 13423' H 4-1/2" HES X NIP, ID = 3.813" I X I 13444' 1-17" X 4-1/2" BKR PREMIER PKR, ID = 3.875" 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -I 13497' I 13471' 1- 1 4 -1/2" HES X NIP, ID = 3.813" .0152 bpf, ID = 3.958" 13479' 1-1 7" X 5" HRD ZXP LW w / 17' PBR, ID = 4.450" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -1 13522' ' 1 13483' H 4-1/2" HES XN NIP, ID = 3.725" I .0152 bpf, ID = 3.958" 13497' -- 14 -1 /2" SELF ALIGNING MULE SHOE, ID = 3.850" I 13507' H 7" X 5" BKR FLEX LOCK HGR, ID = 4.40" PERFORATION SUMMARY /-.....„ ..............1 13516' 1-15" X 4-1/2" XO PUP, ID = 3.94" I REF LOG: SWS- PDC ON 04/03/08 13522' 1- -I 4 -1/2" X 2 -7/8" XO, ID = 2.387" ANGLE AT TOP PERF: 20 ° @ 14274' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2" 6 14274 - 14304 0 06/12/08 Ili I-17" X 5" BKR ZXP LTP w / 12' PBR, ID = 4.350" I 2" 6 14274 - 14339 0 07/27/08 13709' H 7" X 5" BKR FLEX LOCK HGR, ID = 4.370" I 2" 6 14276 - 14296 0 07/04/08 13718' H 5" X 4-1/2" XO PUP, ID = 3.930" I 2" 6 14289 - 14339 0 05/02/08 2" 6 14304 - 14339 0 04/05/08 7" LNR, 29 #, L -80 521 HYDRIL, H 13850' 7 .0371 bpf, ID = 6.184" , - 4 -1/2" LNR, 12.6 #, L -80 521 HYDRIL, -1 14093' .0152 bpf, ID = 3.958" PBTD -1 14408' I • � • � • � 12 -7/8" LNR, 6.4 #, 13CR -80, .0058 bpf, ID = 2.441" H 14504' I �• ■ 4 DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/15/02 JAS INIT COMPLETION 03/29/09 ?/ PJC LNR CORRECTION WELL: NS16A 03/21/03 FM FINAL COMPLETION 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 2061410 03/25/08 N33E SIDETRACK (NS -16A) 03/03/11 PJC DRAWING CORRECTIONS API No: 50- 029 - 23096 -01 07/09/08 WWR/TLH ADPERF & 2 -7/8" LNR CORRECTION SEC 11, T13N, R13E, 1199' FSL & 645' FEL 07/26/08 WWR/PJC DRLG DRAFT CORRECTIONS 09/05/08 WRR/PJC PERFS (07/27/08) I BP Exploration (Alaska) • • a5 � ALAZIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mark Sauve Wells Intervention Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 312 -007 SLAMMED IA 2 6 I {JtL 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 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 23r nP king day if the 23rd day falls on a holiday or weekend. l V V V 1 1 the V a day Daniel T. Seamount, Jr. Chair DATED this /v day of January, 2012. Encl. STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIO v ,,1� APPLICATION FOR SUNDRY APPROVALS, ## JAN 5 2012 /"9.41 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ ' ° ".::Chan* pi 1 1. 61411MiOrl Suspend ❑ Plug Perforations ❑ Perforate El - Pull Tubing ❑ I , 3 r , lintrieExtension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0 Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Ei _ Exploratory ❑ 206 -1410 " 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23096 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ NS16A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO - 312799 - NORTHSTAR Field / NORTHSTAR OIL Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 - 11305.92. 14414 11218 • NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 156' 20" 45 201 45 201 Surface 3206' 13 -3/8" 68# L -80 44 3250 44 2993 4930 2270 Production 12531' 9 -5/8" 47# L -80 43 12574 43 9565 6870 4760 Liner 1672' 7" 26# L -80 12178 13850 9210 10702 7240 5410 Liner 1672' 4 -1/2" 12.6# L -80 13685 14093 10555 10920 8430 7500 Liner 408' 2 -7/8" 6.4# 13CR80 13522 14504 10409 11305 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13Cr80 40 13522 Packers and SSSV Tvoe: 4 -1/2" TRM -4E SSSV Packers and SSSV MD and TVD (ft): 1024 1019 7" Baker ZXP Top Packer 12178 9210 4 -1/2" Baker Premier Packer 13444 10339 5" Baker ZXP Top Packer 13479 10370 5" Raker 7XP Ton Packer 13885 10555 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Si , Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/19/2012 Oil D Gas ❑ WDSPL p Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title PE Signature /� /% Phone Date z "Z m 564 -4660 1/5/2012 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY � Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 [ f �•` 0113- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: l i- f0 1 APPROVED BY / . Approved tl f ' A COMMISSIONER THE COMMISSION Date: / /(`1 1 1 F 1-40 Revised 172610 10 1• LO R 1 G 1 N A L �/ submit in Duplicate NS16A 206 -141 PERF ATTACHMENT .. Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A 4/30/08 APF 14,289. 14,339. 11,099.02 11,146.31 NS16A 5/1/08 RPF 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 RPF 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/08 RPF 14,276. 14,296. 11,086.8 11,105.62 NS16A 7/27/08 RPF 14,274. 14,279. 11,084.93 11,089.62 NS16A 7/27/08 RPF 14,279. 14,289. 11,089.62 11,099.02 NS16A 7/27/08 RPF 14,289. 14,299. 11,099.02 11,108.44 i NS16A 7/27/08 RPF 14,299. 14,319. 11,108.44 11,127.34 NS16A 7/27/08 RPF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 'Aka PERFORATING PROCEDURE Ver 4 0 06/04/01 HDIU pN 111MMONN ONUS Well: NS16A API #: 50- 029 - 23096 -01 Date: 1/3/12 Prod Engr Mark Sauve Office Ph: 564 -4660 H2S Level: Home Ph: 336 -6128 None Anticipated Cell Ph: 748 -2865 CC or AFC: ANSFLDWLI6 Detail Code: Description: Drift to TD & Re- Perforate 35' WBL Entries IOR Type Work Description 75 S Drift to TD with 2" Dummy Gun 75 E Re -pert 45' per the below procedure. Well Obiectives and Logging Notes NS16A was sidetracked from the original wellbore in 2008 and had an initial rate of -2500 bopd The well has a long history of successful stimulations & re- perfs. This program is part of an ongoing effort to stimulate various Northstar wells that appear to be suffering a loss of PI. Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Attachment: Reference Log with annotated perforations. ✓ Reference Log Tie in Log Add /Subtract feet Log: PDC GR /CCL to the tie -in log to be on Date: 4/4/2008 depth with the reference log. Company: Schlumberger Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re /Iperf 14,295' - 14,340' - 45' 6 60° 0 Ivishak Re 0 0 0 Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2" Charge: 2006 PJ Desired Penetration: 21.8 Entry Hole Diam: 0.22 Is Drawdown Necessary/Desired /Unnecessary During Perforating NA Descnbe below how to achieve drawdown (check w/ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie into GR from annotated reference log Tie in using: Schlum PDC log GR /CCL dated 4/4/08 Minimum ID: 2.400 in Min ID Type: 4.5" x 2.875" crossover @ 13527' 'MD 2 -7/8" Liner Top: 13505' ft MD Casing Size: 2.441 in 2 -7 /8" Liner Est Res. Pres. @ 14,350 MD 11100' SS 5,121 psi Last Tag: 14330' SLMD ft 11/16/2011 with static pressure gauges Well: NS16A Perforation Summary Date: API #: 50- 029 - 23096 -01 On -Site Prod Engr: PBTD .... ............................... General Comments: Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf O /B /U - O O /B /U - O O /B /U - O O /B /U - O O /B /U - 0 TREE ABB -VGI5 1/8" 5KSI • N S 16A SA CETOM & E L. REQUIRES A SSSV. WELLHEAt3 = 13 -5/8" MULTIBOWL 5KSI ACTUATOR = BAKER KB. ELEV = 56.46' ' BF. ELEV = 40.56' (CB 15.9') 1 1024' I- 14 -1/2" TRM-4E SSSV NIP, ID = 3.812" 1 KOP = 100' Max Angle = 53° @ 7169' Datum MD = 13686' 1 1587' 1-113-3/8" TAM PORT COLLAR 1 Datum TV D = 10500' SS 120" CONDUCTOR 1 ? 13 -3/8" WHIPSTOCK (02/10/08) 1— 3250' 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" 1-1 '-3274 MILLOUT WINDOW (NS -16A) 3250' - 3274' Minimum ID = 2.387" @ 13522' � GAS LIFT MANDRELS 4 -1/2" X 2 -7/8" XO ST MD TVD DEV TYPE VLV LATCH PORT DATE LI 1 4569 3976 50 MMG _ DMY RK 0 03/27/08 9 -5/8" CSG, 47 #, L -80 513 HYDRIL -1 6831' 1--?C >G XO TO L -80 BTC 12178' 1 1 9 5/8" X 7" BKR ZXP LTP w / 11' PBR, ID = 700" " 1 12199' 1-1 7" X 5" BKR FLEX LOCK HGR, ID = 6.200" 19 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" 1-1 12574' 1-J 1 13398' H4 -1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 1 13423' — I4 -1/2" HES X NIP, ID = 3.813" 1 2 C, 13444' H7" X 4 -1/2" BKR PREMIER PKR, ID = 3.875" 1 4 -1/2" TBG, 12.6 #, 13C R-80 VAM TOP, -1 13497' 13471' 1- 14 -1/2" HES X NIP, ID = 3.813" 1 .0152 bpf, ID = 3.958" 13479' 1-17" X 5" HRD ZXP LTP w / 17' PBR ID = 4.450" 1 4 -1/2" TBG, 12.6 #, 13C R-80 VAM TOP, -1 13522' 13483' H4 -1/2" HES XN NIP, ID = 3.725" 1 .0152 bpf, ID = 3 13497 --14 -1/2" SELF ALIGNING MULE SHOE, ID = 3.850" 1 13507' 1-17" X 5" BKR FLEX LOCK HGR, ID = 4.40" 1 PERFORATION SUMMARY 13516' H 5" X 4 -1/2" XO PUP, ID = 3.94" 1 REF LOG: SWS- PDC ON 04/03/08 13522' 1- 14 -1/2" X 2 -7/8" XO, ID = 2.387" 1 ANGLE AT TOP PERF: 20 ° @ 14274' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2" 6 14274 - 14304 0 06/12/08 / 13685' 1--17" X 5" BKR ZXP LTP w / 12' PBR, ID = 4.350" 1 2" 6 14274 - 14339 0 07/27/08 13709' 1--17" X 5" BKR FLEX LOCK HGR, ID = 4.370" 1 2" 6 14276 - 14296 0 07/04/08 13718' 1-15" X 4 -1/2" X0 PUP, ID = 3.930" 1 2" 6 14289 - 14339 0 05/02/08 2" 6 14304 - 14339 0 04/05/08 7" LNR, 29 #, L -80 521 HYDRIL, -1 13850' ' .0371 bpf, ID = 6.184" 4 -1/2" LNR, 12.6 #, L -80 521 HYDRIL, -1 14093' 1 .0152 bpf, ID = 3.958" PBTD --1 14408' 1 J i •• 12 -7/8" LNR, 6.4 #, 13C -80, .0058 bpf, ID = 2.441" 1 l 14504' 1 �• • •1 DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/15/02 JAS INIT COMPLETION 03/29/09 ?/ PJC LNR CORRECTION WELL: NS16A 03/21/03 FM FINAL COMPLETION 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 2061410 03/25/08 N33E SIDETRACK (NS -16A) 03/03/11 PJC DRAWING CORRECTIONS API No: 50- 029 - 23096 -01 07/09/08 WWR/TLH ADPERF & 2 -7/8" LNR CORRECTION SEC 11, T13N, R13E, 1199' FSL & 645' FEL 07/26/08 WWR/PJC DRLG DRAFT CORRECTIONS 09/05/08 WRR/PJC PERFS (07/27/08) BP Exploration (Alaska) p :~ ~~, #~ ,~~ ~, , ~~ T >~~: R . 9 s . ~~ ~ ~ ~"~ ~~` ,~ ~~~ ;_ t.. h'~~ ~ -., ~.. 5.~ 1 ~ MICROFILMED 6/30/2010. DO NOT PLACE ANY NEW MATERIAL -UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~EC~IVED Mr. Tom Maunder Alaska Oil and Gas Conservation Commission P1AY ~ ~ ~~~~ 333 West 7th Avenue ~&'a~~s~~+'' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar ~ ~~~- ~ (,~-' Dear Mr. Maunder, ~~J " Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar ai~n/~n1 n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30!2009 NS08 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 .50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. DATA SUBMITTAL COMPLIANCE REPORT 5/24/2010 Permit to Drill 2061410 Well Name/No. NORTHSTAR UNIT NS-16A Operator BP EXPLORATION (ALASKA INC API No. 50-029-23096-01-00 MD 14505 ND 11306 Completion Date 4/5/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~ DATA INFORMATgN Types Electric or Other Logs Run: MWD, GYRO, GR, RES, DIR, PWD, DEN, NEU (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / meairrm[ rvumu~r Name aGQIC ir~CUia rvo aiarz atop ~.n Recervea ~.vrnmenw D Asc ~ Directional Survey 0 14505 Open 4/4!2008 Directional Survey 0 14505 Open 4/4/2008 Induction/Resistivity 5 Blu 14056 14400 Case 4/25/2008 Slim Formation Resisitivty tool, SFRT, GR, Pres, Temp, 3-Apr-2008 Perforation 5 Blu 14200 14400 Case 4/25/2008 Pert, SBHP, Pres, Temp, GR, CCL from WPPT 5- Apr-2008 Reservoir Saturation 5 Blu 14000 14403 Case 4/25/2008 RST - C in Sigma 4-Apr- 2008 C Lis 16152~eservoirSaturation 5 13948 14421 Case 4/25/2008 GR, RST Perforation 5 Blu 0 14410 Case 4/25/2008 SFRT, GR, Pres, Temp, Pref Depth Control 3-Apr- 2008 C Lis 16153 /Gamma Ray 2 14414 Case 4/25/2008 LIS Veri, CFRT, GR C Lis 16154~nduction/Resistivity 270 14512 Open 4/25/2008 OH Suite plus PDS of Final, CAL, MWD, RAB Induction/Resistivity 2 Col 14000 14400 Case 4/25/2008 Cased Hole Resistivity, GR C 16155 Induction/Resistivity 0 0 Case 4/25/2008 PDS of FinaI,SFRT C Pds 16151+~Perforation 0 0 Case 4/25/2008 Perf ReGSBHP, SFRT, Mem Depth Log all in PDS graphics •I DATA SUBMITTAL COMPLIANCE REPORT 5/2412010 Permit to Drill 2061410 Well Name/No. NORTHSTAR UNIT NS-15A Operator BP EXPLORATION (ALASF(A) INC API No. 50-029-23096-01-00 MD 14505 TVD 11306 Completion Date 4/5/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ~g Casing collar locator 5 Blu 13300 14408 Case 4/25/2008 MDD, GR, CCL in Carrier 2- Apr-2008 ~g Caliper log 2 Blu 8600 12575 Case 4/25/2008 MD Density Caliper Log 20- Feb-2008 >g Dip 2 Blu 5600 12575 Open 4/25/2008 TVD RAB Images 2-Feb- 2008 ~g Dip 2 Blu 5600 12575 Open 4/25/2008 MD RAB Images 2-Feb- 2008 >g Induction/Resistivity 5 Blu 3250 14466 Open 4/25/2008 MD Vision Service 17-Mar- 2008 ~g Induction/Resistivity 5 Blu 3250 14466 Open 4/25/2008 TVD Vision Service 17-Mar- 2008 ~g Perforation 5 Blu 14200 14400 Case 6/4/2008 Perf Record wGR, CCL 1- May-2008 ~ D C Pds 16363'~Perforation 14200 14400 Case 6/4/2008 Perf Record wGR, CCL 1- May-2008 D C Pds 16573~erforation 14150 14350 Case 7/10/2008 Perf Record wGR, CCL 12- Jun-2008 ~ >g Perforation 5 Blu 14150 14350 Case 7/10/2008 Perf Record wGR, CCL 12- II Jun-2008 CULLED ~g Perforation 5 Blu 14100 14376 Case 7/29/2008 Perf Record, GR CCL 2: Powerjet HSD 4-Jul-2008 D C Pds 16658'~Perforation 14100 14376 Case 7/29!2008 Perf Record, GR CCL 2: Powerjet HSD 4-Jul-2008 / D C Pds Perforation 16833' 14150 14376 Case 9/2/2008 Perf Record, GR CCL 2: Powerjet HSD 26-Jul-2008 ~g Perforation 2 Blu 1 14150 14376 Case 9/2/2008 Perf Record, GR CCL 2: Powerjet HSD 26-Jul-2008 ~g Production 5 Blu 14180 14350 Case 10/14/2008 PPL, Pres, Temp, Gradio, Spin, Deft, Ghost 16-Sep- 2008 D C Pds 17193 Production 14180 14350 Case 10/14/2008 PPL, Pres, Temp, Gradio, Spin, Deft, Ghost 16-Sep- 2008 DATA SUBMITTAL COMPLIANCE REPORT 5/24/2010 Permit to Drill 2061410 Well Name/No. NORTHSTAR UNIT NS-16A Operator BP EXPLORATION (ALASt~ INC API No. 50-029-23096-01-00 MD 14505 TVD 11306 Completion Date 4/5/2008 Completion Status 1-OIL Current Status 1-OIL UIC N og Production 5 Blu 14182 14366 Case . 10/14/2008 Mem PPL, Pres, Temp, Gradio, Spin, Deft, Ghost 12-Sep-2008 tED C Pds 17194~roduction 14182 14366 Case 10/14/2008 Mem PPL, Pres, Temp, Gradio, Spin, Deft, Ghost 12-Sep-2008 ~ ED C Pds 17266' Production 14190 14390 Case 12/10/2008 PPL, Pres, Temp, Gradio, Ghost, ILS, FBS, Deft 20- Oct-2008 og Production 2 Blu 14190 14390 Case 12!10/2008 PPL, Pres, Temp, Gradio, Ghost, ILS, FBS, Deft 20- i Oct-2008 Rpt Production Case 12/10/2008 PPL Interpretation with Ghost and Deft 1-Oct-2008 D C Pdf 17268 v~roduction Case 12/10/2008 PPL Interpretation with Ghost and Deft 1-Oct-2008 bg Production 2 Blu 11150 11390 Case 3/2/2009 PPL w/Deft and Ghost, Pres, Temp, Gradio, Spin 12-Feb-2009 ~~ D C Pds ~ 17676 "Production 11150 11390 Case 3/2/2009 PPL w/Deft and Ghost, Pres, Temp, Gradio, Spin 12-Feb-2009 i pt 17699 ~e Notes 0 0 Case 3/18/2009 PL Advisor, PLI w/Ghost and Deft and w/Word data on disk og Production 2 Blu 14200 14365 Case 5/1/2009 PPL w/Deft and Ghost, Pres, Temp, GR, CCL, Gradio, Spin 20-Apr-2009 D C Pds 17933`~Production 14200 14365 Case 5/1/2009 PPL w/Deft and Ghost, Pres, Temp, GR, CCL, Gradio, Spin 20-Apr-2009 D C Las 18768 ~urvey -Misc 0 899 Case 10!12!2009 Stat Survey, Temp Rpt Survey -Misc 0 Case 10/12/2009 Stat Temp, Pres Survey • DATA SUBMITTAL COMPLIANCE REPORT 5/24/2010 Permit to Drill 2061410 Well Name/No. NORTHSTAR UNIT NS-16A Operator BP EXPLORATION (ALASK/~ INC API No. 50-029-23096-01-00 14505 TVD 11306 Completion Date 4/5/2008 GompleUOn Status 7-VIL current Status ~-vii uic rv pt - 193801 orrosion - 0 14380 Case 2/24/2010 Mem Multi Finger Cali Log ~ Results Summ w/3D PDS graphics D C 19380~Corrosion 0 14380 Case 2/24/2010 Mem Multi Finger Cali Log i Results Summ w/3D PDS graphics ~ D C Pdf 17699 See Notes 0 0 Case 3/18/2009 PL Advisor, PLI w/Ghost and Deft Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? l~~ i Chips Received? =",-;-;:~ Analysis ~.1+F- Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~N Formation Tops ~ N Comments: Compliance Reviewed By: ~ Date: _ _~, -1~~ ~ ~ STATE OF ALASKA ~ ~ V ~ I ~/ L L.~ ALASKA AND GAS CONSERVATION COMMISS~ ~o REPORT OF SUNDRY WELL OPERATIONS ~Z1 APR 2 6 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 ~`~p r Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ / 'Time Exte~n Gab ~'IS. CQfT1ff11SS101 Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ gnC~t(~'~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 206-1410 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 8. Property Designation (Lease Number) : ` 9. Well Name and Number: , ~ ADLO-312799 NS16A 10. Field/Pool(s): ~ NORTHSTAR FIELD / NORTHSTAR OIL POOL 11. Present Well Condition Summary: Total Depth measured 14505 feet Plugs (measured) None feet true vertical 11305.92 feet Junk (measured) None feet Effective Depth measured 14414 feet Packer (measured) 13444 true vertical 11218 feet (true vertical) 10339 Casing Length Size MD TVD Burst Collapse Structural Conductor 201 20" surface - 201 surface - 201 4620 2590 Surface 3208 13-3/8"68# L-80 surface - 3250 surface - 2993 4930 2270 Production 12533 9-5/8" 47# L-80 surface - 12574 surface - 9565 6870 4760 Liner 1072 7" 29# L-80 12178 - 13850 9210 - 10702 7240 5410 Liner 408 4-1/2" 12.6# L-80 13685 - 14093 10555 - 10920 8430 7500 Liner 1024 2-7/8" 6.6# L-80 13479 - 14503 10370 - 11304 10570 11160 Perforation depth: Measured depth: see attached - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 0 - 13522 0 - 10409 Packers and SSSV (type, measured and true vertical depth) 7"x4-1/2" baker s-3 perm okr 13444 10339 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: 1061 24255 963 753 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-041 Contact Gary Preble Printed Name Gary P E61e Title Data Management Engineer Signature Phone 564-4944 Date 4/23/2010 vain w--rv-~ ~ncvwcu ~~wvo RBDMS AI'K ~ 7 aU ~~~..... ~..~..._. ~..., Y-271o ~~ ~i~' NS16A 206-141 DGDG ATTA(_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A 4/30/08 APF 14,289. 14,339. 11,099.02 11,146.31 NS16A 5/1/08 RPF 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 RPF 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/08 RPF 14,276. 14,296. 11,086.8 11,105.62 NS16A 7/27/08 RPF 14,274. 14,279. 11,084.93 11,089.62 NS16A 7/27/08 RPF 14,279. 14,289. 11,089.62 11,099.02 NS16A 7/27/08 RPF 14,289. 14,299. 11,099.02 11,108.44 NS16A 7/27/08 RPF 14,299. 14,319. 11,108.44 11,127.34 NS16A 7/27/08 RPF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • NS16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/16/2010 CTU #5 w / 1.75" ct Job Scope: Log for depth control /Mud Acid & SIT w/ Stim Pkr. STBY for decision from town to start job due to plant being down. Load well w/ 200 bbls 3% NH4cL and 70 bbls of diesel. RIH w/ PDS 2.2" gauge carrier w/ GR jand CCL inside. ""job continued on WSR 04-17-10*'" 4/17/2010. ~__ CTU #5 w/ 1.75" CT Scope; Log for depth control/ Mud Acid & SIT w/ Stim PKR. Continue RIH w/ PDS logging tools inside 2.2" carrier. Tag TD @ 14366' up wt. Flag pipe @ 14300', log 50 fpm to 14000' pooh. RIH w /baker 2.13" retrievable Packer. POOH packer failed to set. RBIH w /packer #2 drop 1/2" aluminum ball,set packer @ 14295, establish infectivity thru packer. launch 5/8" steel ball, good indication of sleeve shifting. Continue pumping NH4CL to cool perfs. ""Job continued on WSR 04-18-10** 4/18/2010~CTU #5 w/ 1.75" CT Scope; Mud Acid & SIT w/ Stim PKR. Continue pumping NH4CL to cool perfs, pump Mud Acid schedule per procedure. Release packer ~ POOH. ««<Job is complete»»> 4/18/2010 T/I/0=400/0/0. (Acid treatment) Spear into FL w/ 2 bbls neat meth followed by 164 bbls Mag-Ox down FL to neutralize acid during flowback. FWHP=750/0/0. FLUIDS PUMPED BBLS 11 60/40 METH 200 3% NH4CL W/F-103 AND SAFELUBE 164 MAG-OX 70 DIESEL 445 Total N S 16A $ ~' ***CHROME TBG $~ LNR*k* ~~ 1024_-~4-1/2"TRM•4ESSSV NIP, ID=3.812" 15$7' I-I 13-3/8" TAM PORT COLLAR 113-318" WHIPSTOCK (02/10108) 113-3i8" EZSV (02110/08) 9-5/8" CSG STUB (02/07/08} I~ D =312.415G, 68#, L-80 BTC 3494' 9-5/8" EZSV 3670' ""' (01/29/08) \ 9-5i8" CSG, 47#, L-80 513 HY DRIL XO TO L-80 BTC 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" Minimum ID = 2.387" @ 13522' 4-1 /2" X 2-7/8" XO 4-1/2" TBG, 12.6 #, 13CR 80 VAM TOP, -~ .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6 #, 13CR 80 VAM TOP, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: SWS- PDC ON 04/03/08 ANGLE AT TOP PERF: 20 ° @ 14274' Note: Refer to Production DB for historical perf data SSE SPF INTERVAL (MD) Opn/Sqz DATE 2" 6 14274 - 14304 O 06/12/08 2" 6 14274 - 14339 O 07/27/08 2" 6 14276 - 14296 O 07/04/08 2" 6 14289 - 14339 O 05/02/08 2" 6 14304 - 14339 O 04/05/08 7" LNR 29 #, L-80 521 HYDRl., .0371 bpf, ID = 6.184" 4-1/2" LNR, 12.6 #, L-80 521 HYDRE, .0152 bpf, ID = 3.958" 2-718" LNR 6.4#, 13CR-80, .0058 bpf, ID = 2.441" MILLOUT WINDOW (NS-16A) 3250' - 3274' GAS LET' MANDRELS V TYPE VLV LATC ~ MMG DMY ~RK 12178' -j 9-5/8" X 7" BKR ZXP LTP w / 11' PBR ID = 6.200" 121 7" X 5" BKR FLEX LOCK HGR ID = 6.200" 1339$' -'4-112" FIBER OP)lC TRANSDUCER ID = 3.958" 13423' 4-112" HES X NIP, ID = 3.813" 13444' 7" X 4-1/2" BKR PRBvIIER PKR ID = 3.$75" 13471' 4-1/2" HES X NIP, ~ = 3.813" 13479' 7" X 5" HRD ZXP LTP w / 17' PBR ~ = 4.450" 13483' 4-1/2" HES XN Ni', ~ = 3.725 13497' 4-112" SELF ALIGN~VG MULE SHOE, ~ = 3.850" 13507 7" X 5" BKR FLEX LOCK HGR, ID = 4.40" 13516' - ~ 5"X 4-1/2" XO PUP, ~ = 3.94" 13522' 4-1/2" X 2-718" XO, ID = 2.387" 13685' --) 7" X 5" BKR ZXP LTP w / 12' PBR, ~ = 4.350" 13709' 7" X 5" BKR FLIX LOCK HGR, D = 4.370" 13718' 5" X 4-1/2" XO PUP, ID = 3.930" I PBTD I 14504' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/02 JAS INIT COMPLETION 07/09/08 WWR/TL ADPERF & 2-718" LNR CORRECT~h 03!21103 FM FlNAL COMPLETION 07/26/08 WWR/PJ DRLG DRAFT CORRECTK~NS 03125!08 N33E SIDETRACK (NS-16A} 09/05108 WRR/PJC PERFS (07/27/08) 04/18/08 f11H GLV C10? (03/27/08) 03/29/09 ?/ PJC LNR CORRECTION 05/02(08 JLJ(TLH ADPERFS 07/05/08 ?1 PJC DRLG DRAFT CORRECTIONS NORTHSTAR WELL: NS16A PERMIT No: a2061410 API No: 50-029-23096-01 SEC 11. T13N. R13E 1199' FSL & 645' FEL BP Exploration (Alaska) TREE= ABB-VGI5-1/8" 5KSI ~. Mr. Jack Lau Well Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 310-041 Dear Mr. Lau: ~06-1~ ~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ~ day of February, 2010 Encl. STATE OF ALASKA UJJ-..'~g~l~ ~ R ~j ALAS~IL AND GAS CONSERVATION COMMISSI~ ~ '~0 " -~ ` ~~~~~ APPLICATION FOR SUNDRY APPROVALS ~~~ ~E~ ~. 2 2010 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^ A'a~~~q~r Alter casing ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ sion ^ a~ll~ . Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate0 ~ Alter Casing ^ Other: ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^, Exploratory ^ 206-1410 . 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ~ Spacing Exception Required? Yes ^ No ^ NS16A - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-312799 ' NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 ~ 11305.92 - 14414 - 11218 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201 20" Surface 201 Surface 201 4260 2590 Surtace 3208 13-3/8"68# L-80 Surtace 3250 Surface 2993 4930 2270 Production 12533 9-5/8" 47# L-80 Surface 12574 Surface 9565 6870 4760 Liner 1072 7"29# L-80 12178 13850 9210 10702 7240 5410 Liner 408 4-1/2" 12.6# L-80 13685 14093 10555 10920 8430 7500 Liner 1024 2-7/8" 6.6# L-80 13479 14503 10370 11304 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13Cr80 0 13497 Packers and SSSV Tvoe: 7"x4-1/2" baker s-3 perm pkr Packers and SSSV MD and TVD (ft): 13444 10339 4-1/2" SSSV 1024 1019 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/25/2010 Oil ^~ - Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby ce ify that the forego is true and co ect to the best of my knowledge. Contact Jack Lau Printed Nam Jack au Title Well Engineer Signatu Phone Date 564-5102 2/11/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY N b S d ~j /~ / /O ~ v ~/ t er: .. un um ry Conditions o royal: tify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: uired: I Q ~ ~ U `~ uent Form Re S bse q u q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: wn `a~ ~ E ~ I ~A L ~~7~0 ~%r~ Form 10-403 Revised 12/2009 ~ Submit in Duplicate NS16A 206-141 ~C~C ATTARLJMGf~IT Sw Name Operation Date Perf Operation Code ~Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 415/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A 4/30/08 APF 14,289. 14,339. 11,099.02 11,146.31 NS16A 5/1/08 RPF 14,299. 14,304. 11,108.44 11,113.16 NS16A 511/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 512/08 RPF 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/08 RPF 14,276. 14,296. 11,086.8 11,105.62 NS16A 7/27/08 RPF 14,274. 14,279. 11,084.93 11,089.62 NS16A 7/27/08 RPF 14,279. 14,289. 11,089.62 11,099.02 NS16A 7/27/08 RPF 14,289. 14,299. 11,099.02 11,108.44 NS16A 7/27/08 RPF 14,299. 14,319. 11,108.44 11,127.34 NS16A 7/27/08 RPF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~~ No Accidents, N~'arm to People, and No damage tom Environment To: Jerry Bixby/Clark Olsen Date: February 10, 2010 Well Operations Supervisors From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Subject: NS16 Mud Acid & SIT Please perform the reauested well work on NS16A per the below procedure. l i l C I Mud Acid & SIT w/ Stim Pkr I Well Detail Current Status: Producer Last Test: 11/11/08: 980 BOPD, 937 BWPD, & 21 MMSCFD Max Inclination: 52.5° at 7,169'; ~20° at Perfs Max Dog Leg: 8.6 at 3,274' MD Minimum ID: 2.40" at the 4.5" x 2.875" crossover C~3 13,522' MD Last TD tag: 02/06/09: 14,349' SLMD w/ 2.13" DMY GUN & S-Bailer (empty) Last Downhole Op: 09/18/09: SBHPS Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 5,108 psia / 249°F Q 11,100 ft ss Objective The objectives of this well intervention design are to: 1) Isolate lower high water perforated intervals with inflatable stimulation packer. 2) Stimulate the upper interval with a mud acid & scale inhibitor treatment. Well History NS16A is a 2008 development well at Northstar. Following a Coil Acid /Scale Inhibition treatment on 4/10/08, the well's productivity dropped off. On 05/02/08 15' of new perforations were added in addition to re-shooting the original 35' of perforations. The 50' of perforations shot 05/02/08 resulted in a 1000 BOPD increase in production. Unfortunately, the wells' production dropped off again and 30' of perforation were shot 06/12/08 consisting of 15' of reperfs and 15' of new perforations. The 30' of perforations shot 06/12/08 resulted in a 2500 BOPD increase, but the test 12 days latter on 06/24/08 showed NS16A's production had dropped 2200 BOPD from the post perforation test. Perforations were required on 07/04/08 & 07/28/08 to maintain NS16A's production. NS-l6A CT Mud Acid & SIT Page 1 of 9 No Accidents, N~Larm to People, and No damage tom Environment A second Coil Acid /Scale Inhibition treatment was performed on 09/13/08 to re- stimulate production by removing scale in the near wellbore area. The treatment resulted in 1500 BOPD increase in production. A subsequent production profile indicated the top 12' of perforations were contributing 87% of production. A diverted bullhead HCI treatment with L066 scale inhibitor was pumped on 3/30/09 in an attempt to remove damage caused by calcium carbonate scale and inhibit against the scale formation. A scale inhibition treatment was subsequently pumped in an attempt to establish along-term scale inhibition program using scale inhibitor EC5526A to prevent scale formation and the need for frequent acid stimulations A CT mud acid job is planned for NS16A during the 2010 ice road season. A caliper will be used to determine the setting depth of the stimulation packer for the proposed acid treatment. The plan forward is to isolate the lower high water intervals with an inflatable stimulation packer and stimulate the upper intervals with a diverted CT mud acid & SIT. Based on the declining benefit of pumping HCI treatments in NS 16 and success of the 2009 NS05 mud acid treatment, the below mud acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. An inflatable stimulation packer will be set to isolate the lower high water interval and a combination mud acid/scale inhibition treatment will be performed to stimulate the upper perforation intervals. Acid compatible scale inhibitor L066 will be included in the acid treatment to provide ~6 months of protection from scale build up. Operational Phases Coil tubing • Drift run -Memory CCUGR log. • Set inflatable isolation packer at 14,295'ELMD • Mud Acid & SIT • Flowback & Sampling Program Risk Discussion A risk review was field between the Wells Group and the North Star teams on 2/17/09 to discuss the risks associated with pumping aggressive HCL treatments and evaluate the feasibility of a HF treatment at Northstar. Risks were identified and mitigation plans have been developed. It is quite evident from the previous experience where using just HCI for stimulation, that main formation damage is calcium carbonate scale. This calcium carbonate poses an additional challenge for any sandstone acidizing treatment containing HF, as precipitation of Calcium Fluoride is irreversible once it happens and we must do whatever we can to avoid it. Using a regular 10 to 15%HCI NS-16A CT Mud Acid & SIT Pale 2 of 9 No Accidents, N~irm to People, and No damage tom Environment treatment before the sandstone acidizing to remove most, if not all carbonate material, will greatly. reduce the possibility of Calcium Fluoride precipitation. Historical Tbg/IA/OA data illustrates a large differential pressure between the tbg, IA, and OA which collaborates with all available data indicating the tubing has integrity and there is no risk of pushing acid into the IA. Acid returns will be neutralized during flow back by pumping MagOx slurry through the tree cap to mitigate the risk of flowing live acid through the facility and down the disposal well. This procedure proved successful during the March-09 NS16 and NS19 HCI jobs. It is critical to have twice the volume of MagOx necessary onsite to neutralize the treatment volume of acid. Action Items from 2/17/09 risk review. • Pump and other process components were verified to be resistant to HCI. • Soft PSV components can be susceptible to HCI. Risk is minimal as operations will mitigate high pressures by establishing an open flow path from the treated well to the disposal well • Using a test separator to bypass the facility was evaluated, however this option is not recommended due to additional risk added by rerouting flow and limited space on NS. • Low/settling points in system will be inspected before and after HC1 treatments. • CIC inspection of water injection header before and after HCl treatments. • Portable acid shower/wash on site. An additional eye wash station is located in NS shop. • Contingency patch/sleeve in case of water injection header failure -North Star Ops will evaluate the need for a contingency repair • Schlumberger will provide Slicker Suits and associated acid resistant PPE for Northstar Ops • A pre-task risk assessment will be performed before sampling returns at the test separator. Use appropriate PPE and acid resistant sample containers. North Star ops have taken on the role of sampling Flowback at the test separator. • SimOps with Drilling to ensure the treatments are scheduled to avoid rig interruptions • Corrosion inhibitor package injected at wellhead during acid during Flowback was deemed not necessary due to the neutralization of the HCL at the wellhead. • HF Neutralization - Mag Oxide slurry Injection at Wellhead The proposed IBP setting depth is heavily shot, at roughly 18 spf, posing potential risk of puncturing IBP during inflate. 3D caliper log indicates ~24% wall loss in addition to perfs at the proposed setting depth. If the initial attempt fails the plan is to redress the inflatable and make a second attempt to set 10' further up hole. NS-16A CT Mud Acid & SIT Paae 3 of 9 No Accidents, N~'arm to People, and No damage tom Environment Scale inhibitor L066 is acid compatible and requires ~4 hour residence time prior to flow back. That being said there is risk associated with leaving HF shut in prior to flow back which can result in the loss of permeability due to damage caused by precipitate formation. To avoid this damage in the near wellbore area, the over flush has been designed to push all HF and byproducts into the formation to roughly 8.5 radial feet (11.8% porosity). .~ Please review the following sections of the PE manual. Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back Coil Tubing Set Inflatable Treating Packer Ns~~~- 1. Obtain,D~oil sample and deliver to Schlumberger Well Services lab for pre-job emulsion/sludge testing at least 5 days prior to acid stim. 2. Contact SLB and order Mud Acid Design. Have sufficient neutralizer available to handle. volume of acid. 3. SI Well. MIRU CTU. a) Note: if coil is new and has not been pickled, follow pickling procedure below. b) Ensure RU is in accordance with MMS regulations and CATII for SIWHP greater than 3500 psi. c) NS Ops has verified acid returns, including MagOx, can be flowed back through test separator to well clean up tank and down disposal well NS32. Ensure well is diverted to disposal well NS32 for FCO and Acid Stim flow back. d) Load out an additional 5 bbls HCI from volume on pump schedule. e) RU acidizing equipment. PT CT & lines. f) Line up to pump acid down CT with coil at surface & take returns to disposal well 4. MU GR/CCL memory tool. Pumping down the backside (CTxTbg annulus) knock down W HP and sweep. gas from wellbore with a minimum of 1.2 wellbore volumes of 1 % KCI + 0.2% surfactant F103 (1.2 wellbore volumes = 252 bbls). Pump 30 bbls of diesel for FP. 5. With well SI; RIH TD for drift/memory log run. Log up flagging coil at +/-14,295'. This flag will be used to correct coil depth to ELMD to provide good depth control for the inflatable stimulation packer. NS-16A CT laud Acid & SIT Pale 4 of 9 wlw wwn~:w.. wi •{.w Mw~w..... wrb ~Mw.Jd L.w wwriwrw.wa u./wuf iirc4 •.~4iwe. 4i.ae 4w er~cure No Accidents, N rm to People, and No damage to Environment 6. POOH. Pump diesel at min rate to keep wellbore gas free. Download data .and tie in to the Reference Log: SLB PDC Log dated 03-April-2008. 7. MU BHA to include inflatable treating packer with concentric ID circulation sub above treating packer. Stab lubricator on well. PT as per standard procedures. 8. RIH to flag, pumping diesel down CT at min rate (backside SI) and change CT depth to the corrected ELMD depth at flag from previous logging run. 9. Set Inflatable packer at 14,295'ELMD per Baker rep recommendations. 10. Establish injection rate at 1 BPM or 3500 psi maximum. SD pumping. Drop 5/8" ball and circulate to seat on concentric circ sub. Open Circ sub at 3500PS1. Mud Acid & SIT w/ Inflatbale Treating. Backer Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please do not filter fluids that contain L066. All filtering should be performed before the addition of the L066 scale inhibitor to insure the inhibitor does not plate out in the filters. • Please do not add friction reducer to water that will contact the formation due to formation plugging issues. • Please avoid contacting L066 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash • Filter all fluids that will enter the perforations to 3 microns absolute. Filter all NH4C1 on site using Northstar's filter pots. • The maximum recommended WHP during treatment is 3500psi. • Well is equipped with 13-CR 4'/2" tubing and 2-7/8" liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • 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. HCI should be within ±1.5% and HF should be within ±0.5% N~-16A CT Maid Acid & SIT Pale 5 of 9 No Accidents, N~arm to People, and No damage to~l~ Environment • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • In general, pump job at maximum allowable or achievable rate/pressure. Scheduled rates are estimates only. • L066 Scale Inhibitor requires a 4-hr shut in period prior to flowing back Open Perforations Zone MDT MDB H TZE 13,805 13,835 3a TZEITZD 13,835 13,860 25 TZD 13,860 13,900 40 Acid Design Details Total Footage 21' (lower 44' will be isolated with inflatable pkr) # of Perforations 342 Wellbore Volume 210.1 bbl (to top of perfs - 14,274'ELMD) Acid Design 10% HCI Pre-Flush - 100 gal/ft 6:1 Mud Acid - 100 gal/ft Over flush - 200 al/ft Acid Volume 10% HCI Pre-Flush - 50 bbls 6:1 Mud Acid - 50 bbls Over flush - 100 bbls Diversion Volume 125#'s total Wax Beads in 30#HEC Gel Reservoir Pressure 5,108 psia / 249°F @ 11,000 ft ss Bottom of Form 11.Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 12.Preheat filtered 3% NH4C1 and diesel to 100°F (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture NS-16A C'1` Mud Acid ~ Sl'1' Yage 6 of y wIA NA~IAM A~ FICA MAIA~~I ~~IAM4 ~hA~~I.I IAA AAY~A YM~\A/'I ~~/IA~~` EIMC~ ~'IfIMN ~I~MA ~A ANC~~MA ' 1 No Accidents, N rm to People, and No damage to Environment 13.RU Acidizing equipment. PT lines. Line up to pump fluids down the coil per the following schedule. 14.Mix/Circulate acid to ensure homogenous solution at pump time 15.Reduce wellbore temperature and condition formation rock by pumping -20o bbls of filtered NH4C1 + Surfactant F103 preheated to 85-90°F at max rate. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 190°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the wax beads of 190°F. 85-90°F water should be used to reduce the wellbore temperature of 256°F to below the 190°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. This volume was calculated based on actual volumes to cool NS-13 during the Aug-03 acid job. NH4C1 will be the only aqueous solution to contact HF; this prevents precipitation of alkaline fluorides. 16.Pump two stage mud acid treatment with wax bead diversion down the tubing per th treatment schedule below. Pump at max rate to corresponding with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/frac gradient). Maintain pump rate as high as feasible below frac gradient after the wax beads are in the liner. It is critical to keep the pumping pressure high after diversion break over is observed. Record pump rates, tubing, IA and OA pressures throughout the job. Note: If the diversion locks up causing loss of infectivity, incrementally increase pump pressure to 3500 psi (max pump pressure while liquid packed) and hold for leak off. If no leak off occurs bleed surface pressure to 0 psi and incrementally increase pressure to 3500 psi looking for leak off. Repeat pressure cycles as needed. If this does not work, as a final contingency flow back 1-2 bbls and continue with pump schedule. Note: When diverter stages contact the formation a pressure increase should be observed. If no pressure change is occurs, the wax bead concentration is too low. If time allows and diverter concentrations can be swapped on the fly increase diversion stage concentration by 30%. Note: 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. Mud Acid Treatment Design Schedule NS16 CT Mud Acid Schedule Fluid Fluid u Sta e # Sta a Fluid Vol Rate Time lui NS-16A CT Mud Acid & SIT Pale 7 of 9 /Jw r.wriiww wi iMw 6wlwu. a wr4 QMw..Id {.w wwriwr...wA .../w..i i:rci iw4ir... is w.w iw wwcurw ' ~ No Accidents, N rm to People, and No damage to Environment Descri tion T e bbl b m min bls 1 Wellbore Coolin 3% NH4CI no U67 200 3.0 67 67 r- 2 Conditioning 3% NH4CI 30 3.0 10 77 ~ 3 Acid Pre-Flush 10% HCI 25 3.0 8 85 `~ 4 Acid 6:1 Mud Acid 25 3.0 8 93 5 Over Flush 3% NH4CI + L066 50 3.0 17 10 6 Diversion 2001bs Wax Beads + 30#HEC 10.0 3.0 3 13 N 7 Spacer 3% NH4CI 5 3.0 2 15 ~ 8 Acid Pre-Flush 10% HCI 25 3.0 8 23 c° 9 Acid 6:1 Mud Acid 25 3.0 8 32 ~ 10 Over Flush 3% NH4C1 + L066 50 3.0 17 48 17.Release IBP and begin POOH. FP and leave under balanced by pumping 30 bbls of diesel while POOH. 18.S1 in for 4 hours. Prepare to flow back acid at exactly 4 hours. Prepare to neutralize acid flow back by slip streaming MagOx. 19. Line-up the well to flow into the test separator and well cleanup tank for flowback. Neutralize flow back by slip streaming MagOx slurry. 20. Begin sampling program. Flowback Sampling Schedule: • Initial sample after 300 bbls returned (flowline + tubing volume + 10 bbls) • Sample once per hour until 603 bbls returned • Sample at the hours 2 and 5 of both 6-hour well tests • Obtain produced fluid samples once per day for 1 week after the treatment Label bottles as: • W ell: ~£rt~' N S /G~4- • Date/Time: • Bbls Produced: • Tests: pH, solids quantification and identification, common cations by ICP, presence of emulsions Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. NS-16A CT Mud Acid & SIT Pale 8 of 9 NA AAK~AB At frMP_ hP_IAW '~ No Accidents, TREE= Al#3-VGI 5-il$' SN51 wEttr+EAb= 13518"AMJIIffiOYlt 5K5I ACTlS4TOR = .M.~~.~.~, BAKECt K9. REV = ,9.,.__ 56.46' f3F. E1EV = 44.58' {GB 153') AAax Ante = 53" ~ 7169 batun A~&.1= ~ 136df3' Dat;m ND = 10500' SS 113-3f8' E2SV {4}2l1fYi}8) ~ =12.415' -5r'e" EILSV 0 513 tfY Cf2~ TO L-8D ~7C i 32ffi' I Minimum Id = 2.387" @ 13522' 4112" X 2'718" XCl 4-112" TByu. 12.6 #, 13G[t-80 VAM 7flP, .0152. bpt, A~ =3.959° 4-112" 1EG, 12.fi #. 13CR•80 VAM #OP, 13! .0152 bpf, ~3= 3.958" PERFORAtKsN SUMJIAfZY fxEF LflC: Sws- t1'?C ad f14p31D$ A1JQE AT 7flF' PE1~: 20 ` ~ 14274' hYrte: I~Siet to Praluction t7$ forhistuicatperf cfBW ~L'tE ~iTEiiVAL{f~) fl{SnlSyz DAtE 2° 6 14274 - 14304 fl !)6!1210$ 2° 8 14274 - 14339 fl 07127.+08 2" 6 1427$ - 14296 +~ a7~it41n$ 2" 6 14299 - 14339 b 0510210$ 2' 6 143Q4 - 14339 O 04145!'08 1 .0371 bpi, ~=6.184" 4-112" LHR, 12.814. L-80521 hfrf, .0152 bpf, ~ =3.959' 6:4#, 13C Ft-~, .005$ bpf, ~ = 2.441 ° NS-16A CT Mud Acid & SIT to People, and No damage to Environment A~ V ~ ~ J~ SAFETYF~TES:'•'{:HRt)METBGSLhtR'•• MLl4llf {88-1$Il) 325iT'- 3274" ~9~519"X7"$K32~XPL7Pw111'P$ft,ID=6.20df' 1 r x F» a~u ~~ ~x Y aux ~ < a ar>~• 13423` 1--14112' h~S X Np? N7 = 3.813" 1 13444' 7" X R-112' 9KR PFt~tutC=li i'!Cf2, ~? = 13471' 4112" f~ESX H9? tl] =3.$13' 13479' r X 5" fZXPLTPw 117` PBft K 1.148.3' H4111° FMS XN f`P; Y7=3.T15' 13497' I-141!2 SEtFAL~iP1NGSK7E. Vii=3.850' 135Q7' 1-17" X 5' $KR FLEX LflOC ~. q = 4.40" 1 13516' S• x 4112" XO , D = 3.94" 1352Z' 4112° x 2-T18" XO, D = 2387" 13685' H7"X5"fiKRZXPL7Pw112'PBR~7=4.350" 1'iTflfl• 1--17" X 5• fIKR FI GX Y t7(1C k9C~2 tl) = 4.?7(t" Page 9 of 9 ~ ~ bP BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed lielow. Tf.,r,,, h~.,p ~n•. n„Petinnc nlPace enntact Tne Lastuflca at (9071564-4091 Jate: 02-22-2010 Transmittal Number: 93130 Deliv Contents Bottom W Name Dam Con Run To th D th es ' tion EMORY MULTI-FINGER ALIPER LOG RESULTS NS07 2-12-2010 PDS 1 0 13406 UMM~-RY D-ROAA - ME~AORY MULTI- . FINGER CALIPER' LOG NS07 2-12-2010 DS RESt-1LTS SUMIWARY EIrAORY MUlT1-FINGER ALIPER LOG RESULTS NS16A 2-11-2010 PDS 2 0 14380 UMMARY D-ROM -MEMORY MULTI- FINGER CALIPER LOG NS16A 2-11-2010 PDS RESULTS SUMMARY /` t ;:. .. '~, Sign and Retura one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS vim; ~~=°.~,.~ ~~~' ~~ ~ l~ /) r `7 J ~" , ~~ David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski _ ~ _- --. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 .-anchorage, AK 99~ 19-6612 ~~~~1 ~ ~.11 use, ~~o 1 `a• a ~~~ L Id ~Ip~6 ~, ~~ by BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf v~u have anv questions. please contact Joe Lastufka at (907)564-4091 Date: 10-08-2009 Transmittal Number: 93102 Delive Contents Bottom SW Name Date Contracto Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS17 10-02-2009 PDS 1 0 17582 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS17 10-02-2009 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS29 10-02-2009 PDS 1 0 13276 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS29 10-02-2009 PDS RESULTS SUMMARY STATIC TEMPERATURE/ NS19 09-28-2009 PDS 1 PRESSURE SURVEY CD-ROM -STATIC TEMPERATURE/PRESSURE NS19 09-28-2009 PDS SURVEY STATIC TEMPERATURE/ NS16A 09-18-2009 PDS 1 PRESSURE. SURVEY CD-ROM -STATIC TEMPERATURE/PRESSURE NS16A 09-18-2009 PDS SURVEY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS RECEI~~ prT ~. ~ 2009 ¢>~Sk~ Oll ~ ~~ David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Static Temperature/ Pressure Survey B.P. Exploration (A/askaJ loc. M We~~ NS - 96A o~D~E s'OF a ~~• North Star ~ ' M North Slope Surface -Before R/H P.on~.~~E u~.~.o+.~~ s..~ccEs Date: September 18, 2009 Start time: 16:52:00 Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 41.08 3579.70 0.5 41.05 3579.71 1.0 41.05 3579.73 1.5 41.00 3579.74 2.0 40.99 3579.75 2.5 40.99 3579.76 3.0 41.00 3579.77 3.5 41.00 3579.78 4.0 40.99 3579.79 4.5 41.03 3579.81 5.0 41.06 3579.82 5.5 41.10 3579.83 6.0 41.10 3579.84 6.5 41.08 3579.85 7.0 41.08 3579.86 7.5 41.06 3579.87 8.0 41.05 3579.88 8.5 41.05 3579.89 9.0 41.06 3579.91 9.5 41.08 3579.92 10.0 41.08 3579.93 AVERAGE 41.05 3579.82 Current Wellhead Read in s Wellhead Pressure (psig) : 3,550 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 Outer Annulus Pressure si ) : 0 Temperature Data 45 43 -----------------. ------ -- 41 .. - - --------------- ----- LL 39 - . _.._._.....---- -------------- - _ - 37 _..._.._._....._..- ----..... ---. ._ -- ------------- ------------ -- 35 -----....--------... -._-...---.........._...----..-_~_ 0 1 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 3590 3585 ---._._...--------------------...------.--..-------------...__....-------..._..-._.-._ . --._._ ._. N 3580 - - -- - a 3575 ----------~------____-.....--------------------....------------._._....__....__....-------...._....-------- 3570 0 1 2 3 4 Minutes 6 7 8 9 10 C~ CN - ~ ~ (,~' Page 1 Static Temperature/ Pressure Survey B.P. Exploration (AlaskaJ. inc. NS - 96A North Star North Slope 90,987' TI/Oss M. D. = 94,229' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 249.05 5095.33 1.0 249.04 5095.34 2.0 249.03 5095.36 3.0 249.03 5095.37 4.0 249.03 5095.39 5.0 249.02 5095.41 6.0 249.03 5095.42 7.0 249.00 5095.43 8.0 249.00 5095.45 9.0 249.00 5095.47 10.0 248.99 5095.48 11.0 249.00 5095.50 12.0 249.00 5095.52 13.0 249.01 5095.53 14.0 249.00 5095.54 15.0 249.00 5095.56 16.0 249.00 5095.57 17.0 248.98 5095.59 18.0 248.99 5095.60 19.0 248.98 5095.62 20.0 248.99 5095.63 21.0 249.00 5095.65 22.0 249.00 5095.66 23.0 249.00 5095.68 24.0 249.01 5095.69 25.0 249.00 5095.70 26.0 249.01 5095.71 27.0 249.00 5095.73 28.0 249.00 5095.74 29.0 248.99 5095.75 30.0 249.00 5095.76 AVERAGE 249.01 5095.56 Date: September 18, 2009 ob~F,M WEl(SI~E. Qa. °'~ s ~ F~ N PwoAcrivc Diwywosiic SEwviccs Start time: 19:56:00 Temperature Data 255 250 LL 245 0 240 235 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes 5100 5090 5080 Q 500 a 5060 5050 5040 5030 Pressure Data ~ 0 2 4 6 8 10 12 mutes 18 20 22 24 26 28 30 Page 2 B.P. Explorab'on(A/aska~ lnc. NS - 96A North Star North S/ope 90,887' TI/Dss M.D. = 74, 7 79' Static Temperature/ Pressure Survey Date: September 18, 2009 Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 248.61 5085.03 0.5 248.61 5085.03 1.0 248.61 5085.04 1.5 248.61 5085.04 2.0 248.61 5085.04 2.5 248.62 5085.04 3.0 248.61 5085.03 3.5 248.62 5085.04 4.0 248.62 5085.04 4.5 248.62 5085.04 5.0 248.61 5085.04 5.5 248.61 5085.04 6.0 248.61 5085.04 6.5 248.61 5085.04 7.0 248.61 5085.04 7.5 248.61 5085.04 8.0 248.61 5085.04 8.5 248.61 5085.05 9.0 248.61 5085.05 9.5 248.62 5085.05 10.0 248.61 5085.05 10.5 248.62 5085.05 11.0 248.62 5085.05 11.5 248.62 5085.05 12.0 248.61 5085.05 12.5 248.61 5085.05 13.0 248.61 5085.05 13.5 248.61 5085.05 14.0 248.62 5085.05 14.5 248.61 5085.05 15.0 248.61 5085.06 AVERAGE 248.61 5085.04 Ob`EN- Wf((SAs a ~~• .s ~~' PvoAcrive Di~Grosric Srwvicrs Start time: 19:56:00 Temperature Data 255 250 p~ 245 ~ + 240 235 ~ I I I I I I I I I I I I I F~-I #--;-I I---,-I t I I I I 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5100 5090 `.-...----..__.._.._._....__._....----..._...._._.._..._.__........._..._._.. ----...__..._........_...._ ___ _ _ --- _ __----...._..--------...._. 5080 --....-..--------. ~._..---------------_-__---...___-----___.....-------..._._. a 5070 _...----------------.._...__....--------.._..__._...__.._...__.....--------...._....._..__._._...__.._._....----...---._.._._.__....._. a 5060 ------------------- -------.._.. 5050 -....-----.._._...----.._.._.-.._-.._-.._-_......__...--- -...-----...__..__.....-------..._._....-----...- ------- 5040 -__....--______-.-.----------------..._._._.._-_------...__..__.._..._._....-------..._...._._.....-----._._.....---------......._. 5030 0 1 2 3 4 5 6 Minute8 9 10 11 12 13 14 15 c: •I Page 3 Static Temperature/ Pressure Survey B.P. Exploration (AlaskaJ. lnc. t,`EM We((sA NS - 96A Qa° `~~.~ North Star ~ N North Slope 90,487 TVDss M.D. = 93,672 PwoAcrive D14QwOSTIC rJF1~V 1CE5 Date: September 18, 2009 Start time: 20:23:00 Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 236.46 5036.32 0.5 236.47 5036.32 1.0 236.46 5036.32 1.5 236.45 5036.32 2.0 236.46 5036.32 2.5 236.47 5036.32 3.0 236.48 5036.32 3.5 236.48 5036.32 4.0 236.48 5036.32 4.5 236.49 5036.32 5.0 236.48 5036.31 5.5 236.48 5036.31 6.0 236.49 5036.31 6.5 236.48 5036.31 7.0 236.49 5036.31 7.5 236.49 5036.31 8.0 236.48 5036.31 8.5 236.48 5036.31 9.0 236.48 5036.30 9.5 236.49 5036.30 10.0 236.48 5036.29 10.5 236.48 5036.29 11.0 236.48 5036.29 11.5 236.46 5036.29 12.0 236.46 5036.29 12.5 236.48 5036.29 13.0 236.46 5036.28 13.5 236.46 5036.28 14.0 236.46 5036.28 14.5 236.48 5036.28 15.0 236.46 5036.27 AVERAGE 236.47 5036.30 Temperature Data 255 250 ------..-_._....-------------------.-......-..-----------------....------------..._.._._-._ u. 245 -_...--- ------------- --- -- 2ao ----------- ------------ --._._.....-.__ 235 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes • Page 4 Static Temperature/ Pressure Survey B.P. ExploraG'on (AlaskaJ. lnc. M We([ NS - 96A 4a~b`~ S,p~c'' North Star ~ M North Slope 90,797 TI/Dss M.D. = 94,099/ PPOACTIVf Di~gwosnc ScavicEs Date: September 18, 2009 Start time: 20:53:00 Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 246.31 5072.74 0.5 246.31 5072.73 1.0 246.30 5072.72 1.5 246.31 5072.71 2.0 246.28 5072.70 2.5 246.26 5072.69 3.0 246.28 5072.69 3.5 246.25 5072.68 4.0 246.25 5072.67 4.5 246.24 5072.66 5.0 246.23 5072.66 5.5 246.22 5072.65 6.0 246.19 5072.64 6.5 246.20 5072.64 7.0 246.17 5072.63 7.5 246.17 5072.63 8.0 246.17 5072.62 8.5 246.16 5072.62 9.0 246.14 5072.61 9.5 246.13 5072.61 10.0 246.12 5072.61 10.5 246.13 5072.60 11.0 246.14 5072.60 11.5 246.14 5072.60 12.0 246.14 5072.59 12.5 246.14 5072.59 13.0 246.14 5072.59 13.5 246.15 5072.59 14.0 246.14 5072.59 14.5 246.15 5072.59 15.0 246.14 5072.59 AVERAGE 246.20 5072.64 Temperature Data 255 250 ------~-------_-..----------------._...----..-..------------------------...-_. _._....._ LL 245 --------..._..---------..__.._..-------....---------------- -- ----. ... 240 -.....--------------- ----------------------...-----.....----...-----__-----------....__ 235 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 5 Static Temperature /Pressure Survey B.P. Exploration (A/askaJ. lnc. NS - 96A North Star North Slope Surface -After POOH Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 39.79 3582.60 0.5 39.78 3582.62 1.0 39.77 3582.63 1.5 39.78 3582.65 2.0 39.81 3582.67 2.5 39.86 3582.69 3.0 39.89 3582.70 3.5 39.86 3582.72 4.0 39.84 3582.74 4.5 39.79 3582.76 5.0 39.77 3582.78 5.5 39.72 3582.80 6.0 39.67 3582.82 6.5 39.60 3582.83 7.0 39.57 3582.85 7.5 39.56 3582.87 8.0 39.52 3582.89 8.5 39.52 3582.91 9.0 39.51 3582.92 9.5 39.48 3582.94 10.0 39.48 3582.96 AVERAGE 39.69 3582,78 Current Wellhead Readin s Wellhead Pressure (psig) : 3,550 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 t~i.~t,er Anniil~is Press~~re (~;~sig; : Q Date: September 18, 2009 ob`F,M WE([ SAF 4a ~~~ i PIOACTIVE Dt~[jMOSTIG SE NVICFS Start time: 22:54:00 Temperature Data 45 43 --- -- ---.........-- ----------._......-.....__....__._...------ ---- -----------..__...._...------...__...-..__.....--- LL 41 --.....--- _.....-----........------._....----------------......_...._.._...._._ O 39 -.__...-------..~_._..._......._..._..._._...._...__.._......_....---_- __----------~-------....---....__.... 37 -__.. -------.. -- ------- ---- 35 0 1 2 3 4 5 6 7 8 9 10 Minutes A Pressure Data .s~av 3585 H 3580 a 3575 3570 0 1 2 3 4 Minutes 6 7 8 9 10 Page 6 B.P. Exploration (A/askaJ. lnc. NS - 96A North Star North Slope Dawnha/e Temp/ Press Date: September 18, 2009 Static Temperature /Pressure Survey Start time: 19:21:00 1 /9/1900 23:05:00 Ob`EM WE(( sA6 4• ~`~• Q ~ W V• F~ N P~oAcriv~ Di~gnosTic ScRVicas Temperature Data 250 - - IMM~NNN 245 W ---------- --------------------...-----...-_.........------ ----- ------ -------- 240 O - ----.-__-.-..------- ----------- ---. -__- --- ----- --.-..---_.-.-._..---.. 235 -_.-..-_.__.._....-----.._..-------------------------- 230 -200 0 200 400 600 800 1000 1200 1400 Minutes Pressure Data 5100 5090 _...------------ ----------...._....____ ----...--- 5080 ---------._....---------------.....---------...._._...._..---...__...-__------- a 5070 -....---------- -- ------ ...__._._....----...._......._......__....----.._._...._...-----...----...-------..._..___ ---._.._...-.......__. a 5060 - --- 5050 _...._...----------....----..__.....-------------__-___-__--. 5040 __._.-..___._._-_..-... _.._._...---------....--------------------...-._..._._-...._...__...--- 5030 6 0 -200 0 200 400 Mirtuces 800 1000 1200 1400 Page 7 .r ~ . BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 - Anchorage, Alaska 99519-6612 ~~~~~ May 26, 2009 ~~~ 7~~ ~~h~r~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7"' Avenue r, .. ~ 1.~ Anchorage, Alaska 99501 ~~' 1~.~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ ~"~ Andrea Hughes - - BPXA, Well Integrity Coordinator - - ,~ "~ Northstar BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date X~"` ~ "-~\ 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 na * na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. L JUN 0 1 2009 ,... _ '' <~; :~a +?s ~~~~ 3~ ~~ to ~ ~~A~ 1 a ~°~A ~ ~~~32 1 .