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Home My WebLink About205-009Nolan 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-05 50029232440000 205009 9/9/2023 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 14,033 feet NA feet true vertical 11,336 feet NA feet Effective Depth measured 13,918 feet See Attachment feet true vertical 11,225 feet See Attachment 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" 12.6# / 13Cr-80 13,366' 10,698' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: NORTHSTAR 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: 13-3/8" See Attachment 323-493 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 88920 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 N/A measured true vertical Packer MD 201' Size 201' 3,183' Length Liner 2,011' 674' Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 366 Gas-Mcf 287 611 40083930 385 975580 899 TVD 7" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-009 50-029-23244-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799, ADL0312808 NORTHSTAR / NORTHSTAR OIL NORTHSTAR UNIT NS-05 Plugs Junk measured measured Conductor 10,862' 11,334' 13,537' 14,031' 11,702' 3,187'Surface Intermediate Production 20" 9-5/8" 201' 3,187' 11,702' 9,402' 7,020psi 7,500psi 5,020psi 6,870psi 8,160psi 8,430psi 4,760psi Burst NA Collapse NA 2,260psi 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 1:24 pm, Sep 22, 2023 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.09.21 11:28:09 - 08'00' Sara Hannegan (2519) RBDMS JSB 092623 WCB 12-5-2024 DSR-9/23/25 Type Measured Depth (feet) True Vertical Depth (feet) 4-1/2" TRM-4E SSSV 994 994 9-5/8" x 7" Liner Top Packer 11,524 9,293 7" x 4-1/2" S-3 Packer 13,316 10,650 HRD ZXP Liner Top Packer 13,357 10,689 Northstar NS-05 Packer and SSSV Depths Well Name Rig API Number Well Permit Number Start Date End Date NS-05 Slickline / E- Line 50-029-23244-00-00 205-009 9/9/2023 9/9/2023 Slickline: ***CONT WSR FROM 9/8/23*** (perforating) DRIFT TBG W/ 3.50" CENT, 1.75" SAMPLE BAILER, TAG HARD BTM @ 13,884' SLM DRFT W/ 3.50" CENT, 9' STEM, 3.46" CENT, 9' STEM, 3.28" GAUGE RING (21.5' oal). SD @ 13,896' SLM ***WELL LEFT S/I ON DEPARTURE*** E-Line: *** WELL SI ON ARRIVAL *** LRS PUMPING SEAWATER TO LOAD WELL INITIAL T/I/O = 800/73/14 RIH 20 FT 2-7/8" PERF GUN, INTERVAL = 13878-98 FT. 6 SPF, 0.34" HOLES, 42.46" PENETRATION. CCL OFFSET = 8.5 FT, CCL STOP = 13869.5 FT, ALL SHOTS FIRED. ELINE COMPLETE, NOTIFY DSO, SSV CLOSED, SWAB CLOSED. FINAL T/I/O = 1450/72/18 *** WELL SI ON DEPARTURE *** 9/9/2023 - Saturday Hilcorp Alaska, LLC Weekly Operations Summary RIH 20 FT 2-7/8" PERF GUN, INTERVAL = 13878-98 FT _____________________________________________________________________________________ Revised By: NLW on 09/12/23 Northstar Unit Well: NS-05 Last Completed: 4/12/2005 PTD: 205-009 TD =14,033’ (MD) / TD = 11,336(TVD) 20” Orig. KBE = 56.37’/ BFE = 40.1’ (CB 15.9’) 7” 4 5 6 7 9-5/8” 1 2 8 9 11 & 12 Min ID= 3.725” @ 13,351’ Ivishak PBTD = 14,027’(MD) / PBTD = 11,330’(TVD) 3 Top of Fill @ 13,918’ Tag 2/20/2016 13-3/8” 10 13 4-1/2” 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 / Btrc. 12.415 Surface 3,187’ 0.150 9-5/8" Production 47 / L-80 / Btrc. 8.535 Surface 11,702’ 0.0732 7" Liner 29 / L-80 / Hydril 511 6.184 11,524’ 13,537’ 0.0372 4-1/2” Liner 12.6/13Cr80/Vam Top 3.958 13,357’ 14,031’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366’ 0.0152 JEWELRY DETAIL No Depth Item 1 994’ 4-1/2” TRM-4E SSSV w/ 4-1/2” x Profile - ID= 3.812” 2 3,997’ GLM - MMG Dummy Valve – TVD @ 