~~~~, 2°~~q3~ ~~1~~ ~TVEL,~. ~~'TA ~'RA~1S1~~~'~°A~, Enclosed are the materials listed below. Tf vnn 1'1 `l1~/P an~i nnPCtinnc nlea.ce cnntart _Tne T,astufka at (9071564-4091 date. ~~=~--2e_2~~c Transmittal iVumuer: 93066 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion ULTRASONIC CEMENT/ NS33 04-14-2009 SCH 1 200 14100 CORROSION EVALUATION CD-ROM -ULTRASONIC CEMENT/ CORROSION NS33 04-14-2009 SCH EVALUATION NS19 04-19-2009 SCH 1 13650 13830 PERFORATING RECORD CD-ROM -PERFORATING NS19 04-19-2009 SCH RECORD PRODUCTION PROFILE W/ NS19 04-19-2009 SCH 1 13700 13930 DEFT & GHOST CD-ROM -PRODUCTION NS19 04-19-2009 SCH PROFILE W/ DEFT & GHOST PRODUCTION PROFILE W/ NS16A 04-20-2009 SCH 1 14200 14365 DEFT & GHOST ' CD-ROM -PRODUCTION NS16A 04-20-2009 SCH PROFILE W/ DEFT & GHOST ' "V __ Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center AOGCC Murphy Exploration MMS DNR BPXA ~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 146612 Anchorage, AK 99519-6612 Christine Mahnken Ignacio Herrera Doug Chromanski Kristin Dirks David Fair '~'~~,~~ ~, STATE OF ALASKA ~~.,, Q ALAS~OIL AND GAS CONSERVATION C(AI~11t~11~S10~100~ REPORT OF SUNDRY WELL OP~~~~V~pmmissior~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations imul~,tn f 8~ Other ~ ACID STIM - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' Exploratory ~ 206-1410 3. Address: P.O. Box 196612 StratlgraphlC Service 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 7. KB Elevation (ft): 9. Well Name and Number: ` 55.92 RT ~ NS 16A , 8. Property Designation: 10. Field/Pool(s): ADLO-312799 - NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 ~ feet Plugs (measured) None true vertical 11305.92 - feet Junk (measured) None Effective Depth measured 14414 ~ feet true vertical 11218 , feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201 4620 2590 Surface 3208' X13-3/8" 68# I-80 Surface - 3250 Surface - 2993 4930 2270 Production 12533' 9-5/8" 47# I-80 Surface - 12574 Surface - 9565 6870 4760 Liner 1072' 7" 29# L-80 12178 - 13850 9210 - 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685 - 14093 10555 - 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479 - 14503 10370 - 11304 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 0 - 13522 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S-3 PERM PKR 13444' 0 0 0 0 0 0 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: 1221 12500 1533 754 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run EXplOratOry ~ Development ' ' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ - Gas ~ WAG GINJ WINJ WDSPL 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: 308-465 Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 4/6/2009 Form 10-404 Revised 04/2006 j^+ ! ~~~~ ~ ~ L"'' '~ l ' ~`J f~ ~ ~.~. ti{~,~` Submit O ' final Og~ J~ NS16A 206-1410 PFRF IlTTdt`FIMFNT • O ration Date Pert O eration Code Meas De th To Meas De Base Tvd De th To Tvd De th Base. 4/5108 PER 14,304. 14,319. _ 11,113.16 11,127.34 4/5108 PER. 14,319. 14,339. 11,127.34 11,148.31 4/30/OS APF 14,289. 14 339. 11,099.02 11,146.31 511108 RPF 14,299. 14304. 11,108.44. .11,113.16 5h/08 RPF 14,304. 14 319. 11,113.16 11,127.34 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 5/Z/08 "RPF 14,289. 14,299. 11,099.02 11,108.44 6112108 APF' 14,274. 14,304. 11,084.93 11 113.16 7/4/OS RPF 14 276. 14,296. 11 086.8 11,105.62 ..7/27/08 RPF 14,274. 14,279. 11 084.93 11 089.62 7/27108 RPF 14,279. 14,289. 11,089.62 11,099.02 7/27/08 RPF 14 289. 14,299. 1.1,099.02 11,108.44 7!27108 RPF 14,299. 14 319. 11,108.44 11,127.34 7/27108 RPF 14,319. 14,339. 11,127.34 11 146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO Flll CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE .MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK OPEN OH OPEN HOLE NS16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY I 3/30/2049 T/I/O = 3400/800/0 ***Acid Treatment"** SLB/Dowel) pump online down tubing with 30bbls 12% HCI, 108bb1s 80*F Seawater. LRS pumped 70bbls 80*F ~ Diesel. Flow well. Pickle flowback of 292bb1s. Post flowback, SLB pumped 240bb1s 2% KCI w/ F103 to cool wellbore, followed by acid treatments and wax 'bead diversions. SLB displaced acid w/ 140bb1s 80*F seawater. LRS displaced w/ 70bbls 80*F Diesel. 4hour soak, followed by flowback. ***Job in Progress*** 3/31/2009;***"Acid Treatment with wax beads diversion*""*~ ._ I Pickle well with 30 bbls 12%HCL. Flow back to well clean up tank. Perform 3 stage 12% HCL + L66 scale inhibitor treatment with wa: diversion as per program. Saw 300 psi increase when diversion hit perfs. Schlumberger electronic pump repo 0 0 ow. Slip stream MagOx at the wellhead using LRS to neutralize acid returns ***JOB COMPLETE*"* 3/31/2009***continued from 3/30/09's WSR*** Post acid treatment, injecting Magnesium Oxide slurry into tubing during flowback to neutralize acid. Pumped 65bbls MagOx, 5bbls meth to clean truck. Turn well over to operations. FWHP's = 1700/38/vac FLUIDS PUMPED BBLS 30 12% HCL 145 MAXOX 55 METH 280 DIESEL 240 2% KCL +F103 105 12% HCL +3% L66 SCALE INHIBITOR=3-35 BBL STAGES 10 WAX BEADS 70 2%.KCL+F103+L66 935 Total ~~ ~~' ~: Date: 03-11-2009 Transmittal Number: 93048 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. 43{ '~' ~~ i v ,~~ l'~ ,.,~~. "J" \ A ~_ ~~~ / ~` a lyi~ l T~f < L,., .,,,,cot;`.,,0 /1~PaCP rnntart Tna T actnflra at (9(~715Fi4-491 ~~ v - - ----~ -- -- ------ - Delive Contents SW Name Date Com an Run To De th Bottom De th Descri tion NS08 02-23-2009 PDS 1 11526 11926 CORRELATION LOG STATIC TEMPERATURE/ NS08 02-23-2008 PDS PRESSURE SURVEY CD-ROM -CORRELATION LOG AND TEMPERATURE/ NS08 02-23-2009 PDS PRESSURE SURVEY NS09 02-24-2009 PDS 1 12700 13349 CORRELATION LOG STATIC TEMPERATURE/ NS09 02-24-2009 PDS PRESSURE SURVEY CD-ROM -CORRELATION LOG AND TEMPERATURE/ NS09 02-24-2009 PDS PRESSURE SURVEY PL ADVISOR -PRODUCTION LOG INTERPRETATION S16A 10-01-2008 SCH 14274 14339 WITH GHOST AND DEFT CD-ROM - PL ADVISOR PRODUCTION LOG ~ INTERPRETATION WITH NS16A 10-01-2008 SCH GHOST AND DEFT r ~ ' ~ ; 1 4 J `l s A PYase~3ign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS ~`~ ;_ ~:(, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~.~ _~ ~ :~ 1 ~' ` _, ir33-.1 v _ ~. ,.. David Fair Christine Mahnken Kristin Dirks Ignacio Herrera Doug Chromanski • • 1~~-~ ~3~~~ _~._._- ci ~~~~~ ~ \" ~.-_.._ ,~t, r,~ ~~~ f< 1 r~~ ~~}~~~ ^~,1~~ ~~~~~ .. J~'V ~i1 `~~ .,~--- J ~~~i 1~~ J~ ,,; ,. ;.~. 2'~` ; :. .~. BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vrni have anv miectinn.c nleace contact 7ne i,astufka at (9071564-4091 Date: 02-25-2009 Transmittal Number: 93041 Delive Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS24 12-05-2008 SCH 12450 12490 PL ADVISOR NS24 12-05-2008 SCH CD-ROM - PL ADVISOR NS09 12-17-2008 SCH 1 13044 13339 MEMORY SBHPS LOG CD-ROM -MEMORY SBHPS NS09 12-17-2008 SCH LOG PRODUCTION PROFILE NS16A 02-12-2009 SCH 1 11150 11390 WITH DEFT AND GHOST CD-ROM -PRODUCTION PROFILE WITH DEFT AND NS16A 02-12-2009 SCH GHOST PRODUCTION PROFILE NS05 02-13-2009 SCH 1 13551 13860 WITH DEFT AND GHOST CD-ROM -PRODUCTION PROFILE W ITH DEFT AND NS05 02-13-2009 SCH GHOST ULTRASONIC CEMENT/CORROSION NS33 01-29-2009 SCH 1 100 15550 EVALUATION CD-ROM -ULTRASONIC CEMENT/CORROSION NS33 01-29-2009 SCH EVALUATION NS34A 12-16-2008 SCH 1 16088 17108 MEMORY SBHPS LOG CD-ROM -MEMORY SBHPS NS34A 12-16-2008 SCH LOG STATIC TEMPERATURE/ NS18 02-16-2009 PDS PRESSURE SURVEY NS18 02-17-2009 PDS 1 16250 16851 CORRELATION LOG CD-ROM STATIC TEMPERATURE/PRESSURE SURVEY/CORRELATION NS18 02-17-2009 PDS LOG > ~ - + Please Sign nd turn one copy of this transmittal. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 .Wy. ~..~~ .~.~~ ~ ~~ ~ 111.. __...1 !_l~~l r~..~ .1 ALA58A OIL A1~TD GA5 CO1~T5ERQATIOPIT CO1rII~II55IOr1T Jose Solo PE BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 308-465 Dear Mr. Solo: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~0~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such furtYrer time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ ,~~ ~~ Daniel T. Seamount, Jr. Chair DATED this day of December, 2008 Encl. /~8 Y p~ ' ~ i • STATE OF ALASKA • ,y~, ~ ~(~ ~ `l`" ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~' APPLICATION FOR SUNDRY APPROVAL ~n aa~ ~~ ~Rn 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^ Plug Pertorations^ Stimulate Q ~ Time Extension ^ acid treatment Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 , Exploratory ^ 206-1410 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00- 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: NS16A - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 - 56.46 - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 , 11305.92 - 14414 ' 11218 ~ NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/1/2009 OIL Q ~ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jose Solo Printed Name os S1ol Title Production Engineer Signature Phone 564-5972 Date 12/18/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~Q ) APPROVED BY r 2 ~ ArNroved by: COMMISSIONER THE COMMISSION Date: ` Form 10-403 Revised 06/2006 ~ ° ~~ ~` i>`.f ~ `~ ~~~~ ~~~ `" Submit in Duplicate j ~~ NS16A 206-1410 DFDF ATT~rNMFNT • Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 4/30/08 APF 14,289. 14,339. 11,099.02 11,146.31 5/1/08 RPF 14,299. 14,304. 11,108.44 11,113.16 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 5/1 /08 RPF 14,319. 14,339. 11,127.34 11,146.31 5/2/08 RPF 14,289. 14,299. 11,099.02 11,108.44 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 7/4/08 RPF 14,276. 14,296. 11,086.8 11,105.62 7/27/08 RPF 14,274. 14,279. 11,084.93 11,089.62 7/27/08 RPF 14,279. 14,289. 11,089.62 11,099.02 7/27/08 RPF 14,289. 14,299. 11,099.02 11,108.44 7/27/08 RPF 14,299. 14,319. 11,108.44 11,127.34 7/27/08 RPF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ` No portion of the belo ork should be performed w/out fir aking time to ensure No Accidents~o harm to People, and No damage the Environment To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Robert Younger, Northstar PE Subject: NS16A Bullhead Acid SIT Treatment AFE: NSFLDWLI6 Date: December 11th, 2008 (w: 564-5102 c: 227-2760) (w: 564-5972, c: 244-0529) Cost: $100M IOR: 500 Please perform a bullhead acid treatment on NS16A per the below procedure. 1 F Bullhead Acid Treatment w/ Diversion Current Status: Producer Last Test: 11/11/08: 1,372 BOPD, 771 BWPD, & 13,363 MSCFD Max Inclination: 52.5° at 7,169'; ~20° at Perfs Max Dog Leg: 8.6 at 3,274' MD Minimum ID: 2.40" at the 4.5" x 2.875" crossover @ 13,522' MD Last TD tag: 07/04/08: 14,400' SLMD w/ 2" DMY GUN Last Downhole Op: 10/20/08: Production Profile (14,390-14,190'MD) Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 5,087 psia / 256°F C~ 11,100 ft ss Objective Based on the historical scale issues at Northstar, the below acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. A multi stage diversion treatment will be performed in an attempt to open the middle and lower perforation intervals while stimulating the contributing interval. Well History NS16A is a 2008 development well at Northstar. Following a Coil Acid /Scale Inhibition treatment on 4/10/08. the well's productivity dropped off. On 05/02/08 15' of new perforations were added in addition to re-shooting the original 35' of perforations. ThP 5n' of perforations shot 05/02/08 resulted in a 1000 BOPD increase in production. Unfortunately, the wells' production dropped off again and 30' of perforation were shot 06/12/08 consisting of 15' of reperfs and 15' of new perforations. The 30' of perforations shot 06/12/08 resulted in a 2500 BOPD increase, but the test 12 days latter on 06/24/08 showed NS16A's production had dropped 2200 BOPD from the post perforation test. Perforations were required on 07/04/08 & 07/28/08 to maintain NS16A's production. No portion of the belo ork should be performed w/out fir taking time to ensure No Accidents~o harm to People, and No damage the Environment A second Coil Acid /Scale Inhibition treatment was performed on 09/13/08 to re- stimulate production by removing scale in the near wellbore area. The treatment resulted in 1500 BOPD increase in production. A subsequent production profile indicated the top 12' of perforations were contributing 87% of production. A summary of well work activity is outlined below. Operational Highlights [A~~d t~de!~+:] ['Jie~,+~~ All] Date Comments 09f16f2008 GHOST/DEFT Log --~ M87°I° production from tap N12' of perforations 09/14f2008 CT Acid Jab wf L066 --} N2000 BOPD Increase L. :~~t I frit'~Y' 09 08 f12f20 GHOST/DEFT Log --~ X95°f° production from top X12' of perforations 1I .}} 07f28f2008 65' RePerf --> 1000 BOPD Increase 07 f04f2008 20' RePerf --~ 370 BOPD Increase }} Basic Program Phases • Tubing Pickle • Immediate Pickle Flowback • 1St Stage HCI Acid Treatment • Wax Bead Diverter • 2"d Stage HCI Acid Treatment • Soak - 4 hour Residence Time • Flowback Spent Acid Please contact Bob Younger with any questions, comments, or concerns - 564- 5392 (w); 830-4920 (c); 677-2599 (h). Or Jack Lau 564-5102 (w); 227-2760 (c). No portion of the belo ork should be performed w/out fitaking time to ensure No Accidentso harm to People, and No damag the Environment Design Details Total Footage 65' # of Perforations 1500 Perforations Wellbore Volume 210 bbl (to top pert) Acid Design 60 gpf for perfs Acid Volume 3900 gal; 93 bbls total Diversion Design 6 #/ft in 30# HEC gel C~ 1.5 PPA Diversion Volume 378 # total wax beads Reservoir Pressure 5,087 psia / 256°F @ 11,100 ft ss GLV's All GL Mandrels are Dummied Pre-Acid Stimulation Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please do not filter fluids that contain L66. All filtering should be performed before the addition of the L66 scale inhibitor to insure the inhibitor does not plate out in the filters. • Please do not add friction reducer to water that will contact the formation due to formation plugging issues. • Please avoid contacting L66 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash 1. Obtain NS16A oil sample .and deliver to Schlumberger Well Services lab for pre- job emulsion/sludge testing at least 5 days prior to acid stim. Verify acid design is acceptable for application. 2. Arrange DHD to shoot IA FL. If the IA FL is deeper than 500' top off IA. 3. Mobilize pumps, tanks, and acid transport to Northstar. 4. Order out necessary volume of seawater, 2% KCL and diesel to flush both the pickle and the acid treatment. See attached Volumes table. No portion of the belo ork should be performed w/out fir taking time to ensure No Accidents~o harm to People, and No damag~ the Environment 5. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption. Bullhead Acrd and.Scale Ir}hiibitian Treatment Fluid Requirements 2% KCI + F103 240 bbls 2% KCI + F103 + L066 90 bbls Diesel 55 bbls 12% HCI 100 bbls HEC gel w/378 pounds of wax beads (168°F melting temp) 6 bbls • Filter all fluids that will enter the perforations to 3 microns absolute. Filter all KCI on site using Northstar's filter pots. • The maximum recommended WHP during treatment is 3500psi. • Well is equipped with 13-CR 4'/2" tubing and L-80 2-7/8" liner. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • 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 • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • 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 Robert.Younger@bp.com and IauiiO@bp.com. 6. MIRU. 7. Hold PJSM. • Possible hazards on this job include bringing partially spent acid back to surface. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 8. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. . ' ~ ~ ~ No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidentso harm to People, and No damag the Environment 9. Preheat filtered 2% KCI and diesel to 100°F (Absolute minimum temperature of 80°F). • Do not heat the acid or acid mixture 10. PT Dowell surface lines to 5000 psi. Tubing Pickle Tre~atmerrt 11. Pickle the tubing by pumping the following acid design at 2 bpm. Do not exceed 3500 psi max pumping pressure. Note: Do not pump more than 207 total bbls during pickle treatment. It is critical that the acid not reach perfs. Wellbore volume to top perf is 210 bbls. Stage Fluid Type Vol, bbls Acid -Tubing Pickle (~90ga1/1000') 12% HCI 30 Displacement Filtered Seawater 107 Displacement -Diesel cap Diesel 70 12% Acid Mixture Design: 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.5 % F078 Foaming Agent 10.0 ppt L041 Chelating Agent 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer 12. Produce pickle back to test separator and well clean up tank. Total pickle volume to flowback is 315 Bbls, 1.5 times wellbore volume. HCI Perf Wash /SIT Treatment 13. Reduce wellbore temperature by pumping 240 bbls of filtered 2% KCI + Surfactant F103 preheated to 100°F at 4-6bpm. The objective is to cool the wellbore to help prevent the wax beads from prematurely melting and to displace all gas from the wellbore. The melting point of the wax beads is 168°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the wax beads of 168°F. 100°F water should be used to reduce the wellbore temperature of 256°F to below the 168°F melting point. Ensure there is no shut down time after pumping the cool down, as the formation will quickly warm back up quickly. No portion of the belo ork should be performed w/out fi~taking time to ensure No Accidentso harm to People, and No damag .the Environment 14. Bullhead acid treatment down the tubing per the treatment schedule below. Pump at 3-5 bpm if possible while loading tubing and displacing gas from wellbore. After tubing is displaced with treating fluids, reduce rate to correspond with a maximum surface treating pressure of 3500 psi (to stay below 0.70 psi/frac gradient). Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. Record pump rates, tubing, IA and OA pressures throughout the job. Note: If the diversion locks up causing loss of infectivity, incrementally increase pump pressure to 3500 psi (max) and hold for leak off. If no leak off occurs contact Bob Younger or Jack Lau to discuss plan forward. HCI Treatment Desi n Schedule 12% HCL Acid Design: 8.5 % L66 Scale Inhibitor 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 50.0 ppt L041 Chelating Agent 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer Note: Acid strength to be verified and documented via titration before leaving Sch/umberger. Please note the acid titrations on the WSR and have results. available on location. 15. Shut well in for 4 hours to allow scale inhibitor to precipitate Stage Fluid Type Vol (bbls) 1 Liquid pack -cool wellbore 2% KCI +F103 240 2 Acid 12% HCI + L066 50 4 Over Flush (5' radial displacement) 2% KCI + L066 45 s 1.5 PPA Wax Beads + HEC Wax Beads s s Spacer 2% KCI + F103 5 ~ Acid 12% HCI + L066 50 s Over Flush (5' radial displacement) 2% KCI + F103 45 io Displacement 2% KCI i4o 11 Displacement/Freeze Protect Diesel ~o • ~ No portion of the belo ork should be performed w/out fitaking time to ensure No Accidento harm to People, and No damag the Environment Acid Flowback 16. After the 4 hour shut-in, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 693 bbls (Tubing 210 bbl + Treatment 411 bbl + Flowline 72 bbl). After clean-up, divert back to the plant and get 2 6-hour tests. 17. Start sampling when the tubing volume has been brought back to surface. Grab 1 liter sample in a clean nalgene bottle once per hour until the flowback is complete and the well is returned to production.. Sample should be taken from the test separator. Label bottles as: • Well: NS16A • Date/Time: • Bbls Produced: • Tests: pH, solids quantification and identification, common cations by ICP, presence of emulsions • Contact: Craig Graff 564-5185 Note: Appropriate PPE to be used during acid sampling 18. Post flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree ost acid treatment. 19.Obtain produced fluid samples once per well test after the treatment. Obtain produced fluid samples once per month for ~2 years post treatment, or until scale inhibitor returns diminish to the point the well needs to be inhibited again. These samples should be analyzed for P,Ca, Fe, B, CL. Add well to GPB lab sampling request list. 20. Perform complete water analysis on the sample taken 1 week after treatment. Procedure Contacts: Robert Younger Jack Lau W K: 564-5392 W K: 564-5102 H M: 677-2599 Cell: 227-2760 Cel I: 830-4920 T(2EE= F ~ ABB-VGI5-118" 5KSI N S 16 A S NOTES: ***4-1 /2" GHROME TBG &LNR*** 1024'- j 4-1 /2" TRM-4E SSSV NIP, ID = 3.812" 13-3/8" TAM PORT COLLAR 13-318" EZSV (02/10/08) 9-5/8" CSG STUB (02/07/08~~ -312"4CSG, 68#, L-80 BTC, 3494' s-5/a" Ezsv 3670' (01 /29/08) _ \ 9-5/8" CSG, 47#, L-80 513 HYDRIL XO TO L-80 BTC 9-518" CSG, 47#, L-80 BTC, ID = 8.681" Minimum ID = 2.387" @ 13522' 4-1 /2" X 2-7/8" XO 4-112" TBG, 12.6 #, 13CR-80 VAM TOP, -C .0152 bpf, ID = 3.958" 4-112" TBG, 12.6 #, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: SWS- PDC ON 04/03/08 ANGLE AT TOP PERF: 20 ° @ 14274' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD} Opn/Sqz DATE 2" 6 14274 - 14304 O 06/12/08 2" 6 14274 - 14339 O 07/27/08 2" 6 14276 - 14296 O 07!04!08 2" 6 14289 - 14339 O 05/02/08 2" 6 14304 - 14339 O 04!05/08 7" LNR, 29 #, L-80 521 HYDRIL, .0371 bpf, ID = 6.184" 4-1/2" LNR, 12.6 #, L-80 521 HYDRIL, 0152 bpf, ID = 3.958" 2-718" LNR, 6.4#, L-80 STL, .0058 bpf, ID = 2.441" MILLOUT WINDOW (NS-16A) 3250' - 3274' GAS LIFT MANDRELS / TYPE VLV LATCH-PORT DATE i MMG DMY RK 0 03/27/0 12178' --~ 9-5/8" X 7" BKR ZXP LTP w / 11' PBR, ID = 6.200" 12199' 7" X 5" BKR FLEX LOCK HGR, ID = 6.200" 13398' -14-112" FIBER OPTIC TRANSDUCER, ID = 3.958" 13423' 4-112" HES X NIP, ID = 3.813" 1~' I-17" X 4-112" BKR PREMIER PKR, ID = 3.875" 13471' -~4-1/2" HES X NIP, ID = 3.813"~ 13479' 7" X 5" HRD ZXP LTP w / 17' PBR, ID = 4.450" 13483' 4-1/2" HES XN NIP, ID = 3.725"~ 13497' 4-112" SELF ALIGNING MULE SHOE, ID = 3.850" 13507' 7" X 5" BKR FLIX LOCK HGR, ~ = 4.40" 13516' 5" X 4-1/2" XO PUP, ID = 3.94"~ 13522' 4-1 /2" X 2-7/8" XO, ID = 2.387" 13685' -j 7" X 5" BKR ZXP LTP w / 12' PBR, ID = 4.350" 13709' 7" X 5" BKR FLIX LOCK HGR, 10 = 4.370" 13718' S" X 4-112" XO PUP, ID = 3.930" I PBTD I DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/02 JAS INIT COMPLETION 07/09/08 WWR/TL ADPERF 8< 2-718" LNR CORRECTION 03/21/03 FM FINAL COMPLETION 07126108 WWR/PJ DRLG DRAFTCORRECTIONS 03/25/08 N33E SIDETRACK (NS-16A) 09/05/08 WRR/PJC PERFS (07/27/08) 04/18/08 /TLH GLV C/O? (03/27/08) 05/02/08 JLJ/TLH ADPERFS 07!05108 ?/ PJC DRLG DRAFT CORRECTIONS NORTHSTA R WELL: NS16A PERMIT No: 2061410 API No: 50-029-23096-01 SEC 11, T13N, R13E, 1199' FSL & 645' FEL BP Exploration (Alaska) 113-3/8" WHIPSTOCK 102/11 ,. Y` ~ '~ t~ `~~ ,~~ Date 10-09-2008 ` ,.~+ „~ Transmittal Number:93001 QCT ~ '1r,;~} E ,_,.., BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. ~~ ~ Iq3 1 ~~ If you have anv questions. please contact Joe Lastufka at (9071564-4091 Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS11 08-23-2008 SCH 1 14300 14650 PERFORATION RECORD NS11 08-23-2008 SCH CD-ROM -PERFORATION RECORD NS08 08-28-2008 SCH 1 11000 11899 PERFORATION RECORD / JEWELRY LOG NS08 08-28-2008 SCH CD-ROM -PERFORATION RECORD /JEWELRY LOG NS07 08-26-2008 SCH 1 13334 13374 PERFORATION RECORD NS07 08-26-2008 SCH CD-ROM -PERFORATION RECORD NS05 08-22-2008 SCH 1 13600 13860 PERFORATION RECORD NS05 08-22-2008 SCH CD-ROM -PERFORATION RECORD NS09 08-29-2008 SCH 1 12790 13346 MEMORY DENSITY LOG NS09 08-29-2008 SCH CD-ROM -MEMORY DENSITY LOG NS24 08-29-2008 SCH 1 12006 12482 MEMORY DENSITY LOG NS24 08-29-2008 SCH CD-ROM -MEMORY DENSITY LOG NS16A 09-12-2008 SCH 1 14182 14366 MEMORY PRODUCTION PROFILE NS16A 09-12-2008 SCH CD-ROM -MEMORY PRODUCTION PROFILE NS16A 09-16-2008 SCH 1 14180 14350 PRODUCTION PROFILE NS16A 09-16-2008 SCH CD-ROM -PRODUCTION PROFILE Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~C~ '~ '~~ .') ~....;,, Y ,,: BPXA WELL DATA TRANSMITTAL BPXA AOGCC Murphy Exploration DNR MMS Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 9951.9-6612 Date 10-09-2008 Transmittal Number:93001 David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski E~~-- :., _.. STATE OF ALASKA ~~-- r5 ~~ ~x `~._ ~; ALA~A OIL AND GAS CONSERVATION COM SSIC7fV REPORT OF SUNDRY WELL OP~,.T~I`~S ~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated. Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development -~' - Exploratory -: 206-1410 3. Address: P.O. Box 196612 StratlgraphlC ~ Service ' 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.92 RT - NS16A - 8. Property Designation: 10. Field/Pool(s): ADLO-312799' NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 ~ feet Plugs (measured) None true vertical 11305.92 ~ feet Junk (measured) None Effective Depth measured 14414 feet true vertical 11218 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4620 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 0 - 13497 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" Baker S-3 Perm PKR 1344' 4-1/2" SSSV 1024' 0 0 0 0 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: 950 6756 130 745 Subsequent to operation: 3046 21800 429 1242 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory ~' Development ~ - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~~ ~ Gas WAG ~ GINJ ~~~ WINJ ~' WDSPL 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: 308-284 Contact Gary Preble Printed Name Gary Preble Title Data Engineer Signature Phone 564-4944 Date 9/24/2008 Form 10-404 Revised 04/2006 ~ ~ Submit Original Only NS16A 206-1410 PFRF ATTAC:HMFNT Operation Date Perf Operation Code Meas Depth Top Meas Depth Base ' Tvd Depth Top __ Tvd Depth Base 4/5/08 _ PER 14, 304. 14, 319. 11,113.16 11,127.34 4/5/08 P ER 14,319. 14,339. ___ 11,127.34 11,146.31 4/30/08 _ APF 14,289. 14,339. 11,099.02 11,146.31 5/1 /08 RPF 14,299. 14,304. 11,108.44 11,113.16 5/1 /08 RPF 14,304. 14,319. 11,113.16 11,127.34 5/1/08 RPF 14,319. 14,339. 11,127.34 _ 11,146.31 5/2/08 _ RPF 14,289. 14,299. 11,099.02 11,108.44 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 7/4/08 RPF 14,276. 14,296. 11,086.8 11,105.62 7/27/08 RPF 14,274. 14,279. 11,084.93 11,089.62 7/27/08 RPF 14,279. 14,289. 11,089.62 11,099.02 7/27/08 RPF 14,289. 14,299. 11,099.02 11,108.44 7/27/08 RPF 14,299. 14,319. 11,108.44 11,127.34 7/27/08 RPF 14, 319. 14, 339. 11,127.34 11,146.31 AB ABANDONED PER PERF _ APF ADD PERF RPF REPERF _ BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS ___ SAND PLUG SET __ FIL FILL _ SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ _ SQUEEZE _ MIS MECHANICAL ISOLATED _ STC STRADDLE PACK, CLOSED__ MLK ( MECHANICAL LEAK STO STRADDLE PACK, OPEN OH ~ OPEN HOLE • ~- i NS16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/13/2008 CTU # 6 (acid treatment) (interact not publishing) attend ATP meeting. Rig up, kill l :iwell w/ 10 bbls meth, 340 bbls, 2% KCL, LRS pumped 50 bbls diesel RIH drift to 'below perfs Recip over the perfs with acid **"` Job Continued on 9/14/08 W SR `*** 9/13/2008 *"*CONT WSR FROM 09/13/08""" (mem pprof /pre acid) RAN SLB MEMORY PRODUCTION LOGGING TOOLS MAKING INTERVAL PASSES FROM 14150' SLM TO 14360' SLM. WITH WELL CHOKED BACK TO 50 BEANS. (PERFS: 14274' MD TO 14339' MD). MADE TIE IN PASS FROM 14360' SLM TO 13100' SLM. OBTAINED GOOD DATA. SWAB S/I, WING OPEN, SSV OPEN, MASTER OPEN, CASING VALVES OPEN ' TO GAUGES **`JOB COMPLETE""" 9/13/2008 T/I/O = 3000/vac/89 ***Assist CTU w/ acid treatment'"'* Pumped 50bbls diesel, j after CTU killed well w/ KCI. Acid treatment ongoing. FWHP's = 1200/vac/vac 9/14/2008'CTU # 6 1.75" CT (Interact Not Publishing) Acid Treatment Continued from "9/13/08 WSR Pumping Over Displacement of acid. POOH RD get unit ready to go back on the barge. Acid titration 12.1 iron less than 50 ppm. ****job complete*"`* FLUIDS PUMPED BBLS 10 METH 340 2%KCL 100 DIESEL 450 TOTAL • ~-°~a 3 ~-~ ~,~ ~.~ , ~ ~ J 6_ ~ ~ r A ~ t 1 8 C ~ ~~ SARAH PALIN, GOVERNOR CO~T~y~~~A~O ~OM~r ~ O 333 W 7th AVENUE, SUITE 100 •~-7 ii ~•il~i.i-7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A ~ ~ ~ (~ f -- Sundry Number: 308-284 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Sea_mount, Jr. _ r ~ Chair DAZED this ~ day of August, 2008 Encl. .~df~- , ,~ ~ n ~ ~~ ~ ~.~~ ,p ~ ~~ 8 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION '"~~ l ~ ~'~'~~ ~`~ ~ ~~~8 E1 ~, APPLICATION FOR SUNDRY APPROVA~ 20 AAC 25.280 ~ ` "'" 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ~ Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ~ ~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni0 ~ Exploratory ^ 206-1410 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 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: NS16A _ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 • 56.46 - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 - 11305.92 - 14414 ~ 11218 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/25/2008 OIL ~ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name rf u ger Title Production Engineer Signature Phone 564- 5392 Date 8/11/2008 COMMISSION USE ONLY Number: Q~ ~ ~~ Sund t t ti it C diti f l N tif C i i th a represen ve on ons o approva : o y omm ss on so a a ry may w ness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~F~, auG ~ ~ Boas Subsequent Form equired: ~ r ~ ° APPROVED BY Q ~' ~I Approved by: COMMISSIONER THE COMMISSION Date: D Form 10-4(~ Revis~d a60~ ~ ~ ~ ~ ~ Submit in Duplicate NS16A 206-1410 DFRF ATTA(_HMFNT Sw Name Operation Date Perf Operation Code - -- -- - - - Meas Depth Top - - --- ------ - - Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 4/5/08 PER __ 14,319.. 14,339. 11,127.34 11,146.31 NS16A 4/30/08 APF 14,289. 14,339. 11,099.02 11,146.31 NS16A 5/1/08 PER 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/08 APF 14,276. 14,296. 11,086.8 11,105.62 NS16A 7/27/08 APF 14,274. 14,279. 11,084.93 11,089.62 NS16A 7/27/08 APF 14,279. 14,289. 11,089.62 11,099.02 NS16A 7/27/08 APF 14,289. 14,299. 11,099.02 11,108.44 NS16A 7/27/08 APF 14,299. 14,319. 11,108.44 11,127.34 NS16A 7/27/08 APF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS _ _ BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • No pprtion of the belo~ork should be performed w/out fi~taking time to ensure ~~ No Accidents, o harm to People, and No damage the Environment To: Jerry Bixby/Clark Olsen -Well Operations Supervisor August 8, 2008 From: Robert Younger- Northstar Production Engineer subject: NS16A CTU Acid Treatment Est. Cost: $150 M AFE NSFLDWLI6 Est. IOR: 1000 BOPD Please perform a coil tubing acid treatment on NS16A per the below procedure. Type IOR PR N DSWL AFE Job Description C 1000 NS16A NSFLDWL16 Pump Acid Treatment per below procedure. Current Status: Producer Last Test: 07/28/08: 1944 BOPD, 405 BW PD, & 12525 MSCFD Max Inclination: 52.5° at 7,169' md; ~20° at Perfs Max Dog Leg: 8.6 at 3274' MD Minimum ID: 2.40" at the 4.5" x 2.875" crossover @ 13527' and Last TD tag: 04/28/08: 14,382' SLMD Last Downhole Op: 07/27/08: RePerf Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP: Anticipate 5,100 psia @ 11,100 ft ss NS16A is a 2008 development well at Northstar. Following a Coil Acid /Scale Inhibition treatment, the well's productivity dropped off and on 05/02/08 15' of new perforations were added in addition to re-shooting the original 35' of perforations. The 50' of perforations shot 05/02/08 resulted in a 1000 BOPD increase in production. Unfortunately, the wells' production dropped off again and 30' of perforation were shot 06/12/08 consisting of 15' of reperfs and 15' of new perforations. The 30' of perforations shot 06/12/08 resulted in a 2500 BOPD increase, but the test 12 days latter on 06/24/08 showed NS16A's production had dropped 2200 BOPD from the post perforation test. Perforations were required on 07/28/08 & 07/04/08 to maintain NS16A's production. A summary of activity is outlined below. Operational Highlights [Add New] [View All] Date 07f28J2008 65' RePerf --~ 1000 BOPD Increase Edit Gelete 07}04/2008 20' RePerf --> 370 BOPD Increase Edit Gelete 06/12f2008 15' RePerf & 15' AdPerf --> 2500 BOPD Increase Edit Gelete 051'02/2008 35' RePerf & 15' AdPerf --} 1000 i34PD Increase Edit Gelete 04J10~2008 CT Acid Jvb --~ Minimal Impact Edit Gelete . No portion of the belo~ork should be performed w/out fi~taking time to ensure No Accidents, o harm to People, and No damag the Environment Based on the historical scale issues at Northstar, the below acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. Please contact Bob Younger with any questions, comments, or concerns - 564- 5392 (w); 830-4920 (c); 677-2599 (h). Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. Please do not filter fluids that contain L66. All filtering should be performed before the addition of the L66 scale inhibitor to insure the inhibitor does not plate out in the filters. Please do not add friction reducer to water that will contact the formation due to formation plugging issues. Please avoid contacting L66 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. Prep Work: 1. Mobilize coil unit, pumps, tanks and acid transport to Northstar. Order out necessary volume of seawater, 2% KCL, acid, and diesel. Please review: Alaska Wells Group Rigless Operations Manual: Coiled Tubing Operations Section: CTU Operations at Northstar Island COIL TUBING ACID/SCALE INHIBITION TREATMENT: 2. MIRU. 3. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 4. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 5. PT Dowell surface lines to 5000 psi. 6. Bullhead kill with filtered 2% KCI (volume to top perf is 221 bbls). Please leave a 50 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. No portion of the belo~ork should be performed w/out fi~taking time to ensure No Accidents, o harm to People, and No damage .the Environment 7. RIH with jetted nozzle (min ID = 2.40"). Drift to below perforations to insure no obstructions exist. 8. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 50 bbls Acid w/ 10% L66 b) 75 bbls 2% KCI (75 bbls provides ~5' radial displacement) Please do not POOH until the total over-flush volume has been pumped in order to reduce the chance of stirring-up solids that could plug the perforations. Ensure well has a 50 bbls diesel cap for an under-balanced flowback. Coil Treatment of 12% HCL Acid to contain: 10% L66 Scale Inhibitor 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer Note: 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. 9. Shut well in for 4 hours after injection to allow scale inhibitor to precipitate. 10. RD Schlumberger. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASC11 or EXCEL, copy of the pumping rates and pressures) to Robert.Younger@ bp.com. Flowback Procedure: 11. After the 4 hour shut-in, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 407 bbls (Tubing 210 bbl + Treatment 165 bbl + Flowline 72 bbl). After clean-up, divert back to the plant and get 2 6-hour tests. 12. Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. Procedure Contacts: Robert Younger W K: 564-5392 H M: 677-2599 Cel I: 830-4920 YREE= ~ ~ AE3B-VGI5-1/8"5KSI WELLHEAD = 13-5/8" MULTIBOWL 5KS ACTUATOR = BAKEF ...... KB. ELEV = .. .. . 56.46 BF. ELEV = 40.56' (CB 15.9'; KOP = 100 Max Angle = 53° @ 7169 Datum MD = 13686 Datum TV D = 10500' S: 13-3/8" WHIPSTOCK (02/10/08) I13-3/8" ¢SV (02/10/08) ~5/8" CSG STUB (02!07/08) 13-3/8" CSG, 68#, L-80 BTC, 3494' ID = 12.415" _ 9-5/8" ¢sv 3670' (01/29/08) _ 9-5/8" CSG, 47#, L-80 513 HYDRIL XO TO L-80 BTC 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" I 3282' I Minimum ID = 2.387" @ 13522' 4-112" X 2-7i8" XO 4-1/2" TBG, 12.6 #, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6 #, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: SWS- PDC ON 04/03/08 ANGLE AT TOP PERF: 20 ° @ 14274' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2" 6 14274 - 14304 O 06/12/08 2" 6 14276 - 14296 O 07/04/08 2" 6 14289 - 14339 O 05/02/08 2" 6 14304 - 14339 O 04/05/08 7" LNR, 29 #, L-80 521 HYDRIL, 13850' .0371 bpf, ID = 6.184" 4-1/2" LNR, 12.6 #, L-80 521 HYDRIL, 14093' .0152 bpf, ID = 3.958" 2-7/8" LNR, 6.4#, L-80 STL, .0058 bpf, ID = 2.441" 14504' N S 16 A S NOTES: ***4-1 /2" CHROME TBG &LNR*** V 1024' I--(4-1/2" TRM-4ESSSV NIP, ID = 3.812" 1587' I~ 13-3/8" TAM PORT COLLAR MILLOUT WINDOW (NS-16A) 3250' - 3274' GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE 12178' -~ 9-5/8" X 7" BKR ZXP LTP w / 11' PBR, ID = 6.200" 12199' 7" X 5" BKR FLEX LOCK HGR, ID = 6.200" 13398' ~ 4-1l2" FIBER OPTIC TRANSDUCER, ID = 3.958" 13423' 4-1/2" HES X NIP, ID = 3.813" 13444' 7" X 4-1/2" BKR PREMIER PKR, ID = 3.875" 13471' 4-1/2" HES X NIP, ID = 3.813" 13479' 13483' - 7" X 5" HRD ZXP LTP w / 17' PBR, ID = 4.450" { 4-1/2" HES XN NIP, ID = 3.725" 13497' 4-1/2" SELF ALIGNING MULE SHOE, ID = 3.850" 13507' 7" X 5" BKR FLEX LOCK HGR, ID = 4.40" 13516' 5" X 4-1/2" XO PUP, ID = 3.94" 13522' 4-1/2" X 2-7/8" XO, ID = 2.387" 13685' -j 7" X 5" BKR ZXP LTP w / 12' PBR, ID = 4.350" 13709' 7" X 5" BKR FLIX LOCK HGR, ID = 4.370" 13718' 5" X 4-1/2" XO PUP, ID = 3.930" I PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/02 JAS INIT COMPLETION 07/09/08 WWR/TL ADPERF & 2-7/8" LNR CORRECTION 03/21/03 FM FINAL COMPLETION 07/26/08 WWR/PJ DRLG DRAFT CORRECTIONS 03/25/08 N33E SIDETRACK(NS-16A) 04/18/08 /TLH GLV C/O? (03/27/08) 05/02/08 JLJ/TLH ADPERFS 07/05/08 ?/ PJC DRLG DRAFT CORRECTIONS NORTHSTA R WELL: NS16A PERMff No: 2061410 API No: 50-029-23096-01 SEC 11, T13N, R13E, 1199' FSL & 645' FEL BP Exploration (Alaska) ~~,~ STATE OF ALASKA ~~~~ ~ _ ~ ~~, ''~ ALAS OIL AND GAS CONSERVATION COMM~SION ~~.F~~ REPORT OF SUNDRY WELL OPERATIONS '~f°. ~~~, ~,, ' 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extensiorx~ (,~~ Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well [~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5: ~ermit to Drill Number: Name: De~lopment ~ Exploratory ~ 206-1410 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: ~~ Anchorage, AK 99519-6612 ! 50-029-23096-01-00 7. KB Elevation (ft): 9. Well Name and Number: '`. 55.92 RT '~ NS16A 8. Property Designation: 10. Field/Pool(s): ADLO-312799 '~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 feet Plugs (measured) None true vertical 11305.92 feet Junk (measured) None Effective Depth measured 14414 feet true vertical 11218 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4620 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 0 - 13497 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" Baker S-3 Perm PKR 1344' 4-1/2" SSSV 1024'. 0 0 0 0 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: 1139 7444 114 Subsequent to operation: 2150 13667 222 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~„ Development ~~" Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ? WINJ ~' WDSPL 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: 308-233 Contact Robert Younger Printed Name Robert nger Title Production Engineer Signature Phone 564-5392 Date 8/5/2008 Form 10-404 Revised 04/20 ~ ~~~ ~~~ ' ~ L ~ 1 ~~1 r 1~ `~ ~ ~ ~ ~ Submit Original Only `~,,uF q .~ y ~ k ~r:: ~~ !ice ~-~ ~ ~-~~ NS16A 206-1410 DFRF ATTAf'_HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34_ NS16A 4/5/08 PER 14,319. 14,339. X 11,127.34 11,146.31 NS16A 4/30/08 APF _ 14,289. 14,339. 11,099.02 11,146.31 NS16A 5/1/08 PER 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF _ 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/08 APF 14,276. 14,296. 11,086.8 11,105.62 NS16A 7/27/08 APF 14,274. 14,279. 11,084.93 11,089.62 NS16A 7/27/08 APF 14,279. 14,289. 11,089.62 11,099.02 NS16A 7/27/08 APF 14,289. 14,299. 11,099.02 11,108.44 NS16A 7/27/08 APF 14,299. 14,319. 11,108.44 11,127.34 NS16A 7/27/08 APF 14,319. 14,339. 11,127.34 11,146.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL _ SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED _ FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • .~, • NS 16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY ~~ 7/26/2008'""WELL FLOWING, INITIAL T/I/O = 700/0/75 PSI***Job Scope - Re-perforate :RIG UP ELINE TO PERFORATE 65' OF 2" POWERJET HSD ""*JOB CONTINUED ON 7-27-08 "*'`" JOB IN PROGRESS 7/27/2008'"**JOB CONTINUED FROM WSR 7-26-08 "'`*" 'TIED INTO SLB PDC LOG DATED 4/3/08. RE-PERFORATE FROM 14274' TO :14339', USING 2" 2006 POWER JET HSD' GUNS, 6 SPF, EHD=0.20" TTP=18.6". ALL SHOTS FIRED. ***JOB CONTINUED ON WSR 28-JULY-08""* _..___.._...... ...m__~ ~. __ .. ......_ ... _ __ 7/27/2008 "'`JOB CONTINUED FROM WSR 7-27-08 **** !RIG DOWN AFTER COMPLETING 65' OF 2" POWER JET HSD GUNS TO PERFORATE INTERVALS: 14319'-14339'. 14299'-13319'. 14279'-14299', 14274'-14289' FINAL T/I/O = 745/0/O--MASTER OPEN, SWAB CLOSED, IA/OA OPEN TO :GAUGES **"JOB COMPLETE, WELL LEFT FLOWING, WELL ROW OP NOTIFIED**~ FLUIDS PUMPED BBLS 1 diesel 1 Total NS 16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~CTIVITYDATE SUMMARY 7/26/2008""`*WELL FLOWING, INITIAL T/I/O = 700/0/75 PSI***Job Scope - Re-perforate RIG UP ELINE TO PERFORATE 65' OF 2" POWERJET HSD """JOB CONTINUED ON 7-27-08 **"" JOB IN PROGRESS 7/27/2008 7/27/2008: ***JOB CONTINUED FROM WSR 7-26-08 **"* TIED INTO SLB PDC LOG DATED 4/3/08. RE-PERFORATE FROM 14274' TO 14339', USING 2" 2006 POWER JET HSD GUNS, 6 SPF, EHD=0.20" TTP=18.6". ALL SHOTS FIRED. *"*JOB CONTINUED ON WSR 28-JULY-08*** **JOB CONTINUED FROM WSR 7-27-08 **'`* RIG DOWN AFTER COMPLETING 65' OF 2" POWER JET HSD GUNS TO PERFORATE INTERVALS: 14319'-14339', 14299'-13319', 14279'-14299', 14274'-14289' FINAL T/I/O = 745/0/O--MASTER OPEN, SWAB CLOSED, IA/OA OPEN TO GAUGES **"JOB COMPLETE, WELL LEFT FLOWING, WELL ROW OP NOTIFIED*** FLUIDS PUMPED BBLS 1 diesel 1 Total ~~~ ~^ ~~ Date 07-23-2008 Transmittal Number:92988 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vro, haves anv nnPCtinnc nlPaca contact Toe T.actufka at (90715h4-4091 --~- - Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS10 07-10-2008 PDS 8 0 8022 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS10 07-10-2008 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS32 07-09-2008 PDS 5 0 8116 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS32 07-09-2008 PDS RESULTS SUMMARY NS16A 07-04-2008 SCH 1 14100 14376 PERFORATING RECORD CD-ROM -PERFORATING NS16A 07-04-2008 SCH RECORD NS19 06-30-2008 SCH 1 13550 13940 PERFORATING RECORD CD-ROM -PERFORATING NS19 06-30-2008 SCH RECORD NS30 06-28-2008 SCH 1 15890 16197 PERFORATING RECORD CD-ROM -PERFORATING NS30 06-28-2008 SCH RECORD Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka ac~~-+~r1 '~~~~5~ Petrotechnical Data Center a6~ =ae'1 /(~~ ~' 2 b2 ~ ~~ ~ ~(o~'v BPXA AOGCC Murphy Exploration DNR MMS ~,TCat~-iSsa ~lo~o~~ c~~r.e ~a3 - ts~ ~(~~ G~ David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 - ~~ STATE OF ALASKA ~''~~~ AL~KA OIL AND GAS CONSERVATION COMMISSION 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ F, :. ,~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory ~"' 206-1410 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 55.92 RT • NS16A 8. Property Designation: 10. Field/Pool(s): ADLO-312799 NORTHSTAR Field/ NORTHSfAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 ~ feet Plugs (measured) None true vertical 11305.92 ' feet Junk (measured) None Effective Depth measured 14414 ~ feet true vertical 11218 , feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 0 - 13497 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" Baker S-3 Perm Packer 1344' 4-1/2" SSSV 1024' 0 0 0 0 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: 1598 9255 97 744 Subsequent to operation: 2003 15176 226 736 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ' Development ~` Service I~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil I Gas WAG GINJ ~ ' WINJ WDSPL 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: 308-233 Contact Robert Younger Printed Name Robert Y ger Title Production Engineer Signature Phone 564-5392 Date 7/15/2008 ,~~ ~ ~ zoos REPORT OF SUNDRY WELL OPERATIONS ~''~ ~~" ~~~' ~ "~` ~ ~- ~~~s, ~ inn Form 10-404 Revised 04/2006 ~ ~ ~~~ ,J~~ ~ ~ 1D~~ Submit Original Only NS16A 206-1410 PFRF ~TT~('.HMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A __ 5/1/08 PER __ 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 NS16A 7/4/2008 RPF 14276 14296 11086.8 11105.8 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE LJ 5~ NS 16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~CTIVITYDATE SUMMARY 7/3/2008 `****Well flowing on arrival*****(Re-perforate) ',Travel to Northstar. Begin spotting and preparing equipment for re-perforating Continue on WSR 7/4/08 CONTINUED FROM WSR 7/3/08'`** WELL FLOWING ON ARRIVAL*** INITIAL T/I/O = 745/0/275 PSI TIED INTO SLB PRIMARY DEPTH CONTROL LOG DATED 4/3/08. TAG TD AT 14400' MD. PERFORATE 20' x 2" POWERJET HSD GUNS 6 SPF FROM 14276'-14296'. FINAL T/I/O = 3000/0/0 PSI. PUT ON PRODUCTION. RD. DEPART ISLAND. '`**"**JOB COMPLETE**'`*'`* FLUIDS PUMPED BBLS 1 diesel 1 Total Date 07-10-2008 Transmittal Number:92984 ~~~ ~' :~„ '_ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf von have anv nnectinnc nlease contact .ine T,astufka at (9071564-4091 Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS16A 06-12-2008 SCH 1 14150 14350 PERFORATING RECORD NS16A 06-12-2008 SCH 1 14150 14350 CD-ROM -PERFORATING RECORD NS33 02-11-2007 GYRODATA 1 0 4400 SURVEY REPORT NS33 02-11-2007 GYRODATA 1 0 4400 CD-ROM -SURVEY REPORT %/ ~ ji ~ ~ - Please Sign and eturn one copy of this transmittal. Thank You, _ Joe Lastufka ~ ~ ~ _ Petrotechnical Data Center BPXA David Fair AOGCC Christine Mahnken Murphy Exploration Ignacio Herrera DNR Kristin Dirks MMS Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Btvd. PO Box 196612 Anchorage, AK 995 1 9-66 12 STATE OF ALASKA s-d~ ALASKA C~AND GAS CONSERVATION COMMONS WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~aY 1 3 2008 „I Ol c~ Vas Cans. Commissi>~r 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: nC Ofag@ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or AbaprJ~./ 4/5/2008 ~(•~ ~ 12. Permit to Drill Number 206-141 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/12/2008 ~ 13. API Number 50-029-23096-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/16/2008' 14. Well Name and Number: NS16A - 1199 FSL, 645 FEL, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 1234' FSL, 3603' FEL, SEC. 10, T13N, R13E, UM 8. KB (ft above MSL): 55.92 Ground (ft MSL): 16.1 15. Field /Pool(s): Northstar Unit - Total Depth: 1221' FSL, 3706' FEL, SEC. 10, T13N, R13E, UM 9. Plug Back Depth (MD+TVD) 14414 11218 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 659830 y- 6030971 Zone- ASP4 10. Total Depth (MD+TVD) 14505 ' 11306 - 16. Property Designation: ADL 312799 i TPI: x- 651593 y_ 6030834 Zone- ASP4 Total Depth: x- 651490 y- 6030819 Zone- ASP4 11. SSSV Depth (MD+TVD) 1024 1019 17. Land Use Permit: LO-N96-006 18. Directional Survey ®Yes ^ No bmit I ronic and rin d information er 20 AAC 25. 50 19. Water depth, if offshore 39' ft MSL 20. Thickness of Permafrost (TVD): 1545' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 C 25.071) MWD ,GYRO , GR , RES , DIR , PWD ,DEN , NEU L,I~W40i./~~ol.Sd ivJ,6 _J~o?.e : ~~TYd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT " WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 1 X- rf 2 1' 1' 2 iv n 1 -3/8" 68# L- 0 44' 44' 2993' 16" 618 sx PF 'L' 470 sx CI s ' 9-5/8" L-80 41' 12 74' 41' 9 6 ' 12-1/4" 72 x Ext nded lur 7 sx' ' 2 1 17 ' 1 2' 7 I 'G' 4-1/2" 12. L- 1 140 1 555' 10 20' 119 x Clas 'G' ~ 2-7/ " .4# 1 Cr 1 479' 14504' 1 7 ' 11 - /4" s I 23. Open to production or inject ion? ®Yes ^ No 24. TuswG?RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, 13Cr80 13497' 13444' MD TVD MD TVD 14289' - 14339' 11099' - 11146' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED Freeze Protected with 229 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 6, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 5/6/2008 HOUfS Tested: 4 PRODUCTION FOR TEST PERIOD OIL-BBL: 421 GAS-MCF: 1740 WATER-BBL: 7.6 CHOKE SIZE: 165 GAS-OIL RATIO: 4133 Flow Tubing Press. 765 CaSing PreSS: 1144 CALCULATED 24-HOUR RATE OIL-BBL: 2526 GAS-MCF: 10440 WATER-BBL: 46 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^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. COiNPLETIf}N~ None Form 10-407 Revised 02/2007 ' ~ I ~ ~ ~iONTINUED ON REVERSE SIDE ~ ~ ~~i ~ ~ 008 oR L L ~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested? Yes ®No Permafrost Top If yes, list intervals an rmations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. SV5 3642' 3303' SV4 4036' 3613' None SV3 4368' 3845' SV2 4624' 4011' SV1 5231' 4397' TMBK 5795' 4745' UG3 6484' 5173' UG 1 7374' 5720' WS2 7689' 5913' WS1 8277' 6275' CM3 9179' 6834' THRZ 11423' 8538' BHRZ 11549' 8650' TKUC 11989' 9041' LCU 12111' 9150' Top of Kingak 12850' 9810' Top of Sag River 14040' 10872' Top of Shublik 14178' 10996' TZD 14307' 11116' TZC3 14357' 11163' TZC2 14407' 11211' Formation at Total Depth (Name): Ivishak 14505' 11306' 30. List of Attachments: Summary of Daily Drilling Reports, Post Rig Work Summary, Well Schematic Diagram, Surveys and aLeak-Off Test Summa 31. I hereby certify that the fore oing is true an correct to the best of my knowledge. Signed Sondra ewman Title Drilling Technologist Date - ~ Z- NS16A 206-141 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Paul Hanson, 564-4195 Permi N . / A royal No. INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ' TREE: ABB-VGI 5 1/8" 5ksi ORIGINAL KB. ELEV = 56.46 >. _ _ ~ KB-B F. ELEV = 40.89` WELLHEAD: ABB-VGI 13-5/8" N S 16A Multibowl 5ksi CB. ELEV = 15.57 13 3/8" TAM Port Collar at +/-1587`MD Minimum ID = 2.875 @ 13505' 4.5" x 7" LN R TOP XO 13-3/8" EZSV @ 3282`MD 13-3/8" 68# L-80 BTC @ 3494`MD 9-5/8" EZSV @ 3670`MD 4-1/2" X Nipple @ 12159' MD 4-1/2" Cidra Gauge @ 12180` MD 7" LINER TOP @ 10265` MD 9-5/8 47# L-80 BTC @ 10435'TMD 4.5" Tubing cut @ 11874' 7" PACKER,13 Cr @ 11880' MD 4.5" LINER TOP @ 11926` f„~D 7", 26#/ft L-80, HYDRIL 521 @ 12094` TOC @ 12100' MD Top of Squeezed Perfs @ 12304' MD 4.5", 12.6#, 13Cr Vam Ace PBTD @ 12420' MD TD @ 12424' MD PERFORATION SUMMARY REF LOG: SWS-PDC LOG ON 04/03/08 ANGLE AT TOP PERF: 19° @ 14304' INfrIAL PERF -CHARGE: ???? PENETRATION: ?„ HOLE: ??", PHASE: ?? DEG. Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2" 6 14304 - 14339 O 04/05/08 TD @ 14505' MD DAT€ R)1/ BY COMMENTS DATE REV BY COMMENTS Q611d1D3 N33E 'ORIGINAL COMPLETION D3125/D8 _N33E SIDETRACIC 04!18108 SRBITLH INtTtAL PERFS (04/05108) 0411810$ 1TLH GLV CJO`? (03127108) 2.875", 6.4#, L-80 @ 14504` Northstar WELL: NS1& A API No; 50-029-2309&-01 BP Exploration (Alaska) -120' (4 jts) 5-1 /2" x 4-1/2" VIT (Vacuum Insulated Tubing) 4-1/2" SSSV @ 1024' MD, --1000' TVD 13-3/8" Window Cut @3274' GAS LIFT MANDRELS 7" LINER TOP @ 12178' MD Flex-Lock Hanger and ZXP Packer 9.625", 47# HYDRIL 513/BTC-M @12574' MD X4.5" Fiber-Optic Transducer, 3.945" ID @ 13398' MD 4-t/2" X Nipple @ 13423' MD _ 7" x 4.5" PREMIER PACKER, 13 Cr @ 13444` MD 4-1/2" X Nipple @ 13471' MD (3.813" ID) 4-1/2" XN Nipple @ 13483' MD (3.725" ID) 4-1/2", 12.6#/ft 13CR80 4.5" X 7" LINER TOP XO to 2.875 @ 13505' MD (Flex-Lock &ZXP) 4.5" LINER TOP @ 13685' MD (Flex-Lock &ZXP) 7", 29#/ft L-80, Hydril 521 @ 13850' 4.5", 12.6#, HYDRIL 521 L-80 @14093` TMD 2.875", 6.4#, 13Cr-80 VAM TOP ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: NS16 Page 1 of 47 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To 'Hours ' Task Code NPT Phase Description of Operations 1/18/2008 11:00 - 00:00 13.00 MOB P PRE Pre-job safety meeting and Procedure review with all personnel involved with move. G & I ,ACS, AIC and Pad Operator involved in meeting Discuss responsibilities of all parties involved in the rig move Monitoring flowline, well house & pipe rack clearances Laying Herculite & spotting mats -Had to lay plywood on matting boards as need to keep rig level as we skid out of hole caused by subsidence. 1/19/2008 00:00 - 09:00 9.00 MOB P PRE Move ri from NS23 to NS16 , Pre-job safety meeting and Procedure review with all personnel involved with move. G & I ,ACS, AIC and Pad Operator involved in meeting Discuss responsibilities of all parties involved in the rig move Monitoring flow line, well house & pipe rack clearances Laying Herculite & spotting mats Worked in conjunction with Pad Operator, shut-in and bleed wells and also putting wells back on line as we skid past All work done with appropriate permits 09:00 - 00:00 15.00 RIGU P PRE Rig up Berm Rig, Close doors and weatherize rig, Slide walkways back into position, Rig Up and level stairs, Connect service lines to pipe rack, Secure cellar, Connect Comm lines, Prepare pit to take on seawater, Attach & Test line running to G & I, Complete move check list, Rig up on Well to displace diesel from well, G & I heating seawater for displacement 1/20/2008 00:00 - 12:00 12.00 RIGU P PRE Rig up on Well to displace diesel from well -Rig up on Annulus riser -R/U secondary annulus valve and lines into circ. manifold -R/U and open actuator valve on tree, -G & I take on seawater and heat, -test injection line, -test emergency shut down system, -test remote well emergency shut off, test gas alarms, hang heat blankets on standpipe Rig Acce ted ~ 12:00 Hrs. 1!20/2008 12:00 - 00:00 12.00 RIGU P PRE Rig Up to Displace Diesel freeze protect out of well -G & I take on seawater and heat, -Low PT on circulating lines to 120 psi, -Calibrate Epoch System, -Switch to high line power, -Rig Evacuation drill, j -Adjust pump stroke counters PJSM with all personnel displacing diesel Tested lines to 1500 psi, O.K. Start to displace Diesel out of tubing, Flowline Actuator valve on tree leaking, Blind of flowline actuator line 1/21/2008 00:00 - 02:00 2.00 WHSUR P DECOMP Pre-Job safety meeting with all personnel involved with operation -Line up and start displacing freeze protect diesel from tubing at ICP =1.1 bpm /1720 psi Printed: 421/"LOUB 1:1 S:3J PM a ~ BP EXPLORATION Operations Summary Report Page 2 of 47 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date ICI From - To 'Hours Task '~, Code ~', NPT ~', Phase I Description of Operations ',1/21/2008 00:00 - 02:00 2.00 WHSUR P DECOMP -Pressure increased as we loaded backside up with seawater, FCP = 1.1 bpm / 2010 psi -Pumped a total of 90 bbls from tubing to get good seawater returns G & I Injecting returns 02:00 - 08:30 6.50 WHSUR P DECOMP Line up to pump down tubing to displace diesel freeze protect from IA -pumping ~ 1.3 bpm / 60 psi -Pumped a total of 1737 bbls heated seawater around until clean at surface. G & I Injecting returns 08:30 - 12:00 3.50 WHSUR P DECOMP Continue to circulate 1 annulus volume at 6 BPM 700 psi to allow well to stabilize, taking returns down the drag chain to G &I. 12:00 - 13:30 1.50 WHSUR P DECOMP Pump 70 bbl High-Vis sweep around surface equipment and trip tank to clean same back to G & I. Blow down and RD all circulating lines and manifolds in cellar. Pumped a total of 1897 bbls to G & I. 13:30 - 14:00 0.50 WHSUR P DECOMP Secure tree stand in cellar and check well pressures. Well out of balance 400 psi on tubing, 100 psi on IA. 14:00 - 15:00 1.00 WHSUR P DECOMP RU lines and allow well to U-Tube to balance. T x IA 0 psi. RD and blow down lines. 15:00 - 16:00 1.00 WHSUR P DECOMP PJSM with VETCO service personnel RU T-bar and install BPV, test same from below to 1000 psi. Test held. RD T-bar. 16:00 - 19:00 3.00 WHSUR P DECOMP PJSM -Remove and secure control lines to tree /well head, ND tree and secure same on tree stand. Terminate control line and fiber optic cable at tubing hanger. 19:00 - 20:00 1.00 WHSUR P DECOMP Inspect tubing hanger, threads in good condition. Make dry run with 5.875" MCA x 4.5" IF running tool, 19 rounds to make up. Install blanking plug in tubing hanger. Obtain RKB measurements. 40.21' rotary table to tubing hanger. 20:00 - 00:00 4.00 WHSUR P DECOMP PJSM - NU drilling spacer spool, BOPE, Choke and Kill lines. Install turnbuckles 1/22/2008 00:00 - 12:00 12.00 WHSUR DECOMP PJSM - NU ROPE, Choke and Kill lines. Install turnbuckles, accumulator lines, replace air boots, remove iron rough neck track and master bushings, install drilling riser. Torque all flanges. Make up 5" test joint, Floor safety valve, pump in sub. Center up BOPE with turn buckles, well head leaning to east side of island. 12:00 - 16:00 4.00 WHSUR DECOMP Continue to center BOP stack with rotary table. 16:00 - 17:00 1.00 WHSUR DECOMP PJSM with all personnel. RU test equipment to test 250 psi low, 5000 psi high as per BP / AOGCC regulations. Witness of test by John Chrisp (AOGCC), Kelly Cozby & Roy Hunt (NAD Toolpushers), Chris Clemens (WSL) 17:00 - 21:00 4.00 WHSUR DECOMP Repair leak on riser air boot. Pressure up against Blind shear rams, Kill line, Choke Manifold valves # 2, 5, & 3. Kill line Uni-Bolt connection failed. Replace ring gasket in same and retest. Blind Shear ram bonnet seal failed. PJSM -open blind shear ram and replace bonnet seal. Retest system, 13-5/8" API flange gasket leaking between bottom ram gate and drilling spool. PJSM - Re-torque flange bolts. rnniea: 4i~ vzovo is ixaa rm BP EXPLORATION Page 3 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date 'From - To ~~ Hours Task 'I Code ~ NPT Phase ~ Description of Operations 1/22/2008 21:00 - 00:00 3.00 WHSUR DECOMP Continue Test BOPE Test Blind Shear rams Choke Valves # 1-12 Kill line HCR & Manual: Kill Valves to 250 psi low / 5000 psi High, for 5 min. Test Manual and super choke to 250 psi low / 1500 psi high. 1/23/2008 00:00 - 01:30 1.50 WHSUR DECOMP Install 4-12" test joint, IBOP, Floor safety Valve. 01:30 - 02:30 1.00 WHSUR DECOMP Test: IBOP, Floor Safety Valve, Pass Attempt to test 3-1/2" x 6" VBR, Choke valve #13, Failed Whitey Valve failed on test manifold, bleed off and repair same. Re-pressure system. Whitey valve stem failed on pump in sub and 13-5/8" flange began leaking between bottom ram gate and drilling spool. 02:30 - 03:30 1.00 WHSUR DECOMP PJSM - re-torque flange bolts on drilling spool. 03:30 - 05:30 2.00 WHSUR DECOMP Attempt to test BOP's, found leak between lower ram gate and drilling spool flange again. 05:30 - 08:30 3.00 WHSUR N WAIT DECOMP PJSM on ND BOP's, ND BOP's at drlg spool to change out ring gasket and inspected ring groove, stopped ND operations, Notify Control room of BOP pick in cellar and pick BOP to inspect flange connections on drilling spool and bottom ram gate. 08:30 - 23:30 15.00 WHSUR N WAIT DECOMP Shut down all rig operations do to Phase 3 weather conditions, winds gusting to 65 knots, PJSM with crew on phase 3 weather conditions, unable to move personnel to or from island 23:30 - 00:00 0.50 WHSUR P DECOMP Pre Spud meeting held for NS-16A, Katie Nitzberg, Paul Hanson with Randy Axness rig crew, Anadrill Directional Drillers, Anadrill MWD, MI Mud engineers, WSL & NAD Toolpusher. 1/24/2008 00:00 - 00:30 0.50 WHSUR P DECOMP Continue Pre Spud meeting held by Katie Nitzberg, Paul Hanson with Randy Axness rig crew, Anadrill Directional Drillers, Anadrill MWD, MI Mud engineers. 00:30 - 01:00 0.50 WHSUR P DECOMP PTSM & Helicopter Travel safety video reviewed. 01:00 - 07:00 6.00 WHSUR N SFAL DECOMP PJSM on ND BOP -Remove iron roughneck floor plate, Master bushings, Drilling riser. Inspect bridge crane lines and seat lifting ring. Notify Control room of BOP pick in cellar and pick BOP to inspect flange connections on drilling spool and bottom ram gate. Shorten studs above drilling spool blind flanges and inspect stud cavities on ram gate. Replace API ring gasket and set stack. 07:00 - 09:00 2.00 WHSUR N SFAL DECOMP NU BOPE -Check torque on all BOP flange bolts. Pull riser adapter and reseal same, reinstall drilling riser. Mobilize casing equipment to the rig floor while re-torque flange bolts. 09:00 - 12:00 3.00 WHSUR N SFAL DECOMP Helicopter Crew change, PJSM - & continue NU BOPE -Install and tighten drilling riser, turnbuckles, center stack, and MU 4.5" test joint. 12:00 - 17:00 5.00 WHSUR N SFAL DECOMP PJSM with all personnel. RU test equipment and test BOPE. Top 3.5" x 6" VBR's HCR & Manual Choke valves Choke Manifold valve #13 Bottoms 3.5" x 6" VBR's Printetl: 4212008 1:1 b:JJ t'm i ! BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 1/24/2008 12:00 - 17:00 17:00 - 18:30 18:30 - 19:30 19:30 - 23:00 23:00 - 00:00 1/25/2008 00:00 - 04:30 04:30 - 06:00 06:00 - 09:00 09:00 - 11:30 11:30 - 18:00 18:00 - 21:30 21:30 - 23:00 23:00 - 00:00 1/26/2008 00:00 - 01:30 01:30 - 02:30 02:30 - 03:30 NS16 NS16 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Hours Tank Code NPT 5.00 WHSUR N SFAL Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Phase Page 4 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Description of Operations DECOMP Top Drive Lower well control valve Top Drive Upper well control valve 250 psi low / 5000 psi High Annular preventer 250 psi low 3500 psi High Perform Koomey function test. 1.50 WHSUR N SFAL DECOMP LD 4.5" Test joint and MU 5" Test joint and install same and RU test equipment. 1.00 WHSUR N SFAL DECOMP Test Top set 3.5" x 6" VBR's to 250 psi low / 5000 psi High. Failed. Test Bottom 3.5' x 6" VBR's to 250 psi low / 5000 psi High. Passed. 3.50 ~ WHSUR ~ N ~ SFAL ~ DECOMP ~ PJSM on changing rams -Drain BOP stack open top ram gate bonnets. Inspect rams and replace 3.5" x 6" VBR packer elements on both set of rams. Close and tighten bonnets. 1.00 WHSUR N SFAL DECOMP RU test equipment, fill stack and test Top set of rams with 5" test joint to 250 psi low / 5000 psi High. Test Failed. 4.50 WHSUR N SFAL DECOMP PJSM on changing rams -Drain BOP stack open top ram gate bonnets. Change out top rams to 4-1/2" x 7" VBR's. Close and tighten bonnets. Center BOP stack with rotary. 1.50 WHSUR N SFAL DECOMP RU test equipment, fill stack and test Top set of rams with 5" test joint to 250 psi low / 5000 psi High. Failed, Could visually see leak at top of ram block, possibly wear plate. 3.00 WHSUR N SFAL DECOMP PJSM -Pull test joint, drain stack, remove turnbuckles. Open top bonnets and remove and inspect seal plate and gaskets. One minor scratch found on face of seal plate. 2.50 WHSUR N SFAL DECOMP Install New seal plate and gaskets. Change out rams for 3-1/2" x 6 VBR. Button up bonnets, install turnbuckles and center stack with rotary. 6.50 W HSUR N SFAL DECOMP Install 5" test joint, RU test equipment and fill stack. Attempt to test top rams, 250 psi held, 5000 psi failed. Trouble shooting source of leak, Service surface equipment un-successful in all attempts to obtain high pressure test. 3.50 WHSUR N SFAL DECOMP PJSM -Pull test joint, drain stack, remove turnbuckles. Open top bonnets and remove and inspect seal plate and gaskets. No damage found on seal plate or gaskets. Change out 3-1/2" x 6" VBR's with New never used set of 3-1/2" x 6" VBR's mobilized from NOC. Close and tighten bonnets. Re-Torque Drilling spool BOP bolts top and bottom. 1.50 WHSUR N SFAL DECOMP Center stack with rotary. Install 5" test joint, RU test equipment and fill stack. Attempt to test top rams, 250 psi held, 5000 psi. High Test Failed. 1.00 WHSUR N SFAL DECOMP PJSM -Drain stack and blow down test equipment and lines. Pull and LD test joint. 1.50 WHSUR N SFAL DECOMP PJSM -Remove iron roughneck track, pull master bushings, ND and pull drilling riser to allow better visual inspection of upper ram /seal plate area. 1.00 WHSUR N SFAL DECOMP PJSM -Install 5" test joint and RU testing equipment. 1.00 WHSUR N SFAL DECOMP Fill stack and test top 3-1/2" x 6" VBR with 5" test joint to 250 psi low / 5000 psi High. Good test. Bleed off and repeat test. Held. Witness of test by Chris Clemens (WSL ), Brian Tiedemann (NAD Toolpusher ), Randy Axness (NAD Driller ). Printed: 4/21/2008 1:15:33 PM BP EXPLORATION Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Start: 1/18/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E i Date From - To Hours Task Code NPT 1/26/2008 02:30 - 03:30 1.00 WHSUR N SFAL 03:30 - 05:00 1.50 WHSUR N SFAL 05:00 - 06:00 1.00 WHSUR N SFAL 06:00 - 08:00 2.00 WHSUR N SFAL 08:00 - 09:00 1.00 WHSUR N SFAL 09:00 - 10:30 1.50 WHSUR P 10:30 - 11:00 0.50 WHSUR P 11:00 - 12:00 1.00 WHSUR P 12:00 - 14:00 2.00 WHSUR P 14:00 - 15:00 1.00 PULL P 15:00 - 17:30 2.50 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 21:30 3.50 PULL P 21:30 - 00:00 2.50 PULL P 1/27/2008 00:00 - 02:00 2.00 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 07:00 4.00 PULL P 07:00 - 12:00 5.00 PULL P 12:00 - 20:30 8.50 PULL P Page 5 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Phase Description of Operations DECOMP Witness of test waived by John Chrisp (AOGCC ) DECOMP RD test equipment and LD 5" test joint. PU and MU 4-1/2" test joint and RU test equipment. DECOMP Fill stack and attempt to test upper 3-1/2" x 6" VBR's to 250 psi / 5000 psi. Failed. Test surface equipment. Isolation valves failed on test equipment. Change out two whitey valves on manifold line and test joint line. DECOMP Test top 3-1/2" x 6" VBR with 4.5" test joint to 250 psi low / 5000 psi High. Good test. Witness of test by Richard Bordes WSL ), Kelly Cozby (NAD Toolpusher ), Randy Axness (NAD Driller ). Witness of test waived by John Chrisp (AOGCC ) DECOMP Blow down all lines and RD Test equipment. DECOMP PJSM - NU Drilling riser, install master bushings, iron roughneck track. Wrap wellhead with and herculite and apply steam. DECOMP PU Test joint with Vetco test dart running tool and recover same. LD test dart, running tool and test jiont. DECOMP PJSM - MU 6" lubricator extension and install in BOP stack closed on top set of rams and annular preventer. RU DSM lubricator and running tools. DECOMP PJSM -Test lubricator to 500 psi. Verify IA pressure 0 psi. Pull BPV. Well static. RD DSM lubricator, and blow down Kill line. Clear rig floor of vendors tools. DECOMP Lower top drive to rig floor and service /warm same -35 Deg temperatures. DECOMP PJSM - MU 5.875" MCA running tool to double 5" DP and engage tubing hanger with 19 rounds MU. MU top drive and back out lock down studs on tubing hanger. DECOMP PJSM -Unseat tubing hanger, pulled free 155K PU 2' and monitor well. Static. DECOMP Displace well to 9.3 ppg brine. Pump 100 bbl 100 deg heated seawater followed by 30 bbl heated Safe-Surf W sweep followed by 941 bbls 9.3 ppg brine all returns sent to G & I for injection. Final circulating rate 7 BPM 500 psi. Shut down and monitor well. Static DECOMP Drain BOP stack and work tubing hanger to rig floor, difficult working hanger through BOP stack due to subsidence wellhead / BOP angle. DECOMP Work tubing hanger to rig floor, difficult working hanger through BOP stack due to subsidence wellhead /BOP angle. Re-center BOP stack. Up wt 175k Dn wt 160k DECOMP Terminate control line and fiber optic cable. RU casing tools and LD tubing hanger and DP landing joint. DECOMP PJSM -Work on centering BOP stack with rotary table by skidding rig floor 4" to the west to center rig over wellhead. Secure rig floor to substructure, realign BOP stack, PU all tools. Tubing string now hanging in center of rotary table. DECOMP POH Laying down 4.5" Vam Ace 13Cr80 completion from 11,835' to 10,205' spooling up 971' of TRSV Control line and Fiber Optic cable, Removing control line clamps every joint. DECOMP Continue POH Laying down 4.5" Vam Ace 13Cr80 completion from 10,205' to 5,500' spooling up Fiber Optic cable, Removing control line clamps every joint. Excessive crude /Paraffin build Printed: 4/21/2008 1:15:33 PM BP EXPLORATION Page 6 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date i From - To Hours ~', Task Code NPT Phase Description of Operations 1/27/2008 12:00 - 20:30 8.50 PULL P DECOMP up on pipe and clamps. 20:30 - 21:30 1.00 PULL P DECOMP Pump 30 bbl 100 deg Safe-Surf W sweep around ~ 11 BPM, 325 psi to clean tubing string. 21:30 - 00:00 2.50 PULL P DECOMP Continue POH Laying down total of 196 Jts 4.5" Vam Ace 13Cr80 completion from 5,500' to 3,799' spooling up Fiber Optic cable, Removing control line clamps every joint. Pipe much cleaner. 1/28/2008 00:00 - 06:30 6.50 PULL P DECOMP POH Laying down 4.5" Vam Ace 13Cr80 completion from 3,799' spooling up Fiber Optic cable, Removing control line clamps every joint. Recovered: 278 Jts 4.5" Vam Ace 13Cr80 Tubing 7 each 4.5" Vam Ace Pup Jts. 1 each cut pup Jt. 1 TRSV assembly 2 GLM assembly 1 HES X Nipple assembly 1 Cidra Gauge Carrier Mandrel 288 Cannon Control Line Clamps 1 Stainless Steel bands. 06:30 - 08:30 2.00 PULL P DECOMP RD casing equipment and clear-rig floor of vendors tools. 08:30 - 09:00 0.50 WHSUR P DECOMP MU running tool on 5" drill pipe and install wear bushing in tubing head. Bushing ID = 8-13/16" 09:00 - 10:00 1.00 FISH P DECOMP PU Baker fishing tools and stage on rig floor. 10:00 - 13:30 3.50 MOB N SFAL DECOMP Mobilize Schlumberger E-Line unit. Pintle hitch on island loader became damaged while moving pipe trailer out of E-line units way. Unable to spot E-line unit. Repair Pintle hitch and spot E-line unit. 13:30 - 16:00 2.50 EVAL P DECOMP PJSM - RU Schlumberger E-Line, Load pipe shed with tools, MU 8.5" Gauge Ring /Junk Basket / CCL / GR and RIH to 4,010' & POH. Minimal debris in junk basket. LD gauge ring / junk basket. 16:00 - 23:00 7.00 EVAL P DECOMP MU USIT logging tool string and RIH to 4,010' and Log up to surface. Repeat log from 3,700' up to 2,000' POH and LD USIT tool string. Cement stringers from -1,900' to 2,370' TOC -2,370' 23:00 - 00:00 1.00 DHB P DECOMP PJSM - MU HES 9.625" EZSV Bridge Plug. 1/29/2008 00:00 - 02:00 2.00 DHB P DECOMP Continue PJSM - MU HES 9.625" EZSV Bridge Plug &RIH to 3,800' and correlate log up to 3,450'. RIH and PU placing plug Mid Joint C~ 3,670'. Set Plug ~ 3,670', good indication plug set. SO setting tool to confirm set, Plug in place. POH with E-Line 02:00 - 03:00 1.00 DHB P DECOMP LD setting tool & RD Schlumberger, Clear rig floor of vendors tools 03:00 - 04:00 1.00 DHB P DECOMP PJSM - RU and Test 9.625" EZSV CIBP & casing to 2000 psi and record on chart for 30 min. Good Test. RD & Blow down test equipment. 04:00 - 05:00 1.00 STCTPL P DECOMP PJSM - PU and MU BHA #1 Baker 8-1/4" Multi String Cutter with 3-1/2" Knives / XO 05:00 - 14:00 9.00 STCTPL P DECOMP RIH Picking up 5" Drill Pipe 1 x 1, Tag EZSV ~ 3,670' with 10k set down weight. Printed: 4/21/2008 1:15:33 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS16 NS16 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 33E Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Page 7 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Date From - To Hours ' Task Code NPT Phase Description of Operations 1/29/2008 14:00 - 16:00 2.00 STCTPL P DECOMP Monitor hole, Static. POH racking back 39 stands 5" DP. 16:00 - 17:00 1.00 STCTPL P DECOMP MU running tool and pull wear bushing. LD running tool and single DP. 17:00 - 19:00 2.00 MOB P DECOMP Mobilize E-line tools for free point operations and load in pipe shed. 19:00 - 21:30 2.50 STCTPL P DECOMP PJSM - MU side door entry sub to Baker 9.625" spear !~ assembly. Open blind shear rams and drain BOP stack. MU Top drive to spear assembly, RIH and engage 9-5/8" casing hanger. 21:30 - 22:30 1.00 STCTPL P DECOMP PJSM - RU Schlumberger E-line unit, hang a-line sheave in derrick and MU free point tool. 22:30 - 23:30 1.00 STCTPL P DECOMP RIH with E-line tool and place on depth ~ 1,800' 23:30 - 00:00 0.50 STCTPL P DECOMP Monitor open OA to bleed trailer in preparation to back out lock down studs on 9-5/8" packoff while installing shock hose on mud line. 1/30/2008 00:00 - 03:00 3.00 STCTPL N RREP DECOMP Continue to Monitor open OA to bleed trailer in preparation to back out lock down studs on 9-5/8" packoff while installing shock hose on mud line. Shock hose split while installing. 03:00 - 04:30 1.50 STCTPL N RREP DECOMP Continue to Monitor open OA to bleed trailer, discuss options with rig team on free pointing while mobilizing back up hose. 04:30 - 08:00 3.50 STCTPL P DECOMP PJSM -with all personnel on free point operations. Back out 9-5/8" pack off lock down studs and unseat casing hanger with 300k pull up to 450k, approximately 2.5" pipe stretch. Repeat cycle while checking free point ~ 1,800'. Free point inconclusive. Move Free point tools up to 1,000' and work pipe up to 450k with same inconclusive results. 08:00 - 09:00 1.00 STCTPL P DECOMP Consult with Anchorage rig team on forward plan. Decision made to make first cut ~ -1,915' 09:00 - 11:00 2.00 STCTPL P DECOMP POH with a-line tool-string, LD tools, RD a-line. Release spear, LD side-door entry sub, double DP and spear. Clear rig floor of vendor's tools. 11:00 - 12:00 1.00 STCTPL P DECOMP MU BHA #3 Baker 9.625" Multi-String Cutter. 12:00 - 14:00 2.00 STCTPL P DECOMP RIH slow to 800', knifes catching on casing collars on trip in. 14:00 - 14:30 0.50 STCTPL P DECOMP Pressure test new mud line shock hose to 250 psi / 3500 psi. Good Test. 14:30 - 16:00 1.50 STCTPL P DECOMP Continue to RIH from 800' to 1,889' with multi-string cutter. Obtain SPR #1 MP = 1.5 BPM 113 PSI / 2.5 BPM 155 PSI. 16:00 - 17:00 1.00 STCTPL P DECOMP PJSM on cutting casing. MU top drive, Obtain up and down weights, up / do / rt 82k, pump at 3.5 BPM to open cutters and SO, locate collar at 1,918'. PU 2' to place cutters at 1,916'. Bring pump rate up to 5 BPM / 550 PSI, 70 RPM's , 2k TO. Good indication of cut by casing /rig jump and pressure drop. 17:00 - 18:00 1.00 STCTPL P DECOMP Shut down pumping and investigate leak in cellar. Notified on site ACS Environmental Tech, OIM and Town DE. 1/2 gallon of diesel released from needle valve on OA on to secondary containment. Clean up with absorb and placed into oily waste bags for disposal. 18:00 - 22:30 4.50 STCTPL P DECOMP PJSM on circ out diesel. RU cellar lines from OA to choke, Open up OA to closed choke 240 psi. Crack open choke and pump 100 bbl 100 deg 9.3 ppg brine down the DP and establish displacement rate of 1.5 bpm maintaining fluid level in Printetl: 4/21/LUUtf 1:15:JJ PM BP EXPLORATION :Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 33E Date From - To Hours ' Task Code NPT 1/30/2008 18:00 - 22:30 4.501 STCTPL P 22:30 - 00:00 1.50 STCTPL P 1/31/2008 00:00 - 01:00 1.00 STCTPL P 01:00 - 02:00 1.00 STCTPL P 02:00 - 04:00 2.00 BOPSU P 04:00 - 06:00 2.00 BOPSU P 06:00 - 07:00 1.001 FISH P 07:00 - 07:30 0.501 WHSUR P 07:30 - 08:00 0.501 FISH P 08:00 - 12:00 4.00 FISH P 12:00 - 15:30 3.501 FISH P 15:30 - 16:00 0.50 FISH P 16:00 - 16:30 0.50 FISH P 16:30 - 19:30 3.00 FISH P 19:30 - 20:00 0.501 FISH P 20:00 - 21:00 1.00 (STCTPL P 21:00 - 22:30 I 1.50 I STCTPL I P 22:30 - 00:00 1.50 STCTPL P 2/1 /2008 100:00 - 04:30 4.50 STCTPL I P Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Page 8 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Phase Description of Operations DECOMP IA taking returns to the trip tank, shipping diesel to G & I for injection. ~ 94 bbls close annular preventer and pump 30 bbl viscous SafeSurf-O sweep followed by 160 bbls heated 9.3 ppg brine, at 130 bbls clean brine returns observed, switch to active system and increase pump rate to 5 bpm 500 psi DP / 50 psi Csg, overboard sweep down drag chain to G & I. Shut down open well and monitor. Well static. RD and blow down circulating equipment /clean diesel out of trip tank. DECOMP POH with BHA #3 to pull casing. DECOMP LD BHA #3 DECOMP PJSM -Drain stack, MU running tool and pull wear bushing, LD running tool. DECOMP PJSM -Change out top set of rams to 9-5/8" DECOMP PJSM - MU 9-5/8" Test joint & RU Test equipment and test Rams to 250 psi low / 3500 psi high. RD blow down test equipment. Witness of test by R. Bordes / C. Clemens (WSL), B. Bixby / B. Tiedemann (NAD Toolpusher). DECOMP PJSM - MU BHA #4 9-5/8" casing spear RIH and engage fish at wellhead DECOMP Check OA pressure 0 psi. Back out lock down studs on 9-5/8" packoff. DECOMP Unseat casing string /hanger with 140k and pull casing hanger to rig floor. Release spear and LD BHA #4. DECOMP RU casing tools, LD casing hanger & pup jt. POH LD 9-5/8" Casing from cut C~ 1,916'to 1,412'. DECOMP Continue POH laying down 9-5/8" Casing. Recovered: Csg Hanger& Pup Jt. 44 Full Joints 1 Cut Jt. 40.25'. Total = 45 Joints 9-5/8" #47 L-80 BTC-M casing Slight traces of cement on joints # 43, 44, & 45 three feet off the pin end. DECOMP RD casing tools, Clean and clear rig floor DECOMP MU BHA #5, 9-5/8" ITCO casing spear / XO /Single 5" DP. DECOMP RIH to 1,824'took 10k drag over normal down wt. ~ 1,814' Up Wt. 80k / Dn Wt. 85k. DECOMP Break circulation and clear drill pipe prior to engaging fish. Blow down top drive and mud line. DECOMP PJSM - MU sidedoor entry sub to drill string, SO and engage fish ~ 1,916'. Pull 200k to verify spear set and SO to neutral wt. DECOMP PJSM - RU Schlumberger a-line and MU Free point tool and RIH to 1,990'. DECOMP Calibrate FPIT and check Stations working pipe between 80k up to 230k 1,990' Free. 2,355' Free DECOMP Pull up to 1,990' and recalibrate tool and Continue to free point stations as follows, working pipe between 60k up to 230k 1,990' Free 100% 2,030' Free 99% 2,598' Stuck 100% rnntea: 4izuzuu° ia°:aarm BP EXPLORATION Page 9 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2008 00:00 - 04:30 04:30 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:30 09:30 - 10:15 10:15 - 11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 15:00 I 15:00 - 16:00 16:00 - 16:30 16:30 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 00:00 4.50 STCTPL P DECOMP 2,308' Free 82% 2,438' Free 31 2,352' Free 80% 2,397' Free 30% 1.50 STCTPL P DECOMP POH & LD free point tool string & RD E-Line, Release spear and LD side-door entry sub. 1.00 FISH P DECOMP POH - 10 stands to 975' 1.00 FISH P DECOMP Circulate -Run #1 & 2 mud pumps to check loping problem with #2 and check calibration of stroke counters, GPM, Flow show on EPOCH. 1.50 FISH P DECOMP Cont' POH to BHA. 0.75 FISH P DECOMP LD BHA #5 Spear assembly, Change out knifes on multi string cutter. 1.25 WHSUR P DECOMP MU running tool and install wear bushing, LD running tool. Wear bushing ID 12-5/16" 0.50 STCTPL P DECOMP PJSM - MU BHA #6 Baker 9.625" Multi-String Cutter. 1.50 STCTPL P DECOMP RIH to 2,361' -Obtain SPR's #2 MP - 2 bpm = 92 psi. 3bpm = 189 psi w/ 9.3 ppg brine. Establish parameters, Up Wt. 90k / Dn Wt. 93k, Pump 211 gpm, 235 psi, S/O and locate collar ~ 2,371' and set down w/ 10k to verify. PU 2' to place cutter ~ 2,369'. 0.50 I STCTPL I P 1.00 I STCTPL I P 1.00 STCTPL P 0.50 STCTPL P 3.50 FISH P 2.00 FISH P 0.50 FISH P 1.501 FISH I P ~ 2/2/2008 00:00 - 00:30 ~ 0.50 ~ FISH ~ P 00:30 - 03:00 2.50 FISH P 03:00 - 04:00 1.00 FISH P 04:00 - 05:30 1.50 FISH P 05:30 - 06:00 0.50 FISH P 06:00 - 08:00 2.00 FISH P DECOMP Start cutting operations, 211 gpm / 585 psi / 70 rpm / 2-3k Tq / pressure increased to 605 psi, observed pressure drop to 553 psi, and increase in torque. Stop rotary and PU 10k over-pull. DECOMP CBU 420 gpm / 2107 psi, Monitor well, Static. Fluid Wt in and out 9.3 ppg. DECOMP POH with BHA #6 DECOMP LD Cutting BHA #6, Clean and clear rig floor DECOMP MU Fishing BHA #7 - Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub /Bumper Sub /Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier DECOMP RIH from 322'to 1,857' DECOMP Establish parameters, Up Wt 97k / Dn Wt 100k, SO and engage fish ~ 1,916 and swallow spear up to stop sub / PU 3', Fish free C~3 118K Up Wt, establish circulation. DECOMP Ramp pumps up to 888 gpm, 1067 psi, &CBU fine sand cement after 1.5 bottoms up increasing to larger pebble sized up to 2.5" rock sized soft cement chunks, mix and pump 30 bbl DuoVis sweep around and continue to circulate until well cleaned up. DECOMP Monitor well, Static. Rack back 1 stand DP and Blow down top drive and mud line. Fluid Wt in and out 9.3 ppg. DECOMP POH with 9-5/8" casing fish on 5" DP to BHA DECOMP LD Intensifier, Stand back 3 stands of DC's DECOMP Release spear from fish, LD remainder of fishing BHA #7 DECOMP PJSM - RU 9-5/8" Casing tools DECOMP POH LD 453' of 9-5/8" 47# L-80 BTC-M casing. No residual cement on casing joints. RD casing tools. Recovered: 2' Stub 10 Full Joints Printed: 4/21/2008 1:15:33 PM • BP EXPLORATION Page 10 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release Rig Name: NABORS 33E Rig Number 1 /18/2008 3/25/2008 33E Spud Date: 6/29/2002 End: 3/25/2008 Date From - To (Hours Task I! Code NPT Phase Description of Operations 2/2/2008 06:00 - 08:00 2.00 FISH P DECOMP 1 Cut Joint = 39.91' 11 joints for this run. Total Recovered from well = 56 Jts. 08:00 - 09:00 1.00 FISH P DECOMP Service Top Drive, Blocks & Crown, Draw works. 09:00 - 10:00 1.00 STCTPL P DECOMP Clean & Clear rig floor, Change out knifes on multi-string cutter. 10:00 - 10:30 0.50 STCTPL P DECOMP PJSM - MU BHA #8 Baker 9-5/8"" Multi-String Cutter. 10:30 - 12:30 2.00 STCTPL P DECOMP RIH with MSC on 5" DP to 1,224' 12:30 - 14:00 1.50 STCTPL N RREP DECOMP Iron Roughneck hydraulic cylinder failure / RU floor tools to continue to RIH while trouble shooting Iron Roughneck. 14:00 - 15:00 1.00 STCTPL P DECOMP Cont' RIH from 1,224'to 2,440' 15:00 - 15:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 90k / Dn Wt. 92k, Pump 131 gpm, 220 psi, S/O and locate collar ~ 2,451' and set down w/ 10k to verify. j PU 2' to place cutter C~ 2,449'. Start cutting operations, 210 gpm / 585 psi / 70 rpm / 2-3k Tq / observed pressure drop to 489 psi, and increase in torque. 15:30 - 16:00 0.50 STCTPL P DECOMP CBU - 398 gpm / 1,685 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Blow down top drive /mud line. 16:00 - 19:30 3.50 STCTPL P DECOMP POH from 2,449' to BHA using chain tongs. 19:30 - 20:00 0.50 STCTPL P DECOMP LD cutting BHA #8 & Clear rig floor 20:00 - 23:30 3.50 BOPSU P DECOMP PJSM - MU BOP flushing tool and wash out stack. Blow down top drive. Pull wear bushing. MU 5" test joint to test plug and install floor safety valve and IBOP. RU test equipment and fill BOP stack with water. 23:30 - 00:00 0.50 BOPSU P DECOMP Test BOPE as per BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of test waived by Chuck Sheeve (AOGCC State Inspector). Test witnessed by Chris Clemens (WSL), Brian Tiedemann (NAD Toolpusher), Randy Axness (NAD Driller). Test as follows with 5" Test Joint. #1) Annular 250 psi / 3500 psi. 2/3/2008 00:00 - 06:00 6.00 BOPSU P DECOMP Continue to Test BOPE as follows with 5" Test Joint: #2) Bottom 3.5" x 6" VBR 250 psi / 5000 psi. / IBOP #3) Floor Safety Valve #4) Lower Well Control Valve #5) Upper Well Control Valve Function Test Accumulator #6) Blind Shear Rams /Kill HCR /Choke Valve #8 - 9 - 11 #7) Choke Valve #9 -12 (Choke Valve # 12 Failed) 06:00 - 06:30 0.50 BOPSU P DECOMP Drain BOP stack, blow down all lines and test equipment to change out top set of rams to 3.5" x 6" VBR's while repairing #12 Choke manifold valve. 06:30 - 08:30 2.00 BOPSU P DECOMP Change Top set of rams to 3.5" x 6" VBR's, Rebuild #12 Choke manifold valve while changing out rams. 08:30 - 09:30 1.00 BOPSU P DECOMP Install 5" test joint and RU test equipment. 09:30 - 12:30 3.00 BOPSU N DECOMP Continue to Test BOPE as follows with 5" Test Joint: #8) Top Rams 3.5" x 6" VBR 250 psi / 5000 psi. / IBOP #9) Choke Valve # 9-12-13 #10) Choke Valve # 8-11 #11) Choke Valve # 4-7-10 Printed: aizvzuun i:io::ttrM BP EXPLORATION Page 11 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABORS 33E Rig Number: 33E i Date 'From - To '. Hours Task Code I NPT ~ Phase Description of Operations 2/3/2008 09:30 - 12:30 3.00 BOPSU N DECOMP #12) Manual Kill Valve /Choke Valve #3-5-6 #13) Choke Valve #1 #14) Choke Valve #2 #15) Choke HCR Valve #16) Manual Choke Valve Witness of test by Richard Bordes (WSL), Bill Bixby (NAD Toolpusher), Sean Holcomb (NAD Driller) 12:30 - 13:30 1.00 WHSUR P DECOMP RD Test equipment and blow down all lines, Install wear bushing. ID = 12-5/16" 13:30 - 16:00 2.50 FISH P DECOMP MU Fishing BHA #9 - Bull Nose /Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub /Bumper Sub /Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier &RIH to 405' 16:00 - 18:00 2.00 FISH P DECOMP Rig Morale /Team Building Meeting with Sean Holcomb's Crew / Day and Night WSL's, Toolpushers /Mud Engineers. 18:00 - 19:00 1.00 FISH P DECOMP RIH from 405' to 2302' 19:00 - 19:30 0.50 FISH P DECOMP Establish parameters, Up Wt 103k / Dn Wt 103k, SO and engage fish ~ 2,369 and swallow spear up to stop sub / PU 3', Fish free ~ 110K Up Wt, establish circulation without problem. 19:30 - 21:00 1.50 FISH P DECOMP CBU with 35 bbl high vis sweep with 930 gpm / 1180 psi. while reciprocating pipe, Sweep brought up moderate amount of contaminated cement and continued to increase, pumped second 35bb1 high vis sweep around, hole unloaded large chunks of soft rock sized cement up to 3" in length and cleaned up after another bottoms up. Fluid Wt in and out 9.3 ppg. 21:00 - 22:00 1.00 FISH P DECOMP Monitor Well, Static. POH with fish from 2,449' to BHA 9# 22:00 - 00:00 2.00 FISH P DECOMP LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #9 2/4/2008 00:00 - 01:00 1.00 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 80' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jt #57 and Jt #58 was clean.RD casing tools. Recovered: 1.3' Stub 1 Full Joints 1 Cut Joint = 40.40' 2 joints for this run. Total Recovered from well = 58 Jts. 01:00 - 01:30 0.50 STCTPL P DECOMP PJSM -Change Knifes & MU BHA #10 Baker 9-5/8" Multi-String Cutter. 01:30 - 02:00 0.50 STCTPL P DECOMP RIH with MSC to 1,135' 02:00 - 03:00 1.00 STCTPL P DECOMP Service Top Drive, Blocks, Crown & Draw works. 03:00 - 05:00 2.00 STCTPL P DECOMP RIH with MSC from 1,135' to 2,610' 05:00 - 05:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 95k / Dn Wt. 95k, Pump 130 gpm, 198 psi, S/O and locate collar ~ 2,613' and set down w/ 10k to verify. PU 2' to place cutter ~ 2,611'. Start cutting operations, 211 gpm / 600 psi / 70 rpm / 2-3k Tq / observed pressure drop to 483 psi, and increase in torque. 05:30 - 06:30 1.00 STCTPL P DECOMP CBU - 398 gpm / 1,685 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. 06:30 - 08:30 2.00 STCTPL P DECOMP POH with MSC BHA #10 Remove knife blades and LD same. 08:30 - 10:00 1.50 FISH P DECOMP PJSM -Redress 9-5/8" Spear and MU BHA #11 Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub / Printed: 4/21/2008 1:15:33 PM BP EXPLORATION Operations Summary Report Page 12 of 47 Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date Frorn - To Hours Task Code NPT Phase Description of Operations 2/4/2008 08:30 - 10:00 1.50 FISH P DECOMP Bumper Sub /Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier. 322', Blow down kill line. 10:00 - 11:30 1.50 FISH P DECOMP RIH from 322' to 2,396' 11:30 - 12:00 0.50 FISH P DECOMP Establish parameters, Up Wt 105k / Dn Wt 105k, SO and engage fish ~ 2,449 and swallow spear up to stop sub, Pull 200K and hit jar, PU to 250k Up Wt, establish circulation without problem 940 gpm / 1170 psi. Repeat several times and casing pulled free with 115k 12:00 - 13:00 1.00 FISH P DECOMP Pump two 40 bbl high vis sweeps back to back pumping 940 gpm / 950 psi while reciprocating pipe until hole cleaned up. Large amounts of cement chunks to surface. Monitor well, Static. Blow down top drive and mud line. Fluid Wt. in and out 9.3 PPg• 13:00 - 14:00 1.00 FISH P DECOMP POH with fish to BHA #11 14:00 - 15:30 1.50 FISH P DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #11 15:30 - 17:00 1.50 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 162' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jts #59 and Jt #62. RD casing tools. Recovered: ', 1.6' Stub 3 Full Joints 1 Cut Joint = 38.06' 4 joints for this run. Total Recovered from well = 62 Jts. 17:00 - 17:30 0.50 STCTPL P DECOMP PJSM - MU BHA #12 Baker 9-5/8" Multi-String Cutter. 17:30 - 19:00 1.50 STCTPL P DECOMP RIH to 3,207' and MU TDS 19:00 - 20:00 1.00 STCTPL P DECOMP Obtain SPR's w/ #2 MP 2 bpm = 75 psi / 3 bpm = 170 psi. Establish parameters, Up Wt. 108k / Dn Wt. 104k, Rt Wt. 105k Pump 130 gpm, 190 psi, S/O and locate collar ~ 3,237' and set down w/ 10k to verify. PU 2' to place cutter ~ 3,235'. Start cutting operations, 211 gpm / 558 psi / 70 rpm / 2-3k Tq / observed pressure drop to 493 psi, and increase in torque. 20:00 - 21:00 1.00 STCTPL P DECOMP CBU - 419 gpm / 1,885 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. 21:00 - 23:00 2.00 STCTPL P DECOMP POH with MSC BHA #12 and LD same. 23:00 - 00:00 1.00 FISH P DECOMP PJSM - PU 9-5/8" Spear and change out packoff. 2/5/2008 00:00 - 01:30 1.50 FISH P DECOMP Change out packoff and RIH with remainder of BHA #13) 9 x 6-1/4" DC's / XO / Intensifier to 322'. 01:30 - 03:30 2.00 FISH P DECOMP RIH from 322' to 2,585' 03:30 - 05:30 2.00 FISH P DECOMP Establish parameters, Up Wt 110k / Dn Wt 105k, SO and engage fish ~ 2,611' and swallow spear up to stop sub, Pull 250K and hit jar, PU to 250k Up Wt, break circulation 84 gpm / 400 psi. Start Jarring Up with 250k pulling up to 250k while staging pump rate up to 700 gpm 2000 psi, Increase Jar & pull to 270k. Increase Jar to 300k & pull up to 350k, pump 35 bbl high vis sweep and increase pump rate to 780 gpm 1900 psi. Increase pump rate to 914 gpm, jar with 300k and pull to 400k. Jarred free to 3,235'. 05:30 - 07:30 2.00 FISH P DECOMP Reciprocate pipe and wash back down to stub at 3,235'. Pump 2 x 35 bbl high vis sweep around at 926 gpm / 1250 psi. Printetl: 4/21/2008 1:15:33 NM ' • BP EXPLORATION Page 13 of 47 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/5/2008 05:30 - 07:30 07:30 - 10:30 10:30 - 11:00 11:00 - 14:30 14:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 20:30 20:30 - 22:30 22:30 - 00:00 2/6/2008 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 09:00 09:00 - 10:00 NS16 NS16 Spud Date: 6/29/2002 REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 NABOBS 33E Rig Number: 33E Hours I Task Code NPT Phase Description of Operations 2.00 FISH P DECOMP Followed by 1 x 80 bbl high vis sweep. Continue to circulate until hole cleaned up. Monitor well, Static, Fluid Wt in and out 9.3 PP9• 3.00 FISH P DECOMP Blow down TDS & Mud line, POH with fish from 3,235' to BHA #13 0.50 FISH P DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #13 3.50 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 162' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jts #63 - Jt #77. RD casing tools. Clean and Clear Rig Floor. Recovered: 1.11' Stub 14 Full Joints 1 Cut Joint = 40.47' 15 joints for this run. Total Recovered from well = 77 Jts. 2.00 STCTPL P DECOMP PJSM - MU BHA #14 Baker 9-5/8" Multi-String Cutter &RIH to 3,450' 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 112k / Dn Wt. 105k, Pump 130 gpm, 200 psi, S/O and locate collar ~ 3,487' and set down w/ 10k to verify. PU 2' to place cutter ~ 3,485'. Start cutting operations, 211 gpm / 660 psi / 70 rpm / 2-3k Tq / observed pressure drop to 565 psi, and increase in torque. 1.00 STCTPL P DECOMP CBU - 419 gpm / 1,866 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Stand back one stand DP & Blow down top drive / mud line. 2.50 STCTPL P DECOMP POH from 3,485' with MSC BHA #14 and LD same. 2.00 STCTPL P DECOMP PJSM -Redress 9-5/8" Spear and MU BHA #15 Bull Nose / Packoff / ITCO Spear w/ 8.861 grapple /Extension /Stop sub / Bumper Sub / PU New Oil Jar / XO / 9 x 6-1/4" DC's / XO / Intensifier. 322'. 1.50 STCTPL P DECOMP RIH, to 3,184', PU 1 single DP & MU TDS 2.00 FISH P DECOMP Establish parameters, Up Wt 125k / Dn Wt 112k, SO and engage fish ~ 3,235' and swallow spear up to stop sub, Pull 150K and attempt to break circulation without success, Hold 1000 psi, PU 250K and hit jar, Pull to 300k Up Wt, Start Jarring Up with 250k pulling up to 300k while holding 1000 psi, Increase Jar to 300k & pull up to 400k holding 1500 psi. -30 deg ambient temp. Bleed off pressure and Circulate surface equipment every 45 min. Jarred Free. 2.00 FISH P DECOMP Work fish up the hole to 3,395' trying to establish circulation. Break circulation and stage pump rate up to 905 gpm / 950 psi. Reciprocate pipe 30' & CBU x 2. Large amounts of contaminated cement back. 1.00 FISH N SFAL DECOMP Circulate while trouble shooting electrical problem. 1.50 FISH P DECOMP Wash back down to top of the stub ~ 3,485' &CBU with sweep until hole cleans up 914 gpm / 900 psi. Monitor well, Static. Fluid Wt in and out 9.3 ppg. Blow down TDS and mud line. 2.50 FISH P DECOMP POH with fish from 3,485' to BHA #15 1.00 FISH DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #15 Nnntea: ainizuus i:u:~s rnn BP EXPLORATION Page 14 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours ' Task Code NPT Phase Description of Operations -- 2/6/2008 10:00 - 12:00 2.00 FISH P DECOMP PJSM - RU 9-5/8" Casing tools & POH LD 250' of 9-5/8" 47# L-80 BTC-M casing. Residual cement on Jts #78 - Jt #83. RD casing tools. Clean and Clear Rig Floor. Recovered: 1.23' Stub 5 Full Joints 1 Cut Joint = 40.70' 6 joints for this run. Total Recovered from well = 83 Jts. 12:00 - 12:30 0.50 FISH P DECOMP Clean and clear rig floor 12:30 - 13:00 0.50 STCTPL P DECOMP PJSM - MU BHA #16 Baker 9-5/8" Multi-String Cutter 13:00 - 15:00 2.00 STCTPL P DECOMP RIH to 3,586' 15:00 - 15:30 0.50 STCTPL P DECOMP Establish parameters, Up Wt. 118k / Dn Wt. 105k, Pump 130 gpm, 200 psi, S/O to locate collar ~ 3,609' took Wt f~ 3,605'. PU to place cutter ~ 3,600'. Start cutting operations, 211 gpm / 675 psi / 70 rpm / 4.5k Tq / observed pressure drop to 550 psi, and increase in torque then drop to 2.8k. SO 10k to verify cut. SPR- #2 MP) 2 bpm = 100 psi / 3 bpm = 180 psi. 15:30 - 16:30 1.00 STCTPL P DECOMP CBU - 419 gpm / 1919 psi. Monitor well, Static. Blow down TDS and mud line. Fluid WT in and out 9.3 ppg. 16:30 - 18:30 2.00 STCTPL P DECOMP POH with MSC BHA #16 18:30 - 19:00 0.50 STCTPL P DECOMP Make service breaks and LD BHA #16 19:00 - 20:30 1.50 FISH P DECOMP MU Fishing BHA #17 - Bull Nose / Packoff / ITCO Spear w/ ~, 8.861 grapple /Extension /Stop sub /Bumper Sub /Oil Jar / XO / 9 x 6-1/4" DC's / XO /Intensifier 20:30 - 21:30 1.00 FISH P DECOMP RIH -from 322' to 3,433' 21:30 - 22:00 0.50 FISH P DECOMP MU TDS and CBU ~ 900 gpm / 985 psi ~ 3,487' 22:00 - 00:00 2.00 FISH P DECOMP Establish parameters, Up Wt 130k / Dn Wt 115k, SO and engage fish @ 3,485' and swallow spear up to stop sub, Pull 200K and attempt to break circulation without success, Hold 500 psi, PU 250K and hit jar, Pull to 300k Up Wt, Start Jarring Up with 250k pulling up to 300k while holding 500 psi, Increase Jar to 300k & pull up to 400k holding 600 - 700psi. -30 deg ambient temp. Break connection every 45 minutes and circulate surface equipment for 5 minutes. 2/7/2008 00:00 - 02:30 2.50 FISH P DECOMP Continue -Jar to 300k & pull up to 415k holding 600 - 700psi. -30 deg ambient temp. Break connection every 45 minutes and circulate surface equipment for 5 minutes. Injection rate established C~? 690 psi. 8 spm. Total of 16 bbls of fluid loss to formation while jarring. 02:30 - 03:30 1.00 FISH P DECOMP Release spear from fish. 03:30 - 04:00 0.50 FISH P DECOMP CBU with 918 gpm 945 psi. Monitor well. Static. Fluid Wt in and out 9.3 ppg. Blow down TDS & mud line. 04:00 - 06:30 2.50 FISH P DECOMP POH with BHA #17 for 13-3/8" clean out assembly 06:30 - 07:30 1.00 FISH P DECOMP PJSM - LD Intensifier, Stand back 3 stands of DC's, Release spear from fish, LD remainder of fishing BHA #17 07:30 - 08:00 0.50 STWHIP P DECOMP Clean and clear rig floor of vendors tools. 08:00 - 09:30 1.50 STWHIP P DECOMP MU Clean out BHA #18 - 12-1/4" Bit / 13-3/8" Scrapper /Bit Sub / XO /Bumper Sub /Jar / XO / 9 x DC's / XO / 09:30 - 10:30 1.00 STWHIP P DECOMP RIH from 305'to 1,248' 10:30 - 11:30 1.00 STWHIP P DECOMP Service TDS, Blocks, Crown and Draw Works rnniea: vizvzuuo i:ixaariw BP EXPLORATION Page 15 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/7/2008 11:30 - 13:00 1.50 STWHIP P DECOMP RIH from 1,248' to 3,416' MU TDS, Break circulation and wash down to casing stub C~ 3,485'. Up Wt 132k /Down Wt. 116k 13:00 - 14:00 1.00 STWHIP P DECOMP Pump 50 bbl High Vis Sweep around ~ 900 gpm / 1570 psi. Monitor well, Static. Blow down TDS and mud lines. Fluid Wt in and out 9.3 ppg. 14:00 - 16:00 2.00 STWHIP P DECOMP POH from 3,485' to BHA #18 C~3 305'. 16:00 - 18:30 2.50 STWHIP P DECOMP LD -BHA #18. 18:30 - 19:00 0.50 STWHIP P DECOMP Clean and clear rig floor of vendors tools. 19:00 - 20:00 1.00 EVAL P DECOMP PJSM - RU Schlumberger E-line and MU CCL / GR tools. 20:00 - 22:30 2.50 EVAL P DECOMP RIH with E-Line to 3,560' and Log up to surface. 22:30 - 23:30 1.00 EVAL P DECOMP RD SWS. 23:30 - 00:00 0.50 ZONISO P DECOMP PJSM - MU 13-3/8" EZSV CIBP Running tool and make dummy run through BOP and well head to 80'. 2/8/2008 00:00 - 03:30 3.50 ZONISO P DECOMP MU 13-3/8" EZSV CIBP To running tool &RIH on 5" DP. 03:30 - 04:00 0.50 ZONISO P DECOMP MU TDS Up Wt. 110k / Dn Wt. 100k circulate 80 bbls 70 deg fluid around EZSV to warm up prior to setting at 3 bpm / 55 psi. PU to place top of the 13-3/8" CIBP 5' above casing collar ~ 3,287' Rotate 36 turns, PU 20k and pause 2 min / PU 10k, pause 2 min / PU 10k, pause 2 min / PU 10k, pause 2 min / PU 10k and shear off plug with 170k. Rotate 20 turns to retract mandrel, SO & weight check plug with 25k. TOP of the plug set ~ 3,282' 04:00 - 05:00 1.00 ZONISO P DECOMP RU and test EZSV to 1000 psi for 10 min. 29 strokes. Test held. RD & blow down test equipment. 05:00 - 09:00 4.00 STWHIP P DECOMP POH laying down 5" DP. 09:00 - 10:00 1.00 STWHIP P DECOMP LD EZSV running tool and clean /clear rig floor of vendors tools. 10:00 - 10:30 0.50 STWHIP P DECOMP RIH with remaining DP from derrick to 479' 10:30 - 11:30 1.00 STWHIP P DECOMP POH laying down DP 11:30 - 12:30 1.00 STWHIP P DECOMP Clear rig floor. Off load drill pipe out of pipe shed. 12:30 - 20:30 8.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, _3,025' 20:30 - 23:00 2.50 STWHIP P DECOMP PJSM -Slip and cut 132' of drilling line. Function test crown-o-matic. 23:00 - 00:00 1.00 STWHIP P DECOMP POH racking back 20 stands 5" DP 2/9/2008 00:00 - 01:00 1.00 STWHIP P DECOMP POH racking back 12 stands 5" DP 01:00 - 07:00 6.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, _3,025' 07:00 - 08:30 1.50 STWHIP P DECOMP POH racking back 32 stands 5" DP 08:30 - 14:00 5.50 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 96 Jts, -3,025' 14:00 - 15:30 1.50 STWHIP P DECOMP POH racking back 32 stands 5" DP 15:30 - 16:30 1.00 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 15 Jts, -472' 16:30 - 17:00 0.50 STWHIP P DECOMP POH racking back 5 stands 5" DP 17:00 - 17:30 0.50 STWHIP P DECOMP Clean & clear rig floor and ready tool for mill BHA #19 17:30 - 18:00 0.50 STWHIP DECOMP PJSM on picking up milling assembly / BHA #19 18:00 - 21:00 3.00 STWHIP P DECOMP PU & MU Whipstock Mill Assembly BHA #19 -Starter Mill /Bit Sub /Flex Jt. /Upper Mill / XO / 1 x HWDP / XO /Bumper Sub / Flt Sub /MWD / UBHO /Orient MWD & UBHO Sub to starter rnntea: aizuzuua ~:ios~rm i ~ BP EXPLORATION Page 16 of 47 Operations Summary Report Legal Well Name: NS16 Common W Event Name Contractor Rig Name: Date ~ ell Name: N : R Name: N N From - To ' S16 EENTE ABOBS ABOBS Hours R+COM ALASK 33E Task ~ PLET A DRI Code ~ E LLING NPT I~ Start I Rig R Rig N Phase ~) Spud Date: 6/29/2002 : 1/18/2008 End: 3/25/2008 elease: 3/25/2008 umber: 33E Description of Operations 2/9/2008 18:00 - 21:00 3.00 STWHIP P DECOMP mill. 21:00 - 00:00 3.00 STWHIP P DECOMP Cont' RIH PU - 6 x 8" DC's / XO / 21 x HWDP 2/10/2008 00:00 - 02:30 2.50 STWHIP P DECOMP RIH Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 27 Jts, 1,786' 02:30 - 03:00 0.50 STWHIP P DECOMP D-1 Drill & secure well. Safety meeting discussing D-6 stripping drill and D-5 well kill drill. 03:00 - 05:00 2.00 STWHIP P DECOMP Install IBOP Pressure up to 200 psi & Perform D-6 stripping drill, Strip in the hole picking up singles from the pipe shed maintaining 200 psi on choke. Perform D-5 well kill drill, pumping ~ 3 bpm holding 240 psi. back pressure, allowing hands to become accustom to bringing up pumps to kill rate and choke operations. 05:00 - 05:30 0.50 STWHIP P DECOMP Bleed off pressure, POH to IBOP & floor safety valve, LD same. Blow down TDS and all surface equipment. 05:30 - 08:00 2.50 STWHIP P DECOMP Cont' RIH from 1,786'to 3,220' Picking up new string of 5" DP 1 x 1 cleaning shipping compound off of pin ends. 08:00 - 09:00 1.00 STWHIP P DECOMP MU TDS, Wash down and tag EZSV CIBP W/ 15k ~ 3,282' & CBU Up Wt: 150k / Dn Wt: 130 / 620 gpm / 560 psi Monitor Well, Static. Fluid Wt in and out 9.3 ppg 09:00 - 11:00 2.00 STWHIP P DECOMP POH from 3,282' to BHA 11:00 - 12:00 1.00 STWHIP P DECOMP POH stand back HWDP & DC's 12:00 - 14:30 2.50 STWHIP P WEXIT PJSM - PU and MU BHA #20) 13-3/8" whipstock slide to starter mill assembly &RIH with DC's &HWDP to 954' 14:30 - 16:00 1.50 STWHIP P WEXIT RIH from 954' to 3,249' 16:00 - 16:30 0.50 STWHIP P WEXIT MU TDS and establish parameters / Up Wt 155k / Dn Wt 129k / 702 gpm / 765 psi. Orient whipstock 21 deg LHS. SO, tag CIBP & set bottom trip anchor with 26K, PU to 170k & verify anchor set. SO and shear off of whipstock with 60k. TOW = 3,250" BOW = 3,274' 16:30 - 18:00 1.50 STWHIP P WEXIT Displace well -Pump 50 bbl high vis sweep followed by 446 bbls 8.8 ppg LSND milling fluid Vis 77 / YP 33 ~ 939 gpm / 303 psi, rate adjusted as per G & I. Obtain SPR's #1 MP 2 bpm = 90 psi / 3 bpm = 100 psi #2MP2bpm=80 psi/3bpm=110 psi MD 3,250 TVD 2,993 18:00 - 00:00 6.00 STWHIP P WEXIT Mill Window from 3,250' to 3,268' Up Wt 145k / Dn Wt 130k / Rt Wt 140k / 766 gpm / 840 psi / RPM 80 / TO 5k off bttm - 7 - 12 k on. 2/11/2008 00:00 - 03:00 3.00 STWHIP P WEXIT Cont' Mill Window from 3,268' to 3,274' & 20' of new hole to 3,294' Up Wt 145k / Dn Wt 130k / Rt Wt 140k / 766 gpm / 840 psi / RPM 80 / TO 5k off bttm - 7 - 12 k on. Dress window, work mills through with and without pumps and rotation. 03:00 - 05:00 2.00 STWHIP P WEXIT Pump 30 bbl 11 ppg weighted super sweep followed by 30 bbl high vis super sweep around pumping 880 gpm 1030 psi, rotating 120 rpm's. Circulate 3 x surface to surface until well cleaned up. Mud Wt. in and out 8.9 ppg. 05:00 - 06:00 1.00 STWHIP P WEXIT RU & Perform LOT MD 3,250 /TVD 2,993, Mud Wt in and out rnntea: aizuzuua iaossrm ' • i BP EXPLORATION Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date From - To Hours ' Task Code NPT Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Phase 2/11/2008 105:00 - 06:00 1.001 STWHIP~ P WEXIT 06:00 - 06:30 0.501 STWHIP P WEXIT 06:30 - 11:30 5.00 STWHIP P WEXIT 11:30 - 13:30 2.00 STWHIP P WEXIT 13:30 - 14:30 1.00 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30-16:00 0.50STWHIPP (WEXIT 16:00-23:00 7.OOSTWHIPP (WEXIT NS I I t~ oaI ~a`Z 23:00 - 00:00 1.00 STWHIP N SFAL WEXIT 2/12/2008 00:00 - 01:00 1.00 STWHIP N SFAL WEXIT 01:00-02:00 1.OOSTWHIPP (WEXIT 02:00 - 03:00 1.00 DRILL P INT1 03:00 - 07:00 4.00 DRILL P INTi 07:00 - 07:30 0.50 DRILL P I NT1 07:30 - 08:30 1.00 DRILL P I NT1 08:30 - 10:00 1.50 DRILL P I NTi 10:00 - 10:30 0.50 DRILL P INT1 Page 17 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Description of Operations 8.9 ppg, LO pressure 545, EMW 12.43 ppg. RD and blow down test equipment. Obtain SPR's #1 & 2 MP's, 2 bpm = 60psi / 3 bpm = 80 psi. Pump dry job, monitor well, Static. Blow down TDS and mud lines. POH racking back 5" DP &HWDP PJSM - LD BHA #20, Upper watermelon mill in full gauge Clean & Clear rig floor of vendors tools MU running tool and pull wear bushing & LD same, MU BOP flushing tool and flush BOP stack, LD flushing tool and blow down lines. MU & install lower test plug and RU test equipment and fill BOP stack and choke manifold with seawater Test BOPE as per BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Witness of test waived by Lou Grimaldi (AOGCC State Inspector). Test witnessed by Brian Buzby /Chris Clemens (WSL), Bill Bixby /Roy Hunt (NAD Toolpusher), Kevin Castleman /Jeff Quittschreiber (NAD Driller). Test as follows with 5" Test Joint. 250 psi / 5000 psi. #1) Top Rams 3.5" x 6" VBR /Floor Safety Valve /Kill HCR / Choke Valves # 9, 12 & 13 #2) Manual Kill Valve /Choke Valves # 8 & 11 #3) (BOP /Choke Valves # 4, 7, & 10 #4) Choke Valve # 4-7-10 #5) Choke Valve #1 #6) Choke Valve #2 #7) Manual Choke Valve #8) Choke HCR Valve #9) Annular 250 psi / 3500 psi. #10) Bottom 3.5" x 6" VBR #11) Lower Well Control Valve #12) Upper Well Control Valve (Failed) Function Draw Down Test Accumulator #13) Blind Shear Rams Trouble shoot and Service Upper Well Control Valve Continue Test as follows with 5" Test Joint. 