3,979’ – Set 3/29/2005 3 11,524’ 9-5/8” x 7” Liner Top Packer and Hanger 4 13,261’ 4-1/2” X Nipple, ID= 3.813 5 13,292’ 4-1/2” Cidra Fiber Optic Transducer, ID= 3.958 6 13,316’ 7” x 4-1/2” Baker S-3 Packer, ID= 3.950” (13,310’ ELMD) 7 13,340’ 4-1/2” X Nipple, ID= 3.813 8 13,351’ 4-1/2” XN Nipple,ID= 3.725” (13,368’ELMD) 9 13,357’ Baker 5” x 7” HRD ZXP Liner Top Packer (11.76 TB) 10 13,362’ 4-1/2” Self-aligning Mule Shoe, ID= 3.958”– Bottom @ 13,366’ 11 13,377’ RS Pack-off Seal Nipple – ID=4.25” 12 13,379’ Baker 5” x 7” Flex-Lock Liner Hanger ID=4.41” 13 13,388’ 5” Vam Ace x 4-1/2” Vam Top Cross-over – ID=3.90” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ivishak 13,707’ 13,727’ 11,024‘ 11,043‘ 20 6/28/05 Open 13,710’ 13,740’ 11,026‘ 11,055‘ 30 4/30/13 Open 13,733’ 13,764‘ 11,048‘ 11,078‘ 31 8/22/08 Open 13,734’ 13,764‘ 11,049‘ 11,078‘ 30 9/20/05 Open 13,735’ 13,766‘ 11,050‘ 11,080‘ 31 8/22/08 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 4/12/05 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 5/28/05 Open 13,759’ 13,809’ 11,073’ 11,121’ 50 3/4/2016 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 8/22/08 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 3/11/08 Open 13,810’ 13,830‘ 11,122‘ 11,141‘ 20 8/22/08 Open 13,830’ 13,850’ 11,141’ 11,160’ 20 03/01/20 Open 13,878’ 13,898’ 11,187’ 11,206’ 20 09/09/23 Open WELL INCLINATION DETAIL KOP @ 1,969’ Max Hole Angle = 56 deg. @ 7,693’ Max Angle at Top Perf: 17 Deg. @ 13,707’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23244-00-00 Completed – 4/12/2005 Re-perforate – 3-11-2008 Add Perforations – 8/22/2008 Add Perforations – 4/30/2013 Add Perforations – 3/4/2016 Add Perforations – 9/09/2023 SAFETY NOTE Well requires a safety valve, 4-1/2” Chrome Tubing & Liner 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): 14,033 NA Casing Collapse Structural 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: 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 Same 9-5/8" x 7 " Liner Top, 7" x 4-1/2" S-3 5" x 7" HRD ZXP Liner Top, and TRM-4E SSSV 11,524 MD / 9,293 TVD, 13,316' MD / 10,650' TVD & 13,357' MD / 10,689' TVD and 994' MD / 994' TVD NA 13,537' 11,702' 2,011' 907-748-8581 brenden.swensen@hilcorp.com Operations Manager September 10, 2023 14,031'674' 4-1/2" 11,334' Perforation Depth MD (ft): See Schematic 4-1/2" See Schematic 10,862'7" 20" 13-3/8" 201' 9-5/8"11,702' 3,187' N/A 5,020psi 201' 3,183' 9,402' 201' 3,187' 12.6# / 13Cr-80 TVD Burst 13,366 8,160psi MD 6,870psi 50-029-23244-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 11,336 14,027 11,330 3,990 NORTHSTAR OIL Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799, ADL0312808 205-009 C.O. 458A NORTHSTAR UNIT NS-05 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,430psi Tubing Grade: Tubing MD (ft): 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. NORTHSTAR Authorized Name and Digital Signature with Date: 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 8:57 am, Aug 30, 2023 323-493 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2023.08.29 18:23:00 - 05'00' Sara Hannegan (2519) DSR-8/31/23MDG 9/6/2023 10-404 MGR01SEP23*&: 09/06/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.06 16:06:23 -08'00' RBDMS JBS 090823 Page 1 of 4 Add Perf Well: NS-05 PTD: 205-009 Well Name:NS-05 API Number:50-029-23244-00 Current Status:Ivishak Producer PTD #205-009 Estimated Start Date:9/10/2023 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:5100 psi @ 11,100’ TVD (Adjacent SBHPS’s) Maximum Expected BHP:5100 psi @ 11,100’ TVD (est.) 