250 psi / 5000 psi. #14) Service & Retest Upper Well Control Valve (Passed) RD & blow down test equipment, Pull test plug and install wear bushing. PU BHA tools to rig floor and ready for MU PJSM - MU Drilling BHA #21 & Orient, RIH with 3 stands of HWDP Shallow hole Test MW D 613 gpm = 490 psi, Good Test Service TDS, Draw Works, Blocks and Crown RIH from 390' - 3244' Break Circulation and establish parameters -900 gpm / 80 rpm = 9.28 ECD -Perform SPR's ,.,.....,...,, ., ., ., o~..,o ~~ o „o _ Printed: 4/21/2008 1:15:33 PM • BP EXPLORATION Page 18 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/12/2008 10:30 - 12:00 1.50 DRILL P INT1 tvd) MW= 8.7 ppg In / 8.9 ppg Out 800 GPM 1200 psi off / 1300 psi on WOB =5-25 klbs 100 rpm Tq = 5k off / 6k on PUW = 142k SOW = 128k RtWt = 138k ECD = 9.23 CECD = 9.28 ADT - 0.97 hrs / AST = 0.97 hrs 12:00 - 00:00 12.00 DRILL P 1NT1 Directionally Drill 12 1/4" Intermediate hole 3434'-4867' (4168' tvd) MW= 8.7 PP9 In / 8.9 PP9 Out 840 GPM 1870 psi off / 1990 psi on WOB =25k Ibs 100 rpm Tq = 5k off / 6.5k on PUW = 169k SOW = 150k RtWt = 153k ECD = 9.73 CECD = 9.62 ADT = 7.25 hrs AST = 4.10 hrs ART = 3.15 hrs Total time on bit = 2/13/2008 00:00 - 12:00 12.00 DRILL P INT1 Directionally Drill 12 1/4" Intermediate hole 4867' - 5824(4782' tvd) MW= 9.1 ppg In / 9.2 ppg Out 840 GPM 2300 off / 2450 on WOB =25k Ibs 120 rpm Tq = 6k off / 8k on PUW = 175k SOW = 1550k RtWt = 160k ECD = 9.81 CECD = 9.76 ADT = 6.45 hrs AST = 1.78 hrs ART = 4.67 hrs Total time on bit = 14.7 hrs 12:00 - 00:00 12.00 DRILL P INT1 Directionally Drill 12 1/4" Intermediate hole 5824- 6879(5412' tvd) MW= 9.2 ppg In / 9.3 ppg Out 850 GPM 2400 off / 2540 on WOB =25k Ibs 120 rpm Tq=9k off/11kon PUW = 203k SOW = 160k RtWt = 181 k ECD = 9.78 CECD = 9.74 ADT = 7.68 hrs AST = 2.03 hrs ART = 5.65 hrs Total time on bit = 22.4 hrs Total Bit revs = 329k 2/14/2008 00:00 - 12:00 12.00 DRILL P INTi Directionally Drill 12 1/4" Intermediate hole 6879 - 7452'(5767' tvd) MW= 9.2 ppg In / 9.2 ppg Out 850 GPM 2470 off / 2520 on WOB =25k Ibs 120 rpm Tq = 11 k off / 14k on PUW = 225k SOW = 165k RtWt = 190k ECD = 9.67 CECD = 9.73 ADT = 7.90 hrs AST = 1.3 hrs ART = 6.63 hrs 12:00 - 00:00 12.00 DRILL P INT1 Directionally Drill 12 1/4" Intermediate hole 7452'- 8027 (6120' tvd) MW= 9.2 ppg In / 9.3 ppg Out 850 GPM 2590 off / 2680 on WOB =25k Ibs rnnteo: aizuzuvu i:io:aarm • BP EXPLORATION Page 19 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E i I Date From - To I Hours Task Code NPT Phase Description of Operations 2/14/2008 12:00 - 00:00 12.00 DRILL P INTi 120 rpm Tq = 11 k off / 13k on PUW = 225k SOW = 173k RtWt = 188k ECD = 9.73 CECD = 9.71 ADT = 9.88 hrs AST = 1.58 hrs ART = 8.3 hrs Total time on bit = 40.1 hrs Total Bit revs = 619k 2/15/2008 00:00 - 08:30 8.50 DRILL P INTi Directionally Drill 12 1/4" Intermediate hole 8027 -8600(6471' tvd) MW= 9.3 ppg In / 9.3 ppg Out 850 GPM 2810 off / 3000 on WOB =25k Ibs 120 rpm Tq = 10k off / 14k on PUW = 237k SOW = 170k RtWt = 200k ECD = 9.89 CECD = 9.76 ADT = 6.07 hrs AST = 1.70 hrs ART = 4.37 hrs Total time on bit = 46.23 hrs Total Bit revs = 750k 08:30 - 11:30 3.00 DRILL P INT1 Circulate and Condition hole -CBU 3x for hole cleaning -120 RPM 12k FVLbs -850 gpm 2815 psi 9.3 ppg in/out 11:30 - 12:30 1.00 DRILL P INT1 Monitor well- Well Static POH from 8600 - 7739' 12:30 - 13:00 0.50 DRILL P INTi Pump Dry Job -install stripping rubber -monitor well, static 13:00 - 17:00 4.00 DRILL P INT1 POOH from 7739 - 3250' -minor tight spot in UGNU, work through without issues 17:00 - 18:00 1.00 DRILL P INT1 MADD pass log to tie-in NS16a with NS16 -log up without pumps ~ 300 fph 18:00 - 20:00 2.00 DRILL P INT1 POOH to BHA 20:00 - 23:00 3.00 DRILL P INT1 PJSM on Handling BHA -Stand Back Collars, UD Stabs, UD MWD, -Break Bit and UD Motor UD NM Pony Collars Clear Floor of BHA Tools 23:00 - 23:30 0.50 DRILL P INT1 Clean Floor and UD tools outside, P/U new BHA Tools 23:30 - 00:00 0.50 DRILL P INTi Service TDS, Draw works and install rotary table chain 2/16/2008 00:00 - 01:30 1.50 DRILL P INTi PJSM on P/U Rotary Steerable BHA -P/U SLB Power Drive Tools and Shallow hole test, Good Test 01:30 - 04:30 3.00 DRILL P INT1 PJSM on Loading nuke source in LWD P/U MWD /LWD tools and Load source 04:30 - 06:00 1.50 DRILL P INTi RIH with DC's and HWDP Shallow Hole Test MWD /LWD Good Test 06:00 - 07:30 1.50 DRILL P INT1 RIH to 3250' -Fill Pipe, -Monitor well, Static 07:30 - 10:00 2.50 DRILL P INT1 PJSM on Cutting drilling line -Reviewed procedure and update as needed -First time this crew cut drilling line on this rig 10:00 - 11:00 1.00 DRILL P INT1 Service TDS, Draw Works, Crown rnmea: viz vzvua i:io:oa riw ' • BP EXPLORATION Page 20 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours ,Task Code NPT Phase Description of Operations 2/16/2008 11:00 - 15:00 4.00 DRILL P INT1 RIH to 8377' -Fill Pipe every 2000' 15:00 - 16:00 1.00 DRILL P INTi Precautionary Ream 8377 - 8600' 16:00 - 00:00 8.00 ~ DRILL ~ P 2/17/2008 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P 12:00 - 22:00 10.001 DRILL ~ P 22:00 - 00:00 I 2.001 DRILL I P 12/18/2008 100:00 - 01:30 ~ 1.50 ~ DRILL ~ P 01:30 - 03:30 I 2.001 DRILL I P 04:30 - 06:00 I 1.501 DRILL I P 06:00 - 08:00 I 2.001 DRILL I P -700 gpm / 2350 psi -120 rpm / 9K Tq. -No Problems Reaming to bottom INT1 Directionally Drill 12 1/4" Intermediate hole 8600 - 9142' (6810' tvd) MW= 9.3 ppg In / 9.4 ppg Out 870 GPM 3215 psi WOB =20k Ibs 140 rpm Tq = 11 k off / 16k on PUW = 233k SOW = 179k RtWt = 199k ECD = 9.94 CECD = 9.82 ADT = 6.1 hrs Total ADT = 6.1 hrs Total Bit revs = 51 k INT1 Directionally Drill 12 1/4" Intermediate hole 9142 - 10,195(7506' tvd) MW= 9.5 ppg In / 9.6 ppg Out 850 GPM 3300 off / 3510 on WOB =15k Ibs 120 rpm Tq = 13k off / 19k on PUW = 225k SOW = 195k RtWt = 210k ECD = 9.99 CECD = 9.82 ADT = 9.5 hrs Total time on bit = 15.6 hrs INTi Directionally Drill 12 1/4" Intermediate hole 10,195 -11054' 8216(7506' tvd) MW= 9.5 ppg In / 9.6 ppg Out 850 GPM 3715 off / on WOB =15k Ibs 120 rpm Tq = 17k off / 21 k on PUW = 280k SOW = 200k RtWt = 230k ECD = 10.29 CECD = 10.01 ADT = 8.5 hrs Total time on bit = 24.1 hrs INT1 Circulate and condition mud, Weight up to 10.5 ppg Weight up mud from 9.5 to 10.5 with "Spike "Fluid 677 GPM 2750 psi, Rotate ~ 120 RPM 21 k fUlbs INTi Finish Weight up to 10.5 ppg -Treat and condition new mud -Monitor Well, Static 10.5 ppg In /Out INT1 Wipe hole back to 8600' -Intermittent 40 -50k overpulls from 9700 - 9200' -pull slow through, no back reaming -No swabbing while pulling through trouble area INT1 RIH 10959 -Precautionary Ream last stand down No Issues RIH INT1 CBU and condition mud -800 gpm / 3490 psi -120 rpm / 19k Tq -Even out Mud Wt. to 10.5ppg In/Out rnntea: gauzuua iao:~arnn • BP EXPLORATION Page 21 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours I Task Code NPT Phase Description of Operations 2/18/2008 08:00 - 12:00 4.00 DRILL P INT1 Directionally Drill 12 1/4" Intermediate hole 11054'-11341(8403' tvd) MW= 10.5 ppg In / 10.6 ppg Out 800 GPM 3650 off / on WOB =10-20k Ibs 120 rpm Tq = 17k off / 28k on PUW = 295k SOW = 200k RtWt = 220k ECD = 11.15 CECD = 10.9 ADT = 2.5 hrs Total time on bit = 26.6 hrs 12:00 - 00:00 12.00 DRILL P INT1 Directionally Drill 12 1/4" Intermediate hole 11341 -12138(9173' tvd) MW= 10.5 ppg In / 10.5 ppg Out 830 GPM 3800 off / on WOB =10-20k Ibs 140 rpm Tq = 21 k off / 28k on PUW = 320k SOW = 210k RtWt = 250k ECD = 11.25 CECD = 10.89 ADT = 10.4 hrs Total time on bit = 37.0 hrs Bet Rev's 285k 2/19/2008 00:00 - 02:30 2.50 DRILL P INTi Directionally Drill 12 1/4" Intermediate hole 12138 - 12316 MW= 10.5 ppg In / 10.5 ppg Out 830 GPM 3800 off / on WOB =10-20k Ibs 140 rpm Tq = 21 k off / 28k on PUW = 335k SOW = 210k RtWt = 250k ECD = 10.90 CECD = 10.89 02:30 - 04:00 1.50 DRILL N RREP INTi Repair #1 mud pump / ~2 cylinder -c/o Liner, Swab & Gasket seal - circ with 1 pump @ 100 spm 1250 psi 116 rpm / 18k Tq 04:00 - 09:00 5.00 DRILL P INT1 Directionall Drill 12 1/4" Intermediate hole to cs t. 1231 - 12575 9502'tvd MW= 10.5 ppg In / 10.5 ppg Out 830 GPM 3800 off / on WOB =10-20k Ibs 140 rpm Tq = 21 k off / 28k on PUW = 325k SOW = 200k RtWt = 255k ECD = 11.25 CECD = 10.89 09:00 - 14:00 5.00 DRILL P INTi Circulate hole clean -850 gpm 3750 psi -140 rpm / 19k ft/Ibs Tq CBU 3x ECD = 10.91 CECD = 10.89 14:00 - 16:30 2.50 DRILL P INT1 Attem t to POH on elevators, Hole started ullin 50k over from 12 41 - Back ream throu h trouble area 2x C~ 830 GPM 3800 off / on 140 rpm Tq = 21 k - 28k on No issues back reaming, no packing off or high torque Attempt to pull on elevators after reaming, 50k overpulls again between 12,440' and 12,350 (trouble area correlates to ... stabilizers pulling through faulted area No problem running down through area, just POH without rnntea: ainrzuuts inos~rm ' • i BP EXPLORATION Page 22 of 47 Operations Summary Report Legal Well Name: NS11i Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/19/2008 14:00 - 16:30 2.50 DRILL P INT1 pumps or rotation 16:30 - 18:30 I 2.001 DRILL 18:30 - 19:30 I 1.001 DRILL I P 19:30 - 21:30 2.00 DRILL P 21:30 - 22:30 1.001 DRILL P 22:30 - 00:00 I 1.501 DRILL I P 12/20/2008 100:00 - 01:30 1.501 DRILL P 01:30 - 03:30 I 2.001 DRILL I P 03:30 - 10:30 7.00 DRILL P Back ream through trouble area ~ 830 GPM 3800 off / on 140 rpm Tq = 21 k - 28k on No issues back reaming, no packing off or high torque Successfully pulled through trouble zone 30-40 k overpulls. RIH without additional drag INT1 Continued to POH to 10959' - Previous short trip depth of 11,054 MD - No other issues, some intermittent overpulls of 30-40k, not unexpected for the Kuparuk sands interval INTi RIH to 11,940', tag up solid (bottom of the TKC) Pick up and work down through area 2X, no issues after working through Continued to RIH with some intermittent slack off drag of 30-40k Trip down through 12340 - 12,420 without any additional drag., Pulled back up through trouble zone with out no increase in drag, RIH 2 stands to CBU INT1 Wash and ream last stand to bottom CBU ~ 810 gpm / 3834 psi 130 rpm 22k ft/Ibs of torque CECD = 10.89 AECD = 11.21 20-50-% increase in cuttings for apx. 1000 strokes just before we got bottoms up, shakers clean up with a small amount of sand coming across. No shale splinters observed during this circulation. INTi Attempt to POH on elevators, Hole started pulling 50k over from 12,388 - 12,340 Correlates to bit across faulted area Pulled up 50k three times to get above it, RIH with no indication of additional drag INT1 Circulate and Condition Mud -Weight mud to 11.0 ppg Only Circ. with 1 pump due to Popoff leaking by on #1 500 gpm / 1780 psi 120 rpm / 22k Tq INTi Circulate and Condition Mud -Weight mud to 11.0 ppg Only Circ. with 1 pump due to Popoff leaking by on #1 500 gpm / 1780 psi 120 rpm / 22k Tq INT1 Circulate hole clean at full rate -775 gpm / 3750 psi -130 rpm / 22k fUlbs Tq Monitor well 11.0 ppg MW in/out, Well static INT1 POH on elevators 12,575 - 8600' -Pulled through faulted zone with 20 - 40k overpull, no erratic drag rnntea: ninizuua ia°:~srm ' • $P EXPLORATION Page 23 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABORS 33E Rig Number: 33E I I i Date ,From - To 1 Hours Task ', Code NPT Phase Description of Operations 2/20/2008 ~ 03:30 - 10:30 ~ 7.00 ~ DRILL ~ P ~ ~ INT1 10:30 - 11:30 1.001 DRILL ~ P ~ ~ INT1 11:30 - 18:30 7.00 DRILL P INTi 18:30 - 22:00 3.50 DRILL P INT1 22:00 - 22:30 0.50 DRILL P INT1 22:30 - 23:00 0.50 CASE P INT1 23:00 - 23:30 0.50 CASE P INT1 23:30 - 00:00 0.50 CASE P INT1 2/21/2008 100:00 - 02:00 ~ 2.001 CASE ~ P ~ INTi 02:00 - 05:00 3.001 CASE P INT1 05:00 - 07:30 2.50 ~ CASE P INT1 07:30 - 09:30 2.00 CASE P INTi 09:30 - 14:00 4.50 CASE P INT1 14:00 - 17:00 3.00 CASE N HMAN ~ INT1 -Intermmitant 30 40k overpulls through Kuparuk sand interval No Issues pulling on elevators Spot "G Seal pill across West Sak -100 bbl / 15# per barrel of G Seal pill 330 gpm / 850 psi POH to BHA PJSM on Laying Down BHA with RA source -POH and remove Source -UD 8" LWD\MWD andBHA tools -Clear floor of drilling tools Pull wear bushing Flush stack with jet tool PJSM on changing Pipe Rams -Drain Stack PJSM on changing Pipe Rams -Change rams from 3 1/2" x 6" variable rams to 9.625 rams -Secondary control during lifting of rams PJSM on testing BOP - Set Test Joint - R/U test equipment - Chart and Test top set of Rams, - low pressure of 250 psi for 5 min, good test - Attempt to pressure up to 3500 psi test failed - Pulled test jt and replace O-ring - Set test jt and rig up to test - Pressure up low 250 psi for 5 min., good test, - Pressure up to 3500 psi for 5 min., Good Test - Rig Down test equipment and laydown test jt -Test witnessed by NAD Brian Tiedemann and BP WSL Dave Newlon Service Pipe handler on Top Drive System -Change out on tong dies in pipe handler to make up Franks tool -P/U Elevators and Make Up Franks tool Rig up to run 9 5/8" casing R/U Power tongs, Slips, Scaffolding and secure rig floor area Run 9 5/8" 47# L-80 Intermediate String Baker-Lock Shoe Tract (HES Shoe, 2 Jts of csg, HES Float Collar) Use Best of Life 2000NM thread compound on all BTC-M connections - 9800 ft /Ibs of make up torque - Flow check shoe after making up first 4 joints - Fill each jt. - Circ. Every 20 jts. - 1 Rigid body stab / jt on each joint of BTC-M casing Safety Stand down to investigate incident of Parting of casing sling The rig was in the process of running 9 5/8" casing. When the hook for the casing pick up sling, snagged the eye of a cable used as a secondary restraint on the bumper bar on top of the rrintea: arzvzvva i:io:oarm ' • BP EXPLORATION Page 24 of 47 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date Name: N ell Name: N : R Name: N N From - To S16 S16 EENTE ABOBS ABOBS .Hours ' R+COM ALASK 33E Task PLET A DRI .Code E LLING NPT Start I Rig R Rig N -Phase Spud Date: 6/29/2002 : 1/18/2008 End: 3/25/2008 elease: 3/25/2008 umber: 33E Description of Operations 2/21/2008 14:00 - 17:00 3.00 CASE N HMAN INTi "V" Door. The driller was unable to visually see this area and the floorhands did not see the hook catching the eye before the hook pulled tight and parted. After the sling parted the joint fell back down on to the skate. No Personnel were injured; The only damage was to the parted sling. A safety stand down was initiated immediately . an investigation team was mobilized to conduct a thorough investigation of the Incident. 17:00 - 19:00 2.00 CASE P INT1 Install shorter secondary restraint on bumper bar and tie sling back as much as possible Install shorter lower section of the Franks tool and Rig up new longer casing pick up sling to allow for more space to stab pipe before inserting fill up tube into casing - Complete the investigation 19:00 - 23:00 4.00 CASE P INT1 PJSM on running casing Run 9 5/8" 47# L-80 Intermediate String f/1400 - 3229' (shoe) Use Best of Life 2000NM thread compound on all BTC-M connections - 9800 ft /Ibs of make up torque - Fill each jt. -Circ. Every 20 jts. - 1 Rigid body stab / jt on each joint of BTC-M casing 23:00 - 00:00 1.00 CASE P INT1 CBU 1.5x at top of whipstock -8 bpm / 540 psi 2/22/2008 00:00 - 01:30 1.50 CASE P INT1 PJSM on running casing Run 9 5/8" 47# L-80 Intermediate String f/3229' (shoe) - 4050' Use Best of Life 2000NM thread compound on all BTC-M connections - 9800 ft /Ibs of make up torque - Fill each jt. -Circ. Every 20 jts. - 1 Rigid body stab / jt on each joint of BTC-M casing 01:30 - 03:00 1.50 CASE N RREP INT1 PJSM on Changing out Franks fill up rubber cup Changed out failed cup on fill up tool 03:30 - 08:00 4.50 CASE P INT1 Run 9 5/8" 47# L-80 Intermediate String f/ 4050 - 5703 Use Best of Life 2000NM thread compound on all BTC-M connections - 9800 ft /Ibs of make up torque - Fill each jt. -Circ. Every 20 jts. - 1 Rigid body stab / jt on each joint of BTC-M casing 08:00 - 09:00 1.00 CASE P INT1 Rig Torque Turn tools for Hydril 513 casing -Change rubber on Franks tool 09:00 - 00:00 15.00 CASE P INT1 Run 9 5/8" 47# L-80 Intermediate String f/ 5703 - 1 1004 Use Seal guard thread compound on all Hydril 513 connections - 17,000 ft /Ibs of make up torque - Fill each jt. -Circ. Every 20 jts. - 1 Cementralizer on the first 81 jts 2/23/2008 00:00 - 04:00 4.00 CASE P INTi Run 9 5/8" 47# L-80 Intermediate String f/ 11004 - 12,550 Use Seal guard thread compound on all Hydril 513 connections - 17,000 ft /Ibs of make up torque - Fill each jt. -Circ. Every 20 jts. - No PUW after 11,000', due to increase in drag 04:00 - 04:30 0.50 CASE P INT1 Make Up Jt #168 of Hydril and wash down_~ 5 bpm / 1150 psi Slack off wt 250k 04:30 - 05:30 1.00 CEMT P INT1 Lay Down Franks tool Printetl: 4/21/2008 1:15:33 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To 2/23/2008 04:30 - 05:30 05:30 - 10:00 10:00 - 15:00 NS16 NS16 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 33E Hours Task Code NPT 1.00 CEMT P 4.50 CEMT P 5.00 CEMT P 15:00 - 19:30 4.50 CASE P 19:30 - 21:00 1.50 CASE C 21:00 - 00:00 3.00 CASE C 2/24/2008 00:00 - 00:00 24.00 CASE C Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Phase INT1 INTi Page 25 of 47 Spud Date: 6/29/2002 End: 3/25/2008 Description of Operations -Make up Crossover pup - M/U Cement head - R/U Cement Lines Stage up pump rates to 10.0 bpm with 1,250 - 875psi. - circ Held PJSM with all personal regarding cementing operations INT1 Shut down pumps, turn over to SLB cementers -Pump 5bbls SW -Test cement lines to 4,000 Psi, Pump 35bbls of CW 101 at 6 bpm, 950psi; 70.5bbls 11.0 ppg Mud Push11 at 5.5 bpm, 875psi; Drop btm plug with good surface indication followed with 424bb1s (851 Sacks) 11.5 -12.Oppg Class "G" Conventional Lead Cement at 6.5 bpm, 1000psi; 131 bbls (619 Sacks) 15.8ppg Class "G" Tail Cement with additives at 5 bpm, 1450 - 750psi, Drop top plug with good surface indication, Displace with 25bbls of SW, 7bpm, 650psi; Switched to rig pumps, Pumped 890 bbls (8836 stk at 96% pump efficiency) of 11.Oppg mud at 8 - 3 bpm, 335 - 720psi, Bump plug with a total of 915bb1s to 1250psi, Hold for 5 mins, Cement in Place at 14:35hrs on 02-23-08. No pipe reciprocation, Good returns, Bleed off pressure, Check floats (Floats not Holding), Shut in Float Collar at 12489', Float Shoe at 12574' INTi Inject into 9 5/8 x 13 3/8 annulus Pump @ 0.5 bpm 11.0 ppg Shoe ~ 3250 / 2993' tvd 40.7 bbls away before leaking off C~ 872 psi (16.6 EMW ~ shoe) Increase injection rate to 3 bpm / 530 psi (14.4 EME ~ shoe) Cleared OA with 192 bbls of 11 ppg mud 1(~~T INT1 Check Floats, holding -Rig Down Cement head -Clean csg equip.-Prep floor to Nipple down INT1 Wait on completion of SIMOPS on NS 15 ~ -Schlumberger rigged up on NS 15 -SIMOPS meeting with rig crew on NS 15 operation -Rig continued with cleaning floor, -Cleaning "L" Pits, -Clean out under shaker and drag chain Injected 20 bbls into OA every 2 hours 2 bpm / 560 psi INT1 Wait on completion of SIMOPS on NS 15 -Schlumberger rigged up on NS 15 -SIMOPS meeting with each rig crew -Rig continued with cleaning floor, -Cleaned "L" Pits, -Clean out under shaker and drag chain -Change Swabs and Liners in Mud Pumps -PM Iron Roughneck -Derrick Inspection -PM Tugger Sheaves Printed: 4/21/2008 1:15:33 PM " ~ • BP EXPLORATION Page 26 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date ~~ From - To ', Hours Task Code ~ NPT Phase ~ Description of Operations 2/24/2008 00:00 - 00:00 24.00 CASE C INT1 -Service Shale shakers and Centrifuges -Injected 20 bbls into OA every 2 hours 2 bpm / 560 psi NS15 update Successfully pump "kill" pill across perfs Schlumberger crew finished ~ 22:00 hrs Production operators bleeding OA from 700 psi to zero starting at 22:30 hrs 2/25/2008 00:00 - 06:30 6.50 CASE C INT1 Wait on completion of SIMOPS on NS 15 Production operators bleeding OA from 700 psi starting at 22:30 hrs 2/24/2008 Bleed off C«? 0600hrs Rig Down abd Safe out area Monitor Rig, and Cellar with periodic checks for gas Remove Slips and pull master bushings, clean under table to prepare to lift riser Continued to Prep rig for drilling 06:30 - 09:00 2.50 BOPSU P INT1 Nipple Down BOP's -Remove Riser -Remove Turnbuckles and Choke & Kill Line -Raise stack 3' 09:00 - 21:00 12.00 BOPSU P INT1 Remove Grating to Gain access to Cellar -Pull 300,000, -Center Casing and -Install emergency sli` ps ,. -Cut Casing and Lay Down -Dress Casing -Install Packoff and run lock down screws -Test packoff to 3800 psi for 10 min 300k setting on slips 21:00 - 00:00 3.00 BOPSU P INT2 ,Nipple up BOP's -center stack and tighten turnbuckles -install riser and finish with BOP Nipple up 2/26/2008 00:00 - 06:00 6.00 BOPSU P INT2 Finish nipple up BOP stack. Pump 20 bbls mud every 2 hrs down the OA 520 psi. Total 40 bbl for tour. MU flushing tool and flush BOP stack. LD flushing tool & drain stack. Install upper test plug and chance out toe cet of rams rn a ~~~ Y - 06:00 - 12:30 6.50 BOPSU P INT2 Test ROPE as oer BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Test witnessed by Chuck Shieve (AOGCC State Inspector). Richard Bordes (WSL), Kelly Cozby (NAD Toolpusher), Kelly Haug /Sean Holcomb (NAD Driller). Test as follows with 4.5" Test Joint. #1) Annular 250 psi / 3500 psi. Test as follows with 250 psi / 5000 psi. rnntea: n2uzuua ~aosarm BP EXPLORATION Page 27 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2008 106:00 - 12:30 I 6.501 BOPSURP INT2 #2) Top Rams 4.5" x 7" VBR / IBOP /Choke Valves # 9, 12 & 13 #3) Floor Safety Valve /Kill HCR /Choke Valves # 8 & 11 #4) Choke Valves # 4, 7, & 10 #5) Super Choke #6) Choke Valve # 3-5-6 /Manual Kill #7) Manual Choke Manifold Valve #8) Choke Valve #1, 3 & 5 #9) Choke Valve #2 #10) Choke HCR Valve #11) Manual Choke Valve #12) Bottom 3.5" x 6" VBR /Upper Well Control Valve #13) Lower Well Control Valve #14) Function Draw Down Accumulator Test Test as follows with 7" Test Joint. 250 psi / 4000 psi. #15) Top Rams 4.5" x 7" #16) Blind Shear Rams Freeze Protected OA out of critical path with 125 bbl diesel C~ 12:30 - 14:30 2.00 BOPSU N SFAL INT2 14:30 - 15:30 1.00 DRILL P INT2 15:30 - 16:00 0.50 DRILL P INT2 16:00 - 21:00 5.00 DRILL P INT2 21:00 - 00:00 I 3.001 DRILL I P I I INT2 12/27/2008 100:00 - 00:30 0.50 ~ DRILL P INT2 00:30 - 04:30 4.00 DRILL P INT2 04:30 - 06:30 2.00 DRILL P INT2 06:30 - 10:00 3.50 DRILL P INT2 10:00 - 10:30 0.50 DRILL P INT2 10:30 - 12:30 2.00 DRILL P INT2 12:30 - 13:30 1.00 DRILL P INT2 13:30 - 15:00 1.50 DRILL P INT2 15:00 - 16:30 I 1.501 CASE I P I I INT2 RD & blow down test equipment, Pull test plug and install wear bushing 9" ID. Top Drive obstructed with an ice plug. Thaw and clear same. Service Top Drive and Crown. PJSM and ready floor to MU BHA #23 MU Drilling BHA #23 -Bit, 8.5" Smith JX8905 / RRS power drive /IBS / NMLDC and surface flow test Power Drive, 400 gpm 665 psi. Continue MU remainder of BHA -Black Box / Rhino Reamer /Flt /ARC / MW D / 3 x NM Flex DC's / XO / CCV /Jar / 23 x HWDP. Marinated Bit, and Basted Rhino Reamer to form an Ionic membrane consisting of Drill Zone WTF. RIH PU 5" DP 1 x 1 to 2090'cleaning storage dope off of pin ends. Cont' RIH PU 5" DP 1 x 1 to 2377'cleaning storage dope off of pin ends. RIH with stands from 2350' to 7315' Perform D-1 Tripping & D-6 Stripping Drills, POH to IBOP & floor safety valve, LD same. Blow down TDS and all surface equipment. RIH from 7315' to 11465' Filling DP every 3000' PJSM on cutting drilling line. Service Top Drive Cut & Slip 57' of drilling line, service draw works. RIH from 11465' to 12326' MU TDS and MAD Pass tie in log for geology ~ 300 fph from 12329' tag cement ~ 12462' Up Wt 326k / Dn Wt. 195k / Rt Wt. 244k / 350gpm / 1429 psi. / 60 rpm / TO. 16-18k PJSM - RU and test 9-5/8" casing to 4000 psi and record on chart for 30 min. 121 stks 10.6 bbls to pressure up. Test held, Bleed off and blow down test equipment. rnmea: arzuzuuo is wss rnn • BP EXPLORATION Page 28 of 47 Operations Summary. Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/27/2008 15:00 - 16:30 1.50 CASE P 16:30 - 18:00 1.50 DRILL P 18:00 - 20:00 2.00 DRILL P 20:00 - 20:30 0.50 DRILL P 20:30 - 00:00 3.50 DRILL P 12/28/2008 100:00 - 04:00 4.00 DRILL P 04:00 - 05:00 I 1.001 DRILL I P 05:00 - 12:00 I 7.001 DRILL I P 12:00 - 16:30 4.501 DRILL P 16:30 - 00:00 7.501 DRILL P INT2 Review D-8 Drill with all crew members. INT2 Drill cement & Float equipment frot 12462' to 12565' while bleeding in spike drilling fluid increasing mud wt to 12.3 ppg. 350 gpm / 1400 psi / 80 rpm / TO 19k INT2 Cont' Circulate and condition mud bleeding in spike fluid raising mud weight to 12.3 ppg in and out. INT2 Cont' Drill cement from 12565' Shoe C~ 12574' and clean out rat hole to 12575' INT2 Drill new 8.5" hole from 12575' to 12592' 350 gpm / 1397 psi / 40 - 100 rpm / TO 20k / WOB 10-20k Total ADT= 1.7 Hrs. SPR's = #1) 2 bpm - 250 psi / 3 bpm - 360 psi #2) 2 bpm - 260 psi / 3 bpm - 350 psi INT2 Drill 8.5" hole from 12592' to 12599' Up Wt. 300k / Dn Wt. 210k / Rt Wt. 247k 350 gpm / 1467 psi / 40 - 100 rpm / TO 20k / WOB 10-30k INT2 PJSM -Obtain SPR's, Perform FIT,- Mud Wt in and out 12.3 ppg. Test pressure 1100 psi TVD 9565'. EMW = 14.51 ppg. RD & blow down surface equipment. INT2 Drill 8.5" hole from 12599' to 12613' Up Wt. 290k / Dn Wt. 205k / Rt Wt. 240k 357 gpm /Off Bttm. 1345 psi / On Bttm. 1530 psi 40 - 100 rpm / TO off & on Bttm 17k / WOB 23k CAL. ECD=12.63 /ACT ECD=12.8 ADT = 7.70 Hrs PMP. 2068E NUT PLUG Sweep. ~ 12605' SPR. #1) 2BPM=250PSI / 3BPM=320PSI SPR. #2) 2BPM=250PSI / 3BPM=360PSI MD/12575' TVD9470' 12.3PPG MWT INT2 Drill from 12613'to 12621' Up Wt. 290k / Dn Wt. 205k / Rt Wt. 241 k 357 gpm /Off Bttm. 1345 psi / On Bttm. 1530 psi 120 rpm / TO off & on Bttm 17k / WOB 30k CAL. ECD=12.63 /ACT ECD=12.8 O en Rhino R m r. Pump 500, 550, 600 gpm. NOTE 5-10K Over-pulls working reamer into casin shoe ncrease in rom 15 to 22k ROP increase from 3 fph to -26 fph INT2 Directionally Drill 9.5" hole from 12,621' to 12,775', ND 9745' Up Wt. 280k / Dn Wt. 204k / Rt Wt. 240k 603 gpm /Off Bttm. 3523 psi / On Bttm. 3527 psi 140 rpm / TO On Bttm 26k -Off Bttm & 22k / WOB 30k CAL. ECD=12.63 /ACT ECD=13.19 ART = 9.30 Pump 30 bbl Sweep 10 Sx Nut Plug, 1 Sx SAP, ~ 12,621' On Connections Back Ream 35' ~ 100 rpm / S/O with 75% drilling pump rate. SPR. #1) 2BPM= 170 PSI / 3BPM= 270 PSI SPR. #2) 2BPM= 170 PSI / 3BPM=260PSI rnntea: aiz vzv~a i:i°:°s rm BP EXPLORATION Page 29 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours I Task Code NPT Phase Description of Operations 2/28/2008 16:30 - 00:00 7.50 DRILL P INT2 MD= 12,709' /TVD= 9,687' /Mud Wt.12.3 PPG Total ADT = 18.70 2/29/2008 00:00 - 12:00 12.00 DRILL P INT2 Directionall Drill 8.5" x 9.5" hole from 12,775' to 13,121' / ND 10,051' Up Wt. 290k / Dn Wt. 210k / Rt Wt. 240k 600 gpm /Off Bttm. 3430 psi / On Bttm. 3720 psi 145 rpm / TO On Bttm 26k -Off Bttm18k / WOB 35k CAL. ECD=13.02 /ACT ECD=13.22 On Connections Back Ream 35' ~ 100 rpm / S/O with 75% drilling pump rate. ADT = 10.30 Hrs. SPR. #1) 2BPM= 260 PSI / 36PM= 340 PSI SPR. #2) 2BPM= 260 PSI / 36PM= 370PSI MD= 13,088' /Mud Wt.12.2 PPG 12:00 - 00:00 12.00 DRILL P INT2 Directionall Drill 8.5" x 9.5" hole from 13,121' to 13,479' / ND 10,372' Up Wt. 300k / Dn Wt. 210k / Rt Wt. 252k 600 gpm /Off Bttm. 3610 psi / On Bttm. 3665 psi 130 rpm / TO On Bttm 27k -Off Bttm & 24k / WOB 25-33k CAL. ECD=13.02 /ACT ECD=13.21 On Connections Back Ream 35' C~ 100 rpm / S/O with 75% drilling pump rate. ADT = 10.40 SPR. #1) 2BPM= 240 PSI / 36PM= 350 PSI SPR. #2) 2BPM= 250 PSI / 36PM= 350PSI MD= 13,185' /Mud Wt.12.3 PPG Total ADT = 39.40 3/1/2008 00:00 - 00:30 0.50 DRILL P INT2 Directionally Drill 8.5" x 9.5" hole from 13,479' to 13,504' Up Wt. 300k / Dn Wt. 210k / Rt Wt. 252k 600 gpm /Off Bttm. 3610 psi / On Bttm. 3665 psi 130 rpm / TO On Bttm 27k -Off Bttm & 24k / WOB 25-33k CAL. ECD=13.02 /ACT ECD=13.21 00:30 - 02:00 1.50 DRILL N SFAL INT2 Pressure loss, #2 mud pump, isolate and replace valves and seats in #1 cylinder on same. Rotate and reciprocate 350gpm / 1515psi / 80rpm / TQ 19k / Rt Wt. 260k 02:00 - 12:00 10.00 DRILL P INT2 Directionally Drill 8.5" x 9.5" hole from 13,504' to 13,785' /10,644' TVD Up Wt. 310k / Dn Wt. 225k / Rt Wt. 255k 600 gpm /Off Bttm. 3650 psi / On Bttm. 3685 psi 120 rpm / TO On Bttm 27k -Off Bttm & 23k / WOB 25-35k CAL. ECD=13.09 /ACT ECD=13.12 On Connections Back Ream 35' ~ 100 rpm / S/O with 75% drilling pump rate. ADT = 8.8 Hrs. SPR. #1) 2BPM= 260 PSI / 36PM= 360 PSI SPR. #2) 2BPM= 260 PSI / 36PM= 360PSI MD= 13,504' /TVD= 10,393'Mud Wt.12.3 PPG 12:00 - 23:00 11 00 DRILL P INT2 Directionall Drill 8.5" x . Up Wt. 315k / Dn Wt. 232k / Rt Wt. 261 k rnncea: vic vcuv° i:~a.oo rm BP EXPLORATION Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date From - To Hours Task ~I Code NPT 13/1/2008 12:00 - 23:00 11.00 DRILL P 23:00 - 00:00 1.00 DRILL P 13/2/2008 100:00 - 02:30 2.501 DRILL P 02:30 - 05:30 3.00 DRILL P Start: 1 /18/2008 Rig Release: 3/25/2008 Rig Number: 33E Page 30 of 47 ~ Spud Date: 6/29/2002 End: 3/25/2008 Phase j Description of Operations INT2 600 gpm /Off Bttm. 3581 psi / On Bttm. 3689 psi 130 rpm / TO On Bttm 25k -Off Bttm & 24k / WOB 20-30k CAL. ECD=13.02 /ACT ECD=13.14 On Connections Back Ream 35' @ 100 rpm / S/O with 75% drilling pump rate. ADT = 9.60 SPR. #1) 26PM= 180 PSI / 3BPM= 290 PSI SPR. #2) 26PM= 180 PSI / 3BPM= 290 PSI MD= 13,855' /TVD= 10,706' Mud Wt.12.3 PPG NOTE: PMP 25BBL 13.3 ppg WT. Sweep at 13950', No increase in cuttings seen in returns INT2 INT2 INT2 05:30 - 06:30 1.00 DRILL N DPRB INT2 06:30 - 07:30 1.00 DRILL P INT2 07:30 - 08:30 1.00 DRILL P INT2 08:30 - 10:30 2.00 DRILL P INT2 10:30 - 12:00 1.501 DRILL P INT2 12:00 - 14:00 2.001 DRILL P INT2 Total ADT = 57.80 Circulate and Condition mud 600 gpm, 3724 psi, 120 rpm, TO Off Bttm 25k Circulate and Condition mud total 4 x bottoms up. Rt Wt. 250k / 600 gpm / 3670 psi / 120 rpm / TO Off Bttm 25k CAL. ECD=13.09 /ACT ECD=13.18 /Final ACT ECD= 13.15 SPR. #1) 26PM= 180 PSI / 3BPM= 290 PSI SPR. #2) 26PM= 180 PSI / 3BPM= 290 PSI MD= 14093' /TVD= 10919' Mud Wt.12.2 PPG POH -Short Trip to 9 5/8" casing shoe, pumping out ~ 200 gpm, 555 psi. Drop 2.125" CCV Ball ~ 12,800' and cont' pump out ~ 100 gpm, 250 psi. to 12,500' No problems on Trip out. Attempt to open CCV sub 2x, Ball blew through seat ~ 2500 psi & 3500 psi without opening valve. CBU 1 X ~ 12512' 170 SPM, 600 GPM, 3500 PSI Service Draw works / TDS /Crown & Blocks UP Wt. 285k / Dn Wt. 220k ~ SHOE RIH -from 12500' to 14085' Work through tight hole at the following depths without pumps or rotation 50k set down wt. .13050' - 13070' 13143' - 13150' 13223' -13230' 13257' 13282' - 13287' 13797' - 13825' Stage up pumps and rotary & wash down through fill from 14085' to TD ~ 14093' CBU 595 GPM / 3700 PSI /120 RPM / 26K TO / 257K RT WT / CAL ECD= 13.09 / IECD= 13.42, steady flow of cuttings across shaker screens with some splintery shale at btms up Cont' Circulate and condition mud 590 GPM / 3533 PSI / 165 RPM /TO OFF 30K / Pump 3066E High Vis Sweep with little increase in cuttings seen back at surface. CAL ECD= 13.09 /ACT ECD= 13.14 SPR. #1) 26PM= 250 PSI / 3BPM= 380 PSI BP EXPLORATION Page 31 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours I Task Code NPT Phase Description of Operations 3/2/2008 12:00 - 14:00 2.00 DRILL P INT2 SPR. #2) 2BPM= 250 PSI / 36PM= 370 PSI MD= 14093 / TVD= 10919' /MUD WT 13.3 PPG 14:00 - 17:00 3.00 DRILL P INT2 Monitor well, Static. POH -Short Trip to 9 5/8" casing shoe, pumping out ~ 203 gpm, 635 psi. 12,517' No problems on trip out to shoe. 17:00 - 18:00 1.00 DRILL P INT2 CBU - 600 GPM / 170 SPM / 3478 PSI Monitor well, Static Mud Wt 12.3 ppg in and out. Pump Dry Job & blow down TDS and surface lines. 18:00 - 00:00 6.00 DRILL P INT2 POH -From 12517 to 942' 3/3/2008 00:00 - 03:00 3.00 DRILL P INT2 PJSM -Monitor Well & LD 23 HWDP and BHA #23 03:00 - 03:30 0.50 DRILL P INT2 Clean & Clear Rig floor of vendors tools 03:30 - 04:30 1.00 CASE P INT2 RU 7" Torque Turn casing tools 04:30 - 10:30 6.00 CASE P INT2 PJSM -Run 7" L-80 #29 H dril 521 Drillin Liner, Baker-Lok first 3 joints up to the landing collar. Check Floats, Floats held. Torque Turn Connections to 9550 ft / Ibs using Jet tube seal guard thread compound. Fill every joint on the fly and top off every 5 jts ran. Running speed 1 min joint. Ran total of 41 Joints 7" liner Ran total of 7, 7-1/8" x 8-1/4" x 8" centralizers free floating between stop rings 10' from box and pin end of casing joints Centralizer Placement Joints #1 - 5 Joints #40 & 41 10:30 - 11:00 0.50 CASE P INT2 Change out handling tools, PU & MU Baker 7" x 9-5/8" HRD ZXP LT packer w/ Flex-Lock DG Rt Liner Hanger RIH with liner on 1 Std 5" DP to 1776'. Hook Load Wt 86K 11:00 - 12:00 1.00 CASE P INT2 Circulate 1.5 Liner volume C~ 255 gpm / 245 psi. RD Casing tools & blow down fill up line. 12:00 - 23:30 11.50 CASE P INT2 Cont' RUN 7" Liner on 5" DP from 1779' to 12480' Running speed 2 min per stand, MU TDS, fill pipe and break circulation every 10 stands 23:30 - 00:00 0.50 CASE P INT2 Stage pumps up to 5.5 bpm / 232 gpm / 625 psi &CBU 3/4/2008 00:00 - 01:30 1.50 CASE P INT2 CBU 5.5 bpm / 232 gpm / 625 psi Establish parameters, UP WT 275k / DN WT 200k / RT WT 235k / 40 RPM / TO 15k Pumps: 10 SPM= 102 psi / 20 SPM= 199 psi / 30 SPM= 240 psi / 40 SPM= 320 psi / 50 SPM= 410 psi / 60 SPM= 482 psi / 65 SPM= 519 01:30 - 03:00 1.50 CASE P INT2 Cont' RUN 7" Liner on 5" DP from 12480' encountered ti ht hol 03:00 - 05:00 2 00 CASE P INT2 Work ti ht hole from 1332 t 1 . staging pumps up to 50 SPM 440 PSI. 05:00 - 08:00 3.00 CASE P INT2 Establish parameters, Up Wt 310k / Dn Wt 205k / Rt Wt 240k / TO 16k and start reaming liner down from 13340' to 13350' 08:00 - 12:00 4.00 CASE P INT2 PU to 13416' and Increase mud weight to 12.8 ppg, Rotating at 30 rpm's / TO 14K / 52 spm / 186 gpm / 260 psi /Mud Wt in and out 12.8 ppg 12:00 - 17:00 5.00 CASE P INT2 Ream from 13416' to 13855' w 52 spm / 185 gpm / 508 psi / 30 rpm / TO 15 - 20k 17:00 - 19:00 2.00 CASE P INT2 Work pipe and regain circulation, stage pumps up to 45 spm / rnniea: viuiw~a r. i o:ao nvi BP EXPLORATION Page 32 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date 'From - To Hours Task. I Code ~ NPT Phase Description of Operations - -- 3/4/2008 17:00 - 19:00 2.00 CASE P INT2 160 gpm / 510 psi. 19:00 - 21:00 2.00 CASE N STUC INT2 Work stuck i Pull 450k working up to 520k, S/O to 50k. 21:00 - 00:00 3.00 CASE N STUC INT2 13/5/2008 00:00 - 00:30 0.50 CASE N STUC INT2 00:30 - 02:30 2.00 CASE N STUC INT2 02:30 - 12:00. 9.50 CASE N STUC INT2 12:00 - 22:00 10.00 CASE N STUC INT2 22:00 - 23:00 1.00 CASE N STUC INT2 23:00 - 00:00 1.00 CASE N STUC INT2 3/6/2008 00:00 - 03:00 3.00 CASE N STUC INT2 03:00 - 05:30 2.50 CASE N STUC INT2 05:30 - 07:00 1.50 CASE N STUC INT2 07:00 - 07:30 0.501 CASE N STUC INT2 07:30 - 08:30 1.00 EVAL N STUC INT2 08:30 - 12:00 3.50 EVAL N STUC INT2 12:00 - 14:30 2.50 EVAL N STUC INT2 14:30 - 20:00 5.50 CASE N STUC INT2 Torque & Slump working 30k torque into drill string /pull 400k / slump to 50k. Stage pump rate up to 80 spm / 284 gpm / 853 psi, pump 65 bbl 10% LO-TORQ tube pill. Spot 15 bbl tube pill outside liner & pump 5 bbls every 30 minutes -continue working stuck pipe pulling 520k, S/O to 75k. Pull 520k and chain down brake. Torque & Slump working 28k torque into drill string /pull 350k / slump to 75k. Work stuck pipe -pump 5 bbls every 30 minutes - Pu11520k, to 75 c. Torque & Slump working 28k torque into drill string /pull 350k / slump to 75k. Pull 520k and chain down brake. Break circulation X01:00 Hrs and stage pump rate up to 80 spm / 284 gpm / 1012 psi Rp,c~~m~a ~~~nrkin~ ct~ir~r;, Pull 520k, S/O to 60k. Torque & Slump working 28k torque into drill string /pull up to 400k-500k /slump to 75-50k. 80 spm / 284 gpm / 1005 psi Work stuck pipe- Pull 520k, S/O to 50k. Torque & Slump working 28-30k torque into drill string /pull up to 350k-500k /slump to 75-50k. / 80 spm / 284 gpm / 1005 psi PJSM -pump 75 bbl 12.8 ppg SFT and spot 51 bbls outside 7" liner from 13850' to 9-5/8" shoe ~ 12574'. 80 spm / 284 gpm / 1015 psi Blow down TDS & mud line. Work 34k Torque into drill string and slump down to 60k, chain down brake and allow pill to soak Hold 34k Torque into drill string and slump down to 60k, chain down brake and allow pill to soak. Repeated Torque and Slump process ~ 02:00 Hrs. PU to neutral Wt. & release Torque, Work pipe to 300k up & 50k Down, Pump 5 bbls SFT out of liner ~ 20 spm / 68 gpm / 267 psi /Blow down top drive. Repeat Torque and Slump process Hold 34k Torque into drill string and slump down to 55k & Chain down brake. PU to neutral Wt & Release Torque, Work pipe to 520k up / 50k Down, Repeat Torque and Slump process Hold 34k Torque into drill string and slump down to 50k & Chain down brake. PU to neutral Wt. & release Torque, Work pipe to 530k up & 50k Down, Pump 5 bbls SFT out of liner ~ 20 spm / 68 gpm / 267 psi /Blow down top drive. PJSM - RU Schlumberger E-Line to free point. RIH with free point tool to 10,000', Set tool and Pull 325k & check tool reading, good pipe free, Cont' RIH to 12,150' Set tool and pull 325k. Top half of liner running tool free. I inar stuck at sli area of liner han r. POH with free point tools and RD Schlumberger E-Line Circulate SFT out of hole ~ 275 gpm 960 psi. Weight up 228 bbls 12.3 ppg mud to 12.8 ppg to return L -Pits to active rnrneu: yic iicwo ~.io.oo rrv~ • BP EXPLORATION Page 33 of 47 Operations .Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To ~ Hours Task ~ Code ~, NPT Phase ~ Description of Operations _ _Y_ _ - i 3/6/2008 14:30 - 20:00 5.50 CASE N STUC INT2 _ system for up coming cement job Consult with Anchorage rig team on plan forward to release and cement 7" liner. 20:00 - 20:30 0.50 CEMT N STUC INT2 PJSM -Rotate 11.5 rounds 11.5k Torque of left hand turn into drill string down to top of the liner PU 200k / SO 100k. Release torque 8 rounds back and PU to 260k, Running tool_free from liner. PU 1' verify free, 255k free up WT. SO to 190k and rotate 5 turns ~ 7k TO to the right to align torque fingers, SO t~^80k & set sli s. LD 1 single DP, Blow down TDS & mud line. 20:30 - 21:30 1.00 CEMT N STUC INT2 MU cementing head & circulating lines. Break circulation and stage pumps up to 214 gpm / 810 psi. 21:30 - 22:00 0.50 CEMT N STUC INT2 PJSM with all personnel on cement job, prime and batch mix mud push. 22:00 - 00:00 2.00 CEMT N STUC INT2 Switch over to Dowell and pump 5 bbl seawater to flow line through wash up tee. Test cement lines to 4500 psi. good test. Open tee to flow line and flush out with Mud Push. Line up on Drill Pipe and pump 10 bbls 14 ppg Mud Push II ~ 4 bpm. Pump 28.5 bbl 15.8 ppg Class G Cement. Kick out wiper dart with 5 bbls seawater and switch over to rig pumps. Displace cement with 12.8 ppg mud ~ 5.5 bpm, slowed to 3 bpm & latch up wiper plug 2340 stks, Increase rate to 5.5 bpm, slow pumps to 3 bpm ~ 2900 stks and bump plug @ 3021 stks. CIP ~ 23:30 Hrs. Increase pressure to 4200 psi. ~n surfara inriiration of liner settin . Bleed off pressure and check floats. Floats held. PU 10' to expose rotating dog sub. SO rotating 20 rpm's & set down 75k X2. Repeat third time with 120k set down. No surface indication of acker settin . pp y 000 psi and PU to release seals from RS nipple. At pressure drop ramp pumps up to 200 spm / 711 gpm / 3100 psi &CBU 3/7/2008 00:00 -01:00 1.00 CEMT N STUC INT2 CBU 200 spm / 711 gpm / 3100 psi. Circulated total 946 bbls. No shale back to s rf 01:00 - 02:00 1.00 CEMT N STUC INT2 RD Cement head and lines and manifold, LD 2 singles DP 02:00 - 03:00 1.00 CEMT N STUC INT2 MU TDS and CBU while reciprocating pipe 203 spm / 721 gpm / 3095 psi. Circulated total 1,116 bbls. Fines cleaned up. No shale to surface. 03:00 - 05:00 2.00 CEMT N STUC INT2 PJSM -Cut & Slip 105' drilling line, adjust brakes. Service TDS, Blocks, Crown & Draw works. 05:00 - 05:30 0.50 CEMT N STUC INT2 Pump dry job, blow down TDS & mud line 05:30 - 12:00 6.50 CEMT N STUC INT2 POH from 12,124' with 7" liner running tool. 12:00 - 13:00 1.00 CEMT N STUC INT2 Make service breaks and LD liner running tool, Clean & Clear rig floor of vendors tools. Service break on running tool belled from working torque down hole. 13:00 - 14:00 1.00 CASE N STUC INT2 PJSM - RU and test 7" liner la to 1500 s' for 10 min. Test held. RD & blow down test a ui me t. 14:00 - 18:30 4.50 CASE N STUC INT2 MU Clean out BHA #6) Consisting of 6" MX-18DX / NB STAB / XO/14x4"HWDP/Jar/54x4"DP/XO rnniea: vic vcuuo is i o.ou r~~~ a • BP EXPLORATION Page 34 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours .Task Code NPT Phase Description of Operations 3/7/2008 18:30 - 20:00 1.50 CASE N STUC INT2 RIH with 1 Stand 5" DP and Circulate 453 gpm / 1212 psi / Up & Dn wt 85k. Calibrate flow paddle. 20:00 - 00:00 4.00 CASE N STUC INT2 RIH from 2167' to 9341' fill DP every 3000' 3/8/2008 00:00 - 02:30 2.50 CASE N STUC INT2 RIH from 9341' to 12,116' fill DP & obtain parameters 02:30 - 03:00 0.50 CASE N STUC INT2 03:00 - 04:30 1.50 DRILL N STUC INT2 04:30 - 07:00 2.50 DRILL N STUC INT2 07:00 - 07:30 0.50 DRILL N STUC INT2 07:30 - 08:30 1.00 DRILL N STUC INT2 08:30 - 10:00 1.50 DRILL N STUC INT2 10:00 - 16:30 6.501 DRILL N STUC INT2 16:30 - 21:30 5.00 ~ DRILL ~ N ~ STUC ~ INT2 21:30 - 22:00 0.50 DRILL N STUC INT2 22:00 - 23:00 1.00 DRILL N STUC INT2 23:00 - 23:30 0.50 DRILL N STUC INT2 23:30 - 00:00 0.50 DRILL N STUC INT2 3/9/2008 00:00 - 03:30 3.50 DRILL N STUC INT2 UP WT 250k / DN WT 190k / RT WT 205k / TO 15k / 603 GPM / 3670 PSI Cont' RIH into 7" liner from 12,116' to 13,550' MU TDS Brake circulation and obtain parameters, Wash & Ream DN from 13,550'tag Cement 13,720' Drill Cement & Float equipment from 13 720' to Landing Collar. ~ 13,762' UP WT 280k / DN WT 205k / RT WT 226k 80 RPM / TO 15k / WOB 10-15k 411 GPM / 2400 PSI Drill Landing Collar from 13762' to 13765' UP WT 280k / DN WT 205k / RT WT 226k 80 - 102 RPM / TO Off Bttm.15k / TO On 19k / WOB 10-20k 411 GPM / 2375 PSI Wash from landing Collar to Float Collar @ 13804', No Cement. Drill Float Collar from 13804' to 13806' . Obtain parameters, Wash down to Reamer Shoe C~ 13847' Drill out of Shoe ~ 13850' UP WT 280k / DN WT 210k / RT WT 230k 80 RPM / TO Off Bttm.19k / TQ On 21 k / WOB 10-20k 411 GPM / 2350 PSI No Cement found below Landing Collar or Reamer Shoe. Wash & Ream from 13850' to 14093' UP WT 250k / DN WT 190k / RT WT 230k 112 RPM/T022k/WOBO- 10k 411 GPM / 2350 PSI CBU x 4 RT WT 230k / 112 RPM / TO 22k / 411 GPM / 2175 PSI No shale seen at shakers while cleaning out 9-1/2" Rat Hole Substantial amount of shale seen on bottoms up after cleaning out 8-1/2" Rat hole. AFTER 2 x bottoms up, held up on ledge ~ 14083' worked back down to 14093' Well cleaned up after 4x bottoms up. POH on elevators from 14093' to 13742' UP WT 295k / DN WT 210k No problems on trip out to 7" liner. Service Top Drive, Blocks, Crown, Draw works & Iron Roughneck. RIH to14028' MU TDS, Stage pumps up to 200 GPM / 740 PSI. Wash down to 14043' took 10k Wt. Start rotating @ 80 RPM's / TO 19k and ream to bottom 14093' with no problems, no fill on bottom. Stage pumps up to 400 GPM / 2150 PSI / 115 RPM's / TO 19-22k / RT WT 230k CBU x 2 400 GPM / 2150 PSI / 115 RPM's / TO 19-22k / RT WT 230k rnmea: ainizuun is i~:aa rm • • BP EXPLORATION Page 35 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From- To Hours Task Code NPT Phase Description of Operations 3/9/2008 00:00 - 03:30 3.50 DRILL N STUC INT2 No shale seen on bottoms up. Well cleaned up after 1.5 x 03:30 - 05:30 I 2.001 DRILL I N I STUC I INT2 05:30 - 07:00 1.50 DRILL N STUC INT2 07:00 - 11:00 4.00 DRILL N STUC INT2 11:00 - 12:00 1.00 DRILL N STUC INT2 12:00 - 13:00 1.00 DRILL N STUC INT2 13:00 - 14:00 1.00 CASE N STUC INT2 14:00 - 15:30 1.50 CASE N STUC INT2 15:30 - 16:30 I 1.001 CASE I N I STUC I INT2 16:00 - 00:00 8.00 CASE N STUC INT2 3/10/2008 00:00 - 05:00 5.00 CASE N STUC INT2 05:00 - 05:30 0.50 CASE N STUC INT2 05:30 - 07:30 2.00 CASE N STUC INT2 07:30 - 08:30 1.00 CASE P INT2 08:30 - 09:00 0.50 CEMT P INT2 09:00 - 10:00 1.00 CEMT P INT2 10:00 - 12:30 ~ 2.50 ~ CEMT ~ P ~ ~ INT2 bottoms up. Mud Wt 12.8 ppg in and out. NOTE: 1 Hour Time Change Daylights Savings Time POH on elevators to 7" Shoe, 13,837' Blow Down TDS & No Problems. Cont' POH to 12,211' MU TDS & wash out top of the 7" liner ~ 12,177' & continue to CBU working pipe form 12,150' to 12,116' / 400 GPM / 1677 PSI / 120 RPM / TO 16k / Monitor Well, Static. Pump Dry Job, Blow down TDS & Mud line. POH from 12,116' To 2166' & Change out handling equipment to 4" Cont' POH from 2166' to 464' LD JARS / 14 JTS 4" HWDP & BHA #6 RU Casing handling tools PJSM -MU 4-1/2" 12 6# L-80 HYDRii Fri, Baker-Lok all connections. MU Shoe Track Check Floats, Held, MU total 9 Jts 369' PU & MU 4.5" x 7" Baker ZXP Liner Top Packer / RS Nipple / Flex-Lock Liner Hanger Mix PA-MIX and apply to Liner Top and allow to set 30 min while RD Casing tools RIH with 4.5" Liner on 4" DP Filling pipe every 10 stands run to 9790', Up WT. 200K, Dn Wt 155K Running Speed @1 MIN PER STD, Record UP & DN WT every 10 STDS Cont' RIH with 4.5" Liner on 4" DP Filling pipe every 10 stands run from 9790' to 13787', 7" Shoe ~ 13850' Circulate 1x Liner DP Volume ~ 253 GPM / 1060 PSI Obtain parameters Up Wt 275k / Dn Wt 202k / Rt Wt 237k / 30 RPM / Tq 11 k RIH from 13787' to 14045' where liner took weight. PU to 14035', Bk circulation and stage pumps up to 210 GPM / 955 PSI and continue to wash to TD ~ 14093' without problems. CBU -reciprocating liner 5' UP WT 295k / DN WT 195k / 217 GPM / 810 PSI Blow down TDS MU cementing manifold and lines Brake Circulation and stage pumps up to 6 BPM / 1000 PSI. Started pumping mud away, reduce pump rate to 3 BPM / 505 PSI, work pipe and stabilize losses. Switch over to Dowell and pump 5 bbl seawater to flow line through wash up tee. Test cement lines to 4500 psi. good test. Open tee to flow line and flush out with Mud Push. Line up on Drill Pipe and pump 20 bbls 14 ppg Mud Push II ~ 2.5 bpm. Pump 33 bbl 15.8 ppg Class G Cement. Printed: 4/21/2008 1:15:33 PM BP EXPLORATION Page 36 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date ', From - To Hours Task ,Code NPT Phase ~ Description of Operations 3/10/2008 10:00 - 12:30 2.50 CEMT P INT2 Wash up cement line through Tee to flow line. Kick out wiper dart with 12.8 ppg mud and displace with Schlumberger C~. 4.5 bpm, slowed to 3 bpm & latch up wiper Bum lu with 230 bbls. CIP ~ 12:05 Hrs.. Increase pressure to 3000 psi. SO to DN WT 195k Increase pressure to 4200 psi ir~dication on weight indicator of hanger setting & release. Bleed off pressure and check floats. Floats held. Purssure up to 1000 psi, PU 4' to expose rotating dog sub. SO rotating 20 rpm's TO 11 k & set down 65k Repeat x 2. Positive surface indication of acker settin . Apply 1000 psi and PU 24' to release & Clear seals from RS nipple. At pressure drop ramp pumps up to 157 spm / 557 gpm / 3207 psi p ~ ~e''~-`'r`~ 12:30 - 13:30 1.00 CEMT P INT2 CBU - reci rocating li r 157 spm / 557 gpm / 3207 psi, Mud Push and 13.5 ppg Cement strung out for 76 bbls after bottoms up. p Wt 260 / n Wt 186k 13:30 - 14:00 0.50 CEMT P INT2 RD & LD cementing head and circulating lines, blow down surface equipment. 14:00 - 15:30 1.50 CEMT P INT2 Clean out L-Pits, Flush surface equipment for Flo-Pro, Move out cement trucks and stage vac-truck for fluid displacement. 15:30 - 18:00 2.50 CEMT P INT2 Displace well over to 9.3 ppg Flo-Pro SF mud system Pump 70 bbl 12.8 ppg High-Vis Spacer followed by 100 bbls Seawater followed by 9.3 ppg Flo-Pro SF, 475 gpm / 2388 psi / Up Wt 263k / Dn Wt 180k 18:00 - 00:00 6.00 CEMT P INT2 Monitor well, pump dry job, Blow down TDS & POH with liner running tool to 4570' 3/11/2008 00:00 - 02:30 2.50 CEMT P INT2 Cont' POH with liner running tool from 4570' to Liner running tool. 02:30 - 03:00 0.50 CEMT P INT2 LD Liner running tool, Dog sub sheared. Clean and Clear rig floor of vendors tools. 03:00 - 04:00 1.00 BOPSU P INT2 Service Rig Draw Works, Top Drive, Iron Roughneck and Crown 04:00 - 06:00 2.00 WHSUR P INT2 Pull wear bushing and RU BOP flushing tool and flush BOP stack, LD flushing tool. 06:00 - 08:00 2.00 BOPSU P INT2 Chan a out to set of ram - 08:00 - 09:00 1.00 BOPSU P INT2 Rig up Test Joint and Rig up BOP Testing Equip. 09:00 - 14:00 5.00 BOPSU P INT2 Test BOPE as per BP / AOGCC Regulations to 250 psi low / 5000 psi High for 5 min each 250 psi / 3500 psi on Annular preventer. Test witnessed Waived by John Crisp (AOGCC State Inspector). Brian Buzby (WSL), Bill Bixby (NAD Toolpusher), Randy Axness /Jeff Quittschreiber (NAD Drillers). Test as follows with 5" Test Joint. #1) Annular 250 psi / 3500 psi. Test as follows with 250 psi / 5000 psi. #2) Top Rams 4.5" x 7" VBR / IBOP /Choke Valves # 9, 12 & 13 #3) Floor Safety Valve /Kill HCR /Choke Valves # 8 & 11 #4) Choke Valves # 4, 7, & 10 #5) Super Choke #6) Choke Valve # 3-5-6 /Manual Kill Nrmted: ainizuue ia5s~rm • • BP EXPLORATION Page 37 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code ICI NPT Phase ' Description of Operations 3/11/2008 09:00 - 14:00 5.00 BOPSU P INT2 #7) Manual Choke Manifold Valve #8) Choke Valve #1, 3 & 5 #9) Choke Valve #2 #10) Choke HCR Valve #11) Manual Choke Valve #12) Bottom 3.5" x 6" VBR /Upper Well Control Valve #13) Lower Well Control Valve #14) Function Draw Down Accumulator Test Test as follows with 7" Test Joint. 250 psi / 4000 psi. #15) Top Rams 4.5" x 7" #16) Blind Shear Rams P/U 2 7/8" Test Jt -Test Upper Pipe Rams 250 psi / 5000 psi. -Test Annular to 250 psi / 5000 psi /12/2008 14:00 - 15:00 15:00 - 18:30 18:30 - 19:30 19:30 - 00:00 00:00 - 00:30 00:30 - 01:00 1.00 3.50 1.00 4.50 0.50 50 0 BOPSU CASE CASE CASE CASE CASE P P P P P P INT2 INT2 INT2 INT2 INT2 INT2 Blow down test equipment and rig down Lay Down 2 7/8" Test Joint Ready Rig Floor to P/U BHA Clean out old mud and cement drip pan under Rig Floor Pick BOT Polish Mill and 9 5/8 Casin scra er assembl , RIH with Polish Mill assembly RIH with Polish Mill assembly Wash and re 'll . 9 5/8" scra er assembl 50 rpm / 7k ft/Ibs Torque 644 gpm / 1830 psi PUW - 255k /SOW - 195k / RtWt - 220k TOL ~ 12,177' 01:00 - 02:30 1.50 CASE P INT2 Pump 40 bbl Steal- tube pill per MI Mud engineer, -send pill to G&I when back to surface. 603 gpm / 1300 psi Monitor well 9.3 ppg In /Out 02:30 - 07:00 4.50 CASE P INT2 POH with Polish Mill assembly to 1857 ' 07:00 - 09:00 2.00 CASE P INT2 Slip and Cut Driling Line 09:00 - 10:30 1.50 CASE P INT2 POH with 4" DP -L/D Scraper and Polish Mill -Clear Floor of XO's, Scraper and Mill 10:30 - 11:30 1.00 CASE P INT2 Pick u Baker ZXP Liner To Tie Back Packer and seal assembl and runnin tool 11:30 - 12:00 0.50 CASE P INT2 Service Crown, TDS and Draw Works 12:00 - 18:00 6.00 CASE P INT2 RIH to 223' - 12,179' Tag with 20k down Tag On Depth 18:00 - 20:00 2.00 CASE P INT2 Set Liner To -Break circulation & obtain parameters -Shut down pumps work seal assembly into liner top and no-go seals out on bottom of tie back extension -pressure up to 500 psi, slowly pull seals from PBR observe pressure loss as seals are pulled free. -Pull seals above tieback. Drop 29/32" setting ball and pump down ~ 4 bpm as ball approach seat, rnncea: arnrmun i:u:~arm ~ ~ BP EXPLORATION Page 38 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date 'I From - To ~i Hours ' Task Code NPT Phase Description. of Operations 3/12/2008 18:00 - 20:00 2.00 CASE P INT2 -slow rate to 2 bpm land ball on seat and pressure up to 530 psi. -Slack off no-go seals out in PBR. -Pressure up to set packer and release setting tool to 3800 psi, Pull up to 270k, Tool not released -Set 20k down (175k SOW), Pressure up to 4000 psi. Pulled up to 290k, tool not released -Set 30k down (165k SOW), Pressure up to 4200 psi. Tool shear, -Pulled up to 260k, tool released -Pull 5' and release dogs and set down with 70K to verify set -Pull up 17' and break circ. 20:00 - 21:00 1.00 CASE P INT2 Place Joint in BOP's to proper depth -close pipe rams -Line up valves Pump C~ 0.7 bpm Test 7" and 4 1/2" liner to 4200 psi for 30 min ~t .c Record test on chart, Good test Bleed off and blow down lines **During testing of the 7" & 4 ?" liner, the pressure sensor that feeds the gauges to drillers console failed. The sensor had previous read to 4200 psi just before the casing test during setting of the liner top packer. But during the liner test it stopped C~ 4000 psi when the rubber in the sensor bottom out. The sensor supplied both gauges on the drillers' console, Epoch and the chart gauge. Before the Driller, Toolpusher and I realized that it had bottomed out we pumped another 10 strokes to a pressure of 4700 psi. We Immediatly bleed off to zero and change sensors then tested again this time all gauges operated. 21:00 - 00:00 3.00 CASE P INT2 Circulate and weight up Flo-Pro from 9.3 to 9.5 ppg -8 bpm (336 gpm) / 1205 psi 3/13/2008 00:00 - 06:30 6.50 CASE P INT2 POH with Liner running tool Monitor well, static 9.5 ppg in /out 06:30 - 07:00 0.50 CASE P INT2 UD Baker Tie-Back running tool 07:00 - 10:30 3.50 DRILL P PROD1 Rig up power tongs and BHA handling equipment Make 3 3/4" Drill out assembl P/U 2 7/8" Pac Pipe R/D BHA Handling equipment 10:30 - 18:30 8.00 DRILL P PROD1 RIH filling pipe every 2000' RIH to 12000' MD 18:30 - 19:00 0.50 DRILL P PROD1 Break Circulation ~ top of 7" liner Estabilish parameters PUW = 240k / 182k SOW / 210k RtWt 120 gpm=920 psi/130 gpm=1040psi/140gpm=1120 psi 150 gpm = 1180 psi / 160 gpm = 1300 psi 20 rpm = 6k fUlbs / 30 rpm = 6k fUlbs 19:00 - 20:00 1.00 DRILL P PROD1 RIH through 7" to above top of 4 1/2" liner ~ 13600 No Issues RIH through top of liner rnntea: uinizws iaos~rnn ~ ~ BP EXPLORATION Page 39 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2008 20:00 - 20:30 0.50 DRILL P PROD1 Break Circulation ~ top of 7" liner Estabilish parameters PUW = 276k / 206k SOW / 241 k RtWt 120 gpm = 890 psi / 130 gpm = 980 psi / 140 gpm = 1120 psi 150 gpm=1210psi/160gpm=1325 psi 20 rpm = 8k fUlbs / 30 rpm = 8k ft/Ibs 20:30 - 21:00 0.50 DRILL P PROD1 RIH through top of 4 1/2" liner, no issues RIH to 13,888, additional 10k drag Pulled up to 13830 and start washing to Landing Collar 21:00 - 22:00 1.00 DRILL P PROD1 Wash down to 14,041', to Landin collar in 4 1/2" liner Intermittent cement stringers from 13888' -14041' no issues washing to bottom 120 gpm = 895 psi no rotation PUW = 276k / 209k SOW 22:00 - 00:00 2.00 DRILL P PROD1 Drill Landing Collar PUW = 286k / 220k SOW / 248k RtWt 120 gpm = 8870 psi / 130 gpm = 930 psi / 140 gpm = 1030 psi 150 gpm=1110psi/160gpm=1295 psi Oscillating ~ 3 revs/ min Unable to drill with with differental pressure, motor stalling immediatly upon tagging bottom Trying different parameters to try and get Landing Collar drilled 3/14/2008 00:00 - 04:00 4.00 DRILL P PROD1 Drill Landing Collar PUW = 286k / 220k SOW / 248k RtWt 150 gpm = 1110 psi / 160 gpm = 1395 psi Oscillating ~ 3 revs/ min Unable to drill with with differental pressure, motor stalling immediatly upon tagging bottom Trying different parameters to try and get Landing Collar drilled Consult with Anchorage Rig Team 04:00 - 15:30 11.50 DRILL P PROD1 Drill Landing Collar PUW = 286k / 220k SOW / 248k RtWt 160 gpm = 1395 psi Start Rotating f~ 20 rpm 7.5k Wlbs off / 8k ft/Ibs on Unable to drill with with differental pressure, motor stalling immediatly upon tagging bottom Try Rotating C~ 30 rpm / 8k off / on with the same results Pump Steel Lube pill X09:00 hrs, Tried pumping water pill Continued to working on LC & Plug until we broke through ~ 15:00 hrs, Through LC ~ 14,046' 15:30 - 17:30 2.00 DRILL P PROD1 Drill Shoe 1 PUW = 286k / 220k SOW / 248k RtWt 160 gpm = 1395 psi off / 1700 psi Rotating ~ 30 rpm / 8k off / on Pump Steel Lube pill ~ FC 17:30 - 19:30 2.00 DRILL P PROD1 Drill New Formation r 1 - PUW = 286k / 220k SOW / 248k RtWt 160 gpm = 1395 psi off / 1700 psi Rotating C~ 30 rpm / 8k off / on 19:30 - 21:00 1.50 DRILL P PROD1 Circ. & Condition for FIT -160 gpm = 1620 psi Printed: 4/21/2008 1:15:33 F'M • • BP EXPLORATION Page 40 of 47 ..Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours I! Task Code NPT Phase .Description of Operations 3/14/2008 19:30 - 21:00 1.50 DRILL P PROD1 -circ up sample for Geologist 21:00 - 21:30 0.50 DRILL P PROD1 Perform FIT to 11.5 EMW -Pull up into casing shoe ,close upper pipe rams and open kill line -Pump @ 0.5 bpm -TVD = 10,937' -Pump 33 strokes (2.9 bbls) @ 1140 psi -Record for 10 min, Initial pressere = 1140, Final Pressure = 1090 21:30 - 23:30 2.00 DRILL P PROD1 Pump out of 4 1/2" liner ~ 130 gpm / 980 psi Pulled ~ 30' /min No Issue pulling above the liner C~ 13,600 and 23:30 - 00:00 0.50 DRILL P PROD1 Drop Ball and open circ sub ~ 160 gp, 1480 psi Circ sub open l~ 2000 psi 3/15/2008 00:00 - 00:30 0.50 DRILL P PROD1 Pump two 7" liner volumes C~? 400 gpm / 1520 psi 00:30 - 04:30 4.00 DRILL P PROD1 Continue pumping out hole C~? 400 gpm / 1470 psi Pulling ~ 30' /min 04:30 - 06:00 1.50 DRILL P PROD1 CBU 1.5x C~3 top of 7" liner 400 GPM = 1300 psi Monitor well for 10 min, static 9.5 ppg in /out 06:00 - 16:30 10.50 DRILL P PROD1 POH to change BHA -POH wet -Set Back 9 stands of 4" and 5 stands of 2 7/8" 16:30 - 17:00 0.50 DRILL P PROD1 UD BHA -UD Break off XO and Circ sub. (Rebuild circ sub) Bit, Reamer and Motor 17:00 - 20:00 3.00 DRILL P PROD1 M/U Drill BHA -PDC, 3 1/8 Motor, XO, MWD / LWD, XO, Circ Sub, XO, 30 jts of 2 7/8 DP, XO, 27 jts of 4" DP, XO 20:00 - 00:00 4.00 DRILL P PROD1 RIH w/ 5" DP -Filling every 2000' -Shallow hole Test, Good Test 100 gpm / 848 psi ~ 2739' and 3/16/2008 00:00 - 04:00 4.00 DRILL P PROD1 RIH to Top of 7" Liner 04:00 - 05:30 1.50 DRILL P PROD1 RIH to Top of 4.5" Liner 05:30 - 06:00 0.50 DRILL P PROD1 Service Top Drive, Crown and Draw Works 06:00 - 07:30 1.50 DRILL P PROD1 Pump 20 bbl Steel Lube Pill and Obtain parameters 140 stks = 1600 psi / 150 gpm = 1710 psi / 160 gpm = 1880 psi PUW = 280k /SOW = 200k 20 rpm = 7.5 ft/Ibs torque Madd Pass log from 14070 - 14113' and 07:30 - 12:00 4.50 DRILL P PROD1 Drill from 1 - (10901 tvd) -160 gpm / 1900 off / 2100 on -28kPUW/21 kSOW Oscillating TDS C~ 3 rpm AST = 3.1 hrs 12:00 - 22:00 10.00 DRILL P PROD1 Drill from 14219 - 14485 (11288 tvd) -160 gpm / 1900 off / 2100 on -288k PUW / 213k SOW Oscillating TDS C~3 3 rpm 22:00 - 22:30 0.50 DRILL P PROD1 Pump up survey and CBU 2x liner volumes Nnnted: aizuzuua i:~os~ rm BP EXPLORATION Page 41 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date ~ From - To Hours ~ Task Code NPT ~ Phase Description of Operations 3/16/2008 22:00 - 22:30 0.50 DRILL P PROD1 -160 gpm - 2000 psi -288k PUW / 213k SOW 22:30 - 23:30 1.00 DRILL P PROD1 Pump out to top of 4 1/2" Liner -No issues pulling in open hole -160 gpm / 2000 psi RIH with out pumping, No issues RIH 23:30 - 00:00 0.50 DRILL P PROD1 _ Drill from 14485 - 14505 TD (11306 tvd) ~ -160 gpm / 1900 off / 2100 on -288k PUW / 213k SOW Oscillating TDS ~ 3 rpm AST = 9.23 hrs 3/17/2008 00:00 - 01:30 1.50 DRILL P PROD1 Pump 30 bbl Hi-Vis sweep out the bit and up above 7" Liner -160 gpm / 2000 psi 01:30 - 02:30 1.00 DRILL P PROD1 Pump out of open hole and 4 1/2" liner -No Issues pulling through open hole -160 gpm / 2000 psi -30 '/min pulling speed 02:30 - 04:00 1.50 DRILL P PROD1 Drop Ball and shear circ sub -Pump 2x 7" liner volume C~ 400 gpm / 1580 psi 04:00 - 07:00 3.00 DRILL P PROD1 Pump out of 7" liner -400 gpm / 1580 psi -30 '/min pulling speed 07:00 - 08:00 1.00 DRILL P PROD1 Circ 1.5x bottoms up -550 gpm / 2450 psi -Cutting increased in volume & size than cleaned up -No cuttings coming across shakers by the end of 1.5x BU -Monitor well, Static -9.5 ppg in/out 08:00 - 16:00 8.00 DRILL P PROD1 POH with 5" DP and 4" DP 16:00 - 17:00 1.00 DRILL P PROD1 UD 17:00 - 18:00 1.00 DRILL P PROD1 Island Muster Drill- All personnel on rig reported, all camp personnel mustered as directed 18:00 - 19:30 1.50 DRILL P PROD1 Resume Laying down 2 7/8" DP 19:30 - 20:30 1.00 DRILL P PROD1 UD BHA -Break XO and Circ Sub, UD Mwd/Lwd, UD Motor & Bit 20:30 - 21:00 0.50 DRILL P PROD1 Clear floor of Drilling Tools and Handling Equipment 21:00 - 22:30 1.50 CASE P PROD1 Ri up to run 2 7/8" Production Liner -Rig up Double stack and Compensator -Change out elevators and slips -Conduct PJSM with all personnel 22:30 - 00:00 1.50 CASE P PROD1 Run 2.7/8 Vam Top 13CR80 LINER -Torqued Turn Liner -Makeup torque 1850 ft/Ibs, -Dope Threads with Jet Lube Seal Guard. -Fill pipe every 10 Bakerlok shoe track. No centralizers will be ran. Bakerlok Baker Float shoe, first joint of liner, Float Collar, Joints 2 & 3, and Landing Collar Filled every 10 joints 3/18/2008 00:00 - 01:30 1.50 CASE P PROD1 Run remaining 19 joints of liner. Total of 31 Jts of Vam Top Ran Nnntea: ainizuue iax~~ rnn BP EXPLORATION Page 42 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date ', From - To 'Hours Task ~ Code NPT Phase Description of Operations 3/18/2008 00:00 - 01:30 1.50 CASE P PROD1 -Torqued Turn Liner -Makeup torque 1850 ft/Ibs, -Dope Threads with Jet Lube Seal Guard. -Fill pipe every 10 Jts 01:30 - 03:30 2.00 CASE P PROD1 Make up Baker ZXP Liner top packer and XO's as per Baker rep. -Mix Gel and set for 30 min. -R/D Power tongs and liner running equipment 03:30 - 16:30 13.00 CASE P PROD1 RIH ~ 60 - 90'/min to 14080' (4 1/2" shoe) -Break circ. every 10 stds 16:30 - 18:00 1.50 CASE P PROD1 Circ. Drill string volume - 114 gpm / 655 psi - 128 gpm 920 psi 285k PUW / 210k SOW 18:00 - 18:30 0.50 CASE P PROD1 RIH f/14080 - 14505 -Hit small bridge C~? 