8.85ppg EMW Max. Anticipated Surface Pressure:3990 psi Gas Column Gradient (0.1 psi/ft) History NS-05 was drilled and completed as an Ivishak producer in 2005. The well was twinned in 2022 to allow for higher gas throughput on the surface piping. This well is perforated above the original oil water contact. When reviewing NS-25, that well has perforations below its original oil water contact. It is believed that this is partially due to fluid contacts being pushed deeper as the gas cap expanded. Using NS-25 as an analog, it is possible to find oil deeper than the original oil water contact in NS-05. Objective Perforate ±20’ of Ivishak rock below the original oil water contact. Obtain well tests to evaluate the new rates of NS-05. If the results are unfavorable, will evaluate setting a plug to isolate the new interval. Procedure Slickline or Eline 1. MIRU. Pressure test PCE low 250psi high 4500psi. 2. Perforate ±20’ from ±13,878’ to ±13,898’ MD. a. Use reference log Ultra Sonic Imaging Log dated April 11 2005. Perforate ±20’ of Ivishak rock below the original oil water contact. Obtain well tests to evaluate the new rates of NS-05. Page 2 of 4 Add Perf Well: NS-05 PTD: 205-009 Reference Log _____________________________________________________________________________________ Page 3 of 4 Northstar Unit Well: NS-05 Last Completed: 4/12/2005 PTD: 205-009 CURRENT SCHEMATIC TD =14,033’ (MD) / TD = 11,336(TVD) 20” Orig. KBE = 56.37’/ BFE = 40.1’ (CB 15.9’) 7” 4 5 6 7 9-5/8” 1 2 8 9 11 & 12 Min ID= 3.725” @ 13,351’ Ivishak PBTD = 14,027’(MD) / PBTD = 11,330’(TVD) 3 Top of Fill @ 13,918’ Tag 2/20/2016 13-3/8” 10 13 4-1/2” 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 / Btrc. 12.415 Surface 3,187’ 0.150 9-5/8" Production 47 / L-80 / Btrc. 8.535 Surface 11,702’ 0.0732 7" Liner 29 / L-80 / Hydril 511 6.184 11,524’ 13,537’ 0.0372 4-1/2” Liner 12.6/13Cr80/Vam Top 3.958 13,357’ 14,031’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366’ 0.0152 JEWELRY DETAIL No Depth Item 1 994’ 4-1/2” TRM-4E SSSV w/ 4-1/2” x Profile - ID= 3.812” 2 3,997’ GLM - MMG Dummy Valve – TVD @ 3,979’ – Set 3/29/2005 3 11,524’ 9-5/8” x 7” Liner top packer and Hanger 4 13,261’ 4-1/2” X Nipple, ID= 3.813 5 13,292’ 4-1/2” Cidra Fiber Optic Transducer, ID= 3.958 6 13,316’ 7” x 4-1/2” Baker S-3 Packer, ID= 3.950” (13,310’ ELMD) 7 13,340’ 4-1/2” X Nipple, ID= 3.813 8 13,351’ 4-1/2” XN Nipple,ID= 3.725” (13,368’ELMD) 9 13,357’ Baker 5” x 7” HRD ZXP Liner Top Packer (11.76 TB) 10 13,362’ 4-1/2” Self-aligning Mule Shoe, ID= 3.958”– Bottom @ 13,366’ 11 13,377’ RS Pack-off Seal Nipple – ID=4.25” 12 13,379’ Baker 5” x 7” Flex-Lock Liner Hanger ID=4.41” 13 13,388’ 5” Vam Ace x 4-1/2” Vam Top Cross-over – ID=3.90” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ivishak 13,707’ 13,727’ 11,024‘ 11,043‘ 20 6/28/05 Open 13,710’ 13,740’ 11,026‘ 11,055‘ 30 4/30/13 Open 13,733’ 13,764‘ 11,048‘ 11,078‘ 31 8/22/08 Open 13,734’ 13,764‘ 11,049‘ 11,078‘ 30 9/20/05 Open 13,735’ 13,766‘ 11,050‘ 11,080‘ 31 8/22/08 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 4/12/05 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 5/28/05 Open 13,759’ 13,809’ 11,073’ 11,121’ 50 3/4/2016 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 8/22/08 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 3/11/08 Open 13,810’ 13,830‘ 11,122‘ 11,141‘ 20 8/22/08 Open 13,830’ 13,850’ 11,141’ 11,160’ 20 03/01/20 Open OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 419 sx PF “L”, 457 sx Class “G” in 16” Hole 9-5/8" 755 sx Extended,595 sx Class “G” in 12-1/4” Hole 7” 469 sx Class “G” in 8-1/2” Hole 4-1/2” 89 sx Class “G” in 6” Hole WELL INCLINATION DETAIL KOP @ 1,969’ Max Hole Angle = 56 deg. @ 7,693’ Max Angle at Top Perf: 17 Deg. @ 13,707’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23244-00-00 Completed – 4/12/2005 Re-perforate – 3-11-2008 Add Perforations – 8/22/2008 Add Perforations – 4/30/2013 Add Perforations – 3/4/2016 SAFETY NOTE Well requires a safety valve, 4-1/2” Chrome Tubing & Liner _____________________________________________________________________________________ Page 4 of 4 Northstar Unit Well: NS-05 Last Completed: 4/12/2005 PTD: 205-009 PROPOSED SCHEMATIC TD =14,033’ (MD) / TD = 11,336(TVD) 20” Orig. KBE = 56.37’/ BFE = 40.1’ (CB 15.9’) 7” 4 5 6 7 9-5/8” 1 2 8 9 11 & 12 Min ID= 3.725” @ 13,351’ Ivishak PBTD = 14,027’(MD) / PBTD = 11,330’(TVD) 3 Top of Fill @ 13,918’ Tag 2/20/2016 13-3/8” 10 13 4-1/2” 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 / Btrc. 12.415 Surface 3,187’ 0.150 9-5/8" Production 47 / L-80 / Btrc. 8.535 Surface 11,702’ 0.0732 7" Liner 29 / L-80 / Hydril 511 6.184 11,524’ 13,537’ 0.0372 4-1/2” Liner 12.6/13Cr80/Vam Top 3.958 13,357’ 14,031’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366’ 0.0152 JEWELRY DETAIL No Depth Item 1 994’ 4-1/2” TRM-4E SSSV w/ 4-1/2” x Profile - ID= 3.812” 2 3,997’ GLM - MMG Dummy Valve – TVD @ 3,979’ – Set 3/29/2005 3 11,524’ 9-5/8” x 7” Liner top packer and Hanger 4 13,261’ 4-1/2” X Nipple, ID= 3.813 5 13,292’ 4-1/2” Cidra Fiber Optic Transducer, ID= 3.958 6 13,316’ 7” x 4-1/2” Baker S-3 Packer, ID= 3.950” (13,310’ ELMD) 7 13,340’ 4-1/2” X Nipple, ID= 3.813 8 13,351’ 4-1/2” XN Nipple,ID= 3.725” (13,368’ELMD) 9 13,357’ Baker 5” x 7” HRD ZXP Liner Top Packer (11.76 TB) 10 13,362’ 4-1/2” Self-aligning Mule Shoe, ID= 3.958”– Bottom @ 13,366’ 11 13,377’ RS Pack-off Seal Nipple – ID=4.25” 12 13,379’ Baker 5” x 7” Flex-Lock Liner Hanger ID=4.41” 13 13,388’ 5” Vam Ace x 4-1/2” Vam Top Cross-over – ID=3.90” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ivishak 13,707’ 13,727’ 11,024‘ 11,043‘ 20 6/28/05 Open 13,710’ 13,740’ 11,026‘ 11,055‘ 30 4/30/13 Open 13,733’ 13,764‘ 11,048‘ 11,078‘ 31 8/22/08 Open 13,734’ 13,764‘ 11,049‘ 11,078‘ 30 9/20/05 Open 13,735’ 13,766‘ 11,050‘ 11,080‘ 31 8/22/08 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 4/12/05 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 5/28/05 Open 13,759’ 13,809’ 11,073’ 11,121’ 50 3/4/2016 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 8/22/08 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 3/11/08 Open 13,810’ 13,830‘ 11,122‘ 11,141‘ 20 8/22/08 Open 13,830’ 13,850’ 11,141’ 11,160’ 20 03/01/20 Open ±13,878’ ±13,898’ ±11,187’ ±11,206’ 20 OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 419 sx PF “L”, 457 sx Class “G” in 16” Hole 9-5/8" 755 sx Extended,595 sx Class “G” in 12-1/4” Hole 7” 469 sx Class “G” in 8-1/2” Hole 4-1/2” 89 sx Class “G” in 6” Hole WELL INCLINATION DETAIL KOP @ 1,969’ Max Hole Angle = 56 deg. @ 7,693’ Max Angle at Top Perf: 17 Deg. @ 13,707’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23244-00-00 Completed – 4/12/2005 Re-perforate – 3-11-2008 Add Perforations – 8/22/2008 Add Perforations – 4/30/2013 Add Perforations – 3/4/2016 SAFETY NOTE Well requires a safety valve, 4-1/2” Chrome Tubing & Liner 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 6HSWHPEHU, 202 Ms. Joleen Oshiro Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-22-026 Well Testing and Safety Valve System Changes NS-05 (PTD 205-009) Northstar Unit Dear Ms. Oshiro: By letter dated