14113' Right out 4 1/2" shoe -Wash from 14113 - 14,144' md, no issues washing down f~ 15 spm -Continue to RIH to 14413, Intermittent 5 - 8k drag -Precautionary wash last stand, Tag up on bottom ~ 14,505' and 18:30 - 20:00 1.50 CEMT P PROD1 Break circulation staging up to 3.8 bpm (160 gpm) 1122 psi -Circ 2 x annular volumes, from TD to 12157' and (TOP of 7" Liner) -Reciprocating pipe 8' 20:00 - 21:30 1.50 CEMT P PROD1 PJSM on rigging up Cement Head -Rig up Cement and hook up bleeder line and cement line -Circ. C~? 3.8 bpm / 950 psi Conduct PJSM with Dowell Cementer, G & I, NAD Rig Crew, MI Mud engineer, NAD Tour Pusher, BP WSL and Drilling Supt. After PJSM Dowell Schlumberger started batch mixing Cement and Mud Push -Start hatching cement ~ 20:58 21:30 - 23:30 2.00 CEMT P PROD1 Switched over to Dowell and flush lines with water through Tee, test lines to 4,500 psi, Pump 10 bbls Chemical wash, followed by 20 bbls Mud Push II weighted to 12 ppg followed by 17 bbls of class G cement weighted to 15.8 ppg pump job ~ 4 bpm. Washed up lines through Tee. Release Wiper plug. Confirmed that plug left the head. Displace cement with Dowell C~3 4 bpm. The first 50 bbls of displacement will be perf pill from G&I then switch to 9.5 ppg Flow-Pro maintained these rates until plug bump. Bump plug with 4200 psi to set liner hancte_r. Bleed pressure to zero and check floats CIP ~ 23:32 hrs 23:30 - 00:00 0.50 CEMT P PROD1 P/U and expose rotating dog sub, Set down 25k, Pick up and and set 50k down while rotating 15 rpm. Apply 1000 psi. Pickup on stringl4' until pressure loss will be observed when pack off is pulled out of RS nipple. Circulate at maximum rate reciprocate pipe when circulating. to clear cement from annulus. -380 gpm / 1250 psi Printetl: 4/"Ll/20UN 1:1 D:33 YM ~ ~ BP EXPLORATION Page 43 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours ~, Task Code NPfi -Phase Description of Operations 3/19/2008 00:00 - 01:30 1.50 CEMT P PROD1 continue circ. out cement ~ 380 gpm / 1250 psi -Cement strung out over 1100 stroke o iscernable cement back to surfaced due th channelin 01:30 - 02:30 1.00 CEMT P PROD1 Rig Down Cement Head and UD 2 joints of pipe 02:30 - 03:30 1.00 CEMT P PROD1 R/U and Test Packer to 500 psi for 5 min., good test -Test packer to 3000 si for 10 min ood test - recorded test on chart 03:30 - 04:30 1.00 CEMT P PROD1 Flush surface lines and prepare pits to displace to seawater - Cut and slip drilling line - G & I making room for displacement and crew finishing the pit preparation 04:30 - 12:00 7.50 CEMT P PROD1 Displace to 8.6 ppg Seawater - Pumped 50 bbl Caustic Wash, - 50 bbl Soap Pill - 100 bbl High Visc Pill. - Mud displaced w/seawater until a Turbidity of <80 ntu was seen with two consecutive tests - The cleaning pills were followed by Seawater to displace all the mud out of the hole mONITOR WELL FOR 30 MINUTES 8.6 PPG in /out 12:00 - 21:00 9.00 CASE P PROD1 POH standing back Drill pipe from 13,400 - 5908' -UD excess 5" Drill pipe -UD 4" Drill pipe 21:00 - 22:00 1.00 CASE P PROD1 UD Liner running tools annd clear floor of pipe handling equipment 22:00 - 23:30 1.50 BOPSU P PROD1 Pull Wear Bushing and Service -Function test BOP Rams -Flush stack with jetting tool 23:30 - 00:00 0.50 CEMT P PROD1 Clear Floor and prepare to Test casing 3/20/2008 00:00 - 01:00 1.00 CASE P PROD1 Test casing/ Liner Lap to 3820 si for 30 min -recor on chart -Good Test Test witness by BP WSL Dave Newlon and NAD TP Brian Tiedemann 01:00 - 01:30 0.50 BUNCO RUNCMP Pre-Job Safety meeting on rigging up Slick line unit with NAD Rig Crew and SWS 01:30 - 09:00 7.50 BUNCO RUNCMP Rig up and Run 6" Gauge Ring, Junk Basket -Unable to get into top of 7" liner top -Tool was covered in pipe dope dope and steel tube 09:00 - 14:30 5.50 BUNCO RUNCMP Reconfigure tools and try again -added weight bars, roller stem and slide jars -RIH w 6.00" GR/JB and 5.935" centralizer without success - Unable to get into 7" Liner Top 14:30 - 21:30 7.00 BUNCO RUNCMP Drop 6" GR/JB and added 3.85" centralizers with Sample Bailer below the 5.93" centralizer with the tool string remaining the same above, RIH on .125 slickline -RIH without problems -No Sample or residue in baler Rig Down Slick line unit and UD Tools 21:30 - 22:30 1.00 BOPSU P RUNCMP Pull Wear Bushing and Make Dummy Drift run with Tubing Hanger PfIfltBtl: 4/'Ll/'LUUti 1:1 ~::i:7 YM ~ ~ BP EXPLORATION Page 44 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase ', Description of Operations 3/20/2008 21:30 - 22:30 1.00 BOPSU P RUNCMP -RT to Tubing Hanger = 40.20' 22:30 - 00:00 1.50 BUNCO RUNCMP PJSM on Rigging up Completion tools -R/U Completion Handling Equipment 3/21/2008 00:00 - 03:00 3.00 BUNCO RUNCMP PJSM on Rigging up Completion tools -R/U Completion Handling Equipment -Ready Floor to run Cidra Gauge Wire 03:00 - 05:00 2.00 BUNCO RUNCMP Run 4 1/2" 13CR Chrome Com letion Vam To -Grade - 13Cr80 / Wei ht /ft - 12.6# -Baker-lock all connections below Packer -Tubing cleaned and doped on location by Vam technician. Jet Lube Seal Guard pipe dope on all connections -Used stabbing guide, torque turn to 4400 ft/Ibs Run the completion assembly as per Driller's Running Tally. 4.5" Self Aligning Mule Shoe Guide - HES 10' Pup Joint XN Nipple (RHC Seat Installed) No-Go ID 3.813" x 3.725" 10' Pup Joint X Nipple (3.813") 10' Pup Joint 10' Pup Joint 7" x 4 1/2" BOT 13Cr Premier Packer 10' Pup Joint 10' Pup Joint X Nipple. (RHC Seat Installed) (3.813") 10' Pup Joint 10' Pup Joint surface with Cannon clamps 1/jt. 10' Pup Joint 05:00 - 07:30 2.50 BUNCO RUNCMP Attach Weatherford fiber optic cable to gauge, makeup tested to 7500psi for 15 minutes, low test to 500 psi for 5 minutes, fiber optic gauge to mandrel assembly makeup tested to 7500 psi for 15 minutes, 500 psi for 5 minutes -Good Test 07:30 - 11:00 3.50 BUNCO RUNCMP Run 4 1/2" 13CR Chrome Completion Vam Top -Grade -13Cr80 /Weight /ft - 12.6# -Tubing cleaned and doped on location by Vam technician. Jet Lube Seal Guard pipe dope on all connections -Used stabbing guide, torque turn to 4400 ft/Ibs -Cannon control line clamp will secure the fiber optic line across each collar -Weatherford/CiDRA representatives running/testing the fiber optic line. 11:00 - 12:00 1.00 BUNCO SFAL RUNCMP Hydraulic line hose powering the tubing tongs from rigs hydraulic pump separated from fitting -Notified ACS Environmental Joe Serra and clean up the hydraulic fluid. -All fluid contained on the rig floor. -All fluid soaked up and bag in oily waste bags and sealed. -Apx 8 gals spilled Repaired line and inspect lines on system. rnnteo: ainizuua i:ro:~a rm ~ ~ BP EXPLORATION Page 45 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours ~ Task Code NPT Phase Description of Operations 3/21/2008 12:00 - 00:00 12.00 BUNCO RUNCMP Run 4 1/2" 13CR Chrome Completion Vam Top -Grade - 13Cr80 /Weight /ft - 12.6# -Tubing cleaned and doped on location by Vam technician. Jet Lube Seal Guard pipe dope on all connections -Used stabbing guide, torque turn to 4400 fUlbs -Cannon control line clamp will secure the fiber optic line across each collar -Weatherford/CiDRA representatives running/testing the fiber optic line. 160 joints ran ~ midnight 3/22/2008 00:00 - 13:30 13.50 BUNCO RUNCMP Run 4 1/2" 13CR Chrome Completion Vam Top -Grade - 13Cr80 /Weight /ft - 12.6# -Tubing cleaned and doped on location by Vam technician. Jet Lube Seal Guard pipe dope on all connections -Used stabbing guide, torque turn to 4400 ft/Ibs -Cannon control line clamp will secure the fiber optic line across each collar -Weatherford/CiDRA representatives running/testing the fiber optic line. 13:30 - 15:00 1.50 BUNCO RUNCMP Rig control line Sheave and Spooling unit -Mak - -Test to 6000 psi for 15 minutes, Good Test 15:00 - 18:30 3.50 BUNCO RUNCMP Ran in to 13,505' Tubing MD and Tag NO-GO Run 4 1/2" 13CR Chrome Completion Vam Top -Grade - 13Cr80 /Weight /ft - 12.6# -Tubing cleaned and doped on location by Vam technician. Jet Lube Seal Guard pipe dope on all connections -Used stabbing guide, torque turn to 4400 ft/Ibs -Cannon control line clamp will secure the fiber optic line and SSSV Control line across each collar -Weatherford/CiDRA representatives running/testing the fiber optic line. -HES Representive running control line spooler maintaining 5000 psi on SSSV -Used Minimumal make up torque on space out joints 315 - 319, -Tag 13.7 'feet in on Joint #319 13,505' Tubing MD 18:30 - 19:00 0.50 BUNCO RUNCMP POH Laying down space out joints -UD 3 joints 19:00 - 00:00 5.00 BUNCO DPRB RUNCMP While pulling the 181 feet of tubing that we used to tag the No-Go. The Weatherford Cidra Fiber Optic cable cease working after pulling 112 feet, the cable was mar and the protective plastic coating was peeled away under the clamp. On the next joint the cable was severely bent and crushed with several twists in the cable. -We contacted the Anchorage ODE and waited for further direction. The Anchoraae ria team directed to proceed and POH to 13,150' and evaluated the condition of the Cable. The cable Continued to increase in the severi of dama e, Stop POH at 13155' after consulting the Anchorage Rig tearr~;t was decided to terminate the Weatherford Cidra Fiber o tic cable and Land the tubin . rnrnea: arzvzuuu i:iossrm ' ~ • BP EXPLORATION Page 46 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 33E Date ~ From - To I' Hours Task Code NPT 3/22/2008 19:00 - 00:00 5.00 3/23/2008 100:00 - 03:30 I 3.50 03:30 - 07:00 3.50 RU 07:00 - 10:00 3.00 RU 10:00 - 12:00 2.00 RUN 12:00 - 14:30 2.50 RUN 14:30 - 17:00 2.50 17:00 - 20:00 3.00 20:00 - 23:00 23:00 - 00:00 3/24/2008 00:00 - 03:30 13 155' and RUNCMP RIH to 13324' MD with 4 1/2" 13CR Chrome Completion Vam Top -Grade - 13Cr80 /Weight /ft - 12.6# -P/U 1 Space out Pup - 3.82' -4 Jts of 5 1/2" VIT tubing -Hanger pup and Hanger 321 -full Cannon clamps, 4 - 5 1/2" clamps for VIT, 1 SS band 2' under hanger RUNCMP Circulate corrosion inhibited Seawater (EC1124A 25 gals/100 bbls + 01 VD121 25 gal/100 bbls in seawater) to treat from WLEG to the gaslift valve at +/-4560' MD to packer setting depth of +/- 13435 (-432 bbls). Maximum displacement rate 3 BPM around the packer / 135 psi RUNCMP Teminate Control line and Band to tubing with 1 SS Band -Attach to Hanger and Test to 5000 psi for 15 minutes, Good Test -RIH with Hanger and Land Tubing with WLEG ~ 13,497' tubing MD -Run Lock Down Screws -Test Hanger body seals to 5000 psi for 10 minutes, Good Test RUNCMP Drop 1.875" ball with 6' rod -R/U and Test Tubin to 4200 si for 10min G RUNCMP wit chlumberger slickline crew and NAD Rig Crew on rigging up slickline -P/U 4 1/2" Tubing landing joint -R/U slickline -M/U Ball & Rod Retrieving tool -2.125" roller stem, 3.80" centalizer, 2.60" wheels, 1.75" oil jars, 1.75" spanner RUNCMP RIH with slickline to 900', RIH slow, -POH and added weight bar and RIH RUNCMP Retrieve 1.875" Ball & Rod from RHC-M plug in X-nipple at 3.00 BUNCO RUNCMP RIH and retrieve RHC-M lu from X-ni le at 13436' slickline measurement 1.00 BUNCO RUNCMP R/D slickline, sheaves and equipment 3.50 BUNCO RUNCMP Drop 1 7/8" in Ball and Rod and land in XN rofile in the tubin< tail. Need 2" RB pulling tool to retrieve ball and rod, and 4.5" GS or GR to retr RHC-M Plug -Pressure u the tubin to 4200 and hold for 3 mi ecorded on Chart. Good Test -Bleed tubing to 2700 psi; Test the annulus to .4200 psi for 30_ -Bleed annulus to ZERO psi. Bleed tubing pressure is ZERO psi -Pressure up on the backside, DCR valve shear at to 2250 psi. -Pump through the valve at 2 bpm to make sure the valve is locked open. Line up and pump down the tubing ~ 2 bpm. No Spud Date: 6/29/2002 Start: 1 /18/2008 End: 3/25/2008 Rig Release: 3/25/2008 Rig Number: 33E Phase ,I Description of Operations DPRB RUNCMP Cut & Secure cable in a Cannon Clamp with a termination Cap to seal Cable Cable located at the clamp between its 310 and its 311 - YflntOtl: 4/Ll/LUUtl 1:1 t):J3 YM • BP EXPLORATION Page 47 of 47 Operations Summary Report Legal Well Name: NS16 Common Well Name: NS16 Spud Date: 6/29/2002 Event Name: REENTER+COMPLETE Start: 1/18/2008 End: 3/25/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/25/2008 Rig Name: NABOBS 33E Rig Number: 33E Date From - To Hours I Task Code NPT Phase Description of Operations 3/24/2008 00:00 - 03:30 3.50 BUNCO RUNCMP issues pumping through DCR valve. -Bleed off Annulus & tubing. Bleed off control line to 0 psi. Pressure up the backside to 1000 psi to test that the tubing retrievable safety valve, test for 5 minutes, Good Test -Pressure up on the SSSV control line to 5,000 psi 03:30 - 04:30 1.00 BOPSU P RUNCMP Set and test the TWC and test to 1000 psi from below for 5 minutes. Good Test 04:30 - 13:30 9.00 BOPSU P RUNCMP PJSM with NAD rig crew on nippling down stack -Nipple Down BOP's -Notified Island control room before lifting stac kto shut in NS17 -OA bled off from 200 psi to zero on NS16a 13:30 - 15:30 2.00 BOPSU P WHDTRE Secure BOP's on Pedestal 15:30 - 20:00 4.50 BOPSU P WHDTRE Nipple up Production Tree and Adaptor flange -Terminate control line and test to 6000 psi for 10 min., O.K., -Bleed off control line to 4500 psi & Shut in, SSSV Open -Test Metal to Metal seal to 5000 psi for 10 min., Good Test 20:00 - 23:00 3.00 WHSUR P WHDTRE -PJSM with Hot oil and NAD rig crew -Position truck and r/u to test Tree to 5000 psi with LRS -Flange leak on choke valve, tighten and retest -Test to 5000 psi for 10 minutes 23:00 - 00:00 1.00 WHSUR P WHDTRE Rig up lubricator and pull TWC 3/25/2008 00:00 - 09:00 9.00 WHSUR P WHDTRE Reverse circulate 229 bbls heated Diesel for Freeze Protect -Diesel heated to 50 degrees -inhibited diesel (1 % solution of Ondeo Nalco CR-0408) -annulus and tubing capacity to a depth of 3000' ND (-3258 MD), 229 bbl diesel. -Displacement rate at 2 bpm ICP / 750 psi FCP - 1150 psi -U-tube diesel and allow tubing and annulus to equalize 09:00 - 10:00 1.00 WHSUR P WHDTRE Install BPV, test from below to 1000psi, secured well, released rig at 10:00 hrs on 3/25/2008 rnntea: ainrzuuu iabssrm • Well History. Well Date Summary NS-16A 3/19/2008 ***ASSIST NABORS 33 E*** TRAVEL TO NORTH STAR, SAFETY MEETING W/ RIG ***CONTINUED ON WSR 03/20/08*** NS-16A 3/19/2008 ***ASSIST NABORS 33 E*** (rig job) TRAVEL TO NORTH STAR, SAFETY MEETING W/ RIG ***CONTINUED ON WSR 03/20/08*** NS-16A 3/20/2008 ***CONTINUED FROM WSR 03/19/08*** RAN JUNK CATCHER W/ 6" GAUGE RING TO 12,135' SLM (RETURNS OF PIPE DOPE) RAN JUNK CATCHER W/ ROLLER STEM AND 5.93" CENT, 6" GAUGE RING W/ DIFF TOOL STRING TO 12,175' SLM (RETURNS OF PIPE DOPE) RAN 5.93" CENT W/ S-BAILER GOT THRU LINER, NO-GO ON 2 7/8" LINER TOP @ 13,506' SLM (NO RETURNS) ***WELL TURNED OVER TO RIG*** NS-16A 3/20/2008 ***CONTINUED FROM WSR 03/19/08*** (rig job) RAN JUNK CATCHER W/ 6.0"" GAUGE RING TO 12,135' SLM. UNABLE TO PASS 7" LINER TOP (RETURNS OF PIPE DOPE) RAN ROLLER STEM, 5.93" CENT, AND JUNK CATCHER W/ 6.0" GAUGE RING TO 12,175' SLM. UNABLE TO PASS 7" LINER TOP (RETURNS OF PIPE DOPE) RAN 5.93" CENT W/ S-BAILER GOT THRU LINER, SAT DOWN ON 2 7/8" LINER TOP @ 13,506' SLM (NO RETURNS) ***TURN OVER WELL TO RIG*** NS-16A 3/22/2008 ***ASSIST NABORS 33E*** (rig job) STAND-BY FOR RIG ***CONTINUED ON WSR 03/23/08*** NS-16A 3/23/2008 ***CONTINUED FROM WSR 03/22/08*** (rig job) PULLED B&R FROM RHC PLUG BODY @ 13445' SLM PULLED RHC PLUG BODY FROM X-NIPPLE @ 13448' SLM ***WELL RETURNED TO RIG*** NS-16A 3/27/2008 ***WELL Sll ON ARRNAL *** (post sidetrack) ASSIST WffH PULLING BPV PULLED B&R FROM 13450' SLM. PULLED DCR SHEAR VALVE FROM STA#1 AT 4559' MD. SET RK-DGLV IN STA #1 AT 4559' MD *** CONT ON WSR 03/28/08 *** NS-16A 3/27/2008 ***WELL S/I ON ARRNAL*** PULLED B&R FROM 13450' SLM PULLED SHEAR VALVE FROM STA #1 @ 4569' MD SET RK-DGLV IN STA #1 @ 4569' MD ***CONTINUED ON WSR 03/28/08*** NS-16A 3/27/2008 T/V0=0/0/0. PULLED 5 1/8 CMI BPV @ 102" 7X5' EXT USED. NO PROBLEMS. BOPE TEST. TAY LOR/MAY NS-16A 3/27/2008 ***WELL S/I ON ARRNAL*** PULLED B&R FROM 13450' SLM PULLED SHEAR VALVE FROM STA #1 @ 4569' MD SET RK-DGLV IN STA #1 @ 4569' MD ***CONTINUED ON WSR 03/28/08*** NS-16A 3/27/2008 ***WELL S/I ON ARRNAL*** PULLED B&R FROM 13450' SLM PULLED RK-SHEAR VALVE FROM STA #1 @ 4569' MD SET RK-DGLV IN STA #1 @ 4569' MD ***CONTINUED ON WSR 03/28/08*** Print Date: 5/8/2008 Page 1 of 3 ' ! • Well Date Summary NS-16A 3/28/2008 *** CONT FROM WSR 03/27/08 *** (post sidetrack) PULLED RHC PLUG BODY FROM XN NIPPLE AT 13482' MD. RAN 12' OF 2.25" DRNE DOWN BAILER FOR DMY GUN DRIFT. SD AT 14116' SLM. WORKED TOOLS DOWN TO 14137' SLM. STICKY BOTTOM. TARGET DEPTH WAS 14408' MD (-250' OF FILL). RECOVERED FULL BAILER OF CONTAMMNNATED CEMENT. RAN 8' OF 2.25" DRNE DOWN BAILER. SD AT 14097' SLM. RECOVERED 1/2 GALLON SAMPLE OF WHAT APPEARS TO BE CONTAMINATED CEMENT/FLOW PRO/PIPE DOPE. MfTIA WfTH TRIPLIX TO 2500 PSI PASSED. *** WELL LEFT S/I. CONTROL ROOM NOTIFIED *** T/VO = 125/70150, Temp = SI. MfT-IA PASSED to 2500 psi (verify integrity). Pressured IA to 2500 psi w ith 5 bbls of diesel. MR-IA lost 6 psi in the first 15 minutes and 3 psi in the second 15 minutes for a total of 9 psi during 30 min test. Bled IA to 125 psi. Final T/VO = 100/125/88. NS-16A 3/29/2008 ***TRAVEL FROM NORTH STAR TO PRUDHOE BAY*** NS-16A 3/29/2008 ***TRAVEL FROM NORTH STAR TO PRUDHOE BAY*** NS-16A 4/1/2008 CTU #5 FCO/ MIRU "~~~~~~~~~Job in progress"'"""" NS-16A 4/1/2008 CTU #5 FCO/MIRU NS-16A 4/1/2008 CTU#5 (job scope; fill cleanout) InterACT publishing. Rig up, RIH w/ 1 11/16" motor and 2.3" mill. Cont' on WSR 4/02/08 ... NS-16A 4/2/2008 CTU#5 (FCO -Log for Depth Control) cont from 04-01-08. InterACT publishing. Cont RIH wl 1 11/16" motor and 2.3" mill. Tag cmt @ 14353'. Max depth achieved w as 14,397'. Pumped two 10 bbl geovis sweeps off bottom. Got cmt chunks back to open top. painted flag @ 20 off btm for mem log reference. RIH w ith SWS memory GR/CCL inside 2.20" carrier. Tag bottom at 14,402 ctm. Log up at 60 fpm to 13,300'. POOH keeping hole loaded w ith 60/40 meth dow n backside of CT. At surface, recover logging tools and determine quality of data. *** Job continued on WSR 04/03/2008 *'* NS-16A 4/2/2008 CTU#5 (FCO) cont from 04-01-08. InterACT publishing. Cont RIH w/ 1 11/16" motor and 2.3" mill. Tag cmt @ 14353'. Max depth achieved w as 14,397'. Pumped two 10 bbl geovis sweeps off bottom. Got cmt chunks back to open top. painted flag @ 20 off btm for mem log reference. NS-16A 4/2/2008 CTU#5 (FCO) cont from 04-01-08. InterACT publishing. Cont RIH w/ 1 11/16" motor and 2.3" mill. Tag cmt @ 14353'. Max depth achieved w as 14,397'. Pumped two 10 bbl geovis sweeps off bottom. Got cmt chunks back to open top. painted flag @ 20' off btm for mem log reference. RIH w ith SWS memory GR/CCL inside 2.20" carrier. ..... Job in Progress ..... NS-16A 4/3/2008 ***WELL SHUT IN UPON ARRNAL*** RIH WffH SFRT TO OBTAIN FORMATION RESISTNfTY. INfTIAL T/VO = 0/157153. CONTINUE ON 04-APR-2008. NS-16A 4/3/2008 CTU #5. Memory Log for Depth Control. *** Continued from WSR 0-03-2008 **' Recover data from memory tools. Gamma Ray data unable to coorelate due to high GR activity. Coorelate CCL data to liner tally. Data indicated cleanout into 28th joint of 2-7/8" liner. CT tag depth at 14,398' ctmd on bottom. RD CTU and prep w ell for a-line. Final WHP = 0/140/50. *** Job complete *** NS-16A 4/4/2008 ***WELL SHUT IN UPON ARRNAL*** Complete PDC/SFRT logging. Sw ap from 7/16" a-line to 7/32" a-line for RST logging and perforating. Rig dow n island 60 ton crane and rig up SLB crane. RIH WfTH RST TOOL. INfrIAL TIVO = 0/157/53. Run RST log in 2-7/8" liner .Tag TD at 14412' md. Confer w ith tow n geologist. Prepare to perforate w ell. *****CONTINUE ON 05-APR-2008. Job in Progress***** NS-16A 4/5/2008 **CONTINUE FROM 04-APR-2008.** COMPLETED RST LOGGING FROM 14000'-14400', OVERLAYS LOOK GOOD AND DATA SENT TO TOWN FOR REVIEW. RIH WffH 2" HSD 6 SPF 2006PJ GUN TO PERFORATE 14304'-14339' (Ref; SWS - PDC Log 4/03/08). MADE TWO PERF RUNS TO COMPLETE. ~ ALL SHOTS FIRED, TOOK PRESSURE AND TEMP STOPS AT 14133', 14188', 14243', 14284' AND 14304'. ALSO TOOK CORRELATION PRESSURE STOP IN LUBE AT SURFACE TO COMPARE WPPT SENSOR TO TREE DIGfTAL SENSOR. WPPT READ 415 PSI, TREE READ 390 PSI. DSO NOTIFIED WELL READY TO POP. *****JOB COMPLETE*"** NS-16A 4/9/2008 CTU #5. Acid Treatment. MIRU CTU. Perform BOP test -passed (State declined to w fitness). *** Job in progress *** Print Date: 5/8/2008 Page 2 of 3 ' • Well Date Summary NS-16A 4/9/2008 CTU #5. Acid Treatment. MIRU CTU. Perform BOP test -passed (State declined to w fitness). Makeup BHA #1w ith 2.00" JSN. Well flow ing upon arrival. Shut in w ell and attempt to bullhead 10 bbls 60/40 mw th spear, then 2% KCI. At 37 bbls into kill, w ellhead pressure locked up at 3500 psi. Begin flow ing w ell to plant and RIH w ith CT. *** Job continued on WSR 04/10/2008 *** NS-16A 4/9/2008 CTU #5. Acid Treatment. MIRU CTU. *** Job in progress *** NS-16A 4/10/2008 CTU #5. Acid Treatment *** Continued from WSR 04/09/2008 *** RIH w ith 2.00" JSN. Dry tag at 14,404' ctmd. Spot 2 bbls of 12% HCI w ith 10% L66. Initial breakdow n resulted w ith a 2 bpm injectivity at 3090 psi WHP. Load w ell w ith 80 bbls of 2% KCI, then 88 bbls of 1 % XS KCI w /0.6% SafeLube, and 10 bbls 60/40 meth. Injected 20 bbls of 2% KCI and 23 bbls of 12% HCI w ith 10% L66 making 3 passes from 14295' to 14350'. Overdisplaced acid w ith 140 bbls of 2% KCI w /10% L66. When acid contacted formation, no noticable breakdow n w as noted, but injectivity increased by 0.5 bpm w ith same CT pressure. *** Job in progress *** NS-16A 4/10/2008 CTU #5. Acid Treatment *** Continued from WSR 04/09/2008 *** RIH w ith 2.00" JSN. Dry tag at 14,404' ctmd. Spot 2 bbls of 12% HCI w ith 10% L66. Initial breakdow n resulted w ith a 2 bpm injectivity at 3090 psi W HP. Load w ell w ith 80 bbls of 2% KCI, then 88 bbls of 1 % XS KCI w /0.6% SafeLube, and 10 bbls 60/40 meth. Injected 20 bbls of 2% KCI and 23 bbls of 12% HCI w ith 10% L66 making 3 passes from 14295'to 14350'. Overdisplaced acid w ith 140 bbls of 2% KCI w/10% L66. When acid contacted formation, no noticable breakdow n w as noted, but injectivity increased by 0.5 bpm w ith same CT pressure. POOH w hile replacing coil voidage w ith diesel. RD CTU #5. Turn w ell over to N* control to POP. *** Job Complete *** NS-16A 4/27/2008 ***WELL FLOWING ON ARRIVAL*** (pre re-perf) CH2MH RIG UP CONTINGENCY KILL LINE IN PREPERATION FOR S-LINE / E-LINE WORK. ***WELL SHUT IN*** NS-16A 4/28/2008 ***WELL S/I ON ARRVAL*** (pre ad-perf) NS-16A 4/28/2008 ***WELL S/I ON ARRVAL*** (pre re-perf) DRIFT TUBING WrrH 10' x 2.130" DUMMY GUN AND SAMPLE BAILER TO 14382' SLM (TARGET DEPTH 14339' MD). SAMPLE OF GRITTY MATERIAL ***WELL LEFT S/I, CONTROL ROOM NOTIFIED*** NS-16A 4/30/2008 T/IAIOA = 2200 / 0 I 0 PSI PREPARING TO RIG UP E-LINE FOR PERFORATION RUN. *** JOB CON'T TO 01-MAY-08*** NS-16A 5/1/2008 *** JOB CON'T FROM 30-APRIL-08*** RIH WrrH 2" HSD GUNS TO 14382' ,MAX OD = 2". PERF INTERVALS: 14299' - 14319', 14319' - 14339'. ***JOB CON'T TO 2-MAY-08*** NS-16A 5/1/2008 *** JOB CON'T FROM 30-APRIL-08*** NS-16A 5/2/2008 *** JOB CON'T FROM 01-MAY-08*" PERFORATED 14289'-14339' W/ 2" HSD 6SPF 60 DEG PHASED PJ 2006 GUNS. DEPTH CORRECTED TO SLB PDC LOG DATED 4-3-08 USING GRICCL. ALL SHOTS FIRED. DSO NOTIFIED WELL READY TO POP WHEN PLANT IS BACK ON LINE. *****JOB COMPLETE***** Print Date: 5/8/2008 Page 3 of 3 BP EXPLORATION Leak-Off Test Summary Legal Name: NS16 Common Name: NS16 Test Date Test Type Test Depth (TMD) 7/3/2002 FIT 3,494.0 (ft) 7/10/2002 FIT 10,434.0 (ft) 7/3/2002 FIT 3,494.0 (ft) 3/18/2003 FIT 12,125.0 (ft) 2/11/2008 LOT 3,250.0 (ft) 2/23/2008 LOT (ft) 2/28/2008 FIT 12,574.0 (ft) 3/14/2008 FIT 14,093.0 (ft) Page 1 of 1 __ _ __ _ Test Depth (TVD) AMW __ __ Surface Pressure -- Leak Off Pressure (BHP) - -- 3,201.0 (ft) 8.70 (ppg) 660 (psi) 2,107 (psi) 9,293.0 (ft) 12.00 (ppg) 970 (psi) 6,763 (psi) 3,201.0 (ft) 8.70 (ppg) 660 (psi) 2,107 (psi) 10,862.0 (ft) 9.20 (ppg) 1,300 (psi) 6,491 (psi) 2,993.0 (ft) 8.90 (ppg) 545 (psi) 1,929 (psi) (ft) (ppg) (psi) (psi) 9,565.0 (ft) 12.30 (ppg) 1,100 (psi) 7,212 (psi) 10,919.0 (ft) 9.50 (ppg) 1,140 (psi) 6,529 (psi) EMW 12.67 (PP9) 14.01 (ppg) 12.67 (PP9) 11.50 (ppg) 12.41 (ppg) 12.41 (PP9) 14.51 (ppg) 11.51 (ppg) • s Printed: 4/21/2008 1:15:28 PM by y~~~~~ F chl~uberger ~;~-~~~-~ IV~I t~H ~U t'[@fJOfi Report Date: March 17, 2008 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 270.460° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: Northstar PF / NS16 TVD Reference Datum: Rotary Table Well: NS16 TVD Reference Elevation: 55.92 ft relative to MSL Borehole: NS16A Sea Bed /Ground Level Elevation: 15.57 ft relative to MSL UWVAPI#: 500292309601 Magnetic Declination: 23.438° Survey Name I Date: NS16A /February 20, 2008 Total Field Strength: 57679.364 nT Tort /AHD / DDI / ERD ratio: 163.498° / 8349.67 ft / 6.243 / 0.739 Magnetic Dip: 81.048° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: February 20, 2008 Location LaVLong: N 70 29 28.174, W 148 41 35.878 Magnetic Declination Model: BGGM 2007 Location Grid NIE Y/X: N 6030971.560 ftUS, E 659829.810 ftUS North Reference: True North Grid Convergence Angle: +1.23170678° Total Corr Mag North -> True North: +23.438° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de _ _ de ___ __ ft __ ~~ ft ~.. ft .. ... ft .. .... ft .. .. ft n nn ft n An de OOft n nn ftUS nnnnn~A nA ftUS c~nOnn AA AI ~n An n0 ~~G \~/ A AO Ai 7G On/\ Projected-Up 0.00 u.ut 1t5'1.iSy -55.yL V.VV U.4U U.VU U.~V I V.V~ -V.4V V.VV VVJV'/ I .VV VJJULJ.Y 1 IY / V GJ GU. I / J YY 1 YU Y i JJ.V~V First GYD GC SS 49.46 0.94 282.89 -6.46 49.46 0.80 0.41 0.82 0.18 -0.80 1.88 6030971.73 659829.01 N 70 29 28.176 W 148 41 35.901 99.46 1.39 278.89 43.53 99.45 1.80 1.43 1.84 0.37 -1.80 0.91 6030971.89 659828.00 N 70 29 28.178 W 148 41 35.931 149.46 2.24 275.10 93.50 149.42 3.38 3.01 3.42 0.55 -3.37 1.72 6030972.04 659826.43 N 70 29 28.180 W 148 41 35.977 199.46 2.39 275.77 143.46 199.38 5.39 5.03 5.43 0.74 -5.38 0.30 6030972.18 659824.41 N 70 29 28.182 W 148 41 36.036 268.46 2.54 273.98 212.39 268.31 8.35 8.00 8.40 0.99 -8.34 0.24 6030972.37 659821.45 N 70 29 28.184 W 148 41 36.123 360.46 2.49 280.72 304.31 360.23 12.35 12.03 12.43 1.50 -12.34 0.33 6030972.80 659817.45 N 70 29 28.189 W 148 41 36.241 449.46 2.76 280.11 393.21 449.13 16.36 16.10 16.50 2.24 -16.34 0.30 6030973.45 659813.42 N 70 29 28.196 W 148 41 36.359 539.46 3.34 277.39 483.09 539.01 21.10 20.89 21.28 2.96 -21.08 0.66 6030974.06 659808.68 N 70 29 28.203 W 148 41 36.498 629.46 4.93 271.58 572.85 628.77 27.57 27.38 27.75 3.40 -27.54 1.82 6030974.37 659802.20 N 70 29 28.208 W 148 41 36.688 719.46 5.79 272.70 662.45 718.37 35.97 35.78 36.14 3.72 -35.94 0.96 6030974.51 659793.80 N 70 29 28.211 W 148 41 36.935 809.46 7.38 276.28 751.86 807.78 46.26 46.10 46.45 4.57 -46.23 1.82 6030975.13 659783.50 N 70 29 28.219 W 148 41 37 Last GYD GC SS 842.46 7.95 279.91 784.56 840.48 50.62 50.50 50.85 5.19 -50.58 2.27 6030975.66 659779.13 N 70 29 28.225 W 148 41 37. First MWD+SAG 932.84 9.34 286.36 873.92 929.84 63.84 64.07 64.32 8.33 -63.78 1.87 6030978.52 659765.88 N 70 29 28.256 W 148 41 37.754 1028.35 11.60 282.98 967.83 1023.75 80.67 81.42 81.56 12.68 -80.57 2.45 6030982.50 659748.99 N 70 29 28.299 W 148 41 38.249 1123.17 13.90 274.23 1060.32 1116.24 101.35 102.31 102.43 15.66 -101.22 3.16 6030985.04 659728.28 N 70 29 28.328 W 148 41 38.856 1218.85 15.75 271.83 1152.81 1208.73 125.80 126.79 126.80 16.92 -125.67 2.04 6030985.77 659703.82 N 70 29 28.341 W 148 41 39.576 1313.60 16.66 273.18 1243.79 1299.71 152.22 153.23 153.15 18.08 -152.08 1.04 6030986.37 659677.39 N 70 29 28.352 W 148 41 40.353 1408.91 18.76 274.53 1334.58 1390.50 181.16 182.22 182.11 20.05 -181.00 2.24 6030987.72 659648.43 N 70 29 28.371 W 148 41 41.204 1503.39 20.84 272.53 1423.47 1479.39 213.11 214.22 214.08 21.99 -212.94 2.32 6030988.97 659616.46 N 70 29 28.391 W 148 41 42.144 1598.46 23.64 269.29 1511.46 1567.38 249.08 250.19 249.92 22.50 -248.91 3.21 6030988.71 659580.50 N 70 29 28.396 W 148 41 43.202 1694.33 26.08 265.29 1598.45 1654.37 289.29 290.47 289.86 20.54 -289.14 3.09 6030985.87 659540.32 N 70 29 28.376 W 148 41 44.386 1789.47 28.82 262.16 1682.87 1738.79 332.82 334.32 333.08 15.69 -332.71 3.25 6030980.09 659496.87 N 70 29 28.328 W 148 41 45.668 SuroeyEditor Ver SP 2.1 Bld( doc40x_100) NSi 6\NS16\NS16A\NS16A Generated 3/27/2008 3:00 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude V Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS 125tSL.;iL Ly.by Lb4. Vb l/b.S.2325 I[51`J.23U J//. 25L J/~.by J//.b~ IV.Gb -J//. /b I.J/ OVJV~/J. O~ OJy4J 1.~0 IV /U L~CB.L/.7 vv 140 41 ~L0.~~4 1977.84 30.93 266. 35 1846.35 1902.27 425. 82 427.89 425.83 6.24 -425. 78 1.78 6030968. 64 659404.03 N 70 29 28.235 W 148 41 48.407 2072.08 31.50 268. 16 1926.94 1982.86 474. 57 476.73 474.57 3.91 -474. 56 1.16 6030965. 26 659355.31 N 70 29 28.212 W 148 41 49.843 2168.38 30.96 269. 24 2009.29 2065.21 524. 48 526.66 524.48 2.77 -524. 47 0.81 6030963. 05 659305.44 N 70 29 28.201 W 148 41 51.311 2264.99 30.80 270. 92 2092.21 2148.13 574. 06 576.24 574.06 2.84 -574. 05 0.91 6030962. 06 659255.87 N 70 29 28.202 W 148 41 52.770 2362.17 30.66 271. 72 2175.74 2231.66 623. 71 625.90 623.71 3.98 -623. 70 0.44 6030962. 13 659206.22 N 70 29 28.213 W 148 41 54.231 2457.47 31.65 268. 49 2257.30 2313.22 672. 99 675.19 673.00 4.05 -672. 98 2.04 6030961. 14 659156.94 N 70 29 28.214 W 148 41 55.682 2551.85 31.30 269. 41 2337.80 2393.72 722. 25 724.47 722.26 3.14 -722. 25 0.63 6030959. 18 659107.71 N 70 29 28.205 W 148 41 57.132 2647.82 31.39 270. 86 2419.76 2475.68 772. 17 774.39 772.18 3.26 -772. 17 0.79 6030958. 23 659057.80 N 70 29 28.206 W 148 41 58.601 2742.60 31.60 267. 08 2500.59 2556.51 821. 65 823.89 821.66 2.37 -821. 66 2.09 6030956. 27 659008.35 N 70 29 28.197 W 148 42 0.057 2838.01 31.72 266. 63 2581.80 2637.72 871. 63 873.97 871.66 -0.38 -871. 66 0.28 6030952. 45 658958.42 N 70 29 28.170 W 148 42 1.528 2933.34 29.79 267. 61 2663.72 2719.64 920. 29 922.71 920.35 -2.84 -920. 34 2.09 6030948. 94 658909.81 N 70 29 28.146 W 148 42 2~ 3029.30 29.89 267. 67 2746.95 2802.87 967. 98 970.46 968.06 -4.81 -968. 05 0.11 6030945. 95 658862.16 N 70 29 28.126 W 148 42 4.365 3124.36 30.51 268. 03 2829.11 2885.03 1015. 75 1018.28 1015.85 -6.60 -1015. 83 0.68 6030943. 13 658814.43 N 70 29 28.109 W 148 42 5.771 Tie In Survey 3220.90 31.26 267. 72 2911.96 2967.88 1065. 25 1067.83 1065.39 -8.44 -1065. 35 0.79 6030940. 23 658764.96 N 70 29 28.090 W 148 42 7.228 TOW (Blind) 3250.00 32.60 267. 90 2936.66 2992.58' 1080. 63 1083.22 1080.77 -9.03 -1080. 73 4.62 6030939. 31 658749.60 N 70 29 28.085 W 148 42 7.681 BOW (Blind) 3274.00 34.30 270. 00 2956.68 3012.60 1093. 85 1096.45 1094.00 -9.26 -1093. 96 8.57 6030938. 79 658736.38 N 70 29 28.082 W 148 42 8.070 Inc+trend 3341.89 35.37 269. 94 3012.41 3068.33 1132. 63 1135.23 1132.77 -9.28 -1132. 74 1.58 6030937. 93 658697.62 N 70 29 28.082 W 148 42 9.211 MWD+IFR+MS 3436.68 39.65 269. 82 3087.58 3143.50 1190. 33 1192.93 1190.48 -9.41 -1190. 44 4.52 6030936. 57 658639.93 N 70 29 28.081 W 148 42 10.909 3534.11 39.35 274. 88 3162.78 3218.70 1252. 22 1254.88 1252.34 -6.88 -1252. 32 3.32 6030937. 77 658578.02 N 70 29 28.106 W 148 42 12.730 3627.43 38.14 270. 25 3235.58 3291.50 1310. 55 1313.27 1310.63 -4.23 -1310. 63 3.36 6030939. 16 658519.67 N 70 29 28.131 W 148 42 14.446 3722.92 35.70 269. 67 3311.91 3367.83 1367. 90 1370.62 1367.99 -4.26 -1367. 98 2.58 6030937. 89 658462.34 N 70 29 28.131 W 148 42 16.133 3818.60 36.70 268. 51 3389.12 3445.04 1424. 39 1427.13 1424.49 -5.17 -1424. 48 1.27 6030935 .77 658405.87 N 70 29 28.122 W 148 42 17.796 3915.59 38.66 267. 59 3465.88 3521.80 1483. 62 1486.41 1483.75 -7.20 -1483. 73 2.10 6030932 .47 658346.69 N 70 29 28.102 W 148 42 19.540 4011.14 42.00 269. 13 3538.71 3594.63 1545 .41 1548.24 1545.55 -8.94 -1545. 53 3.65 6030929 .41 658284.94 N 70 29 28.085 W 148 42 21.358 4106.16 43.62 269. 01 3608.42 3664.34 1609 .96 1612.81 1610.12 -9.99 -1610. 09 1.71 6030926 .97 658220.42 N 70 29 28.074 W 148 42 23.258 4202.18 45.48 269. 14 3676.84 3732.76 1677 .30 1680.17 1677.48 -11.07 -1677. 44 1.94 6030924 .44 658153.12 N 70 29 28.063 W 148 42 25.240 4297.95 48.28 269. 58 3742.30 3798.22 1747 .18 1750.07 1747.37 -11.85 -1747. 33 2.94 6030922 .16 658083.26 N 70 29 28.056 W 148 42 27.297 4393.84 48.64 269. 45 3805.89 3861.81 1818 .95 1821.84 1819.15 -12.45 -1819. 10 0.39 6030920 .01 658011.53 N 70 29 28.050 W 148 42 29 4489.72 49.69 270. 76 3868.58 3924.50 1891 .48 1894.38 1891.68 -12.32 -1891. 64 1.51 6030918 .59 657939.01 N 70 29 28.051 W 148 42 31 4585.39 49.80 270. 92 3930.40 3986.32 1964 .49 1967.39 1964.68 -11.24 -1964. 65 0.17 6030918 .09 657866.00 N 70 29 28.061 W 148 42 33. 4680.54 49.72 271. 48 3991.87 4047.79 2037 .12 2040.03 2037.29 -9.72 -2037. 26 0.46 6030918 .05 657793.38 N 70 29 28.076 W 148 42 35.828 4777.08 51.11 270 .53 4053.39 4109.31 2111 .51 2114.42 2111.67 -8.43 -2111. 65 1.63 6030917 .75 657718.98 N 70 29 28.088 W 148 42 38.017 4872.82 49.93 271 .00 4114.26 4170.18 2185 .41 2188.32 2185.55 -7.44 -2185. 54 1.29 6030917 .14 657645.10 N 70 29 28.098 W 148 42 40.192 4968.66 49.00 270 .52 4176.55 4232.47 2258 .25 2261.16 2258.38 -6.47 -2258. 37 1.04 6030916 .55 657572.27 N 70 29 28.107 W 148 42 42.335 5062.13 51.12 269 .37 4236.55 4292.47 2329 .90 2332.82 2330.04 -6.55 -2330. 03 2.46 6030914 .93 657500.63 N 70 29 28.106 W 148 42 44.444 5158.14 52.32 270 .04 4296.03 4351.95 2405 .26 2408.18 2405.40 -6.94 -2405. 39 1.36 6030912 .92 657425.30 N 70 29 28.102 W 148 42 46.661 5257.59 51.82 271 .12 4357.16 4413.08 2483 .70 2486.62 2483.84 -6.15 -2483. 83 0.99 6030912 .03 657346.87 N 70 29 28.110 W 148 42 48.970 5349.83 51.56 270 .30 4414.34 4470.26 2556 .08 2559.00 2556.21 -5.25 -2556. 20 0.75 6030911 .37 657274.50 N 70 29 28.118 W 148 42 51.099 5445.69 52.03 270 .14 4473.63 4529.55 2631 .40 2634.33 2631.53 -4.96 -2631 .53 0.51 6030910 .04 657199.19 N 70 29 28.121 W 148 42 53.316 5542.16 51.74 270 .27 4533.17 4589.09 2707 .30 2710.23 2707.43 -4.69 -2707 .43 0.32 6030908 .68 657123.31 N 70 29 28.123 W 148 42 55.549 SurveyEditor Ver SP 2.1 Bld( doc40x_100) NS16\NS16\NSi 6A\NS16A Generated 3/27/2008 3:00 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude - Longitude Depth Section Departure tt de de ft ft ft ft it ft ft de 00 tt ftUS ftUS bbi /.4if 51.tS1 L/U. bS 45~JL.15 4b425.V/ L/23L.lil L/[55.11 L/t3L. 31 -4.U`J -L/iSL. 31 U.3L OV3U~U/. O/ OJ/U~iO.~V4 IV /U G.7 GO.IGp VV 140 4G J/. /J3 5733.23 51.86 270. 65 4651.32 4707.24 2857.46 2860.39 2857. 58 -3.23 -2857. 58 0.05 6030906. 91 656973.17 N 70 29 28.137 W 148 42 59. 968 5829.81 51.56 270. 29 4711.17 4767.09 2933.27 2936.20 2933. 38 -2.61 -2933. 38 0.43 6030905. 90 656897.37 N 70 29 28.143 W 148 43 2. 199 5924.83 51.16 271. 22 4770.50 4826.42 3007.48 3010.41 3007. 59 -1.63 -3007. 59 0.87 6030905. 28 656823.17 N 70 29 28.152 W 148 43 4. 383 6020.16 51.09 271. 03 4830.33 4886.25 3081.70 3084.63 3081. 80 -0.18 -3081. 80 0.17 6030905. 14 656748.95 N 70 29 28.166 W 148 43 6. 566 6116.39 51.50 271. 22 4890.50 4946.42 3156.79 3159.73 3156. 88 1.30 -3156. 88 0.45 6030905. 00 656673.86 N 70 29 28.180 W 148 43 8. 776 6212.18 51.80 270. 46 4949.94 5005.86 3231.90 3234.85 3231. 99 2.40 -3231. 99 0.70 6030904. 49 656598.75 N 70 29 28.191 W 148 43 10. 986 6308.61 52.14 270. 57 5009.35 5065.27 3307.86 3310.80 3307. 94 3.08 -3307. 94 0.36 6030903. 54 656522.81 N 70 29 28.197 W 148 43 13. 221 6402.92 52.08 269. 85 5067.27 5123.19 3382.29 3385.23 3382. 37 3.35 -3382. 37 0.61 6030902. 21 656448.40 N 70 29 28.200 W 148 43 15. 411 6499.47 51.92 269. 68 5126.71 5182.63 3458.37 3461.31 3458. 45 3.04 -3458. 45 0.22 6030900. 26 656372.34 N 70 29 28.196 W 148 43 17. 650 6595.75 52.17 270. 00 5185.93 5241.85 3534.28 3537.23 3534. 37 2.83 -3534. 37 0.37 6030898. 42 656296.46 N 70 29 28.194 W 148 43 19. 884 6691.32 52.54 270. 13 5244.30 5300.22 3609.95 3612.90 3610. 04 2.92 -3610. 04 0.40 6030896. 88 656220.80 N 70 29 28.194 W 148 43 22~ 6785.57 52.42 270 .25 5301.70 5357.62 3684.70 3687.66 3684. 80 3.16 -3684. 79 0.16 6030895. 52 656146.07 N 70 29 28.196 W 148 43 24. 6882.05 51.24 270 .93 5361.32 5417.24 3760.55 3763.51 3760. 64 3.94 -3760. 64 1.34 6030894. 67 656070.23 N 70 29 28.204 W 148 43 26. 543 6978.51 52.37 271 .48 5420.97 5476.89 3836.35 3839.31 3836. 43 5.54 -3836. 43 1.25 6030894. 64 655994.43 N 70 29 28.219 W 148 43 28. 773 7073.77 52.21 270 .60 5479.23 5535.15 3911.71 3914.67 3911. 78 6.91 -3911. 78 0.75 6030894. 39 655919.07 N 70 29 28.232 W 148 43 30. 990 7169.36 52.57 270 .57 5537.57 5593.49 3987.43 3990.40 3987. 50 7.68 -3987. 50 0.38 6030893. 53 655843.36 N 70 29 28.239 W 148 43 33. 218 7265.60 51.58 270 .85 5596.72 5652.64 4063.34 4066.31 4063. 42 8.62 -4063. 41 1.05 6030892. 84 655767.45 N 70 29 28.248 W 148 43 35. 452 7361.24 51.39 270 .59 5656.28 5712.20 4138.18 4141.15 4138. 24 9.56 -4138. 23 0.29 6030892. 17 655692.63 N 70 29 28.257 W 148 43 37. 654 7457.03 52.29 270 .44 5715.46 5771.38 4213.49 4216.46 4213. 56 10.24 -4213. 55 0.95 6030891. 23 655617.32 N 70 29 28.263 W 148 43 39. 870 7552.46 52.42 269 .79 5773.75 5829.67 4289.05 4292.03 4289. 12 10.39 -4289 .11 0.56 6030889. 75 655541.78 N 70 29 28.264 W 148 43 42 .094 7648.69 52.12 269 .06 5832.64 5888.56 4365.15 4368.14 4365. 22 9.63 -4365 .21 0.68 6030887. 36 655465.72 N 70 29 28.256 W 148 43 44 .334 7743.88 51.76 268 .74 5891.32 5947.24 4440.07 4443.08 4440. 16 8.19 -4440 .15 0.46 6030884. 31 655390.84 N 70 29 28.242 W 148 43 46 .539 7839.52 52.52 269 .41 5950.02 6005.94 4515.56 4518.59 4515. 65 6.97 -4515 .65 0.97 6030881. 47 655315.39 N 70 29 28.229 W 148 43 48 .760 7934.57 52.45 269 .10 6007.90 6063.82 4590.93 4593.99 4591. 04 5.99 -4591 .03 0.27 6030878. 87 655240.04 N 70 29 28.219 W 148 43 50 .979 8030.84 52.04 270 .05 6066.85 6122.77 4667.04 4670.10 4667. 15 5.42 -4667 .14 0.89 6030876. 67 655163.97 N 70 29 28.213 W 148 43 53 .218 8126.50 51.93 268 .76 6125.76 6181.68 4742.39 4745.46 4742. 51 4.64 -4742 .50 1.07 6030874. 26 655088.65 N 70 29 28.205 W 148 43 55 .436 8222.25 51.87 268 .07 6184.84 6240.76 4817.69 4820.81 4817. 82 2.56 -4817 .82 0.57 6030870. 56 655013.40 N 70 29 28.184 W 148 43 57 .652 8317.46 51.91 268 .55 6243.60 6299.52 4892.55 4895.73 4892. 70 0.35 -4892 .70 0.40 6030866. 74 654938.59 N 70 29 28.162 W 148 43 5 8413.82 52.27 267 .60 6302.81 6358.73 4968.51 4971.75 4968 .68 -2.21 -4968 .68 0.86 6030862. 56 654862.68 N 70 29 28.136 W 148 44 8508.97 52.33 267 .48 6361.00 6416.92 5043.69 5047.04 5043 .90 -5.44 -5043 .90 0.12 6030857. 71 654787.56 N 70 29 28.104 W 148 44 4 . 8591.79 51.97 266 .88 6411.82 6467.74 5108.98 5112.43 5109 .22 -8.65 -5109 .22 0.72 6030853 .09 654722.33 N 70 29 28.072 W 148 44 6 .227 8687.81 51.23 266 .74 6471.46 6527.38 5184.08 5187.68 5184 .36 -12.84 -5184 .35 0.78 6030847 .29 654647.31 N 70 29 28.030 W 148 44 8 .438 8783.27 51.27 266 .77 6531.21 6587.13 5258.37 5262.13 5258 .71 -17.06 -5258 .68 0.05 6030841 .48 654573.10 N 70 29 27.988 W 148 44 10 .625 8878.90 51.55 268 .34 6590.86 6646.78 5333.02 5336.88 5333 .39 -20.24 -5333 .35 1.32 6030836 .69 654498.51 N 70 29 27.956 W 148 44 12 .822 8974.05 51.37 269 .34 6650.14 6706.06 5407.41 5411.30 5407 .80 -21.75 -5407 .76 0.84 6030833 .58 654424.16 N 70 29 27.941 W 148 44 15 .012 9069.58 51.40 269 .31 6709.76 6765.68 5482.04 5485.94 5482 .44 -22.63 -5482 .40 0.04 6030831 .10 654349.57 N 70 29 27.932 W 148 44 17 .208 9165.85 50.91 269.12 6770.15 6826.07 5557.00 5560.92 5557 .42 -23.66 -5557 .37 0.53 6030828 .46 654274.64 N 70 29 27.921 W 148 44 19 .415 9262.50 50.33 269 .30 6831.47 6887.39 5631.69 5635.63 5632 .12 -24.69 -5632 .07 0.62 6030825 .82 654199.98 N 70 29 27.910 W 148 44 21 .613 9357.39 49.71 269.13 6892.43 6948.35 5704.38 5708.34 5704 .83 -25.68 -5704 .77 0.67 6030823 .27 654127.32 N 70 29 27.900 W 148 44 23 .752 9452.49 49.06 268.57 6954.34 7010.26 5776.54 5780.53 5777 .01 -27.13 -5776 .95 0.82 6030820 .27 654055.20 N 70 29 27.885 W 148 44 25 .876 SurveyEditor Ver SP 2.1 Bld( doc40x_100) NS16\NS16\NS16A\NS16A Generated 3/27/2008 3:00 PM Page 3 of 5 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft ft ft de OOft ftUS ftUS 9548.57 48.36 269. 09 7017.74 7073.66 5848. 71 5852.72 5849.19 -28.60 -5849.12 0.83 6030817. 24 653983. 08 N 70 29 27.870 W 148 44 28.000 9644. 36 47.83 269. 55 7081.72 7137.64 5919. 98 5924.01 5920.48 -29.45 -5920.41 0.66 6030814. 86 653911. 83 N 70 29 27.861 W 148 44 30.098 9740. 51 47.04 268. 92 7146.76 7202.68 5990. 78 5994.82 5991.30 -30.40 -5991.22 0.95 6030812. 40 653841. 07 N 70 29 27.852 W 148 44 32.181 9837. 20 46.31 269. 77 7213.10 7269.02 6061. 11 6065.16 6061.63 -31.20 -6061.55 0.99 6030810. 08 653770. 77 N 70 29 27.843 W 148 44 34.251 9932. 26 45.52 269. 33 7279.24 7335.16 6129. 38 6133.44 6129.91 -31.74 -6129.83 0.90 6030808. 08 653702. 53 N 70 29 27.837 W 148 44 36.260 10028. 26 44.84 270. 21 7346.90 7402.82 6197. 47 6201.54 6198.01 -32.01 -6197.92 0.96 6030806. 34 653634. 46 N 70 29 27.834 W 148 44 38.264 10123. 18 43.65 271. 50 7414.90 7470.82 6263. 69 6267.76 6264.22 -31.03 -6264.14 1.57 6030805. 89 653568. 24 N 70 29 27.843 W 148 44 40.213 10219. 15 42.03 272. 10 7485.27 7541.19 6328. 92 6333.02 6329.43 -28.99 -6329.36 1.74 6030806. 54 653503. 00 N 70 29 27.863 W 148 44 42.132 10314. 08 40.57 272. 31 7556.59 7612.51 6391. 55 6395.67 6392.02 -26.58 -6391.97 1.54 6030807. 60 653440. 36 N 70 29 27.886 W 148 44 43.974 10409. 17 39.19 271. 98 7629.56 7685.48 6452. 49 6456.64 6452.94 -24.30 -6452.89 1.47 6030808. 57 653379. 40 N 70 29 27.908 W 148 44 45.767 10504. 89 37.65 271. 72 7704.55 7760.47 6511. 95 6516.12 6512.38 -22.37 -6512.34 1.62 6030809. 22 653319. 93 N 70 29 27.926 W 148 44 47 10599. 15 35.94 271. 22 7780.03 7835.95 6568. 40 6572.57 6568.81 -20.92 -6568.78 1.84 6030809. 46 653263. 48 N 70 29 27.940 W 148 44 49 10695. 93 34.47 270. 51 7859.10 7915.02 6624. 19 6628.37 6624.59 -20.07 -6624.56 1.58 6030809. 11 653207. 69 N 70 29 27.948 W 148 44 50.8 10791. 63 33.42 271. 70 7938.49 7994.41 6677. 62 6681.80 6678.02 -19.05 -6677.99 1.30 6030808. 98 653154. 26 N 70 29 27.957 W 148 44 52.391 10887. 04 32.52 272. 71 8018.54 8074.46 6729. 52 6733.72 6729.89 -17.06 -6729.87 1.11 6030809. 86 653102. 35 N 70 29 27.977 W 148 44 53.918 10982. 32 31.70 273. 53 8099.24 8155.16 6780. 11 6784.37 6780.46 -14.30 -6780.44 0.97 6030811. 52 653051. 74 N 70 29 28.003 W 148 44 55.406 11078. 27 30.65 273. 09 8181.34 8237.26 6829. 71 6834.04 6830.03 -11.43 -6830.02 1.12 6030813. 32 653002. 11 N 70 29 28.031 W 148 44 56.865 11174. 07 29.88 273. 79 8264.08 8320.00 6877. 93 6882.32 6878.23 -8.54 -6878.22 0.88 6030815. 18 652953. 86 N 70 29 28.059 W 148 44 58.284 11269. 55 29.16 273. 79 8347.16 8403.08 6924. 90 6929.36 6925.16 -5.43 -6925.16 0.75 6030817 .28 652906. 87 N 70 29 28.089 W 148 44 59.665 11363. 37 28.35 274. 10 8429.41 8485.33 6969. 95 6974.50 6970.19 -2.33 -6970.19 0.88 6030819 .42 652861. 79 N 70 29 28.119 W 148 45 0.990 11459. 71 27.45 274. 91 8514.55 8570.47 7014. 91 7019.58 7015.13 1.21 -7015.13 1.01 6030821 .99 652816. 79 N 70 29 28.154 W 148 45 2.313 11555. 62 27.45 274. 89 8599.67 8655.59 7058. 99 7063.79 7059.18 4.99 -7059.18 0.01 6030824 .81 652772. 67 N 70 29 28.190 W 148 45 3.609 11651. 26 27.38 273. 89 8684.57 8740.49 7102. 92 7107.82 7103.09 8.36 -7103.08 0.49 6030827 .24 652728. 71 N 70 29 28.223 W 148 45 4.901 11745. 97 27.25 271. 46 8768.72 8824.64 7146 .34 7151.28 7146.50 10.39 -7146.49 1.19 6030828 .34 652685. 27 N 70 29 28.243 W 148 45 6.179 11842. 32 26.97 269. 25 8854.48 8910.40 7190 .24 7195.18 7190.40 10.66 -7190.39 1.08 6030827 .67 652641. 38 N 70 29 28.245 W 148 45 7.470 11938. 46 26.81 268. 57 8940.23 8996.15 7233 .71 7238.66 7233.87 9.84 -7233.86 0.36 6030825 .91 652597. 94 N 70 29 28.236 W 148 45 8.750 12034. 17 27.07 268. 84 9025.55 9081.47 7277 .05 7282.02 7277.22 8.86 -7277.21 0.30 6030824 .00 652554. 62 N 70 29 28.226 W 148 45 10.025 12129. 31 26.65 269. 05 9110.43 9166.35 7320 .02 7325.01 7320.19 8.07 -7320.19 0.45 6030822 .28 652511. 67 N 70 29 28.218 W 148 45 11.290 12226. 20 26.28 268. 05 9197.17 9253.09 7363 .17 7368.19 7363.36 6.98 -7363.35 0.60 6030820 .26 652468. 54 N 70 29 28.207 W 148 45 12. 12321 .53 26.31 267. 30 9282.63 9338.55 7405 .35 7410.42 7405.55 5.26 -7405.55 0.35 6030817 .64 652426. 40 N 70 29 28.190 W 148 45 1 12417 .56 26.33 267 .34 9368.71 9424.63 7447 .87 7453.00 7448.08 3.27 -7448.08 0.03 6030814 .74 652383. 92 N 70 29 28.170 W 148 45 15.053 12503 .97 26.50 267 .74 9446.09 9502.01 7486 .26 7491.44 7486.49 1.62 -7486.49 0.28 6030812 .27 652345. 56 N 70 29 28.153 W 148 45 16.184 12626 .97 27.07 267 .62 9555.90 9611.82 7541 .62 7546.87 7541.87 -0.62 -7541.87 0.47 6030808 .83 652290. 25 N 70 29 28.130 W 148 45 17.813 12721 .83 27.16 269 .01 9640.33 9696.25 7584 .82 7590.10 7585.08 -1.89 -7585.08 0.67 6030806 .63 652247. 07 N 70 29 28.118 W 148 45 19.085 12815 .95 27.24 271 .49 9724.05 9779.97 7627 .84 7633.12 7628.10 -1.70 -7628.10 1.21 6030805 .90 652204. 07 N 70 29 28.119 W 148 45 20.351 12911 .64 27.26 273 .88 9809.12 9865.04 7671 .61 7676.92 7671.85 0.35 -7671.85 1.14 6030807 .01 652160 .28 N 70 29 28.139 W 148 45 21.638 13007 .36 27.22 276 .04 9894.23 9950.15 7715 .28 7720.73 7715.50 4.13 -7715.50 1.03 6030809 .86 652116 .57 N 70 29 28.176 W 148 45 22.923 13102 .79 27.28 276 .78 9979.06 10034.98 7758 .74 7764.43 7758.92 9.01 -7758.92 0.36 6030813 .80 652073 .06 N 70 29 28.223 W 148 45 24.201 13198 .80 27.15 277 .42 10064.45 10120.37 7802 .35 7808.34 7802.50 14.44 -7802.49 0.33 6030818 .29 652029 .38 N 70 29 28.276 W 148 45 25.483 13294 .29 26.80 276 .36 10149.55 10205.47 7845 .39 7851.65 7845.51 19.64 -7845.49 0.62 6030822 .56 651986 .29 N 70 29 28.327 W 148 45 26.748 SurveyEditor Ver SP 2.1 Bld( doc40x_100) NS16\NS16\NS16A\NS16A Generated 3/27/2008 3:00 PM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt ft ft ft tt tt ft de OOft ftUS ftUS 1 f.~.yU.UI Lb./1 L/b .4L IVLJJ. UL IVLyU. y4 /O60. La /Oy4. /4 /OOO. JJ L4. 4J -/OOO. JI V.IV OVJVOLO. `FJ V:JI~YJ.J/ IV /V L~LO. J/J vY IYO YJ LO .VVJ 13485.81 26.58 275 .80 10320. 65 10376. 57 7931. 01 7937. 70 7931. 08 29. 01 -7931. 03 0.32 6030830. 09 651900 .57 N 70 29 28. 418 W 148 45 29 .266 13581.33 26.54 275 .50 10406. 09 10462. 01 7973. 54 7980. 41 7973. 60 33. 21 -7973 .53 0.15 6030833. 38 651857 .99 N 70 29 28. 459 W 148 45 30 .517 13676.79 26.70 272 .59 10491. 43 10547. 35 8016. 22 8023. 18 8016. 27 36. 23 -8016 .19 1.38 6030835. 47 651815 .28 N 70 29 28. 488 W 148 45 31 .772 13772.63 26.69 271 .19 10577. 06 10632. 98 8059. 26 8066. 23 8059. 30 37. 65 -8059 .22 0.66 6030835. 97 651772 .24 N 70 29 28. 502 W 148 45 33 .038 13867.18 26.55 269 .87 10661. 58 10717. 50 8101. 62 8108. 59 8101. 67 38. 04 -8101 .58 0.64 6030835. 45 651729 .88 N 70 29 28. 505 W 148 45 34 .285 13964.09 26.67 269 .38 10748. 23 10804. 15 8145. 02 8152. 00 8145. 07 37. 75 -8144 .98 0.26 6030834. 23 651686 .49 N 70 29 28. 502 W 148 45 35 .562 14013.10 26.75 269 .16 10792. 01 10847. 93 8167. 05 8174. 03 8167. 10 37. 47 -8167 .01 0.26 6030833. 48 651664 .48 N 70 29 28. 499 W 148 45 36 .211 14179.82 24.91 267 .42 10942. 07 10997. 99 8239. 63 8246. 66 8239. 68 35. 34 -8239 .61 1.19 6030829. 79 651591 .95 N 70 29 28. 477 W 148 45 38 .347 14276.06 20.15 266 .14 11030. 94 11086. 86 8276. 42 8283. 53 8276. 48 33. 31 -8276 .42 4.97 6030826. 97 651555 .19 N 70 29 28. 457 W 148 45 39 .430 14370.84 17.20 263 .97 11120. 72 11176. 64 8306. 63 8313. 87 8306 .70 30 .74 -8306 .65 3.20 6030823. 75 651525 .03 N 70 29 28. 431 W 148 45 40 .319 Last Survey 14464.95 14.55 263 .32 11211. 23 11267. 15 8332. 19 8339. 61 8332 .28 27 .90 -8332 .23 2.82 6030820. 36 651499 .51 N 70 29 28. 403 W 148 45 41 TD (Projected) 14505.00 14.55 263 .32 11250. 00 11305. 92 8342. 17 8349. 67 8342 .27 26 .73 -8342 .22 0.00 6030818. 98 651489 .55 N 70 29 28. 391 W 148 45 41 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + SAG - (MWD + Sag correction -- MWD with a BHA deformation correction applied. Covers all BHA corrections-from simple 2D tofinite-element 3D models. ) INC+TREND - (Inclinometer + known azi trend -Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. MWD+IFR-MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) fftUSl Easting (X) IftUSI Surface : 1199 FSL 645 FEL S11 T13N R13E UM 6030971.56 659829.81 Tie-In : 1199 FSL 645 FEL S11 T13N R13E UM 6030971.64 659829.41 BHL : 1220 FSL 3707 FEL S10 T13N R13E UM 6030818.98 651489.55 • SurveyEditor Ver SP 2.1 Bld( doc40x_100) NS16\NS16\NS16A\NS16A Generated 3/27/2008 3:00 PM Page 5 of 5 s: ; ~ L~ ~e I ALASSA OIL A1~D GAS CO1~T5ER'QATIOrT COM1~II551O1~T Robert Younger Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 308-233 Dear Mr. Younger: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 roved A hcation for Sunder Approval relating to the Enclosed is the app PP above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for gopod i~~o shown, a person affected by it may file with the Commission an a p for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following a o weekends lA person ma of app day if the 23rd day falls on a hohd y a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Searnount, Jr. Chair DATED this ~ day of July, 2008 Encl. ~C~'<`!/ t (`~ "~~ J 4/Y~ ,~`~ • STATE OF ALASKA ~ _"`* ~~" ~" ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION M JO APPLICATION FOR SUNDRY APPROVAL ~IUN 2 7 2QG ; `p 20 AAC 25.280 AhoL., :,:.., .. 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ -' a ~Yi~(;Y: _~.~~L2the Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Tim ~}p~~a] Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc . Development Exploratory ^ 206-1410 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownershi p changes: NS16A . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ~ ADLO-312799 - 56.46 ~ NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 ~ 11305.92 14414 11218 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/10/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: _" Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true orrect to the best of my knowledge. Contact Robert Younger Printed Name e oun Title Production Engineer Signature Phone 564-5392 Date 6/26/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S ~~~,- ~~~~~ ~! 2 20D9 Subsequent Form Required: ~('"~, APPROVED BY ~j ~ ,1~ Approved b COMMISSIONER THE COMMISSION Date: / U Form 10-40 Revised 06/2006 Submit in Duplicate ~' v UKI~II~/~L NS16A 206-1410 PERF ATTACHMENT r~ U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS16A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 ___ NS16A 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/1/08 PER 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 NS16A 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED _ FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • PERFORATING PROCEDURE rrrrr~~~m Well: NS16A API #: 50-029-23098-01 Date: 6126108 Prod Engr Robert Younger Office Ph: 564-5392 Home Ph: 877-2599 ............................................ .............. Cell Ph: 830-4920 ............................................ .............. CC or AFC: NSFLDWLIB Detail Code: Description: Re-Perforate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WBL Entries ver a.a or~oaoi H2S Level: ..................................................................... None Anticipated IOR Type Work Description Well Objectives and Loaaino Notes: NS16A is a new development well at Northstar. Following a Coil Acid /Scale Inhibition treatment, the well's productivity dropped off and on 05/02/08 15' of new perforations were added in adition to re-shooting the original 35' of perforatoins. The 50' of perforatoins shot 05/02/08 resulted in a -1000 BOPD increase in production. Unfortunately, the wells' production dropped off again and 30' of perforation were shot 06/12/08 consisting of 15' of reperfs and 15' of new perforations. The 30' of perforatoins shot 06/12/08 resulted in a -2500 BOPD increase, but the test 12 days latter on 06/24/08 showed NS16A's productoin had dropped -2200 BOPD from the post perforation test. The objective of the proposed perforation intervals is to restore the well's productivity. Due to NS16A's production track record to date, it is anticipated that multiple perforation attempts will be required to maintain production and thus the request for two seperate perforation attempts and intervals. The intent of shooting the first proposed interval (14,274'-14296') is to understand the productivity of the top of the reservoir. At a later date, it is anticpated that the whole perforation interval (14,274'-14,339') will need to be re-shot and thus the request for reshooting the entire perforatoin inteval. Please contact Bob Younger with any questions, comments, or concerns - 584-5392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated perforations. Please note that acctual perforated interval depth will vary slightly based on actual pert gun configuration. Please see attached annotated log for additoinal information. Reference Log Tie in Log Add/Subtract feet Log: Prim Depth C to the tie-in log to be on Date: .4/4/2008 depth with the reference log. Company: Schlumberger Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 14,276' - 14,298' - 22' 6 60° 0 Ivishak Re Actual perforations will be 20'. But total interval will be -22' due to -2' for spacers. Please note that the entire reperf interval requested below will be shot at a latter date following the 20' interval. 14,274' - 14,339' ................................. .............................. .... - 65' 6 .......................... ............................... ................ .................... 60° 0 Ivishak Re ...................._................................................................... . .......................... .................... ................................. .............................. .... .......................... ............................... ................ .................... 0 ......................................................................................... . ........................... .................... ........... .. .... .......................... ...........- _.......... ................ 0 ......................................................................... _.................... .................... ...- Gas Jetting Expected? N/A No At what Depth? Requested Gun Size: 2" Charge: ,2006 PJ Desired Penetration: .18:6 Entry Hole Diam: .020 .............. Is Drawdown Necessary/Desired/Unnecessary During Perforating NA Deschbe bebw how to achieve drawdown (check w/ Pad Operator to see i! necessary piping is installed) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (e.g. N2 LiR, Hardline LiR Gas, Gas LiR, Flow Well, BacMlow Through Drain or Hadiline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tie into GR from annotated reference log Tie in using: Tie into GR character indicated in Primary Depth.Control.Log Minimum ID: 2.400 in Min ID Type: 4.5" x 2.875" crossover ~ 13527' 'MD 2-7/8" Liner Top: .1.3505' ft MD Casing Size: .2:441 in 2-7/8" Liner Est Res. Pres. ~ 14,350 MD 11100' SS .5:1.21 psi Last Tag: 14382' SLMD ft 4/28/2008 800 S Dumm Gun Drift -Last Drift 4/28/08 500 E Please Perforate 22' per the below procedure. 800 E Please Perforate 65' per the below procedure. O/B/U - O PERFORATION DEPTH CONTROL LOG SFRT/GR/PRESS/TEMP 03-APRIL-2008 NS16A W ~, u_ g ~ a Z o ~ ~ ~ ~ ~ ~ O ~ ¢ ao `° w rn z z r z m ~. s c c o> o is ~ - a o ~ ~ - E d ~ m ii ~ ~ U Number Fluid Levei 14505 ft 14412 ft 14410 ft 1 1 D.F. Elev.: 0.00 ft 56.46 ft above Perm. Datum Township Range 13N 13E Unit Number __ ~ Location ~ 2i28 ~ PRUDHOE BAY ~ ~ April 04, 2008 PDC GR/CCL 1198.71 ~ FSL & 644.61 ~ FEL Elev.: K.B. 56.46 ft AT SURFACE G.L Permanent Datum: MEAN SEA LEVEL Log Measured From: KELLY BUSHING Drilling Measured From: KELLY BUSHING API Serial No. Section 50-029-23096-01 11 X-N PKF X-! 10i~ PN H %O ~,~, f . ~ ~ ° ~ h , i t " ~:; ',= ' ' ~ ~- saoo oP. __ - P NS16A Apr1104, 2048 PDC GRICCL IP F SIP [FFr 3~ • ~a2oo NS16A April 04, 2008 PDC GR/CCL 14276' to 14296' MD with 2" 6:spf PJ2006 Please note that with the current 2" guns at N* lU' Gun (1-10' gun 8~ 2-5' guns) there will be 20' of perforations, Spacer s' Gun but the interval will be -22' include -2' of spacers. Spacer ---- - i ---; I .. ~ r _. t- __ _ I d 5' Gun 14300 ' ` ' Please Re-Perforate entire existing perf~>ration interval 14274' to 14339' MD with 2" 6 ~pf PJ2006 at a later date following the above 22' perforation request. ~aaao To cede sL+~aL fFlMM RE: NS 16A RePerf ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Younger, Robert O [Robert.Youngert~bp.com] Sent: Monday, June 30, 2008 9:14 AM To: Maunder, Thomas E (DOA) Subject: RE: NS16A RePerf Tom, As an update to current operations at Northstar, over the weekend we shot perforations in NS30. We are currently running our third and final gun run in NS19. As we discussed, the NS19 perforation interval is slightly different than the intervals on the sundry due to the need to down size our guns and tag depth. The actual perforation intervals shot will be reported on the 10-404. With regard to the below request, we wilt plan to work the perforations of NS16A into the wells group schedule and shoot NS16A in the next few days assuming we have sundry approval. Thanks for any help expediting this request if possible. Please let me know if any additional information is needed. Thanks! Bob From: Younger, RoberC O Sent: Friday, June 27, 2008 11:35 AM To: Maunder, Thomas E (DOA) Subject: NS16A RePert Tom, As I mentioned yesterday, the perforations that we shot on NS16A 06/12/08 have dropped significantly. We plan to re-perforate the well per the attached procedure. The sundry will be delivered to the AOGCC this afternoon. We have a perforation campaign scheduled at Northstar for the TAPS slow down this weekend. We plan to shelter perforations on NS30 & NS19 under the TAPS slowdown. If it is possible to get the NS16A sundry approved today, we could also plan to shoot perforations in NS16A possibly over the weekend as well. Please let me know if this is a possibility. Thanks for the help! Bob « File: NS16A 06-26-2008 ADW RePert Procedure.xls» « File: NS16A RePerts 06-26-08.pdf» NS16A Recent Well Test Data « OLE Object: PBrush » Robert Younger BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) younger2@bp.com 6/30/2008 s STATE OF ALASKA 6~~~, ALAS~OIL AND GAS CONSERVATION COMM1~510N °:~~ JUI~ ~ ~ 2008 REPORT OF SUNDRY WELL OPERATION9'~laska ®il 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ORIr?)iS ' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~~~~ ~; C Change Approved Program ~ Operat. Shutdown ~ Perforate 0 ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 206-1410 ~ 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: ! Anchorage, AK 99519-6612 50-029-23096-01 00 7. KB Elevation (ft): 9. Well Name and Number: 55.92 KB NS16A 8. Property Designation: 10. Field/Pool(s): ADLO-312799 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 ~ feet Plugs (measured) None true vertical 11305.92. feet Junk (measured) None Effective Depth measured 14414 feet true vertical 11218 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Perforation depth: Measured depth: SEE ATTACHMENT = _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 13497' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S-3 PERM PACKER 13444' 4-1/2" SSSV 1024' 0 0 0 0 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: 1312 6278 0 744 Subsequent to operation: 4065 24330 135 790 14. Attachments: 15. Well Class after proposed work' Copies of Logs and surveys Run Exploratory ~'~'' Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ~' WINJ ' WDSPL ~' 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: 308-196 Contact ROBERT YOUNGER Printed Name ROBERT.~YOUNGER Title PRODUCTION ENGINEER ~~ 7 Signature ~,~ Phone 564-5392 Date 6/17/2008 4~? Form 10-404 Revised 04/2006 ? ( ~ ~~, ~ ~ ~ Submit Original Only/z ~Cr/ 1 ~ ~ ~.,1 S ~~~W JU~~ ~ 9 2~~5 ,~`e 3 NS16A 206-1410 PERF ~TT~['.HMFNT • Operation Date Pert Operation Code - -- -- - - - - - -- Meas Depth Top - ------ - - Meas Depth Base Tvd Depth Top Tvd Depth Base 4/5/08 PER 14,304. 14,319. 11,113.16 11,12_7.34 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 5/1/08 PER 14,299. 14,304. 11,108.44 11,113.16 5/1/08 RPF 14,304. 14,319. 11,113.16 11,127.34 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 6/12/08 APF 14,274. 14,304. 11,084.93 11,113.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLE D SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u • .. NS 16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY -- ACTIVITYDATE SUMMARY 6/11/2008 ""`WELL FLOWING**" (ad/re perf) TRAVEL TO NORTHSTAR. PREP FOR AD/RE-PERF JOB. STEM TEST WLV TO 5000 PSI. LDFN. ***JOB CONTINUED ON 12-JUN-2008*"" 6/12/2008 ~**RESUMED JOB FROM 11-JUN-2008*** (ad/re perf) INITIAL T/I/O = 2700/0/0 PERFORATE WITH 30' OF 2" HSD 6SPF 60 DEG PHASED PJ 2006 GUNS FROM 14274'-14304' (14274'-14289' ARE ADPERFS - 14289'-14304' ARE ' REPERFS). CORRECTED TO SLB PDC LOG DATED 4-3-08 USING GR/CCL. ':'`'`'`CONTINUED ON 13-JUN-2008"*'` 6/13/2008::**"CONTINUED FROM 12-JUN-2008*** (ad/re perf) ;COMPLETED PERFORATING WITH GR/CCL & 30' OF 2" HSD 6SPF 60 DEG ''PHASED PJ 2006 GUNS FROM 14274'-14304'. USED SLB PDC LOG DATED '''4-3-08 FOR DEPTH CORECTION. CONFIRMED ALL SHOTS FIRED. FINAL 'T/I/0-1900/0/0 WELL LEFT SHUT IN, RETURNED TO DSO COMPLETE****'` FLUIDS PUMPED BBLS 1 diesel 1 Total • @~ ~ ~ ~ ~ .~ SARAH PALIN, GOVERNOR Lai~L~-78A O~ ~ tZAS 333 W. 7th AVENUE, SUITE 100 CO1~T5C' RRA'TIOl~T COl-il-II55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger P.E. BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519-6612 ,~,...~ ; Re: Northstar Fleld, Northstar Oil Pool, NS 16A /~ ~j ~ ~~~ ~ , Sundry Number: 308-196 ~-- Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrriission's petroleum field inspector at (907) 659-3607 (pager). As provided iri AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30' PM on the 23rd day following the date of this letter, or the next working day ft the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2008 Encl. ~~ ~. ,~~ ~ d~ RECEIV~~ ~ ~' b~3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ '~~~ O ~ 2O APPLICATION FOR SUNDRY APPROVAI.~laska Oil & Gas Cons. 's~slon 20 AAC 25.280 Anchorage 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ ~ Waiver ^ Othe Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 - Exploratory ^ 206-1410 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 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: NS16A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 ~ 56.46 - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 11305.92 14414 11218 NONE NON E Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/14/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name R rt Youn er -- Title Production Engineer Signature Phone 564-5392 Date 5/31/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ / l~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: VJtt`~ C~t~~~O `CC °~'V~ Q 3"\CC.S~~t- ~ ~ Gl. L'U' ~ ~ ~ +~~ ~~~'aS ~~~ Subsequent Form Required: ~® APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-~03 Revised 06/20 ~, F Su~mit in Duplicate ~ R I G1 NAL _ ~~~~ ~~~~ ~ ~oo~ NS16A 206-1410 PERF ATTACHMENT Sw Name O eration Date Perf Operation Code Meas Depth To Meas Depth Base Tvd De th Top Tvd Depth Base NS76A 4/5/08 PER 14,304. 14,319. 11,113.16 11,127.34 NS16A 4/5/08 PER 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/1/08 PER 14,299. 14,304. 11,108.44 11,113.16 NS16A 5/1/08 .RPF 14,304. 14,319. 11,113.16 11,127.34 NS16A 5/1/08 RPF 14,319. 14,339. 11,127.34 11,146.31 NS16A 5/2/08 PER 14,289. 14,299. 11,099.02 11,108.44 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SOF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SOZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u ~~ ~ PERFORATING PROCEDURE ADW rnm~^-u Well: NS16A API #: 50-029-23096-01 Date: 5/30/08 Prod Engr Robert Younger Office Ph: 5645392 Home Ph: . 677-2599 . . . .... . ........... ... Cell Ph: ............... ......... . . ... . .. 830-4920 ......................... CC or AFC: NSFLDWL76 Detail Code: Description: Ad / Re-Perforate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WBL Entries Ver 4.0 O6/eM01 H2S Level: .................................................................. None Anticipated IOR Type Work Description 800 S Dummy Gun Drift -Last Drift 4/28/08 800 E Please Perforate 30' per the below procedure. Well Objectives and Logging Notes: NS16A is a new development well at Northstar. Following a Coil Acid /Scale Inhibition treatment, the well's productivity dropped off and 15' of new perforations were added in adition to re-shooting the original 35' of perforatoins. The 50' of perforatoins shot 05/02/08 resulted in a -1000 BOPD increase in production. Unfortunately, the wells' production has dropped off again and thus the below request. The objective of the proposed ad/re-perfs is to restore the wells productivity. Please contact Bob Younger with any questions, comments, or concerns - 5645392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated perforations. Reference Log Tie in Log Add/Subtract feet ................... Log: Prim. Depth. C to the tie-in log to be on Date: 4/4/2008 depth with the reference log. Company: Schlumber~er .............................. Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 14,274' - 14,304' - 30' 6 60° 0 Ivishak Ad/Re ' 0 - - 0 ................................ ............................. ............................. ............................... ................ .................... .......................... ................... 0 ....................................................................................... ................................ ............................. ............................. ............................... ................ .................... .......................... ................... 0 ....................................................................................... Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2" Charge: 2006 PJ Desired Penetration: 18.6 Entry Hole Diam: 0.20 Is Drawdown Necessary/Desired/Unnecessary During Perforating NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Describe below how to achieve drawdown (check w/ Pad Operator to see i/necessary piping is installed) (s.g. N2 Lilt, Hardline Liff Gas, Gas Liff, Flow Well, Backllow Through Drain or Hardline) Tie into GR from annotated reference lob Tie in using: Tie into.GR character indicated in Primar~r.Depth.Control.Lo~ Minimum ID: .2:400 in Min ID Type: 4.5" x 2.875" crossover ~ 13527' 'MD 2-7/8" Liner Top: 13505' ff MD Casing Size: 2.441 in 2-7/8" Liner Est Res. Pres. ~ 14,350 MD 11100' SS 5,121 psi Last Tag: 14382' SLMD ff 4/28/2008 O/B/U - O »ao NS16A April 04, 2008 PDC GR/CCL New F~roposed ~~°°J Perforation Interval ~ .......................... 14274' M D~ to 14304' M D OWC Shot 05/02/08 Shot 04/05/08 ,~ ,, • TREE: ABB-VGI 5 1/8" 5ksi N S 16A WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" TAM Port Collar at +/-1587`MD Minimum ID = 2.875 @ 13505' 4.5" x 7" LN R TOP XO 13-3/8" EZSV @ 3282`MD 13-3/8" 68# L-80 BTC @ 3494`MD 9-5/8" EZSV @ 3670`MD 4-1/2" X Nipple @ 12159' MD 4-1 /2" Cidra Gauge @ 12180` MD 7" LINER TOP @ 10265' MD 9-5/8 47# L-80 BTC @ 10435`TMD 4.5" Tubing cut @ 11874' 7" PACKER,13 Cr @ 11880` MD 4.5" LINER TOP @ 11926` I„~D 7", 26#/ft L-80, HYDRIL 521 @ 12094` TOC @ 12100' MD Top of Squeezed Perfs @ 12304` M 4.5", 12.6#, 13Cr Vam Ace PBTD @ 12420' MD TD @ 12424' MD PERFORATION SUMMARY REF LOG: SWS-PDC LOG ON 04/03/08 ANGLE AT TOP PERF: 20° @ 14289' INITIAL PERF -CHARGE: ???? PENETRATION: ?", HOLE ??", PHASE ?? DEG. Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2" 6 14289 - 14339 O 05/02/08 2" 6 14304 - 14339 O 04/05/08 Landing Collar @ 14414' MD TD @ 14505' MD ~ DIATE REV BY COMMEMS DATE REV BY COMI1iEN'TS 06h4103 N33E ORipNAL COMPLETION 03/25/08 N33E SIDETRACK QM18/08 SRB/TLH NI11AL PERFS (04/05/08) 04H 8/08 ITI.H GLV GO? (03!27/08) 05/02/08 JLJITLH ADPB~FS 9.625", 47# HYDRIL 513/BTC-M @12574' MD 4.5" Fiber-Optic Transducer, 3.945" ID @ 13398` MD 4-1/2" X Nipple (a~ 13423' MD _ 7" x 4.5" PREMIER PACKER, 13 Cr @ 13444' MD 4-1/2" X Nipple @ 13471' MD (3.813" ID) 4-112" XN Nipple @ 13483' MD (3.725" ID) 4-1/2", 12.6#/ft 13CR80 @ 13497' 4.5" X 7" LINER TOP XO to 2.875 @ 13505` MD (Flex-Lock &ZXP) 4.5" LINER TOP @ 13685' MD (Flex-Lock &ZXP) 7", 29#/ft L-80, Hydril 521 @ 13850` 4.5", 12.6#, HYDRIL 521 L-80 @14093` TMD 2.875", 6.4#, 13Cr-80 VAM TOP 2.875", 6.4#, L-80 @ 14504` Northstar WELL: NS18 A API No: 5fl-029-23096-01 LtP Expbration (Alaska) ORIGINAL KB. ELEV = 56.46 DRLG DRAFT KB-BF. ELEV = 40.89` CB. ELEV = 15.57' -'120' (4 jts) 5-1/2" x 4-1/2" VIT (Vacuum Insulated Tubing) 4-1/2" SSSV @ 1024' MD, -1000' TVD 13-3/8" Window Cut @3274` GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4569 3976 50 MMG DMY RK 0 03/27/08 Note that fiber-optic line was terminated due to damage during space-out. Also, single control line from SSSV. 7" LINER TOP @ 12178' MD Flex-Lock Hanger and ZXP Packer • ~~ j ..~ _~' .•~ ~~~ Date 06-02-2008 Transmittal Number:92976 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (907)564-4091 Delive Contents SW Name Date Contractor Run To De th Bottom De th Descri tion STATIC TEMPERATURE / NS09 05-24-2008 PDS 1 0 13247 PRESSURE SURVEY NS09 05-24-2008 PDS 1 12629 12833 CORRELATION LOG CD-ROM -CORRELATION NS09 05-24-2008 PDS LOG /STATIC SURVEY STATIC TEMPERATURE / NS24 05-23-2008 PDS 1 0 12480 PRESSURE SURVEY NS24 05-23-2008 PDS 1 11793 12196 CORRELATION LOG CD-ROM -CORRELATION NS24 05-23-2008 PDS LOG /STATIC SURVEY PERFORATION RECORD W/ NS16A 04-30-2008 SCH 1 14200 14400 GAMMA RAY CD-ROM -PERFORATION NS16A 04-30-2008 SCH RECORD W/ GAMMA RAY MEMORY PRODUCTION NS15 05-10-2008 SCH 1 14726 15080 PROFILE CD-ROM -MEMORY NS15 05-10-2008 SCH PRODUCTION PROFILE Please Sign and Return one copy of this transmittal. Thank You, Joe. Lastufka Petrotechnical Data Center ~v~- ~yl ~ /tc3~o? BPXA AOGCC Murphy Exploration DNR ~RTR~ ~o~-o5N i~ 36~/ a~2-l ~~r ~103~' ~ 01-a tq l (0 3(06 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 David Fair Christine Mahnken Ignacio Herrera Kristin//''''~~Dirks DVIAg 1.11r Vrr~La11J1~1 ~ ~ STATE OF ALASKA ~8 ALAS~OIL AND GAS CONSERVATION COMM~ION MAY 2 1 2008 REPORT OF SUNDRY WELL OPERATIONS Alaska ®il & Gas Cons. Cammissiol 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ Anchorage Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory 206-1410 - 3. Address: P.O. Box 196612 StratlgraphlC ~' SerVICe ~ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.92 KB NS16A _ 8. Property Designation: 10. Field/Pool(s): ADLO-312799 - NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14505 feet Plugs (measured) None true vertical 11305.92 feet Junk (measured) None Effective Depth measured 14414 feet true vertical 11218 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Perforation depth: Measured depth: 14289 - 14304 14304 - 14319 14319 - 14339 = _ True Vertical depth: 11099 - 11113 11113.16 - 11127.34 11127.34 - 11146.31 = _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 13497' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S-3 PERM PACKER 13444' 4-1/2" SSSV 1024' 0 0 0 0 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: 1635 4281 0 731 Subsequent to operation: 2880 8496 0 765 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~'' Service Daily Report of Well Operations X 16. Well Status after proposed work: OiI Gas WAG (~ GINJ WINJ ~ WDSPL 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: 308-135 Contact ROBERT YOUNGER Printed Name ROBERT YOUNGER Title PRODUCTION ENGINEER Signature Phone 564-5392 Date 5/15/2008 Form 10-404 Revise 4/2006 ~~ ~,~ ~ t Submit Original Only ~ _I ~'~. `~ ~ a`v ~~ NS 16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/28/2008;"*"WELL S/I ON ARRIVAL*** (pre re-perf) =DRIFT TUBING WITH 10' x 2.130" DUMMY GUN AND SAMPLE BAILER TO ,14382' SLM (TARGET DEPTH 14339' MD). SAMPLE OF GRITTY MATERIAL '***WELL LEFT S/I, CONTROL ROOM NOTIFIED**" ', *** JOB CON'T TO 01-MAY-08"'`* "**JOB CON'T TO 2-MAY-08*"* 4/30/2008 ~ T/IA/OA = 2200 / 0 / 0 PSI PREPARING TO RIG UP E-LINE FOR PERFORATION RUN. ... 5/1/2008 ~'* JOB CON'T FROM 30-APRIL-08"** RIH WITH 2" HSD GUNS TO 14382' ,MAX OD = 2". PERF INTERVALS: 14299' - 14319', 14319' - 14339'. FLUIDS PUMPED BBLS 1 diesel 1 Total 5/2/2008 ~"" JOB CON'T FROM 01-MAY-08"" PERFORATED 14289 -14339' W/ 2" HSD 6SPF 60 DEG PHASED PJ 2006 GUNS. DEPTH CORRECTED TO SLB PDC LOG DATED 4-3-08 USING GR/CCL. ALL SHOTS FIRED. DSO NOTIFIED WELL READY TO POP WHEN PLANT IS BACK ON LINE. **'`**JOB COMPLETE'**** by BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact Joe Lastufka at {907)564-4091 Date 04-23-2008 Transmittal Number:92959 Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion VISION SERVICE FINAL MD NS16A 03-17-2008 SCH 1-5 3250 14466 LOG VISION SERVICE FINAL TVD NS16A 03-17-2008 SCH 1-5 3250 14466 LOG NS16A 02-20-2008 SCH 3 8600 12575 DENSITY CALIPER NS16A 02-20-2008 SCH 3 8600 12575 RAB IMAGES MD LOG NS16A 02-20-2008 SCH 3 8600 12575 RAB IMAGES TVD LOG CD ROM -LDWG EDIT OF MWD/LWD IN TIF FORMAT NS16A 03-17-2008 SCH WITH FINAL PDS DISPLAY NS16A 04-03-2008 SCH 1 14000 14400 CASED HOLE RESISTIVITY CD-ROM -LDWG EDIT OF REPROCESSED SFRT DATA IN TIF FORMAT WITH FINAL NS16A 04-03-2008 SCH PDS DISPLAY SLIM FORMATION NS16A 04-03-2008 SCH 1 14056 14400 RESISTIVITY TOOL CD-ROM -SLIM FORMATION NS16A 04-03-2008 SCH RESISTIVITY TOOL PERFORATION NS16A 04-05-2008 SCH 1 14200 14400 RECORD/SBHP CD-ROM -PERFORATION NS16A 04-05-2008 SCH RECORD/SBHP RESERVOIR SATURATION NS16A 04-04-2008 SCH 1 14000 14403 LOG CD-ROM -LDWG EDIT OF RST SIGMA-MODE IN TIF FORMAT WITH AVERAGE NS16A 04-04-2008 SCH AND FINAL PDS DISPLAY PERFORATION DEPTH NS16A 04-03-2008 SCH 1 0 14410 CONTROL LOG LDWG EDIT OF PDC GAMMA RAY IN TIF FORMAT WITH NS16A 04-03-2008 SCH FINAL PDS DISPLAY Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 ~ (~~ Anchorage, AK 99519-6612 ~ ~ bP BPXA WELL DATA TRANSMITTAL Date 04-23-2008 Transmittal Number:92959 MEMORY DEPTH NS16A 04-02-2008 SCH 1 13300 14408 DETERMINATION CD-ROM -MEMORY DEPTH NS16A 04-02-2008 SCH LOG ~~~~ APR ~ 5 2003 ease Sign and Return one copy of this transmittal. y, rr~~ 1 f ~1381Cd UPI YX 17C~ ~~i t~ iali~~~~•C.1~R~ Thank You, ,~~~hnr~t~~ Joe Lastufka Petrotechnical Data Center BPXA David Fair AOGCC Christine Mahnken Murphy Exploration Ignacio Herrera DNR Kristin Dirks MMS Doug Chromanski ~(~ - ly 1 c~ sa ~c~ ~~ ~c~~sy /(x/55' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 NS 16A Perforations ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Younger, Robert O [Robert.Younger@bp.com] Sent: Thursday, April 24, 2008 6:44 PM To: Maunder, Thomas E (DOA) Subject: RE: NS16A Perforations Thanks! ' `~ From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Thursday, April 24, 2008 6:00 PM To: Younger, Robert O Cc: Denis, John R (ANC); Garing, John D; Martinez, Stephen A; Nitzberg, Katie E; Siok, Jerry P; Helton, Mike D; Preble, Gary B (SAIC) Subject: RE: NS16A Perforations Robert, Submitting another 403 is not necessary. You have approval to re-shoot the existing interval. You wish to add an additional 15' of new pert based on the well's performance. Nothing further is needed. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC From: Younger, Robert O [mailto:Robert.Younger@bp.com] Sent: Thursday, Apri124, 2008 4:38 PM To: Maunder, Thomas E (DOA) Cc: Denis, John R (ANC); Garing, John D; Martinez, Stephen A; Nitzberg, Katie E; Siok, Jerry P; Helton, Mike D; Preble, Gary B (SAIC) Subject: NS16A Perforations Tom, As we discussed, with the appropriate AOGCC approval we would like to add 15' of perforations to the already approved 35' of re-perforations for NS16A. Please see attached. Please let me know if additional information is needed. Thanks! Bob Latest Proposed Pertoration Interval «NS16A Proposed Perforations 4-24-08.pdf» Approved Sund «NS16A-APPROVED-SUNDRY-308-135.ZtP» Robert Younger BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) 4l2S/2008 14200 NS16A April 04, 2008 PDC GR/CCL ,4300 with 2" 6spf PJ2006 14400 ro . nCLEI'~~; ~~-o~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR I ~ (~(j~ REPORT OF SUNDRY WELL OPERATIl~A~DOi~&~~.,,,,n ~,,_ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ StimulateQ 0 3,31~;;fio ~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~' 206-1410 3. Address: P.O. Box 196612 Stratigraphic SerVICe 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 7. KB Elevation (ft): 9. Well Name and Number: 55.92 KB - !~ 16A 8. Property Designation: 10. Field/Pool(s): ' s S ADLO-312799 ~ OIL~"Pool NORTHSTAR Field/ NORTHSTAR 11. Present Well Condition Summary: Total Depth measured 14505 feet Plugs (measured) None true vertical 11305.92 feet Junk (measured) None Effective Depth measured 14414 feet true vertical 11218 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface - 201' Surface - 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface - 3250' Surface - 2993' 4930 2270 Production 12533' 9-5/8" 47# L-80 Surface - 12574' Surface - 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' - 13850' 9210' - 10702' 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' - 14093' 10555' - 10920' 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' - 14503' 10370' - 11304' 10570 11160 Perforation depth: Measured depth: 14304 - 14319 14319 - 14339 _ _ - True Vertical depth: 11113.16 - 11127.34 11127.34 - 11146.31 _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 13497' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S-3 PERM PACKER 13444' 4-1/2" SSSV 1024' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: - - ''~ ~- ~4~;pi ~ ~ /~~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2544 2544 59 761 Subsequent to operation: 2495 5687 0 743 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: 0it Gas ~~~~, WAG ~' GINJ ~ ,, WINJ ~' WDSPL ~~ 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: 308-103 Contact ROBERT YOUNGER Printed Name ROBERT YOUNGER Title PRODUCTION ENGINEER Signature Phone 564-5392 Date 4/16/2008 Form 10-404 Revise~'04/2006 ~ ~ ~~ ~, ~ ~ ~ ~ ~ ~ ,~``l~ ~.~ Submit Original Only NS16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE'' SUMMARY 4/9/2008CTU #5. Acid Treatment. MIRU CTU. Perform BOP test -passed (State declined to witness). Makeup BHA #l with 2.00" JSN. Well flowing upon arrival. Shut in 'well and attempt to bullhead 10 bbls 60/40 mwth spear, then 2% KCI. At 37 bbls into kill, wellhead pressure locked up at 3500 psi. Begin flowing well to plant and '' RIH with CT. I'~** Job continued on WSR 04/10/2008 **" 4/10/2008 CTU #5. Acid Treatment *** Continued from WSR 04/09/2008 *** RIH with 2.00" 'JSN. Dry tag at 14,404' ctmd. Spot 2 bbls of 12% HCI with 10% L66. Initial ''breakdown resulted with a 2 bpm injectivity at 3090 psi W HP. Load well with 80 bbls of 2% KCI, then 88 bbls of 1 % XS KCI w/0.6% SafeLube, and 10 bbls 60/40 ;meth. Injected 20 bbls of 2% KCI and 23 bbls of 12% HCI with 10% L66 making 3 ;passes from 14295' to 14350'. Overdisplaced acid with 140 bbls of 2% KCI w/10% L66. When acid contacted formation, no noticable breakdown was noted, but ;injectivity increased by 0.5 bpm with same CT pressure. POOH while replacing coil voidage with diesel. RD CTU #5. Turn well over to N* control to POP. *** Job Complete *"" FLUIDS PUMPED BBLS 63 2% KCL 88 1 % XS KCI/W/0.6% SAFELUBE 65 60/40 METH 40 DIESEL 22 12% HCI WITH 10% L66 TITRATION: 11.7%, IRON <50 PPM 139 2% KCI WITH 10% L66 417 TOTAL STATE OF ALASKA ~'~~' '" ~ ALAS~OIL AND GAS CONSERVATION COMMISSION APR 1 6 2008 REPORT OF SUNDRY WELL OPERATION941aska Oil & Gas Cons. Commission ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q Other ~ nC 0(age Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory _ 206-0360 3. Address: P.O. Box 196612 Stratigraphic Ser~Ce 6. API Number: Anchorage, AK 99519-6612 50-029-23303-00-00 7. KB Elevation (ft): 9. Welt Name and Number: 55.87 RT NS11 8. Property Designation: 10. Field/Pool(s): ADLO-312808' NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14800 ~ feet Plugs (measured) None true vertical 11278.46 , feet Junk (measured) None Effective Depth measured 14711 ~ feet true vertical 11194 - feet Casing Length Size MD TVD Burst Collapse SURFACE 3865' 13-3/8" 68# L-80 44' - 3909' 44' - 3210' 5020 2270 PRODUCTION 12775' 9-5/8" 47# L-80 43' - 12818' 43' - 9487' 6870 4760 LINER 1788' 7" 26# L-80 12612' - 14400' 9309' - 10907' 7240 5410 LINER 536' 4-1 /2" 12.6# 13CR80 14264' - 14800' 10783' - 11279' 8440 7500 Perforation depth: Measured depth: 14552 - 14565 14565 - 14577 14577 - 14591 14605 - 14625 True Vertical depth: 11047 - 11058 11058 - 11069 11069 - 11082 11095 - 11114 _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 40' - 14265' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" TRM SCSSV 1021' 7" BAKER ZXP TOP PACKER 12612' 4-1/2" BAKER S-3 PACKER 14215' 4-1/2" BAKER ZXP PACKER 14258' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~ ~'~~ ~ ~ 20~~ 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: 1589 3408 1536 734 Subsequent to operation: 1735 4675 1991 734 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ~ WINJ WDSPL 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: 308-039 Contact ROBERT YOUNGER Printed Name ROBERT~OUNGER Title PRODUCTION ENGINEER Signature ~ ~ Phone 564-5392 Date 4/16/2008 Form 10-404 Revised 04 6 `~ r, Submit Original Only 1 ,- • • N511 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 4/7/2008'.. CTU #5. Acid Treatment. MIRU CTU. InterACT publishing. Complete BOP test - Passed. Shut well in. Load well down backside with 10 bbl spear of 60/40 methanol 'followed by 150 bbls of 2% KCL, 90 bbls of 1 % XS KCL w/ SafeLube, and 15 bbls of 'diesel. RIH with 2.5" JSN. Dry tag down at 14645' ctmd. PUH. PU @ 14636' ctmd. 'Weight at 34k#. Pump 40 bbls of 12%HCI with 10% L66. Displace acid with 150 bbls of 2% KCI with 10% L66. Reciprocate perf interval from 14540' to 14630' ctmd with 4 passes. At 20 bbls of acid into perforations, allow acid to soak for 10 minutes. '. ', No obvious pressure breaks were observed during the acid stage. WHP slowly !increased during over displacement of acid. to a maximum of 1440 psi. POOH ' :.pumping diesel into top of wellbore to replace CT discplacement. Initial injectivity: 1.5' bpm C 1002 psi (2% KCI). Final injectivity: 1.5 bpm @ 1369 psi (after 145 bbls of '; 2% KCI w/10% L66 in formation). '*** Job continued on WSR 04/08/2008 **" 4/8/2008 CTU #5. Acid Treatment *** Continued from WSR 04/07/2008'`*" Finish POOH while !replacing CT displacement with diesel. Total diesel cap in well at 55 bbls. RDMO :CTU. Total soak time on well at 4.5 hours. Notify control room of flowback volumes. 'Final T/I/O = 559//0/0. """ Job complete """ ', ID SUMMARY 155 bbls of 2% KCI 90 bbls of 1 % XS KCI w/0.6% SafeLube 55 bbls of 60/40 meth 38 bbls of Diesel 40 bbls of 12% HCI w/ 10% L66 (titration: 11.8%, iron <50 ppm) 150 bbls of 2% KCI w/ 10% L66 528 BBLS TOTAL FW: NS16A Re-Perf Sundry Maunder, Thomas E (DOA) Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Wednesday, April 16, 2008 10:53 AM To: 'Younger, Robert O' Cc: Preble, Gary B (SAIC) Subject: RE: NS16A Re-Perf Sundry Bob, Thanks for the update. Not a problem on the processing. If we know there is a "hurry" we can sometimes move applications on quickly. I hope the well continues to perform. Tom Maunder, PE AOGCC ~~~_ ~ ~1 1 From: Younger, Robert O [mailto:Robert.Younger@bp.com] Sent; Wednesday, April 16, 2008 10:01 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAIC) Subject: FW: NS16A Re-Perf Sundry Tom, I wanted to thank you for the quick turnaround on the NS16A reperf sundry. t also wanted #o update you on the well's current status. Over the weekend the well cleaned up from the acid /scale inhibition treatment and has returned to the pre-#reatment production trend. We will likely still pursue the reperf rrequested in the sundry, but at a later date. Please let me know if additional information is needed. Thanks again! Bob From: Younger, Robert 0 5eot: Friday, April 11, 2408 10:57 AM To: 'Maunder, Thomas E (DOA)' Cc: Preble, Gary B (SAIC) Subject: NS16A Re-Perf Sundry Tom, Per our conversation, a courier will deliver a sundry for re-perforating NS16A today. Following a Goil Acid /Scale Inhibition treatment, NS16A's productivity has dropped off. The objective of the proposed re-parts is to restore the wells productivity. With the appropriate sundry approval, we could be ready to per#orm the re-perforation early next week. Please let me know if any additional information is needed. Thanks! Bob Robert Younger BP Exploration, Alaska 4/16/2008 ~' G(~,~,r~c'o4~ ~, RECEIVES ,(1~ STATE OF ALASKA ~ ~ APR 1 ~ 2008 ~j`f ALASKA OIL AND GAS CONSERVATION COMMISS ON ` V APPLICATION FOR SUNDRY APPROVAL~aska Oil & Gas Cons. Commissio 20 AAC 25.280 Anchn~~~,~ ~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ Waiver Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Re-pert Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: t7$ BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ \ 206-141 ~~•~ • 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 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: NS16A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 56.46 ~ NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 11305.92 14414 11218 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surtace 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 14304 - 14339 11113 - 11146 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/25/2008 OIL Q ~ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the~regoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Cfert Y er Title Production Engineer Signature Phone 564-5392 Date 4/11/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~' ear n ce ^ l a ^ Location C BOP Test ^ Mechanical Integrity Test Plug Integrity ^ l l • ~ ~ ° ' ~ Other: i-.1k, \\ ~~(°~~ ~~v`~ i''\.Cr V~-~p~ ~ CT-v ~~`,c7~J ~ ~~~ ~ Subsequent Form equired: ~-•` APPROVED BY ~~ ~ ~% ~I ddd A roved b~ COMMISSI E THE C I S Date: Pp Y Form 1 -4 3 Revised 06/2006 ~ R ~ ~ ~ ~ A ~ Submit in Dup'cate~' `~•~~ ..a..~.~ Well: NS16A ................... Date: 4!11/08 CC w AFC: NSFLDWLI6 Description: Re-Perforate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PERFORATING PROCEDURE API ~: 50-029-23096-01 Prod Engr Robert Younger Office Ph: ..................................................... Home Ph: CeN Ph: DMail Code: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WBL EMNea NA v., ~.o odwroi 5645392 .. . . . . . . . . . . . . . . . . . . . . . . . . 677-2599 . . . . . . . . . . . . . . . . . . . . . . . . . . . 830-4920 IOR Type Work Description 1000 S Sbpe Discretion -Dummy Gun Drift -Coil Add Wash 4/10/08 1000 E Please Perforate 35' per the below procedure. Well Obiectivas and Loaaine Notes: NS16A is a new development well at Northstar. Following a Cal Acid /Scale Inhibition treatment, the well's productivity has dropped off. The objective of the proposed t/ re-perfs is to restore the wells productivity. Please contact Bob Younger to conflrrn tie-in. Please contact Bob Younger witlt arty questlorts, comments, or - 5645392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated perforations. Log: Prim Depth C Date: 4/4/2008 Company: Schlumberger Depths (from-to) Dsptha (from-to) Feet SPF 14,304' - 14,339' - 35' 6 Gas Jetting Expected? No At what Dspth? .................................... Requested Gun Size: 2" Charge: 2006 PJ Desired Penetration: 18.6 Is Drawdown NecesserylDesiredNnnetxasary During Perforating Describe 6ebw how ro achieve drawdown (check w/Pad Operator ro see it necessary piping b /nsleNed/ (e.g. N2 Lltt, NanAkle LMGp, see LMC Fbw War, BacMlpw Thrpgh OreM aHeniWwJ Tie into GR from annotated reference log Tie in using: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Minimum ID: 2.400 in Min ID Type: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7/8" Liner Top: 13505' tt MD Casing Size: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Est Res. Pres. O Last Tag: 14,404 tt cLnd Coil Acid Treatment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ........................_H2S.L~vel ................................. None Anticipated N/A ................ EMry Hole Diem: 0.20 Tie into GR character indicated in Primary Depth Contra Log 4.5" x 2.875" crossover ® 13527' 'MD 2441 in 2-7/8' Liner 14,350 MD 11100' SS 5,121 psi Well: NS16A Perforation Summary Date: API a: 50-029-23096-01 On-Site Prod Engr: PBTD General Comments: Depths Balance Referenced to BRCS Feet SPF OriertL Phasing O/B/U - .~_- O/B/U - O/e/U - .._....._.___...._.. ___.~-..__ ~._...___~_ ~V._ ~- --.~_.~ O / B / U _...-------- - ---~- -~ ~~-- --- ---- ----- O/B/U - OO OO O Zone Apsrf/Repert NS16A PERFORATION DEPTH CONTROL LOG g SFRT/GR/PRESS/TEMP `° a 03-APRIL-2008 o Apri 104, 2008 PDC GR/CCL ~ ~ ~ 1198.71' FSL & 644.61' FEL Efev.: K.B. 56.46 ft d ~ J ¢ ut ~ AT SURFACE G.L. ~ D F ~ = r~ d a ~ . . O O °~' in w ~ Permanent Datum: MEAN SEA LEVEL Elev.: 0.00 ft z z r z a m ~ Log Measured From: KELLY BUSHING 56.46 ft above Perm. Datum ~ c o c m Drilling Measured From: KELLY BUSHING ~ :~ a ° ~ ~ m E APl Serial No. Section Township Range m° i~ ~ ~ U 50-029-23096-01 11 13N 13E L o in Date 3- r-2008 Run Number ONE Fluid Level wyyn~ vn ovuvn~ Unit Number Recorded ~nrr~o~~o. 14412 ft 14410 ft 0 ft sEA wA 8,6 ibml~ STRING 3.500 in 2.$75 ir1 6.4 ibm/ 13CR-8t 13505 ft 14505 ft I i :30 Location 2128 PRUDHOE BAY a oun cn~rr ia2oo NS16A April 04, 2008 PDC GR/CCL ,~ ' to 14339' ~acoo Flrst R~Mn Cable S~eN~CSL (F/MN) 200 7D :omputed CCL ICp.C) nn 1 ~ OPEN 1 Dente ~ ~ ORIGINAL KB. ELEV = 56.46 TREE: ABB-VGI 5 1/8" 5ksi N S 16A KB-BF. ELEV = 40.89' WELLHEAD: ABB-VGI 13-5/8" DRLG DRAFT Multibowl 5ksi CB. ELEV = 15.57' 13 3/8" TAM Port Collar I I I I I I ~120' (4 jts) 5-1/2" x 4-1/2" VIT (Vacuum Insulated Tubing) at +/-1587'MD lF------il 4-1/2" SSSV @ 1024' MD, --1000' TVD Minimum ID = 2.875 aG~ 13505' 13-3/8" Window Cut @3274' 4.5" x 7" LNR TOP XO 13-3/8" EZSV ' ~ ~\\ ~\4-1/2" GLM @ 4568' MD 3.833" ID @ 3282'MD I I 13-3/8" 68# L-80 BTC Note that fiber-optic line was terminated @ 3494'MD due to damage during space-out. Also, single 9-5/8" EZSV control line from SSSV. @ 3670'MD 4-1/2" X Nipple @ 12159' MD 9.3 PP9 4-1/2" Cidra Gauge @ 12180' MD KWF 7" LINER TOP @ 12178' MD Flex-Lock Hanger and 2:XP Packer 9.625", 47# HYDRIL 513/BTC-M @12574' MD " Fiber-Optic Transducer, 4.5 3.945" ID @ 13398' MD 7" LINER TOP @ 10265' MD 4-tn° X Nlpple ~ 13423' MD 7" x 4.5" PREMIER PACKER, 9-5/8 47# L-80 BTC @ 10435`TMD 13 Cr @ 13444' MD 4-1/2" X Nipple @ 13471' MD (3.813" ID) 4.5" Tubing cut @ 11874' 4-1/2" XN Nipple @ 13483' MD (3.725" ID) 7" PACKER,13 Cr @ 11880' MD 4 113497' 6#/ft 13CR80 4.5" X 7" LINER TOP XO to 2.875 4.5" LINER TOP @ 11926' MD @ 13505' MD (Flex-Lock & ZXP) 4.5" LINER TOP @ 13685' MD 7", 26#/ft L-80, HYDRIL 521 @ 12094' (Flex-Lock 8~ ZXP) 7", 29#/ft L-80, Hydril 521 @ 13850' 4.5", 12.6#, HYDRIL 521 L-80 TOC @ 12100' MD @14093' TMD iF Top of Squeezed Perfs @ 12304' MD 2.875", 6.4#, 13Cr-80 VAM TOP 4.5", 12.6#, 13Cr Vam Ace 'k PBTD @ 12420' MD TD @ 12424' MD Landing Collar (~ 14414' MD TD ~ 14505' MD ~ 2.875", 6.4#, L-80 @ 14504' DATE REV BY CONIbEMS DATE REV BY COMrFNTS 06H4J03 N33E ORIGINAL COMPLETION 03/25/08 N33E SIDETRACK NOrthStaf 1NH.L: NS16 A API No: 50-029-23096-01 BP Exploration (Alaska) NS 16A Re-Pert Sundry Page 1 of 1 Maunder, Thomas E (DOA) From: Younger, Robert O [Robert.Younger@bp.comj Sent: Friday, April 11, 2008 10:57 AM To: Maunder, Thomas E (DOA} Cc: Preble, Gary B (SAIC) Subject: NS16A Re-Pert Sundry Tom, Per our conversation, a courier will deliver a sundry for re-perforating NS16A today. Following a Coil Acid /State Inhibition treatment, NS16A's productivity has dropped off. The objective of the proposed re-perfs is to restore the welts productivity. With the appropriate sundry approval, we could be ready to perform the re-perforation early next week. Please let me know if any additional information is needed. Thanks! Bob Robert Younger BP Exploration, Alaska NorthstarlBadami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) younger2@bp.com 4/11/2008 C7 .., ALASSA OIL A1~TD GAS COI~SER'QA7`IO1~T COMi~IISSIOI~T Robert Younger Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar FIe1d, Northstar Oil Pool, NS 16A Sundry Number: 308-135 Dear Mr. Younger: SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. /,~ Chair DATED this~~day of April, 2008 Encl. by Date 04-03-2008 Transmittal Number:92952 RE~E11/E APB ~ ~ ~0~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. ~ ~` ~'~ ~~~~ C~mmissiorl ~r,;x,.~.. ~~~ If you have anv questions. please contact Joe Lastufka at (9071564-4091 Delive Contents SW Name Date Contractor Log Run Top De th Bottom De th Lo T e NS16A 03-17-2008 BPXA 1 0 14505 SURVEY REPORT D Ple se Sign and Return one cop of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC Murphy Exploration DNR MMS Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski ~~~- l~fl , v' v~~ STATE OF ALASKA ~O ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 8 2 ~'~ APPLICATION FOR SUNDRY APPROVAL ~n oor. ~~ ~Rn ,i~t~k~ Oil & Gas Cons. Commission 1. Type of Request: Abandon Suspend Operational shutdown Perfor`~ ~~~~g Othe Alter casing^ Repair well ^ Plug Perforations^ Stimulate ~~ Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 206-1410' 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23096-01-00 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: NS16A - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 ' _ 56.46 - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14505 11305.92 ~ 14414 11218 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 201' 20" Surface 201' Surface 201' 4260 2590 Surface 3208' 13-3/8" 68# L-80 Surface 3250' Surface 2993' 4930 2270 Production 12533' 9-5/8" 47" L-80 Surface 12574' Surface 9565' 6870 4760 Liner 1072' 7" 29# L-80 12178' 13850' 9210' 10702 7240 5410 Liner 408' 4-1/2" 12.6# L-80 13685' 14093' 10555' 10920 8430 7500 Liner 1024' 2-7/8" 6.6# L-80 13479' 14503' 10370' 11304 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A - N/A N/A - N/A 4-1/2" 12.6# 13Cr80 Surface - 13497' Packers and SSSV Type: 7"x4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft): 13444' 4-1/2" SSSV 1024' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/11/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Rob Younger Title Production Engineer Signature Phone 564- 5392 Date 3/28/2008 COMMISSION USE ONLY i n /~ Number: V ~ s ~ v Sund it ve Conditions of approval: Notify Commission so that a representat ry may w ness est ^ Mechanical In Plug Integrity ^ BOPT tegrity Test ^ Location Clearance ^ ' Other: ~©0~ ~~~ ~~ \J~ C ~~5~' Subsequent Form Required: W . APPROVED BY b COMMISSIONER THE COMMISS O Date: Approved y: tfh Form 10-403 Revised 06/2006 ~ ~-~ • + ~ No portion of the beloork should be performed w/out flaking time to ensure ~~ No Accidents, o harm to People, and No damage o the Environment To: .Jerry Bixby/Clark Olsen -Well Operations Supervisor March 27, 2008 From: Robert Younger- Northstar Production Engineer subject: NS16A CTU Acid Treatment Est. Cost: $150 M AFE NSFLDWLI6 Est. IOR: 1000 BOPD Please perform a coil tubing acid treatment on NS16A per the below procedure. T ® IOR PR N DSWL AFE Job Descri tion S 1000 NS16A NSFLDWLI6 Drift to TD - Slo a Discretion C 1000 NS16A NSFLDWL16 Pump Acid Treatment - Treatment may be adjusted based on production data and the erforation interval. Current Status: New Well Last Test: No Production Data Max Inclination: 52.5° at 7,169' md; ~20° at Perfs Max Dog Leg: 8.6 at 3274' MD Perforations: TBD Minimum ID: 2.441" 2-7/8" liner starting C~1 13,505' and Last TD tag: Drift Request on WBL Last Downhole Op: Rig ran completion Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP: Anticipate 5,100 psia ~ 11,100 ft ss NS16A is a new development well at Northstar. Based on the historical scale issues at Northstar, the below acid/scale inhibition treatment is proposed to stimulate the well and inhibit against scale formation. The treatment may be adjusted based on production data and the pert interval that is selected. Please contact Bob Younger with any questions, comments, or concerns - 564- 5392 (w); 830-4920 (c); 677-2599 (h). Procedure Pre-job planning is essential to the successful delivery of this procedure due to the simultaneous operations and logistical issues associated with working on the Northstar Island. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. Please do not filter fluids that contain L66. All filtering should be performed before the addition of the L66 scale inhibitor to insure the inhibitor does not plate out in the filters. Please do not add friction reducer to water that will contact the formation due to formation plugging issues. No portion of the belork should be performed w/out ftaking time to ensure ~ k No Accident , o harm to People, and No damag o the Environment Please avoid contacting L66 with methanol or seawater -these fluids will cause premature precipitation of the L66 scale inhibitor and jeopardize the objectives of this procedure. Prep Work: 1. Mobilize coil unit, pumps, tanks and acid transport to Northstar. Order out necessary volume of seawater, 2% KCL, acid, and diesel. Please review: Alaska Wells Group Rigless Operations Manual: Coiled Tubing Operations Section: CTU Operations at Northstar Island DRIFT WITH SLICKLINE: Slope discretion 01/04/08: 2. RU slickline. 3. RIH with slickline to TD. Note if scale is encountered. COIL TUBING ACID/SCALE INHIBITION TREATMENT: 4. MIRU. 5. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 6. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 7. PT Dowell surface lines to 5000 psi. 8. Bullhead kill with filtered 2% KCI (volume to top pert is 221 bbls). Please leave a 50 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 9. RIH with jetted nozzle (min ID = 2.441 "). Drift to below perforations to insure no obstructions exist. 10.Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 25 bbls Acid w/ 10% L66 b) 140 bbls 2% KCI w/ 10% L66 (45 bbls provides 5' radial displacement assuming 40' of perfs, but 140 bbls required to meet L66 scale inhibitor required volume) ~ '~ No portion of the belo~ork should be performed w/out fi eking time to ensure No Accidents,'iNo harm to People, and No damagethe Environment Please do not POOH until the total over-flush volume has been pumped in order to reduce the chance of stirring-up solids that could plug the perforations. Ensure well has a 50 bbls diesel cap for an under-balanced flowback. Coil Treatment of 12% HCL Acid to contain: 10% L66 Scale Inhibitor 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer Note: Acid strength fo be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. 11. Shut well in for 4 hours after injection to allow scale inhibitor to precipitate. 12. RD Schlumberger. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to Robert.Younger@ bp.com. Flowback Procedure: 13. After the 4 hour shut-in, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 447 bbls (Tubing 210 bbl + Treatment 165 bbl + Flowline 72 bbl). After clean-up, divert back to the plant and get 2 6-hour tests. 14. Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. Procedure Contacts: Robert Younger WK: 564-5392 H M: 677-2599 Cell: 830-4920 ~- ' TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" TAM Port Collar at +/-1587'MD -120' (4 jts) 5-1/2" x 4-1/2" VIT (Vacuum Insulated Tubing) 4-1/2" SSSV @ 1024' MD, -1000' TVD 13-3/8" Window Cut @3274' 13-3/8" EZSV @ 3282'MD 13-3/8" 68# L-80 BTC @ 3494'MD 9-5/8" EZSV @ 3670'MD 4-1l2" X Nipple @ 12159' MD 4-1/2" Cidra Gauge @ 12180' MD 4-1/2" GLM @ 4568' MD 3.833" ID 9.3 PP9 KWF Note that fiber-0ptic line was terminated due to damage during space-out. Also, single control Tine from SSSV. 7" LINER TOP @ 12177' MD Flex-Lock Hanger and ZXP Packer 7" LINER TOP @ 10265` MD 9-5/8 47# L-80 BTC @ 10435'TMD 4.5" Tubing cut @ 11874' 7" PACKER,13 Cr @ 11880' MD 4.5" LINER TOP @ 11926' MD 7", 26#/ft L-80, HYDRIL 521 @ 12094' 9.625", 47# HYDRIL 513/BTC-M @12575' MD X4.5" Fiber-Optic Transducer, 3.945" ID @ 13398' MD 4-7/2" X Nipple ~ 13422' MD _ 7" x 4.5" PREMIER PACKER, 13 Cr @ 13444' MD 4-1/2" X Nipple ~ 13471' MD (3.813" ID) 4-1/2" XN Nipple (~ 13483' MD (3.725" ID) 4.5" X 7" LINER TOP XO to 2.875 13505' MD (Flex-Lock &ZXP) 4.5" LINER TOP @ 13685' MD (Flex-Lock &ZXP) 7", 29#/ft L-80, Hydril 521 13848' TOC @ 12100' MD Top of Squeezed Perfs @ 12304' MD 4.5", 12.6#, 13Cr Vam Ace PBTD @ 12420' MD TD @ 12424' MD Landing Collar ~ 14414' MD TD Q 14505' MD ~ GATE REV BY 03!27/08 PMH 4.5", 12.6#, HYDRIL 521 L-80 @14093' TMD 2.875", 6.4#, 13Cr-80 VAM TOP 2.875", 6.6#, L-80 STL Below Landing Collar No-thstar WH.L: NS16 A API No: 50-029-23086-01 ~ EXploration (Alaska) ~ ORIGINAL KB. ELEV = 56.46 NS16A Com ~@t~otl KB-BF. ELEV = 40.89' P CB. ELEV = 15.57' ,4 ~ ~ E j ~ ~ ~ ~ ~..- j ~ J SARAH PALIN, GOVERNOR 1~Lt>•-7~A OII< ~ ~ 333 W 7th AVENUE, SUITE 100 CO1~T5ERQA7'IO1~T COMI~II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska.) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A Sundry Number: 308-103 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2nd day of April, 2008 Encl. NS 16A Status ~ • Page 1 of 1 Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 07, 2008 7:36 AM To: Regg, JamesB (DOA) Subject: FW: NS16A Status FYI From: Hanson, Paul [mailto:Paul.Hansoni@bp.com] Sent: Thu 3/6/2008 10:51 AM To: Maunder, Thomas E (DOA) Subject: NS16A Status Tom, Just to let you know where we are with NS16A, we stuck the 7" liner 250' high in the Kingak while reaming to bottom. The plan forward is to cement the liner in place, drill out and clean up the hole down to the Sag and run and cement a 4-1/2" liner. From there, we'll drill out using a motor and 3-3l4" x 4-1/4" bi-center bit and run an cement a 2-7/8" liner. Just wanted to keep you in the loop. Best Regards, Paul Hanson 3/?/2008 ~UC~ _/~~ ~ FW: NS16A Status Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, March 12, 2008 10:03 AM To: 'Hanson, Paul' Subject: RE: NS16A (206-141) Status Paul, Thanks for the update. Nothing further is needed. will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansoni@bp.com] Sent: Wednesday, March 12, 2008 9:57 AM To: Maunder, Thomas E (DOA) Subject: FW: NSi6A Status Tom, Page 1 of 1 As a followup to the a-mail sent on March 6, on NS16A we have cemented the 7" as stated below, cleaned out the under-reemed hole to TSAG, and have run and cemented a 4-1/2" liner. At present, we are running a 7" ZXP liner tie-back packer and seal assembly due to concerns about the mechanical condition of the packer run with the 7" liner. After setting this and testing the wellbore to 4200 psi (w/9.3 ppg Flo-Pro in the hole), we will go in with our 3-3/4" drilling assembly (no bi-center) and drill to TD as planned below. Targets and directional plans remain the same. Best Regards, Paul Hanson From: Hanson, Paul Sent: Thursday, March 06, 2008 10:52 AM To: 'Maunder, Thomas E (DOA)' Subject: NS16A Status Tom, Just to let you know where we are with NS16A, we stuck the 7" liner 250' high in the Kingak while reaming to bottom. The plan forward is to cement the liner in place, drill out and clean up the hole down to the Sag and run and cement a 4-1/2" liner. From there, we'll drill out using a motor and 3-314" x 4-1/4" bi-center bit and run an cement a 2-7/8" liner. Just wanted to keep you in the loop. Best Regards, Paul Hanson 3/12/2008 NS 16A Status Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, March 08, 2008 5:46 AM To: Regg, James B (DOA) Subject: RE: NS16A Status Page 1 of 1 I was going to ask him for a little more detail about this. Getting stuck short activates the 4-1I2" contingency. While a sundry is certainly possible, I don't think it adds much value. We {ikely won't refuse it. They are proceeding along the same track, although in smaller hole. from: Regg, James B (DOA) Sent: Fri 3/7/2008 12:51 PM To: Maunder, Thomas E (DOA) Subject: RE: NS16A Status Doesn't this change require a 10-403? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Maunder, Thomas E (DOA) Sent: Friday, March 07, 2008 7:36 AM To: Regg, James 6 (DOA) Subject: FW: NS16A Status FYI From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Thu 3/6/2008 10:51 AM To: Maunder, Thomas E (DOA) Subject: NS16A Status Tom, Just to let you know where we are with NS16A, we stuck the 7" finer 250' high in the Kingak while reaming to bottom. The plan forward is to cement the liner in place, drill out and clean up the hole down to the Sag and run and cement a 4-1/2" finer. From there, we'll drill out using a motor and 3-3/4" x 4-1/4" bi-center bit and run an cement a 2-7/8" liner. Just wanted to keep you in the loop. Best Regards, Paul Hanson 3/12/2008 BOPE Test Pressure - 7" liner interval Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 25, 2008 10:45 AM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: BOPE Test Pressure - 7" liner Interval-NS-16A (206-141) Thanks Paul. Testing to the reduced pressure of 4000 psi is acceptable. Call or message with any questions. Tom Maunder, PE AOGCC Page 1 of 2 From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Monday, February 25, 2008 10:20 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: RE: BOPE Test Pressure - 7" liner Interval Tom, With the reduced gradient the maximum anticipated surface pressure is 3927 psi. The 0.12 psi/ft gradient that I used is a consequence of the "richness'° of the gas. Please let me know if this is still acceptable. Best Regards, Paul Hanson From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 25, 2008 9:53 AM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: BOPE Test Pressure - 7" liner Interval Paul, Good news on the progress. I know the pressure difference may be small, but what does MASP calculate to with 0.10 psi/ft gradient? Lowering the test pressure should not be an issue, but 1 do need to know the other value. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto:Paul.Hansonl@bp.com] Sent: Monday, February 25, 2008 9:50 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: BOPE Test Pressure - 7" liner Interval Tom, We have successfully cased and cemented our 12-/14" interval to 12,575'. Our next interval is from the 2/2512U08 BOPE Test Pressure - 7" liner Irval Page 2 of 2 Miluveach to the top of the Sag. Maximum anticipated surface pressure with a full column of gas (0.12 psilft) to surface is 3,710 psi. Our permit was written for a S,OOOpsi BOP test pressure. In the interest of safety, we request permission to test our 7" rams against a #es# joint to 4,000 psi for the liner run. Please call ore-mail with any questions. Best Regards, Paul Hanson (907) 564-4195 Office (907) 360-0388 Cell 2/25/2008 BOPE Test Pressures - NS 16A• Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 13, 2008 2:45 PM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: 80PE Test Pressures - NS16A (206-141) Paul, I concur with your plan. 3500 psi should be sufficient based on the MASP. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paul [mailto;Paui.Hansoni@bp,com] Sent: Wednesday, February 13, 2008 2:40 PM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: FW: BOPE Test Pressures - NS16A (205-141) Tom, Page 1 of 2 1 have attached our a-mail trail from several weeks ago concerning BOP test pressures as a point of reference. Our current situation is that we are drilling 12-1/4" hole after setting a 13-3/8" EZSV, a whipstock and milling a window in accordance with our previous communications. Prior to drilling, after changing out rams we tested BOPs to 5,000 psi as stated in our Drilling Permit. After TD of the 12-1/4" interval, we will install 9-518" rams in order to run our long-string. The Maximum Anticipate Surface Pressure assuming an influx from the KUP C (full column of gas with gradient of 0.12 psi/ft to surface) is 3317 psi. Due to safety concerns we would like to test the 9-5/8" rams against a test joint to 3500 psi, rather than the 5,000 psi. Please let me know if this is acceptable. Best Regards Paul Hanson ODE - Northstar Fro sunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Mon February 04, 2008 12:07 PM To: Hanson, Pau Cc: Kara, Danny T Subject: RE: BOPE Test Pressur S16A (206-141) Paul, Proceeding as described is appropriate. As we ,given that the well waslis plugged deep and pressure tested, testing to 3500 psi was not inapp ate. As furthe ~ cussed, you are free to request a reduced BOP test pressure for similar situations re the deep well section ha en plugged and successfully pressure tested. Call or message wit y questions. Tom Maunder, PE AOGCC used on where the operations presently are, the wellbore reference used by the Commiss ould be NS 16 (202-127). By convention, the redrill is not considered to "begin" until the window is milled. 