August 16, 2022, Hilcorp Alaska, LLC (Hilcorp) requested approval of an alternative well testing methodology and safety valve system changes for Northstar Unit (NU) well NS-05. The well is choked back 67 MMSCFPD due to limitations of the test separator. In order to allow the well to produce at full rate Hilcorp is proposing to “twin” the flowline by utilizing the nearby NS-03 tie-in slot to split production from the NS-05 well into two flowlines and test those flowlines separately and combine the results for well testing and allocation purposes. This configuration has been successfully implemented on several other NU wells. This should increase production rates and ultimate recovery by accelerating recovery. Hilcorp proposes an alternate method of well testing by summation of the individual well tests of the twinned NS-05 flowlines. Performing the well tests of each flowline back-to-back will ensure consistent plant conditions and therefore sufficient accuracy for allocation purposes. Regarding the safety valve system changes, Hilcorp intends to install a low-pressure detection switch in the twinned flowline and connect it into the NS-05 safety valve control panel. Detection of a low-pressure situation in either of the twinned flowlines will close the NS-05 surface and subsurface safety valves. Performance testing of the safety valve system would involve independently actuating the low-pressure switches to verify compliance with Alaska Oil and Gas Conservation Commission (AOGCC) regulations. The AOGCC APPROVES Hilcorp’s request to use the alternate well testing methodology and to install, maintain, operate, and test the twinned flowline safety valve system as described, with the following conditions: - The low-pressure switch (LPS) and surface safety valve (SSV) for the upper and lower flowlines must be properly labeled. - Must submit separate test reports for the upper and lower LPS/SSV testing. Any questions regarding this approval should be directed to Dave Roby at 907-793-1232. Sincerely, Jeremy M. Price Chair, Commissioner cc: BSEE Jeremy Price Digitally signed by Jeremy Price Date: 2022.09.14 11:35:58 -08'00' August 16, 2022 Mr. David Roby Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: NS-05 (PTD # 205-009) Request for Approval of Well and SVS Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well NS-05 (PTD #205-009) in support of a flowline twinning project. Background NS-05 is a downdip Ivishak producer. Production is currently restricted to the 67 MMSCFD gas rate due to design limitations of our Northstar test separator. To allow the well to flow at full rate to the ~740 psi production header, we would like to connect a 2nd “twin” flowline to the tree to carry a portion of the production from NS-05 to the header tie-in slot of nearby, exploration well Northstar 3 (PTD# 93-203). This proposed arrangement has been used successfully to twin well NS-15 (PTD# 202-054), NS-13 (PTD #201-086), and NS-25 (PTD#203-166), all of which have been reconfigured back to single flowlines. Justification Twining NS-05 in this configuration will not only allow for increased production from the well but will also allow for accurate well testing and allocation within the operating limits of the Northstar test separator. Accelerating production from the Ivishak reservoir will increase ultimate recovery by pulling reserves forward into Northstar’s economic field life. 