2/13/2008 Northstar - NS 16A i ~ Maunder, Thomas E (DOA) Page 1 of 2 From: Kara, Danny T [Danny.KaraQbp.com] Sent: Thursday, February 07, 2008 8:51 AM To: Maunder, Thomas E (DDA} Subject: RE: Northstar - NS16A (206-141), NS16 (202-127) Thanks Tom. From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Thursday, February 07, 2008 8:45 AM To: Kara, Danny T Subject: RE: Northstar - NS16A (206-141), NS16 {202-127} Dan, It is acceptable to proceed with the installation of the big bridge plug. Tom Maunder, PE AOGCC From: Kara, Danny T [mailto:Danny.Kara@bp,com] Sent: Thursday, February 07, 2008 8:42 AM To: Maunder, Thomas E (DOA) subject: FIN: Northstar - NS16A (206-141), NS26 (202-127} Tom, We are unable to fish out the last 100' of 9-5/8" below the 13-3/8" shoe. The i3-3/8" shoe is at 3404' MD. vve successfully removed 9-5/8" down to x485' md, 9' inside the shoe. vJe made the next cut at 3600' MD, 106' below the 13-3/8" shoe. We attempted to jar/circulate and could not move pipe or establish circulation - we injected i6 bbis of 9.3 fluids away at n80 psi, thru the cut. As Paul describes below, there is a tested 9-5/8" bridge plug at 3670' MD. You state below that it would be satisfactory to install a i 3-3i8" plug to abandon the hiS i n weilbore. ~"Ve would like to exercise that option and whipstock out the 13-3/8". However, there is now a cut in the 9-5/8" (3600') and that cut will be between the 9- 518" and 13-3/8" bridge plug. This is a bit different than Paul's scenario. C~uestion - Is it still acceptable to install the 13-3/8" plug for proper abandonment? There appears to be reasonable cement outside the 9-5/8" - we could not establish circulation. I'll call you to discuss. Thanks Dan From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Monday, February 04, 2008 12;11 PM To: Hanson, Paul Cc: Kara, Danny T Subject: RE: Northstar - NS16A (206-141), NS16 {202-127} 2/7/2008 Northstar - NS 16A Maunder, Thomas E (D4A) From: Maunder, Thomas E {DOA) Sent: Monday, February 04, 2008 12:11 PM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: Northstar - i!s'1<6lt f2fl6~-14t), NS16 (202-127) Page 1 of 1 Paul, Based on the information provided, if you are unable to recover the 9-5/8" casing to the below the 13-318" shoe setting the 13-38/" retainer and testing it as described in conjunction with the deeper plugs will satisfactorily abandon the NS16 wellbore. Call or message with any questions. Tom Maunder, PE AOGCC From: Hanson, Paui [mailto:Paul.Hansonl@bp.com] Sent: Monday, February 04, 2008 10:47 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: Northstar - NS16A Tom, Pursuant to our conversation on Friday, I will describe our current situation at Northstar on NS16A and our thoughts as we move forward. As you know, NS16A is a planned cut-and-pull sidetrack which salvages the surface easing and the slot in order to complete a new wefil at a bottom-hole location with better isolation from gas. Our plans are to cut the 9-5/8" casing approximately 100' below the surface casing shoe at 3494' MD, leaving an EZSV below the stub and setting a cement kick-off plug. This plan n~quires us to cut 9-5/8" down to about 3640'. The EZSV has been set at 3670' and pressure tested to 2000 psi and weight tested to 10K-tbs. Currently, we have cx.it and pulled down to 2449' and our latest cut was made at 2611' MD. We expect to know whether this section "pulls" later today. A USIT log run conducted before starting the cut-i3~-pull indicates cement stringers as we get deeper, with significant cement in the vicinity of the 13-3/8" shoe, so we expect the fishing to get more difficult from this point forward. Also, it was known before we moved on NS16 that we had no infectivity down the OA. Therefore, we are contemplating cutting down to approximately 3040' MD, setting an EZSV in the 13-3/8", pressure and weight testing this, and then setting a whipstock and exiting the 13-3/8". There is a good sand zone at this depth for kicking off. Our base plan is still to sidetrack off the cement plug, but, if this operation reaches a point of diminishing returns we would like to know if AOGCC would regard the tested cement plug across the perfs, the tested bridge plug in the 9-518" and the tested 13-318" plug and no infectivity down the OA are adequate abandonment of the NS16 wellbore. Thank you for your consideration. Best Regards, Paui Hanson 214/200$ BOPE Test Pressures - NS 16A~ Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: Monday, February 04, 2008 12:07 PM To: 'Hanson, Paul' Cc: Kara, Danny T Subject: RE: BOPS Test Pressures - NS16A (2fl6-14t) i ~5~~ ~a~~-`a~ Page 1 of 1 Paul, Proceeding as described is appropriate. As we discussed, given that the well was/is plugged deep and pressure tested, testing to 3500 psi was not inappropriate. As further discussed, you are free to request a reduced BOP test pressure for similar situations where the deep well section has been plugged and successfully pressure tested. Call or message with any questions. Tom Maunder, PE AOGCC PS: Based on where the operations presently are, the wellbore reference used by the Commission would be NS 16 (202-127). By convention, the redrill is not considered to "begin" until the window is milled. From: Hanson, Paul [mailto:Paul.Hansoni@bp.comj Sent: Thursday, January 3i, 2008 11:24 AM To: Maunder, Thomas E (DOA) Cc: Kara, Danny T Subject: BOPE Test Pressures - NS15A Tom, I am writing in follow-up to our conversation this morning. Early this morning, in preparation for pulling our 9-5/8" casing on NS16, our rig team swapped rams to 9-518" and tested the rams against a test joint to 3500 psi. Our sundry permit stipulates that BOPE be tested to 5000 psi. This came to light in our morning call, and I called you thereafter. We are currently pulling 9-5/8" down to our first cut at 1916'. Our next BOP test is an February 2nd, so I propose that we continue operations until our next BOP test, and, on February 2nd, resume testing at the permitted pressure. As you are aware, the NS16 perforated interval has been abandoned with -184' of 15.8# Class G cement above the uppermost pert which has been pressure tested. We also have an EZSV set, pressure tested and weight tested with 10,000# at 3670'. The annulus was pressure tested, and the entire wellbore has been swapped 9.3 ppg KlNF. We are operating in a mechanically sound wellbore. Sincerely, Paul M. Hanson 2/4/2008 2008 Northstar Drilling Plans Page 1 of ~ • 1r Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 15, 2008 8:06 AM To: Kara, Danny T Subject: RE: 2008 Northstar Drilling Plans ~~~ ~- t Hi Dan, Thanks for the update. It appears from your note on NS16 and 16a that the sundry for the activities prior to drilling is also in place. Good luck, Tom Maunder, PE AOGCC From: Kara, Danny T [mailto:Danny.Kara@bp.com] Sent: Monday, January 14, 2008 4:54 PM To: Maunder, Thomas E (DOA); Monkelien, Kyle (MMS) Cc: Crane, Lowell R Subject: 2008 Northstar Drilling Plans Tom/Kyle, I thought I'd send you guys an update of the drilling plans for Northstar this year. The quick summary is sidetrack NS16a and finish NS34. NS33 will be deferred until the '09 ice road season. We're actively building ice to the island - we need sufficient ice road thickness to support Schlumberger's cementer, before we can start any openhole drilling. At this time we're estimating about Jan 26tr' far heavy equipment travel on the ice road. We plan to MIRt1 on NS16 and begin the tubing & 9-5f8" casing cut and pull on about Jan 18th. That will allow us about a week of rigging up and dealing with the uncertainties associated with the decomplete -get that off the critical path. So our first BOP test will be sometime around Jan 22"d. In summary, we will cut/pull the 9-5/8" below the 13-3/8" surface casing shoe, pump cement, sidetrack from below the surface pipe w! 12-1/4" to the Miluveach and cement 9-5/8" casing, drill the Miluveach/Kingak and fine with 7" to the tap of Sag, drill the Sag/Ivishak production hole and cement in a 4-1l2" liner, then complete with 4-1/2" 13Cr tubing. Pve attached the approved NS16A PTD for your reference. NS16A sidetrack should take ~35 days. to refresh your memory, was attempted last year but we lost the hole and BHA in r uveachlKingak section. el! is suspended with 13-3l8" surface casing set in the SV sands, 5f8" intermediate casing cemented into the uparuk. We pumped cement into the openhole w the 9-5f8" shoe. An extensive review of the (og data sugge Miluveach instability was prob riven by proximity to faulting and wellbore roof collapse associated with boreho e ~ ation approa at of bedding planes (Drilling is still trying to blame the Geologist for these, again}. Our so a to move the well away from the fault as far as possible (limited by exiting the 9-5/8" shoe} and red me t of the hole thru the shales. We will not underream the Miluveach/Kingak, from $-1/2" t A, ~as we've done in the - underreamers make dealing with unstable hole conditions ve cult. Instead of opening the hole we`ll r rr~~cc~e~tFte liner size ftom 7" to 6-5f8", down to top of Sag. Wish the production hole a 5-7/8" bit and 4-1/2" cemen~L~N' er. We have plenty of contingency reed up in the event wellbore instability continues to be a problem. D hnson is currently workin TD application and you guys should see ~ sometime next week. NS34A should take t 5 weeks t rsh. I've attached a coupl of slides which summarize NS34. ~~lsi2oas~ ~-~ 2008 Northstar Drilling Plans Maunder, Thomas E (DOA) From: Kara, Danny T [Danny.Kara@bp.com] Sent: Monday, January 14, 2008 4:54 PM To: Maunder, Thomas E (DOA); Monkelien, Kyle (MMS) Cc: Crane, Lowell R Subject: 2008 Northstar Drilling Plans Attachments: NS16A Drilling Permit.pdf; Northstar NS34A .ppt Tom/Kyle, Page 1 of 2 I though# I'd send you guys an update of the drilling plans for Northstar this year. The quick summary is sidetrack NS16a and finish NS34. NS33 will be deferred un#il the '09 ice road season. We're actively building ice to the island - we need sufficient ice road thickness to support Schiumberger's cementer, before we can start any openhote dritling. At this time we're estimating about Jan 26th for heavy equipment travel on the ice road. We plan to MIRU on IdS16 and begin the tubing 8~ 9-5/8" casing cut and pull on about Jan 18th. That will allow us about a week of rigging up and dealing with the uncertainties associated with the decomplete -get that off the critical path. So our first BOP test will be sometime around Jan 22nd In summary, we will cut/pull the 9-5/8" below the 13-3/8" surface casing shoe, pump cement, sidetrack from below the surface pipe w/ 12-1l4" to the Miluveach and cemen# 9-5/8" casing, drill the Miluveach/Kingak and line with 7" to the top of Sag, drill the Sag/ivishak production hole and cement in a 4-112" liner, then complete with 4-1/2" 13Cr tubing. I've attached the approved NS16A PTD for your reference. NS16A sidetrack should take ~35 days. NS34, to refresh your memory, was attempted last year but we lost the hole and BHA in the Miluveach/Kingak section. The well is suspended with 13-318" surface casing set in the SV sands, and 9-5/8" intem~ecliate casing cemented into the top of Kuparuk. We pumped cement into the openhole below the 9-518" shoe. An extensive review of the log data suggests the Miluveach instability was probably driven by proximity to faulting and wellbore roof collapse associated with borehole inclination approaching that of bedding planes (Drilling is still trying to blame the Geologist for these, again). Our solution wilt be to move the well away from the fault as far as possible (limited by exiting the 9-518" shoe) and reduce the inclination of the hole thru the shales. We will not underream the Miluveach/Kingak, from $-1/2" to 9-1/2", as we've done in the past - underreamers make dealing with unstable hole cenditions very difficult.. Instead of opening the hole we'll reduce the liner size from 7" to 6-518", down to top of Sag. We'll finish the production hole a 5-718" bit and 4-112" cemented liner. We have plenty of contingency cases lined up in the event wellbore instability continues to be a problem. Dave Johnson is currently working the PTD application and you guys should see it sometime next week. NS34A should take about 5 weeks to finish. I've attached a couple of slides which summarize NS34. ' With good planning and same luck we hope to complete the drilling season before May 1St. Please call with questions. Thanks Dan Kara Engineering Team Lead Northstar/Milne FointlEndicott Drilling 2/7/2008 -- - FRANK H. MURKOWSKi, GOVERNOR ~'SA OIL A1~TD GAS 333 W. T" AVENUE, SUITE 100 CO~S~R~AiIOl~ CO~TISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS 16A BP Exploration (Alaska) Inc. Permit No: 206-141 Surface Location: 1199' FSL, 645' FEL, SEC. 11, T13N, R13E, UM Bottomhole Location: 1235' FSL, 3723' FEL, SEC. 10, T13N, R13E, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). erel , n or Chairman DATED this day of October, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 RECEIVEI~~~~ ~ P 2 9 2006 31nr4~ (lil R. f:~c (`nnc Cnmmiecinn 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro s,~,d,,fror: ^ Coalbed Methane ~'G~5 rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: NS16A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14292 TVD 11248 12. Field /Pool(s): Northstar Unit 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 312799 FSL, 645 FEL, SEC. 11, T13N, R13E, UM 1199 Top of Productive Horizon: 1234' FSL, 3449' FEL, SEC. 10, T13N, R13E, UM 8. Land Use Permit: LO-N96-006 13. Approximate Spud December 1 06 Total Depth: 1235' FSL, 3723' FEL, SEC. 10, T13N, R13E, UM 9. Acres in Property: 4392.82 14. Distance to Nea Property: 3400' 4b. Location of Well (State Base Plane Coordinates): Surface: x-659830 y-6030971 Zone-ASP4 10. KB Elevation (Height above GL): 56.46' feet 15. Distance to Nearest Well Within Pool: 2730' away from NS07 16. Deviated Wells: Kickoff Depth: 3696 feet Maximum Hole An le: 44.7 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5118 Surface: 3775 ~ 18' asin P ram: S ificatio ns To -;Settir+ De th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/4" 9-518" 53.5# L-80 BTC-M 11900' Surface Surface 11900' 9307' 891 sx Extended Slur 508 sx'G' ~ 8-1/2" 7" 26# L-80 H dril 521 2142' 11750' 9186' 13892' 10936' 497 sx Class'G' 6" 4-1/2" 12.6# 13Cr80 Vam To 550' 13742' 10807 14297' 11248' 73 sx CI ss'G' r 1 g. PRESE NT'V1lELL CONDITIONS UMMARY (Tti be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12424 Total Depth TVD (ft): 11148 Plugs (measured): None Effective Depth MD (ft): 12420 Effective Depth TVD (ft): 11144 Junk (measured): None Casing `Length ize' Cement Volume MD TVD Conductor /Structural 201' 20" Driven 201' 201' Surface 3450' 13-3/8" 618 sx PF'L' 470 sx Class'G' 3494' 3200' Intermediate Produ tion 10392' 9-5/8" 550 sx Econolite 621 sx Class'G' 10435' 9288' Liner 1829' 7" 288 sx Class'G' 10265' - 12094' 9139' - 10824' Liner 505' 4-1/2" 87 sx Class 'G' 11919' - 12424' 10655' - 11148' Perforation Depth MD (ft): 12304' - 12384' Perforation Depth TVD (ft): 11030' - 11109' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Paul Hanson, 564-4195 Printed Name Pat Archey Title Senior Drilling Engineer // / O Prepared By Name/Numtier: Si nature ~ LrG~,.c(,~. Phone 564-5803 Date ~-r~l~"~ Sondra Stewman, 564-4750 ' Commission Use Onl Permit To Drill Number: ~ API Number: 50-029-23096-01-00 Permit Approv See cover letter for Date: '~ other re uirements Conditions of Approval: L If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ^ ~ -e ~ '1, ~ D ~~L~ "~'~j ~Oc90 r) lic: Samples Req'd: ^ Yes ^ No Mud Log Req'd: ^ Yes ^ No {Pu.l!S k r~.~ l o ~ ~'~C. ZS ~ ~ ~ ~ ~~ ~ t ~ H Measures: ^ Yes ^ No ctional Survey Req'd: ^ Yes ^ No Other: APPROVED BY THE COMMISSION Date ~~ ~c,/ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate OR1~~E`~Ai... by ~ • To: Winton Aubert - AOGCC BP Exploration Alaska Inc. Date: September 26, 2006 From: Paul Hanson Northstar ODE Subject: NS16A Permit Application for Sidetracking NS16 Dear Mr. Aubert, NS16 has experienced high GOR in the Ivishak production from gas coning and/or communication with nearby gas injectors. As a result, NS16 production has been interrupted by cyclic shut-ins (the production history is included in the Sundry Notice for abandonment of the original NS16 wellbore). It is planned to abandon the current wellbore in the Ivishak and sidetrack NS16 to a new bottom-hole location. The sidetracking operation will encompass re-drilling the 12-1/4", 8-1/2" and 6" hole sections ~ per the included directional plan. A proposed casing and completion schematic is attached. The Sundry Notice for P&A has been submitted concurrently with this request. Maximum anticipated surface pressure (full column of gas from TD to surface) is 4~5-3~'" 3~ ~ s~ psi. We will be utilizing Nabor's 33e 5000 psi four preventer stack (3 rams and an ~ annular). The drilling operation will require running 2142' feet of 7" intermediate liner. We are requesting a variance to the requirement to have two ram preventers to cover the 7" liner and 2 ram preventers for the 5-7/8" and 5" DP. We would like to use a variable bore ram on top that can cover both DP and casing. This would provide one ram and the annular for the 7" liner and two rams for the DP and does not necessitate changing rams after picking up the 7" liner. In the event of a well control incident, our standard practice is to immediately cross-over to DP to allow ram to ram stripping (if required) and we would prefer not to have to change out rams during ashut-in. The only close approach for the sidetrack is with the original NS 16 wellbore which will be ~ abandoned. NS16 sidetrack will utilize gas detection equipment but is not planned for mudloggers. ~ Please find attached the NS16 sidetrack Well Plan Summary. If you should have any questions or concerns, please contact me C~ 564-4195. -- Sinc~-el ~ \~ ~ f ; Paul Hanson BP Northstar ODE 564-4171 work 632-5806 cell ~ i NS 16A Sidetrack Permit to Drill -Well Plan Summary The procedural steps highlighted in blue are duplicated from the Sundry Permit Request to P&A the original NS 16 wellbore. These steps are essential preparation for drilling the NS 16A sidetrack. Pre-Rig Work• 1. Test the 9-5/8" Pack-off to 5,000 psi. 2. MIT the inner annulus to 4,200 psi. 3. Full-bore cement squeeze with 15.8 ppg Premium Class G cement down the existing tubing leaving approximately 260' of cement above the uppermost perforation (estimated TOC at ~ 12,044' MD). Estimated volume is 8 bbl -assuming pushing at least 1 bbl into the perfs. Hold pressure and WOC per SLB recommendations. Note: An Infectivity Test should be conducted prior to pumping cement. The cement should be preceded by 50 bbl of seawater. Ideally, we would like TOC to be below the CiDRA mandrel at 11,833' in order that the mandrel can be recovered when the tubing is pulled. If TOC is higher than the mandrel will not be recovered. 4. RU wireline. Drift tubing and tag TOC. Pressure test tubing to 2,000 psi to confirm plug. 5. RU e-line with CCL and Jet-cutter. If TOC allows, cut the 4-1/2" tubing below the uppermost X-nipple at 11,859' and above the 7"x 4-1/2" packer at 11,880'. Circulate 9.3 ppg brine w/300' of diesel freeze protection. If TOC is high, cut as close to TOC as possible -not at the location of a coupling. 6. Install BPV and test down IA with 500 psi. Remove wellhead housing, flow lines and sweeps. Rig Operations: L MIRU. Pull BPV. Circulate well to 9.3# KWF thru jet-cut, displacing diesel FP. 2. Set TWC. Test from above and below (if possible) to 1.,000 psi. ND tree. NU test BOPE to ,000 si. Pull TWC. 3. Pull and LD the 4-1 /2" tubing string to the cut. 4. RU slickline and drift 9-5/8" casing using Gauge Ring/Junk Basket/CCL. 5. PU drillpipe. RIH with permanent bridge plug to approximately 3,600' (actual depth determined by CCL) and set. Pressure test to 2,000 psi to demonstrate plug set. POOH. 6. RIH with a hydraulic multi-string casing cutter. Cut the 9 5/8" casing approximately in the middle of the full joint above the bridge plug. POOH. 7. PU and Spear the 9-5/8" casing and unseat/recover mandrel hanger. RU casing crew. Pull and lay down 9-5/8" casing. 8. RIH w/open-ended drillpipe and lay in approximately 40 bbl of 15.8 ppg Class G cement. The cement should cover the 9-5/8" stub with TOC approximately 100' up inside the 13-3/8" casing 0200' plug). POOH. 9. RIH and dress cement plug off in preparation for sidetrack. 10. MU 12-1/4" directional assembly. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 1 1. Drill out approximately 100' of cement inside the 13-3/8" casing and begin directional work off of cement plug to sidetrack well. Dri1120' of new (virgin) formation below and perform FIT to a / minimum of 12.5 ppg EMW. (FIT/LOT procedure on file with AOGCC). 12. Drill 12-1/4" intermediate hole to the 9-5/8" casing point (approximately 11900' MD t the top of the Miluveach. Minimum mud weight of 9.8 ppg at the top of HRZ and a minimum of 0. ppg at the top of Kuparuk. POOH. 13. Run 9-5/8", 53.5# casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9- 5/8" slips and pack off. Perform adown-squeeze on the 9-5/8" x 13-3/8" annulus with one annular volume of mud upon installing and testing the pack off. Down-squeeze diesel to 2000' TVD (2000' md) for freeze protection after WOC. 9/26/2006 Page 1 of 10 NS 16A Sidetrack Permit to Drill 14. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4700 psi ~ with 10.5 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 15. Drill out remaining cement and weight up to a minimum o 1.5 ppg MW. Dri1120' of new formation/ below 9-5/8" shoe and perform a FIT to a minimum of 1~5 ppg EMW, (FIT/LOT procedure on file with AOGCC). 16. Ensure the mud is in good condition prior to drilling ahead. Drill the drilling liner hole section to the top of the Sag at approximately 13842' MD (10893 TVD RKB). The Intermediate casing point has been picked at 13892' MD. POOH. 17. Run and cement a 7" 29# Hydri1521 drilling liner. Displace cement with mud. Set the liner hanger ~ and liner top packer. Circulate excess cement from well bore. 18. POOH and lay down liner running tools. Test 9 5/8" x 7" casing to 3600 psi with 12.3 ppg fluid. This test pressure may change based on the actual mud weight in the hole. 19. RIH w/ 6" directional assembly. Clean out the 7" 29# liner to the landing collar. Displace the wellbore to 9.1 ppg mud. 20. Drill out maining cement. Dri1120' of new formation below 7" shoe with 9.3 ppg MW. Perform a FIT to l.~ppg. EMW (FIT/LOT procedure on file with AOGCC). 21. Drill ""roduction interval to the proposed TD at 14292' MD. Condition mud weight to 9.3 ppg prior to POOH. 22. Run and cement the 4-1/2" 12.6# 13 CR-80 liner .Set the liner hanger and liner top packer. Circulate a minimum of one bottoms-up to remove excess cement with a 9.3 ppg mud. 23. Once a successful cement job is obtained, pressure test liner lap to 1500 psi with 9.3 ppg mud to confirm pressure integrity. 24. Change well over to clean seawater through the inner string (less than 80 NTU's) and by using spacers as per MI recommendation. 25. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 26. POOH and lay down liner running tool and inner string. 27. Close blind rams and test 9 5/8" casing x 7" drilling liner x 41/2" liner to 3500 psi for 30 minutes. This liner lap test assumes a 14.5 ppg LOT at 7" shoe (10936' TVDrkb) + 500 psi. 28. Run and land the 4-1/2" 12.6# 13-CR80 Vam Top tubing string with fiber optics' as per completion, diagram. Pressure test the control lines and tubing hanger seals to 5000 psi. 29. Set 7" X 41h" packer. Test tubing and annulus to 4200 psi. Open shear valve in gas lift mandrel. 30. Freeze protect the tubing and annulus to 3000' TVD 31. Set the TWC valve in tubing hanger. Nipple down BOPS. Nipple up the 13-5/8" 5000 psi x 7-1/16" 5000 psi tubing head adapter and 7-1/16", 5000 psi tree. Install all flanges and needle valves. 32. Test the tubing head adapter and tree to 5000 psi. Pull TWC valve and install BPV. 33. Ensure all tree and annulus valves are secured. RD and move off well. Post-Rig Work• 1. Tie-in and FCO. 2. Retrieve ball and rod / RHC sub from XN nipple below the new production packer. 3. Perforate ~60' Ivishak formation. 4. Record initial BHP survey. 9/26/2006 Page 2 of 10 r7 NS 16A Sidetrack Permit to Drill General Information Type of Well (producer or injector): Pre-Produced Injector Northstar Slot: NS 16 Surface Location: 1199' FSL, 645' FEL, Sec. 11, T13N, R13E, UM ~ X = 659,829.11 Y = 6,030,971.6 AOR (NS10 or NS32) Well does not enter area of review for NS 10 or NS32. Target (Top of SAG): 400' Radius 1233 FSL, 3449 FEL, Sec. 10, T13N, R13E, UM X = 651,747 Y = 6,030,837 10893 TVDrkb Bottom Hole Location: 200' Radius 1235 FSL, 3723 FEL, Sec. 10, T13N, R13E, UM X = 651,473 Y = 6,030,833 11248 TVDrkb AFE Number: NSD 831384 Rig: Nabors 3 Estimated Start Date: 12/14/2006 Operating days to complete: 36 MD: 14292 TVDrkb: 11248 RKB/Surface Elevation: (a.m.s.l.) 56.46'/ 15.9' Well Desi n conventional, slimhole, etc.): Modified Bi Bore Ob'ective: Ivishak Producer Well Name: NS 16A API Number: BHP: 5141 si C 11,248' T Ds EMW: 8.79 BHT: 254 °F @ 11,100' TVDss Land Use Permit: LO-N96-006 Distance to Nearest Property: 3,400 ft to nearest lease line Distance to Nearest Well within Pool: 2,730' to NS07 ~ MECHANICAL CONDITION: Cellar box: Elevation above MSL = 15.9' RKB to Cellar box: 40.56' (Estimated) Rig Elevation: RKB +MSL = 56.46' N516 - on final See Wellbore Schematic - NS 16 As Is 9/26/2006 Page 3 of 10 NS 16A Sidetrack Permit to Drill -Well Plan Summary General Information Formation Estimated Depths Pore Press. Top (TVDss) TVDrkb MDrkb (Psi) (ppg EMW Top Permafrost 1,150 1,206 1,230 542 8.65 Base Permafrost 1,500 1,556 1,632 700 8.65 SV6 -top confining zone 2987 3,043 3,309 1369 8.65 Surface casing point 3,258 3,314 3,494 Tie-in Point 3,317 3,373 3,696 SV5 -base confining zone 3,560 3,616 3,997 1626 8.65 SV4 3,560 3,616 3,997 1626 8.65 SV2 -top upper injection zone 3,950 4,006 4,541 1802 8.65 SV1 -top major shale barrier 4,340 4,396 5,090 1977 8.65 TMBK -top lower injection zone - To U nu 4,710 4,766 5,611 2144 8.65 WS1 -top Schrader Bluff -Base U nu 6,250 6,306 7,778 2836 8.65 CM3 -Base lower injection zone (top Colville) 6,880 6,936 8,664 3120 8.65 THRZ -Top HRZ 8,540 8,596 10,995 3866 8.65 BHRZ -Base HRZ 8,640 8,866 11,128 3911 8.65 Top Kuparuk 8,870 8,926 11,426 4359 9.45 Kuparuk C 9,000 9,056 11,558 4419 9.44 LCU/Kuparuk A 9,070 9,126 11,667 4452 9.44 RGM_52_S7 fault 9,115 9,171 11,731 Top Miluveach 9,220 9,276 11,861 4521 9.43 Intermediate casing point 9,251 9,307 11,900 Top Kingak 9,902 9,958 12,707 TJC 10,410 10,466 13,336 Top Sag River 10,837 10,893 13,842 5240 9.25* Intermediate casing point 10,879 10,936 13,892 Top Shublik - 90 10,938 10,994 13,962 5063 8.86 Top Ivishak 11,029 11,085 14,078 5084 8.82 Geo Target #1 11,000 11,056 14,041 5077 8.83 Oil -Water contact 11,100 11,156 14,171 5100 8.79 Total Depth 11,192 11,248 14,292 Top Kavik 11,224 11,280 14,332 Notes: Anomalous high gas readings reported in Seal A-01 mud log at the following interval: 3690- 3775; 3925 - 4050; 4140 - 4425, 4510 - 4700 MD - No significant Gas shows in NS10 through NS07 through this interval -max gas = 70 units Depth predictions based on previous NS16 wellbore results applied to seismic velocity model. Pore pressures estimated using RFT/DST data in offset Seal Wells, NS29, NS27, NS31, NS31, NS13 and NS08 etc. 9/27/2006 Page 4 of 10 NS 16A Sidetrack Permit to Drill General Information CASING/TUBING PROGRAM: Items highlighted in BLUE are from the pre-existing NS 16 wellbore. Hole Size i D i i Measured Depth Vertical Depth th Feet L Casing String ng escr pt on Cas Top Bottom Top Bottom eng Conductor Pipe 20 20" 169# X-56 Welded Surface 200 Surface 200 200 Surface Casing 16 13-3/8" 68.0# L-80 BTC Surface 3494 Surface 3314 3494 Intermediate Csg 121/4 9-5/8" 53.5# L-80 BTC-M Surface 11900 Surface 9307 11900 Intermediate Liner 8 1/2 7" 26.0# L-80 Hydril 521 11750 13892 9186 10936 2142 Production Liner 6 4-1/2" 12.6# 13-CR80 Vam Top 13742 14292 10807 11248 550 Tubing - 4-1/2" 12.6# 13-CR80 Vam Top Surface 13682 Surface 10702 13682+/- Formation Integrity Testing: Test Point Depth Shoe Test Type EMW Estimated Casin finer Test 13 3/8" Surface Casin 20' min below shoe FIT 12.5 EMW 3500 si w/ 9.3 9 5/8" Intermediate Casin 20' min below shoe FIT 14.5.0 EMW 4700 si w/ 10.5 7" Intermediate Liner 20' min from 7" shoe FIT 11.5 pp EMW 3600 si w/ 12.3/8.65 4'/z" Production Liner N/A N/A N/a 1500 si w/ 9.3 MUD PROGRAM SUMMARY: Sidetrack Hole Mud Proaerties: Glycol -Seawater Polymer Mud 12-1/4" Hole Section From Surface Casing Shoe into the Top of the Miluveach (11900' MD / 9307' TVD). Interval Density (ppg) PV YP API / HTTP FL pH 3600' Decom letion 9.3 Brine NA NA NA NA 3600 - 10,795' 200' rior to HRZ 8.6 - 9.3 8-15 26-3Q 6-9 / NC 9.0 - 9.5 10,795' - 11,900' 10.2 15 - 25 26 - 30 <5 / <12 9.0 - 9.5 9/26/2006 Page 5 of 10 NS 16A Sidetrack Permit to Drill General Information Drilling Liner Hole Mud Properties: Glycol Inhibited KCL Mud 8-U2" Hole Section From Intermediate Casing Shoe to 13892' MD / 10936' TVD (top of Sag) Interval Density (pp) PV YP API /HTHPFL pH Miluveach & Kingak to top of Sag 10.5 12.3 15-25 26 - 32 <5 / <12 9.0 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid 6" Hole Section From Intermediate Casing Shoe to 14292' MD / 11,248' TVD Interval Density (ppg) PV YP API / HTTP FL pH Initial/Final 9.2 - 9.3 8-12 22-28 4-6 9.0 - 9.5 DIRECTIONAL' KOP: 3373'/3696' TVD/TMD Build Rates 0.58 °/100' to 3.0°/1.00' during Kick-off, 6°/100' in roduction zone. Maximum Hole Angle: ±44.7° Close Approach Wells: None. Passes Major Risk with all Northstar wells. Since NS16A utilizes the existing 13-3/8" surface casin .Most Northstar close-approach issues occur at de the between 400' to 600'. Survey Program: IFR+MS corrected MWD surveys from KOP to TD. WELL CONTROL: Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) / 5000 psi working pressure pipe rams (2) / Blind shear rams / Annular preventer Based upon the calculations below, BOP equipment will be tested to 5000 ps~-- Maximum Surface Pressure -Full Column of Gas from TD - 0 2 sift radient Gradients - p / psi/ft ,_ Pressures 12 ~/a" Intermediate Hole Section: TVD - ss Formation Gas BHP Surface .2 ce Kuparuk C 9,000 9.44 0.12 4418 3338 4006 8 ~/2" Intermediate Hole Section: S 2'S ( ~ ti ~ Sa River 10879 .>~:8~~ ~ Z~ 0.12 5023 3718 4461 6" Production Hole Section: Total De th 11196 8.79 0.12 5118 3775 4530 Planned B OP test ressure: 5000 si annular to 3500 si Planned completion fluid: 9.3 Brine / 6.8 Diesel 9/26/2006 Page 6 of 10 NS 16A Sidetrack Permit to Drill LOGGING PROGRAM: • Well Evaluation 12 1/4" Intermediate 9" Intermediate Pro ram Hole Hole 6" Production Hole Interval - MDrkb de the From TO From TO From TO MW D/LW D Directional 3,696 11,900 Int. shoe 13,892 13,892 14,295 Gamma Ra h4 3,696 11,900 Int. shoe 13,892 13,892 14,295 G ro None None None PWD I'JCA 3,696 11,900 Int. shoe 13,892 None Resistivi -recorded mode ~ 3,696 11,900 None 13,892 14,295 Resistivi -real time mode N/{~ 3,696 11,900 None 13,892 14,295 Densi NfiA None None 13,892 14,295 Neutron NIA None None 13,892 14,295 Sonic (ISONIC) Nf~q None None None Wireline based Open Hole to s G R Nfq None None Contin ent Resistivit HALS NFa None None Contin ent Neutron HGNS N%A None None Contin ent Densi HRMS ** N7A None None Contin ent Sonic N/A None None None FMI 4 arm cali er ** t~ta None None None CMR N/A None None None RE-f N/A None None None MDT tYiR None None None Cased Hole log - SCMT / USIT / CBL N/R None None None Mudlogging Gas Detection Ntk None None None Cuttin s Sam les NIA; None None None Increments N! ' None None None Geochem cans NIAi None None None Increments NIR None None None Comments Im ortance Definitions Wireline Los MWD/LWD to s Intermediate Hole 1: PWD Resistivity and LWD in real time mode in the Low Do not run if unsuccessful. If tool fails -drill ahead Intermediate hole #1 Intermediate Hole 1: Med. Re-run if unsuccessful except if conditioning trip required to run casin . Intermediate Hole II: Cased hole gamma ray to be run . High Re-run if unsuccessful even if If unsuccessful -POOH and repair if for primary depth control after conditioning trip required. DP possible. Willing to run back in hole ri moves off location conve ed to in not re uired. without tool re aired Production Hole: If LWD logs fail while drilling then V. High Re-run if unsuccessful even if DP drill ahead to planned TD. conveyed logging needed Contingent Wireline log run needed should LWD logs fail. 9/26/2006 Page 7 of 10 NS 16A Sidetrack Permit to Drill Required Materials: L-80 11900' 9 5/8", 53.5# L-80 BTC-MOD Intermediate: 1 - 9 5/8" 1- 9 5/8" 1 -set 1 - 13 5/8" x 9 5/8" 155 - 9 5/8" x 12" 155 - 9 5/8"x12" HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers Stop Bands L-80 Drlg 2142' 7", 29# L-80 Hydri1521 Liner: 1 - 8 %z" BBL reamer shoe 1 - 7" HES Super Seal II Float Collar 7 - 7" x 8 1/4" SV Rigid Centralizers 7 - 7" x 8 1/4" Stop Bands 1 - 7" x 9 5/8" Baker Double-Grip Flex Lock Hydraulic Set Liner Hanger -Rotating hanger. 1 - 7" x 9 5/8" Baker ZXP Liner Top Packer 1 - 7" Baker HRD running tool 1 - 7" Baker Landing Collar and plug set 13CR Liner: 553' 4-1/2", 12.6# 13 Cr-80Vam Top 1 - 4-1/2" HES Super Seal II Float Shoe 1 - 4-1/2" HES Super Seal II Float Collar 30 - 4-1/2" x 5-3/4" SV Rigid Centralizers 30 - 4-1/2" x 5-3/4" Stop Bands 1 - 4-1/2" x 7" Baker Flex Lock Hydraulic Set Liner Hanger 1 - 4-1/2" x 7" Baker ZXP Liner Top Packer 1 - 4-1/2" Baker Landing Collar and plug set 13Cr 13682' 4-1/2", 12.6# 13Cr-80 Vam Top Completion: 1 41/z" ABB-VGI tubing hanger 1 41h" ABB-VGI adapter flange 1 41/z" ABB-VGI 5-1/8" SK Swab Valve w/ tree cap 1 CIDRA mandrel and 0.25" fiber optic cable (w/ 41/z" cable clamps). 1 41/s" SVLN and 1 - 0.25" control lines 1 41h" x 1 '/2" GLM with dummy valve installed 1 41/2" x 1 %z" GLM with RP Shear valve installed 1 7" x 4 lh" Baker 13 Cr packer S-3. 1 41/z" WLEG (Self-Aligning Mule Shoe) 2 41/z" 13 Cr X nipples 1 41/z" 13 Cr XN nipple 9/26/2006 Page 8 of 10 NS 16A Sidetrack Permit to Drill CEMENT' The following cement calculations are based upon a single stage job. Casing 9-5/8" 53.5# BTC-M asis: tage 1: ead: Based on 59 0 12 1/4" open hole x 9 5/8" csg +30% excess ead TOC: At ~ 45 MD (4006' TVD - SV2) ail: Based on 13 1' of 121/a" open hole x 9 5/8" csg + 30% excess + 80' shoe joint. ail TOC: At ~ 10529' MD (8261' TVD) Shoe at 11900' MD. Stage 1: Total Cement / I Preflush 135 bbls CW 101 ~ acer 75 bbl Mu h II Spacer Lead bbl / 9 k of 11.5 ppg Extended Slurry. Tail //50§~k of 15.8 ppg Premium `G'. 7" 29# 521 Hydril Drlg tage 1: ` Slurry: Based on 2342' ofA'1/2" open hole x 7" csg + 50°Io excess + 150' 9 5/8" csg x 7" liner lap + 200' 9-5/8" s x 5" drillpipe above TOL + 80' shoe joint. Slurry TOC: At ~ 1 55 MD 1: Total Cement / `-'`' I Preflush 130 bbl CW 101 Spacer 50 bbl MudPush II Spacer Slurry 1y36;bb1 / 9 sk of 15.8 ppg Premium `G'. 1/2" 12.6# 13Cr-80 Prod asis: tage 1: Slurry: Based on 403' f 6" open hole x 4 1/z liner + 100°Io excess + 150' of 7" csg x 4 1/2" sg liner lap + 200' f 7' csg x 4" drillpipe above TOL + 40' shoe joint. Slurr TOC: At ~ 35 ' MD tage 1: Total ..pacer 15 bbl MudPush II Spacer Cement / S acer Slurry 2fd'6a1 / 73 k of 15.8 ppg Premium `G'. 9/26/2006 Page 9 of 10 NS 16A Sidetrack Permit to Drill Big Bore Pre-Produced Injectors Casing Specifications Summary Surface Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID in Drift in Min/Max Coupling OD Strength (10001bs) Strength (1000 lbs) Streneth (psi) Stren¢th (asi) 13-3/8" 68 L-80 BTC 12.4[5 12.295 Position 14.375 1556 1545 5024 2264 , Intermediate Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size h Grade Connection ID in Drift in Min/Max Couuling OD Strength (10001bs) Strength (10001bs) Strength (asi) Stren th (osi) 9-5/8" 53.5 L-80 BTC-M 8.535 8.5 Position 10.625 1244 1268 7927 6617 c, Production Liner Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Wei t Grade Connection ID in Drift in Min/Max Coupling OD Strength (1000 Ibs) Streneth Strength Stren h 7" 29 13CR-80 VAM TOP 6.184 6.059 6900/8900 7.656 676 691 8160 7020 , Production Tubing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID in Drift in Min/Max Coupling OD Stren h (10001bs) Strength (10001bs) Strength (psi) Streneth (psi) 4.5" 12.6 13CR-80 VAM TOP 3.958 3.833 3600 4.964 288 288 8430 7500 9/26/2006 Page 10 of 10 TREE= ABB-VGI5-1/8" 5K WELLHEAG= ABB-VGI 13-5/8" MULTIBOWL 5K ACTUATOR = KB. ELEV = 56.46' BF. ELEV = 40.56' (CB 15.9') KOP = Max Angle = 33 @ 9614' Datum MD = Datum TV D = 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3494' /[ /~ C '~ ~ NS16 I I S~1(NOTES: *"*4-1 /2" CHROME TBG &LNR*"" 972' -14-1/2" TRM•4E SSSV, ID = 3.813" 1587' 13-3/8" TAM PORT COLLAR GAS LIFT MANDRELS Minimum ID = 3.725" @ 11915' 4-1/2" XN NIPPLE TOP OF 7" LNR 9-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" 10265' 10435' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 4981 6453 4483 6453 27 26 11833' -14-112" FIBER OPTIC TRANSDUCER, ID = 3.945" 11836' ELM 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.945" 11859' 4-1/2" X NIP, ID = 3.813" 11880' 7" X 4-1/2" PKR 11903' 4-1/2" X NIP, ID = 3.813" 11915' 4-1/2" XN NIP, ID = 3.725" ~TOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR VAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 HY DRIL 521, ID = 6.276" 11919' 11926' I 12094' I PERFORATION SUMMARY REF LOG: PDC GR/CCL on 07/14/03 ANGLE AT TOP PERF: 9 deg @ 12304' INITIAL PERF-CHARGE 2906 POWERJET, HSD, PENETRATION: 27", HOLE 0.36", PHASE 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 12304 - 12384 O 07/15/03 PBTD 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE, .0152 bpf, ID = 3.958" 12420' 12~ 424' ~ ~ 11926' ~ 4-1/2" SELF ALIGNING WLEG ID = 3.850" ELMD TT NOT LOGGED? DATE REV BY COMMENTS DATE REV BY COMMENTS 07/15/02 JAS INIT COMPLETION 03/21/03 FM FINAL COMPLETION 07/18/03 EMF ADD PERFS 11/04/05 BJM NEW FORMAT NORTHSTAR WELL: NS16 PERMfT No: 2021270 API No: 50-029-23096-00 BP 6cploration (Alaska) TREE: ABB-VGI 5 1/8" 5ksi N S 16 - P and A WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" TAM Port Collar at +/-1587'MD L-80, BTC @ 3494' ORIG~KB. ELEV = 55.9' J' KB-B V = 40.2' CB. ELEV = 16.0' TOC PLUG @ -3394`MD BRIDGE PLUG @ -3600'MD 9-5/8" 47# ~ rfj`~- 7" LINER TOP @ 10265' L-80 BTM-C @ 10435' ~J 4.5" X NIPPLE, @ 11903' 7" PACKER,13 Cr @ 11880' MD 3 813" ID . , 4.5" XN NIPPLE, @ 11915' 3.725" ID ~ 4.5" WLEG, @ 11926' 5" LINER TOP @ 11919' MD 4 3.958" I . " 7", 26#/ft L-S0, BTC-M @ 12094' PROPOSED TOP OF 4.5 CEMENT @ 12044' MD Top of Squeezed Perts @ 12304` MD PBTD @ 12420' M~~~~ 4.5", 12.6#, 13Cr Vam Ace TD @ 12424' MD DATE REV. BY COMMENTS Northstar /23/06 PMH NS16 Pro ose P and A WELL: NS16 API NO: 50-029-23096-00 BP Exploration (Alaska) I TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS16A Proposed IGINAL KB. ELEV = 55.77` -BF. ELEV = 39.87' CB. ELEV = 15.9' )' 5-1 /2" x 4-1 /2" VIT Tubing /2" TRM- 4E SSSV @ 1000' TVD 1004' MD) 3.813" ID PPG DIESEL FREEZE PROTECTION +/- 3000' TVD (3258'MD) 4 1/2" GLM @ 4000` TVD (4533' MD) w/ 3.833" ID Top of 11.5 ppg "extended leadl" at 4541' 13 3/8" TAM Pc at +/-1587`MD L-80, BTC @ 3494 4 1/2", 12.6#/ft, 13-Cr, Vam TUBING ID: 3.958" CAPACITY: 0.01522 BBL 9-5/8" 53.5# L-80 BTM-C @ 11 £ 4.5" X NIPPLE, @ 1366: 3.8' 4.5" X NIPPLE, @ 1370. 3.8' 4.5" XN NIPPLE, @ 1371: 3.7. 4.5" Self Aligning WLEG, @137; 3.8 I 7", 29#/ft L-80, Hydril @ 13892' MD Perf Strategy 60` @6spf, 60 phasing PBTD @ 14 TD @ 1425 ~.~~ .p of 15.8 ppg "tail" at 10529` 7" LINER TOP @ 11750` MD ~.5" Fiber Optic Transducer ..945" ID @ 13652` 'ACKER,13 Cr @ 13682` MD, .25' TVD 4.5" LINER TOP @ 13742' MD 4.5", 12.6#, 13Cr-80 Vam Top DATE REV. BY COMMENTS Northstar 8/24/06 PMH NS16A Pro osed WELL: NS16A API NO: BP Exploration (Alaska) Schlumberger NS16A (P16b) Proaosal Client: BP Exploration Alaska Field: Northstar Structure 1 Slot: Northstar PF / NS16 ~ O~'~ Well: NSt6 O~ Borehole: Plan NS16A ~~~r UWIIAPIq: 500292309601 Survey Name 1 Date: NS16A (P16b) /September 13, 2006 Tort I AHD 1 DDI I ERD ratio: 87.968° / 8361.75 ft 15.971 / 0.743 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.49115951, W 148.69329938 Location Grid NIE YIX: N 6030971.560 ftUS, E 659829.810 ftUS Grid Convergence Angle: +1.23170678° Grid Scale Factor: 0.99992902 Vertical Section Azimuth: 270.470° ! Vertical Section Origin: N 0.000 ft, E 0.000 ft r TVD Reference Datum: Rotary Table TVD Reference Elevation: 56.46 ft relative to MSL Sea Bed 1 Ground Level Elevation: 15.57 ft relative to MSL Magnetic Declination: 24.200° Total Field Strength: 57665.396 nT Magnetic Dip: 81.061 ° Declination Date: December 20, 2006 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North •> True North: +24.200° Local Coordinates Referenced To: Well Head Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea TVD TVp NS ~ DLS Build Rate Walk Rate Northing Easting LatiWde Longitude Depth Section Tool Face k de d k it k ft k d d 1100 k d 100 k d 1100 h ftUS ftUS Ile-In JUfVey 30`Jb.O`J 3l./0 Lb/.l/ 337/.l0 SS/3.OL 1313.3b -Ib.bO -1313.b4 /V.4lL U.bb UA`J -U.b4 OU3U`JLb.Ob ODOO1/.U3 IV /U.4`J-IIIJOJ VV-140./U4W040 KOP Crv 3/100 3700.00 31.76 267.14 3319.80 3376.26 1314.99 -16.76 -1315.17 10.25R 0.58 0.19 -1.03 6030926.54 658515.40 N 70.49111341 W 148.70404984 3800.00 34.71 268.07 3403.44 3459.90 1369.72 -19.03 -1369.93 9.46R 3.00 2.96 0.94 6030923.09 658460.71 N 70.49110718 W 148.70449739 3900.00 37.67 268.88 3484.13 3540.59 1428.73 -20.58 -1428.95 8.81 R 3.00 2.96 0.81 6030920.27 658401.74 N 70.49110290 W 148.70497984 4000.00 40.64 269.59 3561.67 3618.13 1491.85 -21.42 -1492.08 8.26R 3.00 2.97 0.71 6030918.08 658338.64 N 70.49110060 W 148.70549589 4100.00 43.61 270.21 3635.83 3692.29 1558.92 -21.52 -1559.15 7.80R 3.00 2.97 0.62 6030916.53 658271.60 N 70.49110026 W 148.70604412 End Crv 4137.17 44.72 270.43 3662.49 3718.95 1584.82 -21.38 -1585.05 -- 3.00 2.97 0.58 6030916.12 658245.71 N 70.49110064 W 148.70625580 SV2 4541.77 44.72 270.43 3950.00 4006.46 1869.49 -19.26 -1869.71 -- 0.00 0.00 0.00 6030912.12 657961.08 N 70.49110625 W 148.70858273 SV1 5090.60 44.72 270.43 4340.00 4396.46 2255.65 -16.39 -2255.86 -- 0.00 0.00 0.00 6030906.69 657574.99 N 70.49111381 W 148.71173916 TMBK l Top Ugnu 5611.29 44.72 270.43 4710.00 4766.46 2622.00 -13.66 -2622.20 - 0.00 0.00 0.00 6030901.54 657208.70 N 70.49112093 W 148.71473373 WS1 /Top Schrader 7778.48 44.72 270.43 6250.00 6306.46 4146.83 -2.31 -4146.98 -- 0.00 0.00 0.00 6030880.11 655684.14 N 70.49115004 W 148.72719762 CM3 l Top Colville 8665.05 44.72 270.43 6880.00 6936.46 4770.62 2.33 -4770.76 -- 0.00 0.00 0.00 6030871.35 655060.45 N 70.49116170 W 148.73229 Drp 1/100 10735.71 44.72 270.43 8351.41 8407.87 6227.53 13.18 -6227.63 178.25R 0.00 0.00 0.00 6030850.87 653603.79 N 70.49118838 W 148.7442 10800.00 44.07 270.45 8397.35 8453.81 6272.50 13.52 -6272.60 178.23R 1.00 -1.00 0.04 6030850.25 653558.82 N 70.49118922 W 148.74457 10900.00 43.07 270.50 8469.79 8526.25 6341.43 14.10 -6341.53 178.20R 1.00 -1.00 0.05 6030849.35 653489.91 N 70.49119063 W 148.74513638 Top HRZ 10995.37 42.12 270.54 8540.00 8596.46 6405.98 14.68 -6406.08 178.17R 1.00 -1.00 0.05 6030848.55 653425.36 N 70.49119208 W 148.74566403 11000.00 42.07 270.55 8543.43 8599.89 6409.08 14.71 -6409.18 178.17R 1.00 -1.00 0.05 6030848.51 653422.26 N 70.49119216 W 148.74568938 11100.00 41.08 270.60 8618.24 8674.70 6475.44 15.37 -6475.54 178.13R 1.00 -1.00 0.05 6030847.74 653355.91 N 70.49119381 W 148.74623179 Base HRZ 11128.80 40.79 270.61 8640.00 8696.46 6494.31 15.57 -6494.40 178.12R 1.00 -1.00 0.05 6030847.54 653337.05 N 70.49119430 W 148.74638603 11200.00 40.08 270.65 8694.19 8750.65 6540.49 16.08 -6540.58 178.09R 1.00 -1.00 0.05 6030847.05 653290.88 N 70.49119557 W 148.74676345 NS16A Kup Flt Tgt 11207.58 40.00 270.65 8700.00 8756.46 6545.37 16.13 -6545.45 177.70R 1.00 -1.00 0.05 6030847.00 653286.00 N 70.49119571 W 148.74680332 11300.00 39.08 270.71 8771.27 8827.73 6604.20 16.83 -6604.28 177.66R 1.00 -1.00 0.06 6030846.43 653227.18 N 70.49119748 W 148.74728420 11400.00 38.08 270.78 8849.45 8905.91 6666.55 17.64 -6666.63 177.60R 1.00 -1.00 0.07 6030845.90 653164.83 N 70.49119953 W 148.74779387 Top Kuparuk 11426.06 37.82 270.79 8870.00 8926.46 6682.58 17.86 -6682.66 177.59R 1.00 -1.00 0.07 6030845.77 653148.80 N 70.49120009 W 148.74792487 11500.00 37.08 270.84 8928.70 8985.16 6727.53 18.50 -6727.61 177.55R 1.00 -1.00 0.07 6030845.45 653103.85 N 70.49120173 W 148.74829232 WeIlDesign Ver SP 2.1 Bld(doc40x_100) NS16\NS16\Plan NS16A\NS16A (P16b) Generated 9/13/2006 2:26 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea TVD Typ Vertical NS EW Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft d d ft ft ft ft ft d de 1100 ft d 100 ft de 100 ft ftUS ftUS End Crv 11584.79 36.23 270.91 8996.72 9053.18 6778.15 19.27 -6778.22 --- 1.00 -1.00 0.07 6030845.13 653053.24 N 70.49120372 W 148.74870602 Kuparuk C 11588.86 36.23 270.91 9000.00 9056.46 6780.55 19.31 -6780.62 -- 0.00 0.00 0.00 6030845.12 653050.83 N 70.49120381 W 148.74872568 LCU / Kuparuk A 11675.64 36.23 270.91 9070.00 9126.46 6831.84 20.12 -6831.91 -- 0.00 0.00 0.00 6030844.83 652999.55 N 70.49120590 W 148.74914490 Fault Crossing 11731.42 36.23 270.91 9115.00 9171.46 6864,81 20.64 -6864.88 -- 0.00 0.00 0.00 6030844.64 652966.58 N 70.49120724 W 148.74941439 Top Miluveach 11861.59 36.23 270.91 9220.00 9276.46 6941.75 21.86 -6941.80 -- 0.00 0.00 0.00 6030844.20 652889.65 N 70.49121037 W 148.75004322 9-5/8" Csg Pt 11900.02 36.23 270.91 9251.00 9307.46 6964.46 22.22 -6964.52 -- 0.00 0.00 0.00 6030844.07 652866.93 N 70.49121129 W 148.75022887 Top Kingak 12707.08 36.23 270.91 9902.00 9958.46 7441.46 29.76 -7441.46 -- 0.00 0.00 0.00 6030841.36 652389.97 N 70.49123063 W 148.75412760 Drp 1/100 13222.51 36.23 270.91 10317.77 10374.23 7746.09 34.57 -7746.07 178.22E 0.00 0.00 0.00 6030839.63 652085.35 N 70.49124294 W 148.75661760 13300.00 35.46 270.86 10380.58 10437.04 7791.47 35.27 -7791.44 178.19E 1.00 -1.00 -0.05 6030839.35 652039.98 N 70.49124472 W 148.75698845 TJC 13336.04 35.10 270.84 10410.00 10466.46 7812.28 35.58 -7812.25 178.17E 1.00 -1.00 -0.05 6030839.22 652019.17 N 70.49124551 W 148.75715855 13400.00 34.46 270.81 10462.54 10519.00 7848.76 36.11 -7848.73 178.14E 1.00 -1.00 -0.06 6030838.96 651982.69 N 70.49124684 W 148.75745 13500.00 33.46 270.75 10545.48 10601.94 7904.62 36.87 -7904.58 178.10E 1.00 -1.00 -0.06 6030838.52 651926.84 N 70.49124876 W 148.75791 13600.00 32.46 270.69 10629.39 10685.85 7959.02 37.55 -7958.98 178.04E 1.00 -1.00 -0.06 6030838.03 651872.44 N 70.49125046 W 148.75835798 13700.00 31.46 270.62 10714.23 10770.69 8011.95 38.16 -8011.90 177.99E 1.00 -1.00 -0.07 6030837.50 651819.52 N 70.49125196 W 148.75879062 13800.00 30.46 270.55 10799.98 10856.44 8063.39 38.69 -8063.34 177.93E 1.00 -1.00 -0.07 6030836.92 651768.09 N 70.49125325 W 148.75921110 Sag River 13842.85 30.03 270.52 10837.00 10893.46 8084.97 38.89 -8084.93 177.90E 1.00 -1.00 -0.07 6030836.66 651746.50 N 70.49125374 W 148.75938753 End Drp 13846.00 30.00 270.52 10839.72 10896.18 8086.55 38.90 -8086.50 --- 1.00 -1.00 -0.07 6030836.64 651744.93 N 70.49125378 W 148.75940039 Bld 6/100 13867.00 30.00 270.52 10857.91 10914.37 8097.05 39.00 -8097.00 HS 0.00 0.00 0.00 6030836.51 651734.43 N 70.49125401 W 148.75948622 7" Csg Pt 13891.53 31.47 270.52 10879.00 10935.46 8109.59 39.11 -8109.54 HS 6.00 6.00 0.00 6030836.35 651721.89 N 70.49125428 W 148.75958872 13900.00 31.98 270.52 10886.20 10942.66 8114.04 39.15 -8113.99 HS 6.00 6.00 0.00 6030836.30 651717.44 N 70.49125438 W 148.75962511 14000.00 37.98 270.52 10968.10 11024.56 8171.34 39.67 -8171.29 HS / 6.00 6.00 0.00 6030835.59 651660.15 N 70.49125563 W 148.76009351 End Bid 14033.66 40.00 270.52 10994.26 11050.72 8192.52 39.87 -8192.47 --- 6.00 6.00 0.00 6030835.32 651638.97 N 70.49125609 W 148.76026663 Ivishak 14079.01 40.00 270.52 11029.00 11085.46 8221.67 40.13 -8221.62 -- 0.00 0.00 0.00 6030834.96 651609.83 N 70.49125672 W 148.76050488 14171.69 40.00 270.52 11100.00 11156.46 8281.25 40.67 -8281.19 -- 0.00 0.00 0.00 6030834.22 651550.26 N 70.49125802 W 148.76099186 OWC 14171.71 40.00 270.52 11100.01 11156.47 8281.25 40.67 -8281.20 -- 0.00 0.00 0.00 6030834.22 651550.25 N 70.49125802 W 148.76099193 TD / 4-1/2" Lnr 14291.69 40.00 270.52 11191.93 11248.39 8358.38 41.37 -8358.32 -- 0.00 0.00 0.00 6030833.26 651473.14 N 70.49125970 W 148.76162236 Le gal Description: Northi ng (Y) [ftUS] Easting (X) [ftUS] Surface : 1199 FSL 645 FEL S11 T13N R13E UM 6030971.56 659829.81 BHL : 1235 FSL 3723 FEL S10 T13N R13E UM 6030833.26 651473.14 WeIlDesign Ver SP 2.1 Bld( doc40x_100) NS16\NS16\Plan NS16A\NS16A (P16b) Generated 9/13/2006 2:26 PM Page 2 of 2 . by Schlumberger WELL NS16A (P16b) FIELD Northstar STRUCTURE Northstar PF Ma9netlc Parameters SuRace Location NA02)Ahska Spta Planes, Zone 0a. U6 Feet MlscalWneous MoEel: BGGM 209fi Qp: B1061' Dale: December 30. 2006 Lat: N)02920.1 )< NoMri~q'. 69399)1.56 RUS Grq DOpv: •1.231106]0' Slat: NS16 NO Ref'. Rotary Table (5046R above M6LI Mag Dec: •2C.300' F6'. SJ6654 nT Lon: WI<e a1 358)8 Eaztln9: 65902901 RU6 Scale Fact: 0.9999290185 Plan: NS16A IP16bi 6nry Date: September 1J. 2006 0 1500 3000 4500 6000 7500 9000 0 1500 3000 4500 0 0 c 6000 m U ?~ 1"' 7500 9000 10500 I \ ~. 1 0 1500 3000 4500 6000 7500 Daru ......... ...... .....a................................ ~~- ~~ 9000 op Miluveach 95/8" Csg Pt Top Kingak Drp 1/100 ::~::-::.::: -:: -::-::-:: -:: i::-:. •~::: -:: -:: -::-:: -: % 10500 End Drp Bld 6/100 •Sag Rifer 7" Csg Pt S16A (P16• Entl Bld Tb / 4-1/2" Lnr 0 1500 3000 4500 6000 7500 9000 Vertical Section (ft) Azim = 270.47°, Scale = 1(in):1500(ft) Origin = 0 N!-S, 0 E/-V by Schlumberger WELL NS16A (P16b) FIELD Northstar STRUCTURE Northstar PF Magnetic Parameters Surtace LocaGOn NND2] P6ska Sble Planes, Zone 04, U5 Feel Miscellaneous MaEel: BGGM 2006 nip: Bt 061' Data: December 20. 2006 Lat N]02928.1 ]4 NaMi~q: 60309]1.56 flUS Grq Conv: .1.231 ]06]8' Slat: NSi6 NO Ref: Rotary Table (5646fl above MSL( Mag Dec: X24.200' FS: 5]665 <nT Lon: W14841368]8 Eas4ng'. 659829.61 ftUS Scale Facl'. 0.9999290185 Plan: NS)6N (P18b~ Srvy Date: BepRmber 13. 2006 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 2000 n 1000 n Z O O O II ~ 0) tC U V V V -1000 ................................... t................................... t..................................;... N i =nd Bld 7" Csg Pt Fault CrosSin . ~Itl 61100 NS16A Kup Flt 7gt 9S/6" Csg Pt KOP Crv 0/100 End Drp Tie-In S4rvey End Crv p ~ .... .......................... ~. .. Drp 1/100 End Crv Drp 1100 516; 4-1/2" Lnr I ......j ..................................:..................................:...................................j..................................~..................................~...................................j..................................j.................................. ~... 2000 • 1000 0 -1000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 «< W Scale = 1(in):1000(ft) E »> • (_ __ 500 3000 x,-500 6000 X500 g000 NS 16/Plan NS 16A ~'O ~ O ._ _______, 00 ,. ?~ O ~Q --- -- i i 'I I i i ~;' A ,~ ~~ i I O . __ _ O \~QO `/SOO ;~~/SQ G ~0~0 -- NS16(NS16) PIanNS16A • • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Wednesday, September 13, 2006 Paul Hanson BP Exploration Alaska Schlumberger Northstar NS16A (P16b) Nabors 33E Close Approach Analysis We have examined the potential intersections of 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 thousand 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. Survev Prooram: Instrument Type Start Depth End Depth GYD GC SS 50.00'md 843.00'md MWD + SAG 933.38'md 3,696.89'md MWD + IFR + MS 3,696.897'md 14,291.69'md Close Approach Analvsis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. ~n s c~ ~~ ~. ~, fi Checked by: Scott DeLapp 09/13/06 • BP Alaska Anticollision Report Company: BP Amoco Meld: Northstar Reference Site: Northstar PF Reference Well: NS16 Reference Wellpath: Plan NS16A NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 5.00 ft Depth Range: 3700.00 to 14291.69 ft Maximum Radius:10000.00 ft Survey Program for Definitive Wellpath Date: 7/28/2006 Validated: No Planned From To Survey ft ft ~ 50.00 843.00 Survey #1 (50.00-843.00) (0) 933.38 3696.89 Survey #2 MWD+Sag (933.38-1232 3696.89 11900.00 Planned: Plan #16 V1 11900.00 13895.00 Planned: Plan #16 V1 13895.00 14291.69 Planned: Plan #16 V1 Casing Points Dute: 9!14!2006 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Time: 14:23:42 Well: NS16, True North NS16 56.5 Page: 1 Db: Oracle Reference: Principal Plan & PLANNED PROGRAM Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 8 Toolcode Tool Name GYD-GC-SS MWD+SAG MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS Gyrodata gyro single shots MWD +Sag correction MWD +IFR + Multi Station MWD +IFR + Multi Station MWD +IFR + Multi Station bID TVD Diameter Hole Site Namc ft ft in in 3494.00 3200.41 13.375 16.000 13 3/8" 11900.02 9307.46 9.625 12.250 9 5/8" ' 13891.53 10935.46 7.000 8.500 7" ' 14291.69 11248.39 4.500 6.125 41/2" Summary - -_ <------------- Offset WeApath - - -- ---z - Reference - Offset Ctr-Ctr No-Co Allo~~abie Site Well Wellpath MD 111D Distance Area Deviation Warning / ft ft ft ft k Northstar Island NORTHSTAR1 NORTHSTAR1 V5 Out of range I~ Northstar Island NORTHSTAR2 NORTHSTAR2 V2 Out of range Northstar Island NORTHSTAR2 NSTAR2PB1 V1 Out of range Northstar PF NS05 NS05 V4 3700.00 4180.00 1539.52 54.85 1484.67 Pass: Major Risk ~, Northstar PF NS05 NS05P61 V8 3700.00 4180.00 1539.52 54.85 1484.67 Pass: Major Risk Northstar PF NS06 NS06 V35 3700.00 6720.00 4854.76 82.29 4772.46 Pass: Major Risk Northstar PF NS07 NS07 V34 3702.81 3855.00 955.13 138.06 817.06 Pass: Major Risk Northstar PF NS08 NS08 V19 3700.00 4040.00 1055.29 90.41 964.87 Pass: Major Risk 'i Northstar PF NS09 NS09 V15 3700.00 7965.00 6036.40 58.91 5977.49 Pass: Major Risk ~, Northstar PF NS10 NS10 V17 3700.00 4495.00 2052.07 111.41 1940.67 Pass: Major Risk ', Northstar PF NS11 NS11 V12 3700.00 6360.00 4469.60 95.20 4374.40 Pass: Major Risk ', Northstar PF NS12 NS12 V30 3700.00 7705.00 5982.82 58.19 5924.63 Pass: Major Risk Northstar PF ~ NS13 NS13 V15 3700.00 3990.00 974.14 50.69 923.45 Pass: Major Risk Northstar PF NS14 NS14 V13 3700.00 3995.00 822.81 86.72 736.08 Pass: Major Risk ', Northstar PF NS14 NS14A V12 3700.00 3995.00 822.73 86.81 735.92 Pass: Major Risk ', Northstar PF NS15 NS15 V20 3747.05 3980.00 472.10 134.85 337.25 Pass: Major Risk Northstar PF NS16 NS16 V40 3705.00 3705.00 0.01 0.92 -0.92 FAIL: NOERRORS '; Northstar PF NS17 NS17 V16 3700.54 4030.00 766.86 114.15 652.71 Pass: Major Risk Northstar PF NS18 NS18 V15 3702.07 4110.00 1327.66 148.22 1179.44 Pass: Major Risk Northstar PF NS19 NS19 V18 3700.00 5435.00 3211.23 84.51 3126.72 Pass: Major Risk Northstar PF NS20 NS20 V14 3701.59 4305.00 1588.76 115.59 1473.17 Pass: Major Risk ', Northstar PF NS20 NS20PB1 V11 3701.59 4305.00 1588.76 115.59 1473.16 Pass: Major Risk Northstar PF NS21 NS21 V60 3704.26 4455.00 1868.18 114.37 1753.81 Pass: Major Risk Northstar PF NS22 NS22 V14 3700.00 5335.00 3292.21 75.81 3216.40 Pass: Major Risk '; Northstar PF NS23 NS23 V36 3702.38 4270.00 1816.41 104.68 1711.73 Pass: Major Risk Northstar PF NS24 NS24 V16 3700.00 4385.00 1776.51 94.38 1682.13 Pass: Major Risk Northstar PF NS25 NS25 V4 Out of range Northstar PF NS25 NS25PB1 V10 Out. of range Northstar PF NS25 NS25PB2 V4 Out of range Northstar PF NS26 NS26 V24 Out of range Northstar PF NS27 NS27 V30 3700.00 4270.00 1651.53 60.26 1591.27 Pass: Major Risk Northstar PF NS28 NS28 V8 3703.57 3780.00 822.59 111.11 711.48 Pass: Major Risk Northstar PF NS29 NS29 V23 3701.76 4090.00 1569.34 114.92 1454.43 Pass: Major Risk Northstar PF NS30 NS30 V5 Out of range !, Northstar PF NS31 NS31 V15 3700.00 4265.00 1683.63 52.70 1630.93 Pass: Major Risk Northstar PF NS32 NS32 V12 3700.00 7155.00 5496.21 81.97 5414.24 Pass: Major Risk Northstar PF NS33 Plan NS33 V10 Plan: PI 3700.31 4240.00 1700.61 115.08 1585.53 Pass: Major Risk Northstar PF NS34 NS34 V7 Plan: Plan #12 Out of range • BP Alaska Anticollision Report I~ i Company: BP Amoco Field: Northstar Reference Site: Northstar PF Reference Well: NS16 Reference Wellpath: Plan NS16A Summary <--------- Offset Wellpath ----> i Site Well Wellpath NORTHSTAR3 NORTHSTAR3 NORTHSTAR3 V7 ~i Seal Island SEAL-A-01 SEAL-A-01 V4 Seal Island SEAL-A-02 SEAL-A-02 VO Seal Island SEAL-A-02 SEAL-A-02A V4 Seal Island ~ SEAL-A-03 SEAL-A-03 V4 I Seal Island SEAL-A-04 SEAL-A-04 V4 Date: 9!14/2006 Time: 14:23:42 Page: 2 Co-~~rdinate(NE) Refe rence: Well: NS16, True North Vertical (TVD) Reference: NS16 56.5 Db: Oracle Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft Out of range 3700.00 4100.00 1328.21 75.77 1252.45 Pass: Major Risk 3700.00 4910.00 2571.77 60.84 2510.93 Pass: Major Risk 3700.00 4920.00 2584.18 59.10 2525.08 Pass: Major Risk 3700.00 5890.00 3554.24 80.90 3473.33 Pass: Major Risk 3700.00 4860.00 2606.08 174.17 2431.90 Pass: Major Risk • • FieldbTorthstar SiteNorthstar PF We11:NS16 WellpathElan NS16A Site: Northstar PF Drilling Target Conf.: 95% Description: Map Northing: 6030835.00 ft Map Easting :651634.00 ft Latitude: 70°29'28.520N Shape: Circle Target: NS 16A Tgt ell: NS16 Based on: Planned Program Vertical Depth: 11000.00 ft below Mean Sea Level Local +N/-S: 39.65 ft Local +E/-W: -8197.43 ft Longitude: 148°45'37.106W Radius: 300 ft ~\ O % ~ O O O ~ ~ O ~ ~ O i I I I i O _.. O O O O C~ N ~ ~ I O O O O i ~I O O O O O O - O ~ O~ ~ O I O I ~ I l- I ~ I -~~~ ~~~ O O ~D I • d SONDRA D STEWMAN ss-si~zsz 148 BP EXPLORATFON AK INC "Mastercard Check" PO BOX 196612 MB 7-5 '~' ANCHORAGE, AK 9951.9-6612 DaTE C~~P ~ ~.,~,~Y PAY TO THE --~~~ S ~LJL~. •Li~s ORDER OF ~ First-National ank .Alaska Anchorage, AK~ r9^79'JJ5~~~0F1 MEMO ~: L 25 2Q0060~:99 L4~~~6 2 27~~~ L 564~I' O L48 • TRANSMITTAL LETTER CI3ECKLIST WELL NAME ~~~,~ ~~> /~ PTD# ZD~ ., / ~ ,, , Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS WHAT j (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well (If last two digits API number in ~ Permit No. ,API No. 50- - - between 60-69) are i Production should continue to be reported as a function of the I I ~ original API number stated above. i PILOT HOLE Irt accordance with 20 A.AC 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 ' (~0- - -_) from records, data and logs I acquired for well - i SPACING j The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.05~. Approval to perforate and produce i inject is contingent I 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 j 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: ~ production or production testing of coal bed methane is not allowed Well ;for (name of welly until after (Com a~nv Name) has designed and j 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 Rev: 1125/06 C:`jody`transmittal checklist WELL PERMIT CHECKLIST Field & Pool NORTHSTAR, NORTHSTAR OIL - 590100 _ _ _ Well Name: NORT_HSTAR UNIT_N$-16A _ ___ Program DEV_ ___ Well bore seg I _' PTD#:2061410 Company BP EXPLORATION (ALASKA) INC ___ _ __ _ Initial ClasslType _DEV 11-01L GeoArea 890. _ _ Unit 11500 __ _ On10ff Shore Off __ Annular Disposal '] Administration ' 1 Permit fee attached Yes II2 Lease number appropriate Yes i3 .Unique well name and number Yes 4 Well located in a defined _pool Yes i5 Well located proper distance from_ drilling unit. boundary- Yes 6 Well located proper distance from. other wells. Yes ~!,7 Sufficient acreage available in drilling unit _ Yes _ - 'S If deviated, s_wellbore plat included _ Yes ~i9 Operator only affected party Yes 10 Operator has appropriate. bond in force _ Yes 111 Permit can be issued without conservation order Yes !12 Permit can be issued without administrative_approval Yes Appr Date 13 _Can permit be approved before 15-day wait_ Yes RPC 10!2!2006 114 Well located within area and strata authorized by Injection Order # (put 10# in-comments) (For_ tJA_ I,15 All wells-within 1/4-mile area of review identified (For service well only) NA 16 Pre-produced injector: durat_io_n ofpre-production I_essthan_ 3 months_(For service well only) NA_ 17 Nonconven. gas conforms to AS31.05,030(j.1,A),(j.2.A-D) NA_ _ _ _ _ 18 Conductor string_pravided NA Engineering j19 Surface casing protects all kngwn_ USDWs NA ',20 CMT_vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate-to tie-in_long string tosurf csg _ _ _ _ _ No I22 CMT_will coyer all known_productive horizons_ Yes Adequate excess. 23 Casing designs adequate for C, T, B & permafrost_ Yes _ 124 Adequate tankage or reserve pit Yes Nabors 33E. 125 If a re-drill, has a_ 1.0-403 for abandonment been approved Yes 26 Adequate wellbore separation proposed _ _ _ . Yes _ _ _ _ X27 If diverter required, does it meet regulations- NA_ - Sidetrack. - !28 Drilling fluid program schematic & equip list adequate_ Yes Max MW 12,3_ppg. Appr Date 'I29 BOPEs,_do they meet_ regulation Yes WGA 10/3/2006 130 BOPE_press rating appropriate; test to (put psig m comments)_ Yes Test to 5000 psi. MSP 3775 psi, 31 Choke manifold complies wlAPl RP-53 (May 84) _ _ _ _ Yes _ I32 Work will occur without operation shutdown_ _ Yes _ _ _ _ 33 Is presence of H2S gas_ probable _ _ _ - _ No Not an H2S area._ _ 34 Mechanical condition of wells within A0R verified (For service well only) NA_ _ - 35 -- - Permitcan be issued w!o_ hydrogen sulfide measures No_ - __ _ Geology x'36 Data_presented on_potential overpressure zones NA_ 37 Seismic analysis_ of shallow gas zones_ NA_ Appr Date 38 Seabed condition survey (if off-shore) _ NA _ RPC 10/2/2006 X139 Contact namelphone for weekly progress reports [exploratory only] NA Geologic Engineering Date Commissioner: Date: Commissioner: Date Co issio DTs ~~/~ ~~ ~0 3-0~6 _ _ _ __ • • Well History File APPENDIX Information of detailed nature that is not ~~ particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efi(ort has been made to chronologically . organize this category of information. PL Advisor Production Log Interpretation With GHOST and DEFT Company Field Well Date Logged Date Processed Reference Number API Number Log Analyst Reviewed By BP Exploration ~Alaska-, Inc. Northstar NS-16A 12-Sep-2008/16-Sep-2008/21-Oct-2008/ 12-Feb-2009 01-Oct-2008 12083411 /11970846/12031525/ AYTO-00005 50-029-23096-01 Jenna Taylor Erika Bowen Alaska Data and Consulting Services 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 (907) 273-1700 III interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and de shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting ~om any interpretation made by any of our officers, agents or employees. These Interpretations are also subject to clause 4 of our general terms and conditions asset out in our currei rice schedule. BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar 1. Production Logging Objectives: The objective of this logging suite was to evaluate fluid entry into this wellbore in order to determine the production splits. Production logs were acquired on four separate dates to evaluate an acid treatment. 2. Main Results: Table 1 Interpreted Downhole Results Pre-acid Treatment De th Oil Water Gas From Ft To Ft Downhole BPD % Downhole BPD % Downhole BPD 14274 14289 1498.1 100% 10.9 5% 9489.8 95% 14303 14308 0.0 0% 88.7 48% 532.8 5% 14320 14339 0.5 0% 87.0 47% 0.7 0% Total 1498.6 186.6 10023.3 Table 2 Interpreted Downhole Results Post-acid Treatment Depth Oil Water Gas From Ft To Ft Downhole BPD % Downhole BPD % Downhole BPD 14274 14289 2266.6 94% 0.0 0% 6143.0 94% 14303 14308 129.5 5% 298.2 51 % 357.5 5% 14320 14339 5.9 1 % 286.4 49% 0.4 0% Total 2402.0 584.6 6500.9 Table 3 Interpreted Dnwnhele Results ~cteber 21.2008 Depth Oil Water Gas From Ft To Ft Downhole BPD % Downhole BPD % Downhole BPD 14274 14289 2051.1 98% 254.9 44% 8708.4 100% 14303 14308 42.1 2% 27.8 5% 47.9 0% 14320 14339 2.0 0% 300.7 51 % 0.0 0% Total 2095.2 583.4 8756.3 Table 4 Interpreted Downhole Results February 12. 2009 Depth Oil Water Gas From Ft To Ft Downhole BPD % Downhole BPD % Downhole BPD 14274 14289 1816.8 99% 90.3 13% 6435.6 89% 14303 14308 17.1 1 % 448.8 65% 793.6 11 14320 14339 1.3 0% 153.7 22% 1.1 0% Total 1835.2 692.8 7230.3 2 ~, BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar Table 5 Internreted Surface Results converted from downhole rates: Pre-acid Treatment Depth Oil Water Gas From Ft To Ft Surface STBPD % Surface STBPD % Surface Mscf/D 14274 14289 1125.2 100% 10.5 6% 6225.0 95% 14303 14308 0.0 0% 84.0 48% 302.0 5% 14320 14339 0.4 0% 82.2 46% 1.5 0% Total 1125.6 176.7 6528.5 Table 6 Internreted Surface Results converted from downhole rates: Post-acid Treatment Depth Oil Water Gas From Ft To Ft Surface STBPD % Surface STBPD % Surface Mscf/D 14274 14289 1290.6 94% 0.0 0% 8970.5 94% 14303 14308 73.7 5% 284.4 51 % 524.2 6% 14320 14339 3.4 1% 272.8 49% 10.7 0% Total 1367.7 557.2 9505.4 Table 7 Internreted Surface Results converted from downhole rates: October 21.2008 Depth Oil Water Gas From Ft To Ft Surface STBPD % Surface STBPD % Surface Mscf/D 14274 14289 1318.9 98% 243.3 44% 9513.6 99% 14303 14308 27.1 2% 26.4 5% 68.9 1 14320 14339 1.3 0% 285.2 51 % 6.3 0% Total 1347.3 554.9 9588.8 Table 8 Internreted Surfare Results converted from downhole rates: Fehruarv 12.2009 Depth OiI Water Gas From Ft To Ft Surface STBPD % Surface STBPD % Surface Mscf/D 14274 14289 1073.2 99% 86.2 13% 8506.3 90% 14303 14308 10.1 1 % 427.8 65% 913.1 10% 14320 14339 1.0 0% 146.3 22% 5.2 0% Total 1084.3 660.3 9424.6 3 BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar 3. Production Log Interpretation: BP Exploration (Alaska, Inc. (BP) well NS-16A is a producing well located in the Northstar field. This well was completed with 2 7/8" 6.4 Ib/ft liner with perforations located in the liner. The NS-16A well was logged with the PS Platform production logging tools consisting of gamma ray, CCL, temperature, pressure, gradiomanometer, ILS, turbine PFCS spinner, X-Y caliper, DEFT and GHOST .The tools were conveyed with electric line using surface readout. The single perforated interval in this well 13274-14339, was sub divided into three intervals for analysis between pre and post stimulation. Data was correlated to provide base gamma ray. Data intervals for interpretation were kept uniform for each interpretation to allow comparison. All interpretations were preformed with Kappa's Emeraude software package. Downhole contribution per zone was determined with a 3 phase correlation model using Standford Drift for both liquid-gas correlation and water-oil determination. Data spikes were selectively removed from both DEFT and GHOST probe data before determination of water and gas holdups using Schlumberger MapFlo* algorithm. Pre-acid Summary September 12, 2008: Production log was acquired on Sep 12, 2008 prior to an acid treatment. The surface well test at this time reported: 1130 bopd, 175 bwpd, 7.6 MMSCF. ' The downhole temperature and pressure at 14,376 ft. are 257°F and 1,912 psi Post-acid Summary September 16, 2008: ' Production log was acquired on Sep 16, 2008 after an acid treatment. At this time the surface test reported: 2000 bopd, 300 bwpd and 9.7 MMSCF. Surface rates were not confirmed at the time. The downhole temperature and pressure at 14,360 ft. are 260 °F and 4,199 psi. i, October 21, 2008 Summary: The well test performed during this phase of the operation indicated, 1300 bopd, 500 bwpd and 9.6 MMSCF. The downhole temperature and pressure at 14,360 ft. are 261 °F and 3,188 psi. ' February 12, 2009 Summary: The well test performed during this phase of the operation indicated, 1169 bopd, 600 bwpd and 9.8 MMSCF ' The downhole temperature and pressure at 14,376 ft. are 258 °F and 3,891 psi r 4 BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar Figure below shows downhole cumulative zonal (QZT) rates for all four tests. 5 i ~, BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar 3.1. Interpretation Results: Production interpretation at downhole conditions. Nre-acid Ireatment1Z-Sep-ZD08 6 BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar Interpretation Results: Production interpretation at downhole conditions. ~ost-acia i reatment i b-Sep-~uuts Depth ell Sket Z GR QZT QZI Interpretation # 1 (ft? {in) -50 GAPI 45D -100 BID 15000 -1 DOD B!D 90DD '~i'aTEF' F'~~_1,11 ate ~~ °F ~h~ i+v"RE Past,! 1 a ~ is usia =. 7 ~ ~ BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Interpretation Results: Production interpretation at downhole conditions. (lrtnhPr 71 7f1nR g BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Interpretation Results: Production interpretation at downhole conditions. February 12, 2009 9 1 1 1 1 1 1 1 1 1 1 1 1 1 • BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar 3.2. The figure below represents GHOST gas holdua and DEFT water holdup data at downhole conditions. Pre-acid Treatment 12-Sep-2008 10 1 s BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar The figure below represents GHOST gas holdup and DEFT water holdup data at downhole conditions. post-acrd I reatment 16-Jep-LUUtf Depth Z ell Sket ~Zr GHOST Bub 1 DEFT Bub 3 Interpretation ~ 1 (n) (in) -100 BiD 15000 0 3363.5 0 972.851 ~~~7E~ Pos[ N TI53lY~ _:'-1 7~~ 11 • • BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar The figure below represents GHOST gas holdup and DEFT water holdup data at downhole conditions. October 21, 2008 Depth Z OZT GHOST Bub 6 {ft) _1 G0 B!D 15000 0 3385.44 0 Interpretation # 1 1712.6 vVTEF ~: s~ N _'4-1 -'F ir.a. 12 BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar 13 The figure below represents GHOST gas holdup and DEFT water holdup data at downhole conditions. BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar 3.3. The figure below represents stacked Up/Down flowing passes of PSP sensors. Pre-acid Treatment 12-Sep-2008 Depth GR Calipers ell Skeic Z SPIN VVPRE WFDE WTEP (ft) -50 GAPI 50D F'FI_:1 F'rE,l-l1 (in) -20 rps 130 1855 psia 1925 0 glcc 1.4 220 °F 270 ---- - -1.97848 -i ire ? ''~ ~ I I I C ~' '- 1 I ~ I' i ~ ~ I j , ~ ~ ~ l~ ~ ~ ~ ~ i I I ~ i i I ~ ~ ~ '. ~~ ~t i ~ l _ I I I. ~~ P '~ ,1 ~1 T.,l. I t '' i ~ ~er-. l i _` ~ ~ _.. _ ~ I ~~ u l 5 ~ . ~ ~~ ~~,li I i - ,~' .. I i; ~~- ~- ~~': r. ~~ f ~r i ~ ~ ~F . 'P 14300 ~ l ~ ~ ~ '~ I ~ . J`~) I ~, I I I 1 l i~~ I ~ ' Y Il, ~ ~~, l i. i l ItI ~l I l ` ~- ~i , lull ~ 555 li~ A l 00 ~ I I I I ~ ~, ~ I ll i I ~ ~. I ~ n , ~. ~- 1 I !l~ l l 8l 3~~~ ~~ ~' ~ i l ~. :~r . , ~ l I ~ li , ~ I i ~ ~, i ill li ll I ~l 1~ I l,4 I! , ~l l '1~~~ "i ~ll~o, 'l~'l l~ ~,' ,i E ~I E - 14 BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar The figure below represents stacked Up/Down flowing passes of PSP sensors. Post-acid Treatment 16-Sep-2008 Depth GR Calipers e ll Sket Z SPIN WPRE UWFD WlEP (ft} -50 GAPI 450 PFG1 F'ost,D1 (in} -2D rps 110 4130 psia 4210 0 glcc 1.8 248 °F 262 - iri I I I ~ ' ~ i ~ ~ I ~ !~ l , ~ I~ I I ~~ ~~ '! ~, ~ ~, ! ;~ I ~~I I I , I ~ _ ~' ~ ~ ~ j I , I ~~ II , ~, ''? alp,, ~;~ II ~, ' ~~ ~, Ji 4,;. ~ I I '(f i - ~ I '~ I I I I I I I III I I' I + I 4 r ~( jl, I I t ~', '~~ ~ 'I I , .I 14300 ~ I ~ ' 'i j , I .I, I ~ I i ~. 11 f i 1 ~ ~ I ~' E~ I it ~ ~ ` ~~ li ~ I I I I I I i I I I j ~ t ~ I I ! i Q i i I II I iI ~ 1'I I I' I i, ~I'I !~ II+{{ 1 I I l 'G 'il ill ' I ' t 1 i 4400 I i I I I I II I I %;. I I I § li I 15 ~ ~ BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar The figure below represents stacked Up/Down flowing passes of PSP sensors. October 21, 2008 Depth ID Calipers ell Sketc Z SPIN WPRE UWFD WTEP (n) -1.4 in 1.4 FF!:1 ~=i_21 11 (in) -20 rps 13D 3115 psia 3195 -2 gicc 4 242 °F 264 - -1.91I~848 -7 iri ~, I i [ I I I 1 I I ~ I I I I I I I i ~ (~ °I ! ` C y I I I I I ~ I t ; I, ~ ~i~ ~,:~ ,:. I I I I ~ ' ~ ~~ ~ ~~ '~ ~t I I I I I I i ~ ~~ I i I I I I ~ 14300 i i I I ~, j ~ i I ~ ~ ~~" ~~ e; ; I II ~ I I I I I I ~~ oD I I I I I I i i I i , ti I ~ C I I I I ;I i r' °~ ,. ~;, s;: I I I I I t I 1 ! ~ i I li I i iI ti I' ,, I I I I I I i I I I I I I I I i I 16 • BP Exploration (Alaska), Inc. Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Well: NS-16A Field: Northstar The figure below represents stacked Up/Down flowing passes of PSP sensors. February 12, 2009 Depth Calipers ID ell Sketc Z SPIN WPRE UWFD IMEP (ft} FF!= 1 84,U2^o -1.4 in 1.4 (in} -20 rps 120 3825 psia 3900 0.2 g/cc 1.2 246 °F 262 -1.979.848 in ='F,. t I I ! I ~i i ~; sl r Sli' li ~ I I I I ~~. ~~. :. I I I I ' 11 ~~~ ~i I ~. ~ ~ ~` I . ~,. . I ~i I h °- l`` I I ~ ~. I ~:. I I P I 1 ~ I 1 i I l i ~- I ~ I I rs; 'I I 1Y I!' ~ ~ I I ~ ~- 3 00 I I I ~ ~I .~_ ' ~" I , ~~ I~i i r f II I r, i ,~1 ~ I i I I I &~: ` S it 'I I ' I I I IC ; ~ 1 ~ ~ ~ t I I w{=; .~ b ~~" ~ I I ~ I li I, 111 ~ I 111 I,.. III ELI i. ~ - I 'I II'll i ~If ~I I ' ~i ~ ~' I ' `~: I ' i~ ~ ~ i i I ~ i ," ! ,~ ~~ ~! ' I I ~ ' ~ is ~ I ~. a4 00 ~I I I ,', ~ I 17 BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar 3.4. Interpretation Results: Flowing Passes Pre-acid Treatment 12-Sep-2008: Figure below shows tlownhole cumulative rates both zonal (QZT) antl continuous (Q-. Curves to the left are stacked input curves to model (red) along with reconstruct over-lay (green) to show quality control of rate analysis to acquir eu rne asurernen ts. Depth Z ell Sketch Calipers Density match asholdupmatch VelociHmatch aterholdupmatc QZT Q (ft) (in) FF _ t Pre,i_i1 0.2 glcc 2 0 1 -200 fkmin 1600 0 1 -100 BID 15000 -1000 B!D 15000 -1.9iL6848 - - - 1~'dFDE Fre,it ~,Pily Fr?,11 ire .~._~ . ~ , fG F're,ll C r"~+1r_GFT F're,ll i - _,,, r I I I I I k : °4 i;,. - s i ' ~ I I I I I I I i j. . r I I 14300 ~ [ ~~,~~~ '4 .' ~ i ~ I I i ak {~~` y I t ~~~ 1e~, li ' 14400 '*'~.. d+ ~ l { 1g • BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Interpretation Results: Flowing Passes Post-acid Treatment 16-Sep-2008: Figure below shows tlownhole cumulative rates both zonal (QZT) and continuous (Q-. Curves to the left are stacked input curves to model (red) along with reconstruct over-lay (green) to show quality control of rate analysis to acqulrea measurements. Depth Z ell Sket Calipers DensiA/match as holdup match ater holdup matt Velocitymatch QZT Q (ft) (in) F'F?'1 Postp1 0 glcc 1.8 0 1 0 1 -100 fVmin 1400 -1000 BID10000 -1000 B1D 11000 ~.~~ --- U iFD F.:.aI1 _ r .! '!'; tiF'IPd F'n~t,ll in ? - - fG Post,l1 `MJ_DFT Post,ll :.: ,~' , S I I I I I i I I I ll I I I I I I 1 I k' '„ <: i II I I 14300 I I C ~ _- s :~, i I I i i ~I I I ~ 6E t i I I j ~ 400 I I I I I i (~I 1, ~i I I , 19 • BP Exploration (Alaska), Inc. Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Well: NS-16A Field: Northstar Interpretation Results: Flowing Passes October 21, 2008: Figure below shows downhole cumulative rates both zonal (OZT) and continuous (O-. Curves to the left are stacked input curves to model (red) along with reconstruct over-lav lateen) to show quality control of rate analysis to acquired measurements. Depth Z ell Sketc Calipers Density match as holdup match ater holdup matt Velocity match QZT Q (ft) (in) FF r_ 1 r ~ 11 U 1 -2 gJcc 4 0 1 0 1 -200 ffimin 1800 -1000 BJD 12000 -200D 81D 22000 -1.9Z~B48 - ~::~~F'qd (i tl I1 in _ ~,rcC _ e1 I' ~ : - sl I' 6F7 - ~ I II ~I~' ,.. Vii,.. ~> ~ I I i I I I I I I ~ I I I I I ¢ r ~ ~,. I I I I I I i I I ~ ~ 4 ~„ l I ' I .S t ~ I ! I~ I~ 14300 I 11. "' C ~, " I I I I I I , I I. P l ~; ~~ ~: ~r"' ~. y I ~ I I, I I ~ ~~: Ig' ~' , ' I I I I I I I I I I I I I I I I I I I 14400 I I I I I I I I 20 • i BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar Interpretation Results: Flowing Passes February 12, 2009: Figure below shows downhole cumulative rates both zonal (QZT) and continuous (Q-. Curves to the left are stacked input curves to model (red) along with reconstruct over-lay (green) to show quality control of rate analysis to acquired measurements 21 ~ • a BP Exploration (Alaska), Inc. Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Well: NS-16A Field: Northstar 3.5. Spinner Calibration: Pre-acid Treatment 12-Sep-2008 0 so so ao za -160a -800 -2a 800 1600 -40 -60 -80 -100 -120 rps versus fUmin Threshold (+] 9 ftlmin Threshold (-] -9 ftJmin Calib. Zone Slope (+] Slope (-) Int (+] Int (-] Int. Diff. ft ft/min ft/min ft/min ^ 14217.0-14255.0 0.059 0.061 -1756.87 -1710.97 -45.90 p 14346.0-14380.1 D.077 0.063 0.96 -17.04 18.00 22, • i BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Spinner Calibration Post-acid Treatment 16-Sep-2008 rps versus ftlmin Threshold (+) 9.9 ftlmin Threshold [-) -9.9 ftlmin Calib. Zone Slope (+} 51ope (-) Int (+) Int (-) Int. Diff. ft fflmin ft/min fvmin ^ 14216.5-14255.4 0.069 NIA -1282.52 NIA 0.00 D 14292.5-14298.5 0.078 NIA -139.15 NIA 0.00 + 14345.7-14353.0 0.078 0.063 9.93 -9.91 19.84 8a so 40 2 -800 800 -20 -40 -60 -80 -100 23 • BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Spinner Calibration October 21, 2008 00 so so ao zo -soo .20 soa -ao -so -so -100 -120 rps versus ftlmin Threshold (+] 6.85 ftlmin Threshold (-] -s.85 ftlmin Calib. Zone Slope (+] Slope (-) Int (+] Int (-) Int. Diff. ft ftlmin ftlmin ft/min ^ 14217.0-14255.0 0.086 NIA -1261.18 NIA 0.00 p 14292.3-14299.9 0.078 0.047 -42.14 -55.84 13.70 + 14346.0-14380.1 0.074 0.041 7.30 -6.40 13.70 24 • • BP Exploration (Alaska), Inc. Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Spinner Calibration February 12, 2009 sD 60 40 -800 80D -20 -d0 -60 -80 -1 D0 rps versus ft/min Threshold (+} 1.15 ftlmin Threshold (-} -1 .15 ft/min Calib. Zane 51ope (+} Slope (-] Int (+} Int (-} Int. Diff. ft ftlmin ft/min ft/min ^ 14217.0-14255.0 0.077 NIA -1277.06 NfA 0.00 O 14292.3-14299.9 0.083 NIA -188.16 NfA 0.00 + 14346.1-14364.3 0.08D 0.057 2.78 2.90 -0.12 25 ' ~ • BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar 3.6. Summary Table Results Pre-acid Treatment 12-Sep-2008: Inflow Zone (stable calculation zones) Inflow zones 1 Inflow zones 2 ;Inflow zones 3 From ,ft 14274 143D3 14320:' To ,ft 14289 14308 143391 'Water , _ _ _ FVF _ 1.D438 1.0556 1.05841 Viscosity cp D2669' 0 235 _ 0 2291'. Density, glee 0 97' 0 96' _ 0 96'. Oil+Gas F VF 1.3314 1.3343 ! 1.3362 '. Viscosdy, cp 0.3371: D.3133 0 3081'. Density, glee _ 0.67 D.66 _ 0.66'; .Gas FVF 0.0094 ` O.OD99 ` 0.01' Viscosity,. cp O.D169' 0 0171 ! 0 D172 Density, gfcc D.0942' 0 D893 0 0886 Temperature, °F 231.42 _ 256 27 _ 261 85':. iPressure, psis 1874.6.: 1885.8;. 1895 6 :Diameter, in 2.441 2.441 2 441' Deviation, ° 21.93 19.53 ' 18.94' ..Roughness 2.46E-04" 2.46E 04 2.46E-04 Rs, cffbbl 502 d75 d71' Rsw, cffbbl 10.7 11.41 11.6', V mixture, ftlmin 1400. 85.1 10.6'. .Vise. Mixture , cp 0.0652 0.12 0 23' Vpcf _ 0.91 ' 0.87 0.84!. Q total res., BID 11678! 708.96 88.18' dQ res., BID 10998.8: 821.02 _ . 88.181 OJ° Qt 93.94, 5.31 0.75''. Qw total res., BID 184.42' 175.44': 86 96 it Qwtotal s. c., STBID 176.67' 166 19 82 16' dQw res., BfD 10 94 88 71 86.96': dQw s. c. , STBID ' 10.48' 84.03' 82.16' Qo total res., BID 1498.06 0 0.52' Qo total s. c., STBID 1125.19 0; 0.39' dQo res., BID 1498.06': -0.51 ; 0 52" dQo s.c., STBID 1125.19'. -0.39 _ 0.39'. Qg total res. , BfD ' 9995.51 ' _ 533.53 0 7 Qg total s. c., Mscf1D 6528.55 303.53 1 53' dQg res., BfD ' 9489.8 53283 0.7. dQg s. c., Mscf/D 6225.02' 30' 1.53, V Superficial Vsw, ftlmin ' 22.128 21.048 10.433 Vso, ftlmin 179.73 0 0 062' Vsg, ftlmin ... 1199 22! 64.01 _ 0.084; V Average Vw, ftlmin 1290.93' 42.553' 10 463' Vo, ftlmin 1306.89 D 42.333' !Vg, ftfmin 1418.83 . 126.883- 59.453'. Yw 0.01.7 0.495. ..... 0.997' !yo 0.138. 0' 0.001'. V g 0 845 '. 0 505 0.001 Vslip, ftlmin 113.504 83.986 64 02' Vslip W-O, ftlmin 2.469 31 824; :Regime Distributed :Distributed Distributed !Carrel. Stanford Drift Flux LG !Stanford Drift Flux LG Stanford Drift Flux LG Carrel. W-O Stanford Drift Flux LL Stanford Drift Flux LL Stanford Drift Flux LL Oil fraction 0.$9 0.0029 0.0059' 26 BP Exploration (Alaska), Inc. • Well: NS-16A Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Field: Northstar Summary Table Results Post-acid Treatment 16-Sep-2008: Inflow Zone (stable calculation zones) ':Inflow zones 1 Inflow zones Z Inflow zones 3 -.From ,ft 1427A 143D3 14320' To ,ft 14289:.. 143D8 _ 14339': Water F V F 1 .0468 ' 1.0485 !, 1 .05 Viscosity, cp 0.2383 O 2343 i 0.2311 '-. Density, glee 097, 0.97} _0.97,- Oil+Gas F VF 1.7561 ' 1.7559 ; 1.7533'. Viscosity, cp ', 0.2177'. 0.2159.,.. D.2148' Density, gfcc D 57'', 0.57' O 57' Gas , FVF 0.0047 D.D047' 0.0047' Viscosty, cp 0.0237 0 0237 0.0237' Density, gfcc ' 0.19 4.19' 0.19 Temperature, °F 253.32 256.93. 259.9' .Pressure, psia 4171 .2' 4188.5 4190 9' Diameter, in 2.441 2.441 2.441'. Deviation, ° 21.93. 19.53, 18.94'. Roughness 2.46E-04' 2.46E-04; 2.46E-04 Rs, cflbbl 1230' 1230 1220 !Rsw, cffbbl 21.8' 22.2 22.5: V mixture, ftfmin 114D 129 35.1 Vise. Mixture cp 0.0885 0.18 D 23 Vpcf ; 0.91 ' O 88! 0.86 Qtotal res., B!D `. 9484.38' 1D77.45j 292.68 dQ res., BfD 8409.66' 785 18, 292.68' Qt 88.64''.. 8.28'; 3 D8'' 'Qwtotal res., BID 583.22' 584.19' 28638!. Qwtotal s.a, STBlD 557.17' 557.17' 272.75' dQw res. , B!D O 298.21 ' 286 38' dQw s.c , STBfD O 284 42 272.75' Qo total res., B!D 2401.89'. 135.35' S 87' Qo total s. c. , STBlD 1367.71 ' 77 08' 3.35 dQo res., B!D 2266.63' 129.48 5.871 dQo s. c. , STBfD 1290.631 73 73' 3.35' Qg total res., B!D 6499.28' 357 92 0.4d' Qg total s. c., MscffD - 9505.43 534.93 1073' dQg res., B!D 6143.03 357 49 0.44 dQg s. c., MscfJD 8970.5 524.21'. 10 73 V Superficial Vsw, ftfmin 69.971 ' 7D.088 34.359'. Vso, ftfmin 288.167: 16.238' 0.704'' jVsg, ftfmin .. 779.753 42.942 0 052'. V Average Vw, ftfmin 1088.61. 114.578'. 35.137' Vo, ftfmin 1D96.69' 119.186'. 38 934'' Vg, ftfmin 1158.69', 170.368 12.851 Yw 0.064'. 0.612• 0.978'. Yo 0.263 0.136 ! 0.018': Yg 0.673 0.252' 0 004' Vslip, ftfmin 63.588 54.95' 51.403 Vslip W-O, ftfmin ` 2.641' 3.4461 3 781 Regime Distributed Distributed Distributed Correl. 'Stanford Drift Flux LG Stanford Drift Flux LG Stanford Drift Flux LG C:orrel. W-O Stanford Drift Flux LL Stanford Drift Flux LL Stanford Drift Flux LL Oil fraction 0.8 0 19 0 0201 27 BP Ex loration Alaska), Inc.• • Well: NS-16A p Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar Summary Table Results October 21, 2008: Inflow Zone (stable calculation zones) ;Inflow zones 1 'Inflow zones 2 '.Inflow zones 3 .From ,ft _ _ 14274' 14303 14320 To ,ft 14289' 14308'. 14339 Water FVF 1.D476' 1.0535' 1.0544 Viscosity, cp 0.2441 0.2307'- _ 0.2289 Density, glcc 0.97' 0..96; 0..96! Oil+Gas FVF 1.5551 i 1.5535 1.5532' Viscosrty,_cp__ ! 0.2527" 0.2457 0.2447'. Densely, gfcc D.61 0.61 0,61 .Gas FVF 0.0059'. D.006' O.OD6' Viscosty, cp 0.0206; 0 0206 0.0206' '.Density, g/cc 0.15' 0.15 0.15! Temperature, °F 248.3 26Q2f5 262.11'.. Pressure, psia 3144.2' 3168.1 3171.5' Diameter, in 2.441 2.441 2.441'. Deviation, ° 21_93 19.53 18.94' Roughness 2.46E-04 " 2 46E-04 2.46E-04' 'Rs, cflbbl 891': 872 869-- Rsw, cffbbl 17.1 ' 18 1.8.1 V mixture, ftlmin 1370. 50.4'. 36.3' Visc. Mixture , cp 0.0766 0.22 0.23' Vpcf 0.91 0.86 0.86' O total res., BID 11431.6 420.2'. 302.7'. dQ res., BID 11D14.3' 117.76'. _ 302.7'. °!° Qt 96.32' 1.03' 2.65'. Qwtotal res., BID 581.24! 3282 30D.71 Qwtotal s. c., STBID 554.82 311.54': 285.19': dQw res. , BID 254.86 27.76'. 300.71'. dQw s. c., STBID 243.27'.. 26.35, 285.19', Qo total res., BfD 2095.12'. 44.09' 1.99' !Qo total s. c., STBID ', 1347 27' 28.38' 1.28! dQo res. , B!D 2051.12 42.1 ' 1 .99' dQo s. c., STBID 1318.89' 27 1' _ 1.28 Qg total res., BID 8755.22~ 47 9 0! Qg total s. c., MscffD 9588.79'.. 75.2' 6.281. dQg res., BID 8708.36' 47 9' 0'- dQg s.c., MscffD 9513.58', 68.93. 6.28' V Superficial Vsw, ft/min 69.735: 39.377' 36.078'. Vso,ftlmin 251.363' 5.29'. 0.239' Vsg, ftlmin . " 1050 41' 5.747' 0' V Average 'Vw,ftlmin 1310.65 46.943 36.408!: Vo, ftlmin 132122'.. 50.502 26 321'. Vg, ftlmin 1388.43', 101.844. 0' Yw 0.053' 0.839'. 0.991' Y o 0.19 !" 0.105 0.009'. Y g 0.757 0.056 i 0' 'Vslip, ftlmin ' 69.519' 54.506 0': Vslip W-O, ftlmin 2.574 3.358 10.08$'.. 'Regime Distributed Distributed Single phase ligwd Correl. .Stanford Drift Flux LG Stanford Drift Flux LG '.Stanford Drift Flux LG Correl. W-O Stanford Drift Flux LL Stanford Drift Flux LL Stanford Drift Flux LL Oil fraction 0.78' 0.12 ', 0.0066 28 BP Exploration (Alaska), Inc • Job Number: 1 208341 1 /1 1 970846/1 2031 525/AYTO-00005 Inflow Zone (stable calculation zones) Summary Table Results February 12, 2009: !Inflow zones 1 Inflow zones 2 ':Inflow zones 3 _ _ 'From , ft 14274 14303' 14320'. To_,ft 14289 14306 14339'', 'Water f FVF 1.D468 1 0491. 1.0505' Viscosity,. cp 0.2406 0.2351. 0.2322'.. Density, gfcc 0.97- 0.97; 0.97, Oil+Gas _ _ _____ FVF 1.6929', 1.6921 ` 1.69D5 Viscosity, cp 0.2273 _ 0 2248 0.223E Density, gfcc 0.58.: . D.58, 0.5E !Gas , FVF D.005 0.005 D.005' _._ .. ; Viscosity,_cp O.D228 D.0~28 O.D227' ' Density, gfcc 0.18 _ D.18 0.18 ' Temperature, °F 251.26 256.181 258.88' Pressure, Asia 3854.2 3871 9; 3875.7 :Diameter, in 2.441 2.441 ; 2.441 Deviation 21 .93 19 53, 18.94. Roughness. 4.10E-04 410E-04; 4.10E-04'. Rs, cflbbl 1130'. 1120 1110' Rsw, cflbbl ' 20.4 20.8; 21 V mixture, ftfmin 1170; _ _ 170,,. 18.7 Visc. Mixture , cp O.D79 0 13; 0.23' Vpcf 0.91 0 88' 0.85'. O total res., BID 9750.81 1415.42- 156.1'. d0 res. , BID _ 8342.81: __ 1259.53!. 156.1 Qt 85.49' 12.91 1.8i :Qwtotal res., BfD 691 18! 802.27! 153.7' Qwtotal s. c., STBfD 88028! 574.08] 146.31'. dQw res., BID 90.25' 448.77;. 153.7'. dQw s. c. , STBID 88.22' 427.75' 148.31 Qo total res. , BfD 1835.19': 18.41 Qo total s. c., STBfD 1084 D5! 10.88! dC~o res., BID 1818.79' 17.12'. dQo s. c. , STBID 1073.17': 10.11 Qg total res., BfD 7224.48 794 74 Qg total s c., MscflD ! 9424.5 918.25 dQg res. , BID 8435.57 793.84.,.. dQg s. c. , MscflD 8508.25:. 913 08' V Superficial Vsw,ft/min Vso,ftfmin Vsg,ftfmin 'V Average Vw, ftfmin Vo, ftfmin Vg, ftfmin 82.922' 72.258 220.177 2.2D9 888.758, 95.349 Yw Yo Yg Vslip, ftfmin Vslip UV-O, ft/min Regime Gorrel. Correl. W-O .Oil fraction Well: NS-16A Field: Northstar 1.29 0.78 1.29 0.78 1.11' 5.17 .1.11'. 5 17'. 18.44' 0.155' 0.133'. 1115.11: 143.099 18. 533'. 1124.81 , 149.878 85 .541 !. 1187.52 198.522 49 .754'- 0.074.'. 0.505 0 .995 0.198 ` 0.015 0 .002 0.73 0.48 0 .003''. 85.374 55.237. 51 .488'. 2.822 3.419 ! 48 .882 I Distributed Distributed Distributed Stanford Drift Flux LG Stanford Drift Flux LG Stanford Drift Flux LG ' -Stanford Drift Flux LL Stanford Drift Flux LL 'Stanford Drift Flux LL 0.73 0.0297 __ 0.0083''. 29 • • BP Exploration (Alaska), Inc. Job Number: 12083411/11970846/12031525/AYTO-00005 Well: NS-16A Field: Northstar 4. Table of abbreviations: Mnemonic Units: Descrintion B/D Barrels er Da scf/bbl Standard Cubic Feet er Barrel c Viscosit centi oises fUm Feet er minute cc Grams er cubic centimeter MMSCF/D Million Standard Cubic Feet er Da MSCF/D Thousand Standard Cubic Feet er Da Res. To denote reservoir conditions downhole r s Revolutions er second S.C. To denote surface conditions u hole) SCF Standard Cubic Feet STB/D Stock Tank Barrels er Da P~/T' Pracanra \/nluma Tamnaratura Bo Oil volume factor Bw Water volume factor B Gas volume factor FVF Fluid volume factor GOR Gas Oil Ratio Watercut Ratio of roduced water to total fluids Holdu Fraction of fluid resent in an interval of i e Interpretation: Correl. Correlation Model L-G: Liquid Gas W-H: Water H drocarbon; O-W Oil-Water ID Internal Diameter O Cumulate Rate with continuous solution OZI Incremental rate er zone OZT Cumulative Rate track with zonal contribution Re ime Modeled YG Gas Holdu YO Oil Holdu YW Water Holdu YW_DFT Water Holdu from DEFT Z Zone: Yellow -spinner calibration Red -Perforation White -Inflow Zones Gra :Calculation stable zone Tool Channel Descrintion CVEL Cable velocit CCLD/ CCLC Casin Collar Locator Discriminated /Calibrated DFB1/2/3/ 4 DEFT bubble count er robe DFH1/2/3/ 4 DEFT water holdu er probe SCVi De th corrected cables eed to in-lines inner SCVL De th corrected cables eed to s inner GHHM2 Field calculated combined as holdu DFHM Field calculated combined water holdup MWFD Field ressure derived densi GR Gamma Ra GHB1/2/3/ 4 GHOST as bubble count per robe GHH1/2/3/ 4 GHOST as holdu er robe SPI1 In-lines inner WPRE Pressure DPHZ Pressure derived densit (from Emeraude) PFC1 / PFC2 PSP Cali er 1 and Cali er 2 O Rate Di RB2 Relative bearing for probe 1 of second tool (GHOST D1 RB Relative bearin of robe 1 SPIN Sinner (fullbore or turbine WTEP Tem erature TENS Tension UWFD Uncorrected Fluid Density (from radiomanometer WFDE Well fluid densi from radiomanometer PSP Production Services Platform DEFT Di ital First Ent Tool ater holdu GHOST Gas Holdu O tical Sensor Tool Gas holdu Spinner Calibration: Slope of rps/ (Wm). Defines conversion of Sloe sinner to velocit . Int Interce t of line of slo a defines velocit Difference between up/down passes. This is the Threshold velocit re uired to initiate rotation of the s inner. 30 BP Exploration (Alaska), Inc ~ • Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar 5. Tool Diagram: DOWNHOLE EQUIPMENT MH-22 MH-22 ERS 1145 ERS-E 1145 EQF-43 EQF-43 AH-Swivel AH-Swivel EQF-43 EQF-43 EQF-43 EQF-43 Detail MT TelStatus PSPT-A/B 730 CTEM _ 27.8 PSC-A PSPT-A PSTC GR _ 24.1 PBMS-A 730 10k Sapphire Mano GF~ Thermometer yyell Temp 21.0 Manometer / 20.9 PBMS 730 CCL _ 20.3 PBMS PSTC _ 19.6 PGMC-A/B 852 ACCE PGMC-B 852 Gradioman ! _ 18.1 Accelero PSOI Gradio PGMC _ 14.8 PILS-A 870 PILS-A 870 Spinner ~ _ 13.2 GHOST-A2 Flowmeter Probes Relative Bearing Caliper 's. GHOC-C 733 GHOST2 Pr 7.2 GHOH-C 733 GHOST2 Ca " /_ 7.1 GHOST2 Ca 5.1 PFCS Spin / PFCS Cali 1.9 PFCS-A 856 PFCS Prob 1.5 Holdup Probes GHOST2 Wa HV Turbine GHOST2 Re Relative Bearing PFCS Wave Caliper PFCS Rela PFGG-A PFCS Cart PFCH-A Tensi 0 TOOL ZERO MAXIMUM STRING DIAMETER 1.69 IN MEASUREMENTS RELATIVE TO TOOL ZERO ALL LENGTHS IN FEET 50.0 48.4 47.1 41.1 39.8 33.8 I 27.8 I 19.61 14.8 I 12.31 5.1 I 31 BP Exploration (Alaska), Inc. ~ Well: NS-16A Job Number: 12083411/11970846/12031525/AYTO-00005 Field: Northstar 6. Well Schematic: r'viLtttn;7= ,}sy +.1uLr~ x:.sx:~ ~ ~ " ~ ~~•~1,~~~t~arn~TeGaLr~~.. +~ VI ~t ~e ~ ~~: 'u; sr ~~. E~_°'i :; ,/~~_4:: 1' e "5_'~) 1(~4' 1lY'[~'J-1£uSSV ham. ps 3.Bi~ :L ~f = fiY°r Llau,~m ~aLl ~'~~~' ,. ~~~ ~ :,. ...,,.-. 1587" 13-x' i7t~t tA3t :.i9iax:it •.1 a,~~:~ ss~ ~3t8" G'SCS STt~ (4}2fi471fl1 'L. _....~ ~ ~ ~ I.FtLCk1T YM1O+CIC31N DNS-'fi~fi.; :k':•~'-3274° 12415" ~crCfi M t ~. \`\ ~/ I I U GASLht 1„W.+•t~,uELS ~ ~SF&' CSG, 470, 6ti°i7' L-&151.3 FIYLiPo~ XO F4~ i~'41 BTC 5±8° x.47#, i-SS7 8~ D ~ a.s81` 12574 ~IfYpl~}fTtlyilll (y~f~= Z.~$7'~ Q 13522' 4.112" x ~'"TATdn xW ~r315~e.99~3.958" ~ 4-id2"'TSG, 1280, 1~CR~b VAIATOP, .61152 fxvt. N7~. 3.58" T~MI FtY E L4." SMi ~~ Pl7C C7}d t34ftl3J~ dkNCLE.- T 1'. ~-~:". : 2i3 ° ~ 14274' 1°IH~@: f7l~H ,,3 -_~ . - -t4 f~W 1118~&31'/G~II~II" '-' 3 T 6 t4; 74- ra ,_,i ~ .,~ 421 ~i 2" 8 1+1289- in ;.,s +,7 :: .3 2' 8 14'3df4- i t ~ ,., t7 ~-r ~-: ,i I .d337t t+E+i, Cb ~ S.i84" 4-1,2" 6 ~l i 0, L-861521 6~7E t~v av w r _ ~ .v ~v 6x1!~.+'w4=~ar ~ o7at~rrr~ aas sr~ ~ ~faw ,~~ n a 2-7as° Lr1R 03d2f103 FM Po14A4-CU4~1V'I F tKN4 Q7 _~; %8 FZF'J ORL6"i ~Lt.FT£X74~ECPr3N^s 03J".~+1~ t13 91TRALti' h}c.~rp? 6.W ` ~- -4 fft3-t C,~V C r ~ , • s P,~ it3 its 14-~,~° Fr3ERK'K/~ Tf =3.968" r<' ~+c ~ '-+>. PKR ~ 3:875" S.R. Nr °. ILl = 3~ p; ~i° i=:'_l ~Y;i'L I!`v!~!I d872. C1"r 4.4" NcS XN r1H', r-1 ~ .'... r c x ti • -:r R FLJ6 lC1~d6 9-K3~2, [1 x.43 :° XC~ k?lk*. 01.E 3.94", f/2' X2-T~" XQ U ~ 2:387• 1 Z.XF"r.T?w 12 4?8 ErK:R. FLEX LC3CK. !-IG.12. 1 w f2° Xa3 f1Jp 17 i.g30.. NL?k ('iS' (A ~. J~fsa. £~itfMi ham. !":i?>f+c ~~~ APi t.~ ..mod-2-011 3$A`. 11, Tf~d, ~4 -` JJ _3 t&45` FEt 0p rfora4i~~ a (^d>~ka~ 32 Memory Multi-Finger Caliper Log Results Summary Company: BP Exploration (Alaska), Inc. Well: NS-16A Log Date: February 11, 2010 Field: Northstar Log No.: 7385 State: Alaska Run No.: 2 API No.: 50-029-23096-01 Pipet Desc.: 4.5" 12.6 Ib. 13CR-80 VAM TOP Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 13,534 Ft. (MD) Pipet Desc.: 2.875" 6.4 Ib. 13CR-80 Top Log Intvl2.: 13,534 Ft. (MD) Pipet Use: Liner Bot. Log Intvl2.: 14,380 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied info the 4.5"mule shoe @ 13,497' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage, and to determine the setting depth of the stimulation packer in the 2.875" liner for the proposed acid treatment in 2010. A 3-D log plot of the caliper recordings across the proposed packer setting depth is included in this report. The caliper recordings indicate the 4.5" tubing appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 2.875" liner logged is in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate slight buckling throughout the 2.875" liner logged. This is the second time a PDS caliper has been run in this well and the first time this 4.5" tubing and 2.875" liner have been logged. A comparison of the current and previous log (September 11, 2007) indicates the ' configuration of the 4.5" tubing has changed during the time between logs. 4.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 10%} are recorded. 4.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: ' No significant areas of cross-sectional wall loss (> 4%) are recorded. 4.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: ' No significant I.D. restrictions are recorded. ' 2.875" LINER -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 4%) are recorded throughout the liner logged. t ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (28i) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memeryiog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 ~;~, _~Cf/ / ~~~,~Lj 1 ~, ~ ~ ~ 2.875" LINER -MAXIMUM RECORDED GROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the liner logged. 2.875" LINER -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the liner logged. 11 1 i~ c i~ Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: T. Atkinson & M. McGuiness ProActive Diagnostic Services, Inc. / P,O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS'amemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 r PDS Multifinger Caliper 3D Log Plot ~° __ ~~. Company : BP Exploration Alaska), Inc. Field : Northstar Well : NS-16A Date : February 11, 2010 Description : Detail of Caliper Recordings Across Proposed Packer Setting Interval. Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-0 Log Image Map -` :~ 1ft:240ft ~ 100 1.875 2.875 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 1.875 2.875 Nominal I.D. (ins.) i ................................................! 1.875 2.875 i Joint 23 14250 , lid i 14260 i Joint 24 14270 ~ ~ , a Pertorations - _ 14280 - I -± ~ ;, : ~ ~ ~^ '_ ~ 14290 ~ I - --~ ~ -- ~_. .~ ~ .~ -`~ ` -~ 14300 _ ~ Joint 25 --t- ~ ~; ~ ~ ~.,_ -.. __--..~. -~ =, Pertorations Perforations a 14310 .. _ . _ ~. -" .. _ '~'}' I I ' ~_. ..._. '~ - ~-"~_ - r " 14320 r ~ - - ! i -~ >~ _ oint 26 14330 " ~ ~ ~ . _ ,~.,---~ _-- ~" =.- - - - _ ~ ~ - Perforations 14340 _ ~.... 14350 ~ Joint 27 I ~ _ - 14360 i _ ~. Nominal I.D. (ins.) :..................................................: 1.875 2.875 Min. I.D. (ins.) 1.875 2.875 Comments Depth Max. Pen. (°~) Max. I.D. (ins.) 3-0 Log Image Map 1ft:240ft 0 100 1.875 2.875 0° 0° 90° 180° 270° 0° • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (-3.3' - 13534.7) Well: NS-16A Pipe 2 2.875 in (13534.7' - 14353.3') Field: Northstar Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: February 11, 2010 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 0 2050 4152 GLM 1 62 81 ~_ 8380 s a a~ O 10485 12589 13535 27 14353 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 27 50 100 ~_ 150 I a~ E ZL00 c .a 250 300 1 PDS Report Overview ~ ~,~ Body Region Analysis Well: NS-16A Survey Date: February 11, 2010 Field: Northstar Tool Type: UW MFC 24 Ext. No. 214040 Company: BP Exploration (Alaska), Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f 13CR-80 VAM TOP 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) penetration body metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10`% 20% 40% 85% 85% Number of'oints anal sed total = 333 pene. 151 182 0 0 0 0 loss 251 82 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole/puss pitting corrosion corrosion corrosion ible hole Number of "oints damn ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body _ > metal loss body 0 50 100 n GLM 1 Bottom of Survey = 320.1 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft) PE~n. l)hset (Ins.) Pen. Body (Ins.) Pen. % Metal loss ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -3 U 0.01 ; Z 3.94 PUP 1 0 U 0.01 i ' 3.93 2 32 (! 0.01 ~ 1 3.91 3 64 U 0.01 3 ~' 3.92 ~ 4 94 ! ! 0.00 1 3.92 4.1 126 U 0.01 > ~' 3.92 PUP 5 130 (! 0.01 3 ~' 3.91 6 172 U 0.01 2 I .90 7 214 i) 0.00 1 1 3.90 8 257 O 0.00 I 1 3.92 9 299 (! 0.00 1 I 3.91 10 341 U 0.01 3 3.92 11 383 O 0.00 1 I 3.92 12 42 5 t l 0.00 1 I 3.92 13 467 U 0.00 I I 3.92 14 510 l) 0.01 3 1 3.91 15 552 U 0.01 3 ' 3.92 16 594 ~) 0.01 2 I 3.90 17 636 O 0.01 2 1 3.92 18 678 U 0.00 1 1 3.92 19 721 ~! 0.00 1 I 3.91 20 763 U 0.01 2 1 3.92 21 805 ~) 0.00 1 I 3.92 22 847 i) 0.01 ~ 3.92 23 890 ~) 0.01 3.91 24 932 U 0.00 1 1 3.92 24.1 974 U 0.01 ~ _' 3.94 PUP 24.2 983 U 0 ~) (1 3.81 4.5" TRM-4E SSSV Ni le 24.3 989 t) 0.00 1 1 3.96 NUN 25 998 O 0.00 I I 3.93 26 1040 0 0.01 ~ 3.92 27 1083 t) 0.00 1 I 3.93 28 1125 l! 0.01 3 _' 3.93 29 1167 (1 0.00 I 1 3.91 30 1209 a 0.00 1 I 3.94 31 1251 ~! 0.01 ~ ~' 3.94 32 1294 (! 0.01 2 I 3.92 33 1336 U 0.00 1 1 3.92 34 1378 U 0.01 2 1 3.93 35 1420 +! 0.00 I 1 3.91 36 1462 ~? 0.00 1 I 3.93 37 1504 i) 0.01 ? I 3.92 38 1544 t! 0.00 I 1 3.94 39 1586 O 0.02 8 -# 3.90 40 1628 (! 0.00 1 1 3.92 41 1671 O 0.01 ~ 3.92 ~ 42 1713 C! 0.00 1 1 3.93 43 1755 ~! 0.01 3 _' 3.93 44 1797 t) 0.00 1 1 3.92 45 1839 ~) 0.01 3 ? 3.93 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft.) I'o°n. llpse~i (Ins.l Pen. Body (Ins.) Pen. % Metrl Inns "'~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 46 1882 t1 0.00 1 I 3.93 47 1923 (? 0.01 2 1 3.93 48 1966 t 1 0.01 3 1 3.93 49 2008 t? 0.00 ~l 1 3.94 50 2050 t? 0.00 I 1 3.93 51 2092 U 0.01 :' 1 3.92 52 2134 U 0.00 1 1 3.92 53 2176 U 0.01 ~ ~' 3.92 54 2218 U 0.01 ~' 1 3.93 55 2261 !! 0.01 ? 1 3.92 56 2302 U 0.00 1 1 3.92 57 2344 t? 0.00 1 1 3.93 58 2383 U 0.01 3 ? 3.93 59 2425 U 0.00 I I 3.92 60 2467 t? 0.00 1 1 3.92 61 2509 t? 0.01 2 1 3.93 62 2551 U 0.01 t 3.92 63 2593 t? 0.00 1 I 3.93 64 2635 tl 0.00 i I 3.93 65 2678 n 0.00 1 1 3.94 66 2718 tl 0.00 1 1 3.92 67 2760 U 0.01 ' 3.92 68 2803 U 0.00 1 1 3.92 69 2845 (t 0.00 1 1 3.94 70 2887 c? 0.00 1 I 3.92 71 2929 (? 0.01 z i 3.92 72 2971 n 0.00 I I 3.93 73 3013 c) 0.01 3 _' 3.94 74 3056 t? 0.00 1 I 3.92 75 3098 0 0.01 3 3.92 76 3140 U 0.01 2 1 3.92 ` 77 3182 U 0.00 i I 3.92 78 3224 U 0.01 3 _' 3.91 79 3267 U 0.01 ~ _' 3.92 80 3309 (? 0.00 ! I 3.92 81 3351 n 0.01 ~> 3 3.92 82 3393 U 0.00 1 1 3.92 83 3435 U 0.01 ~ ? 3.92 84 3477 U 0.01 ~ ? 3.91 85 3519 (t 0.01 ~' 1 3.92 ` 86 3561 U 0.01 j 2 3.91 g 87 3604 l1 0.00 I 1 3.91 88 3646 (? 0.00 1 I 3.90 89 3688 n 0.01 2 w 3.92 90 3730 O 0.01 ~ 3.91 91 3772 U_ 0.01 ~ 3.92 92 3814 1? 0.01 r 3.91 93 3857 U 0.00 I 1 3.92 94 3899 U 0.01 Z 1 3.91 95 3941 (1 0.01 ? 1 3.91 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft.) i'~~n. Upset !InS.} Pen. Body (Ins.) Pen. % Metal loss °io Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3983 t) 0.01 ~; 3.92 97 4026 U 0.00 1 1 3.92 98 4068 0 0.00 1 1 3.91 ~ 99 4110 O 0.01 3 2 3.92 100 4152 U 0.01 3 Z 3.91 101 4194 U 0.00 1 I 3.92 102 4236 t) 0.00 1 I 3.92 103 4279 l) 0.01 3 3.92 104 4321 U 0.00 1 I 3.92 105 4363 t1 0.01 ? I 3.93 106 4405 U 0.00 I 1 3.92 107 4447 tl 0.00 1 I 3.92 108 4490 U 0.01 3 3.92 108.1 4532 i) 0.02 ~) -t 3.92 PUP 108.2 4542 U 0 ti U N A GLM 1 Latch P 8:30 108.3 4553 U 0.01 Z 1 3.92 PUP 109 4561 t) 0.00 1 1 3.92 110 4603 U 0.00 1 1 3.93 111 4645 t) 0.01 ~' 1 3.91 112 4687 U 0.01 2 1 3.92 113 4729 i) 0.01 _' ! 3.93 114 4771 U 0.01 ? I 3.93 115 4810 t) 0.01 ? 3.93 116 4852 l) 0.01 ~ 3.93 ~ 117 4892 U 0.01 3 Z 3.92 118 4931 U 0.00 1 I 3.92 119 4974 U 0.01 ' 1 3.93 120 5016 a 0.01 3.92 121 5058 U 0.01 3.91 122 5100 O 0.00 1 I 3.91 123 5142 U 0.00 i I 3.92 ~ 124 5184 U 0.00 I i 3.91 125 5226 i) 0.01 3.90 126 5268 U 0.01 3.91 127 5310 l) 0.01 3 Z 3.91 128 5353 t) 0.01 2 1 3.91 129 5395 0 0.01 3 ? 3.90 130 543 7 U 0.00 I 1 3.90 131 5479 l) 0.01 3 I 3.91 132 5522 U 0.01 3 Z 3.92 133 5564 t? 0.00 1 i 3.91 134 5606 U 0.01 ? I 3.90 ' 135 5648 l) 0.00 I 1 3.91 136 5690 U 0.01 3 3.92 137 5732 t) 0.01 3 ~' 3.91 ~ 138 5775 c) 0.01 ~ I 3.91 139 5817 i) 0.00 1 I 3.90 140 5859 O 0.01 Z I 3.91 141 5901 U 0.00 1 I 3.91 142 5943 U 0.01 ~ I 3.91 Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft) I'c~n. Upsel (Im.} Pen. Body (Ins.) Pc~n. % Mclal Loss `?~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 143 5985 t ~ 0.01 2 1 3.90 ' 144 602 7 U 0.01 2 1 3.91 ' 145 6070 l) 0.01 3 ~' 3.92 146 6112 t) 0.01 3 ..' 3.92 147 6154 a 0.01 S 3.93 148 6196 U 0.01 > 3.91 ~ 149 6239 (1 0.01 ~ 2 3.90 150 6281 c) 0.01 2 1 3.91 151 6323 a 0.00 1 1 3.91 152 6365 U 0.01 2 1 3.91 153 6407 0 0.00 1 1 3.90 154 6449 i) 0.01 2 1 3.91 155 6492 t) 0.00 1 I 3.92 156 6534 t) 0.01 3 ? 3.91 157 6576 t? 0.01 2 I 3.92 158 6618 ~ } 0.00 1 I 3.91 159 6660 t) 0.00 1 1 3.92 160 6703 U 0.01 3 ? 3.91 161 6745 i ? 0.00 1 I 3.91 162 6785 U 0.00 1 I 3.91 163 6827 t) 0.01 3 ~' 3.91 164 686 7 t ~i 0.00 1 I 3.91 165 6909 t} 0.01 ~3 3.91 166 6951 O 0.01 l I 3.90 167 6993 i i 0.01 ~ 3.92 168 7035 i) 0.01 i 3.91 ' 169 7077 t) 0.01 ~ 3.91 170 7120 t) 0.01 ~ 1 3.92 ' 171 7162 i i 0.01 ~ 3.90 172 7204 U 0.01 .? I 3.92 ' 173 7246 U 0.00 1 i 3.91 174 7289 i1 0.00 1 I 3.90 175 7330 l) 0.01 ~ I 3.92 ' 176 7373 U 0.01 s I 3.89 177 7415 (1 0.00 1 1 3.92 178 7455 t) 0.00 ! I 3.91 179 7497 l) 0.00 1 1 3.91 180 7539 !? 0.00 1 I 3.92 181 7581 i~+ 0.01 3 _' 3.91 182 7624 ~ ~ 0.01 _> 3.91 183 7666 i? 0.01 i ~' 3.91 184 7708 t1 0.01 1 3.90 185 7750 O 0.01 1 2 3.90 186 7792 t! 0.01 ~ 3.90 187 7834 ti 0.01 ~ I 3.90 188 7876 a 0.01 3 ? 3.90 189 7919 t' 0.01 ' 1 3.92 190 7959 a 0.01 5 ; 3.90 191 8001 l) 0.00 I 1 3.91 192 8043 U 0.00 1 1 3.91 _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint )t. Depth !'c•n. Pen. Pen. tih•tal Min. Damage Profile No. (Ft.) l Ipso~t Body °in I c~s~ LD. Comments (%wall) lln~.) (Ins.) °« (Ins.) 0 50 100 0.00 1 0 0.00 i 1 1 0.00 1 1 0.01 1 0.00 I 1 I ~2~ I a~~~ I n I nn~ I I i I ~aa I ~ 233 9769 CI 0.00 1 1 3.91 234 9811 ti 0.00 I 1 3.91 235 9854 U 0.00 1 1 3.90 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINTTABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint Jt. Depth Pen. Pen. Pen. ~~lctal Min. Damage Profile No. (Ft.) i)pset Body °~~ I+rss LD• Comments (%wall) (Ins.) (Ins.) "~~~ (Ins.) 0 50 100 I ASS I 1n~QS I ~~ I n n~ I ~ 1 i I z 4~ I 1 256 10737 t? 0.01 3 1 3. 1 257 10780 t? 0.00 1 1 3.92 258 10822 i? 0.00 1 1 3.91 259 10864 U 0.00 1 i 3.91 260 10906 U 0.00 1 I 3.91 "261 10948 0 0.00 1 1 3.92 262 10990 U 0.00 1 I 3.91 263 11032 a 0.00 I 1 3.93 264 11074 a 0.00 1 1 3.92 265 11117 ~? 0.01 ? I 3.91 _ Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM TOP Well: NS-16A Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft.) I'c~n. Uhsc~t (In~.j Pen. Body (Ins.) Pc~n. % Mel.+l Ic~ss ",~o Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 293 12294 U 0.00 1 1 3.91 294 12336 ) 0.01 ~3 <~ 3.92 295 12378 t) 0.01 2 1 3.91 296 12421 U 0.00 1 I 3.90 297 12463 l) 0.01 ~' I 3.91 298 12505 U 0.00 I I 3.90 299 12547 t) 0.01 ~ I 3.91 300 12589 l) 0.00 1 1 3.92 301 12631 O 0.00 1 1 3.91 302 12673 U 0.01 ~ I 3.91 303 12 716 U 0.00 1 1 3.89 304 12 755 t) 0.00 1 1 3.90 305 12798 t) 0.01 ? 1 3.91 306 12840 t) 0.00 1 1 3.89 307 12881 a 0.01 l I 3.92 308 12924 U 0.00 1 1 3.90 309 12966 l) 0.00 1 I 3.90 310 13008 (+ 0.01 Z I 3.90 311 13051 U 0.00 1 I 3.90 312 13093 t) 0.00 1 I 3.90 313 13135 t) 0.01 3 1 3.91 314 13177 t) 0.00 1 1 3.91 315 13219 [) 0.00 1 1 3.90 316 13261 t) 0.01 > 1 3.91 317 13304 U 0.01 3 I 3.90 318 13346 t) 0.00 1 1 3.90 318.1 13388 it 0.01 ~ t+ 3.91 PUP 318.2 13398 t) 0 U U 3.96 4.5" Fiber O tic Transducer 318.3 13403 t) 0.01 2 I 3.91 PUP 318.4 13413 t! 0.00 1 t) 393 PUP 318.5 13422 t) 0 0 +) 3.81 4.5" HES X-Ni le 318.6 13424 i1 0.02 H I 3.91 PUP 318.7 13434 t) 0.01 2 l) 3.92 PUP 318.8 13443 t) 0 O t) 3.88 7" x 4.5" Baker Premier Packer 318.9 13452 t) 0.01 I 3.91 PUP 319.1 13461 i~ 0.01 ~ ! 3.92 PUP 319.2 13472 t) 0 [) ! ~ 3.81 4.5" HES X-Ni ~ le 319.3 13473 t) 0.01 3 t) 3.92 PUP 319.4 13482 t+ 0 it l) 3.73 4.5" HES XN-Ni le 319.5 13487 U 0.03 1 U I 3.92 PUP 319.6 13497 ~ 0 0 U 3.85 4.5" Self Ali nin Mule Shoe 319.7 13503 U 0 U c) 4.45 7" x 5" HRD ZXP LTP w 17' PBR 319.8 13512 ri 0 O i) 4.4~ 7" x 5" Baker Flex Lock Han er 319.9 13523 i! 0 +~ 3.94 5" x 4.5" X-Over PUP 320.1 13532 ~ 0 2.39 4.5" x 2.875" X-Over _ Penetration Body Metal Loss Body Page 7 • PDS Report Overview ~k.__ s,. Body Region Analysis Well: NS-16A Survey Date: February 11, 2010 Field: Northstar Tool Type: UW MFC 24 Ext. No. 214040 Company: BP Exploration (Alaska), Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper Ien. Lower len. 2.875 ins 6.4 f 13CR-80 2.441 ins 2.875 ins 6.0 ins b.0 ins Penetration and Metal Loss (% wall) ~ penetration body Y,-- metal loss body 30 20 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 27 pene. 0 24 0 0 0 3 loss 20 7 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body , ;~~, metal loss body 0 50 1 11 Bottom of Survey = 27 100 21 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.4 ppf 13CR-80 Well: NS-16A Body Wall: 0.217 in Field: Northstar Upset Wall: 0.217 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: February 11, 2010 Joint No. Jt. Depth (Ft.) I'i~n. UI>set (lns.) Pen. Body (Ins.) Pen. % VI~~t,~l loss °~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 13535 i? 0.00 2 I 2.41 To of 2.875" Liner 2 13565 tt 0.01 2 ,_' 2.41 Sli ht Bucklin . 3 13597 t) 0.01 4 1 2.41 4 13629 t) 0.00 2 I 2.41 5 13658 ~? 0.01 ~ _' 2.41 ~ 6 13689 t) 0.01 4 1 2.41 ~ 7 13721 li 0.01 4 I 2.41 Sli ht Bucklin ~ 8 13752 U 0.01 4 I 2.40 I I 9 13784 i) 0.01 4 I 2.41 10 13816 O 0.01 4 1 2.41 11 13848 U 0.01 2 I 2.41 12 13879 (1 0.00 ~' 1 2.39 Sli ht Bucklin . 13 13911 (1 0.01 4 1 2.41 14 13942 t t 0.01 4 I 2.40 15 13974 O 0.01 ,' I 2.40 16 14006 U 0.01 _' 1 2.40 17 14037 U 0.00 .' I 2.38 Sli ht Bucklin . 18 14069 ~) 0.00 <' I 2.40 19 14101 It 0.01 4 I 2.40 20 14132 t) 0.00 L 1 2.39 21 14164 l) 0.01 4 2.39 22 14195 U 0.01 4 Z 2.41 Sli ht Bucklin . 23 14227 It 0.01 ? I 2.39 24 14259 U 0.20 9O fs 2.38 Perforations. 25 14290 U.t16 0.23 lOt? t3 2.35 Perforations. 26 14322 (t.tt~) 0.20 ~t:3 ~) 2.26 Perforations. - 27 14353 O 0.01 ~ I 2.38 Sli hl I~ucldin~. _ i I I ~ ~ _ Penetration Body Metal Loss Body Page 1 TREE= ABB-VGI5-1/8" SKSI -LHEAD = 13-5/8" MULTBOWL SKSI AGTilATOR _ BA KB. ELEV..- 56.46' BF. EIEV - 40.56' (CB 15.9') KOP = 100' Max Angle = 53° @ 7169' Datum MD - 13686' Datum N D = 10500' SS 13-3/8" WHIPSTOCK (02/10/08) 13-3/8" FZSV (02/10/08) 9-5/8" CSG STUB (02/07/08) 13-318" CSG, 68#, L-80 BTC, 3494' D =12.415" 9-5/a~ Ezsv 3670' (01129!08} _ ~ N S 16A S TES: ***CHROME TBG &LNR*** 1024' 4-1l2" TRM-4E SSSV Nom, D = 3.812" 15$T I~ 13-3l8" TAM PORT COLLAR ~ 9-518" CSG, 47#, ~ 6831 L-80 513 HYDRL XO TO L-80 BTC ~5/8" CSG, 47#, L-80 BTC, ID = 8.681" 12574 Minimum ID = 2.387" @ 13522' 4-1/2" X 2-7/8" XO 4-1/2" TBG, 12.6 #, 13CR-80 VAM TOP, -~ .0152 bpf, D = 3.958" 4-1/2" TBG, 12.6 #, 13CR-80 VAM TOP, 13 .0152 bpf, D = 3.958" PERFORATION SUMMARY REF LOG: SWS- PDC ON 04!03/08 ANGLEATTOPPERF: 20 ° @ 14274' Note: Refer to Production DB for historical pert data SIZE SPF RNTERVAL (MD} OpnlSgz DATE 2" 6 14274 - 14304 O 06/12/08 2" 6 14274 - 14339 O 07/27/08 2" 6 14276 - 14296 O 07/04/08 2" 6 14289 - 14339 O 05/02/08 2" 6 14304 - 14339 O 04/05/08 7" LNR, 29 #, L-80 521 HYDRL, 13850' .0371 bpf, ID = 6.184" 4-1l2" LNR, 12.6 #, L-80 521 HYDRL, 14093' .0152 bpf, D = 3.958" LNR, 6.4#, 13CR-80, .0058 bpf, D = 2.441" 14504' MLLOUT WINDOW (NS-16A) 3250' - 3274' GAS LIFT MANDRELS 12178' I-~ 9-5/8" X 7" BKR ZXP LTP w / 11' PBR, ID = 6.200" 12~ 99~ 7" X 5" BKR FLIX LOCK HGR, D = 6.200" 13398' - 4-1/2"FIBER OPTICTRANSDUCB~,D=3.958" 13423' 4-1/2" HES X Nom, ID = 3.813" 13444' 7" X 4-1 /2" BKR PREMIER PKR, D = 3.875" 13471' 4-1/2" HES X NIP, ID = 3.813" 13479' 7" X 5" HRD ZXP LTP w / 17' PBR, D = 4.450" 134$3' 4-1/2" HES XN NIP, D = 3.725" 13497' 4-1/2" SELF ALIGNING MULE SHOE, D = 3.850" 13507' 7" X 5" BKR FLIX LOCK HGR, D = 4.40" 13516' 5" X 4-1 /2" XO PUP, D = 3.94" 13522' 4-1/2" X 2-7/8" XO, D = 2.387" 136$5' -~ 7" X 5" BKR ZXP LTP w ! 12' PBR, D = 4.350" 13709` 7" X 5" BKR FLEX LOCK HGR, D = 4.370" 13718' 5" X 4-1/2" XO PUP, D = 3.930" I PBTD i DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/15/02 JAS INIT COMPLETION 07/09108 WWR/TL ADPERF & 2-7/8" LNR CORRECTION WELL: NS16A 03/21/03 FM FlNALGOMPLEf10N 07/26/08 WWRlPJ DRLGDRAFTCORRECTIONS PERMffNo:1061410 03/25708 N33E SIDETRAGK(NS-16A} 09!05108 WRR/PJC PERFS (07/27/08) API No: 50-029-23096-01 04/18/08 /TLH GLV C/O? {03/27!08} 03/29!09 ?/ PJC LNR CORRECTION SEC 11, T13N, R13E, 1199' FSL &645' FEL 05/02/0$ JLJiTLH ADPERFS 07/05/08 ?/ PJC DRLG DRAFT CORRECTDNS BP Exploration (Alaska) i~