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Page |2 Well Testing Methodology During this period of twinning, Hilcorp will utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). NS-05’s well tests would be obtained through a summation of individual tests of the original and twin NS-05 flowlines. Currently NS-05 is tested a minimum of once monthly. With the addition of once monthly tests from the twinned flowline, a minimum of 2 tests would be taken to ensure a combined NS-05 well tests per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain the same utilizing individual tests and flowline On/Off times as determined by the wing valves’ open/closed position. Production values for each flowline would then be combined and reported as a single value for NS-05. This methodology would result in no change or disruption to NS-05’s well test or production reporting. Safety Valve System Low Pressure Switch Configuration After twinning, Hilcorp will operate and test the SVS systems with the addition of a second low pressure switch to protect against a pressure drop in the twinned flowline. The second low pressure switch would be connected from the twinned flowline to NS- 05’s safety valve panel. NS-05’s surface and subsurface safety valves would remain unchanged, and the overall safety valve system functionality would be unaffected. When the low pressure switch from either flowline is tripped, both NS-05’s surface and subsurface safety valves would actuate. Once installed, this configuration would be function tested and an AOGCC witnessed performance test would be requested. As part of the performance test, each flowline low pressure switch would be tripped independently to verify the correct system actuation pressure for the respective flowline. If you have any additional questions, please contact me at 650-483-4774 or Joleen.oshiro@hilcorp.com Sincerely, Joleen Oshiro Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments -NS-05 Wellhead Twinning – Wellhead Arrangement -NS-05 (Twinned) Proposed P&ID -NS-05 Twinning Aerial View Page |3 - Page |4 NS-05 (Twinned) Proposed P&ID Page |5 NS-05 Twinning Aerial View David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type NS-05 500292324400 205-009 3/1/2020 Perf Record NS-11 500292330300 206-036 3/2/2020 Perf Record NS-17 500292311300 202-169 1/19/2020 Perf Record Please include current contact information if different from above. Received By: 07/30/2021 37' (6HW By Abby Bell at 10:42 am, Jul 30, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15.Well Class after work: Exploratory Development ServiceStratigraphic 16.Well Status after work:Oil Gas WDSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) WINJ W AG tion: tion: Gas-Mcf Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl W ater-Bbl summary: olumes used and final pressure: epth feet epth feet true vertical depth) d and true vertical depth) Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: mber):8.Well Name and Number: onic data per 20AAC25.071):10.Field/Pool(s): ry: ured feet feet tical feet feet ured feet feet tical feet feet CollapseBurstTVD 5.Permit to Drill Number: Size measuredPlugs Junkmeasured 4. W ell Class Before W ork: measured true vertical Packer MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-009 50-029-23244-00-00 ADL0312799 & ADL0312808 NORTHSTAR UNIT NS-05 N/A NORTHSTAR / NORTHSTAR OIL 14033 11336 N/A N/A 13918 11225 See attachment See attachment Conductor 201 20 201 201 N/A N/A Surface 3187 13-3/8 3187 3183 5020 2260 Intermediate 11702 9-5/8 11702 9402 6870 4760 Production 2011 7 13537 10862 8160 7020 Liner 674 4-1/2 14031 11334 8430 7500 See Schematic See Schematic 4-1/2 12.6#/13Cr-80/Vam 13366 10698 See Schematic N/A N/A 740 58916 267 975 2804 812 59976 125 944 2859 320-068Chad Helgeson Operations Manager David Gorm dgorm@hilcorp.com 777-8333 ✔ ✔ ✔✔ ✔ Digitally signed by Chad Helgeson DN: cn=Chad Helgeson, ou=Users Date: 2020.04.01 18:12:18 -05'00' Chad Helgeson By Samantha Carlisle at 3:30 pm, Apr 01, 2020 DSR-4/1/2020 RBDMS HEW 4/2/2020 SFD 4/2/2020gls 4/6/20 Type Measured Depth (feet) True Vertical Depth (feet) 4-1/2" TRM-4E SSSV 994 994 9-5/8" x 7" Liner top 11,524 9,293 7" x 4-1/2" S-3 13,316 10,650 HRD ZXP liner top 13,357 10,689 Northstar NS-05 Packer and SSSV Depths _____________________________________________________________________________________ Revised By: DH on 03-17-2020 Northstar Unit Well: NS-05 Last Completed: 4/12/2005 PTD: 205-009 TD =14,033’ (MD) / TD = 11,336(TVD) 20” Orig. KBE = 56.37’/ BFE = 40.1’ (CB 15.9’) 7” 4 5 6 7 9-5/8” 1 2 8 9 11 & 12 Min ID= 3.725” @ 13,351’ Ivishak PBTD = 14,027’(MD) / PBTD = 11,330’(TVD) 3 Top of Fill @ 13,918’ Tag 2/20/2016 13-3/8” 10 13 4-1/2 ” 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 / Btrc. 12.415 Surface 3,187’ 0.150 9-5/8" Production 47 / L-80 / Btrc. 8.535 Surface 11,702’ 0.0732 7" Liner 29 / L-80 / Hydril 511 6.184 11,524’ 13,537’ 0.0372 4-1/2” Liner 12.6/13Cr80/Vam Top 3.958 13,357’ 14,031’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366’ 0.0152 JEWELRY DETAIL No Depth Item 1 994’ 4-1/2” TRM-4E SSSV w/ 4-1/2” x Profile - ID= 3.812” 2 3,997’ GLM - MMG Dummy Valve – TVD @ 3,979’ – Set 3/29/2005 3 11,524’ 9-5/8” x 7” Liner top packer and Hanger 4 13,261’ 4-1/2” X Nipple, ID= 3.813 5 13,292’ 4-1/2” Cidra Fiber Optic Transducer, ID= 3.958 6 13,316’ 7” x 4-1/2” Baker S-3 Packer, ID= 3.950” (13,310’ ELMD) 7 13,340’ 4-1/2” X Nipple, ID= 3.813 8 13,351’ 4-1/2” XN Nipple,ID= 3.725” (13,368’ELMD) 9 13,357’ Baker 5” x 7” HRD ZXP Liner Top Packer (11.76 TB) 10 13,362’ 4-1/2” Self-aligning Mule Shoe, ID= 3.958”– Bottom @ 13,366’ 11 13,377’ RS Pack-off Seal Nipple – ID=4.25” 12 13,379’ Baker 5” x 7” Flex-Lock Liner Hanger ID=4.41” 13 13,388’ 5” Vam Ace x 4-1/2” Vam Top Cross-over – ID=3.90” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Ivishak 13,707’ 13,727’ 11,024‘ 11,043‘ 20 6/28/05 Open 13,710’ 13,740’ 11,026‘ 11,055‘ 30 4/30/13 Open 13,733’ 13,764‘ 11,048‘ 11,078‘ 31 8/22/08 Open 13,734’ 13,764‘ 11,049‘ 11,078‘ 30 9/20/05 Open 13,735’ 13,766‘ 11,050‘ 11,080‘ 31 8/22/08 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 4/12/05 Open 13,739’ 13,794‘ 11,054‘ 11,107‘ 55 5/28/05 Open 13,759’ 13,809’ 11,073’ 11,121’ 50 3/4/2016 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 8/22/08 Open 13,763’ 13,794‘ 11,077‘ 11,107‘ 31 3/11/08 Open 13,810’ 13,830‘ 11,122‘ 11,141‘ 20 8/22/08 Open 13,830’ 13,850’ 11,141’ 11,160’ 20 03/01/20 Open OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 419 sx PF “L”, 457 sx Class “G” in 16” Hole 9-5/8" 755 sx Extended,595 sx Class “G” in 12-1/4” Hole 7” 469 sx Class “G” in 8-1/2” Hole 4-1/2” 89 sx Class “G” in 6” Hole WELL INCLINATION DETAIL KOP @ 1,969’ Max Hole Angle = 56 deg. @ 7,693’ Max Angle at Top Perf: 17 Deg. @ 13,707’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23244-00-00 Completed – 4/12/2005 Re-perforate – 3-11-2008 Add Perforations – 8/22/2008 Add Perforations – 4/30/2013 Add Perforations – 3/4/2016 SAFETY NOTE Well requires a safety valve, 4-1/2” Chrome Tubing & Liner Open13,830’ 13,850’ 11,141’ 11,160’ 20 03/01/20 Well Name Rig API Number Well Permit Number Start Date End Date NS-05 Eline 50-029-23244-00-00 205-009 3/1/2020 3/1/2020 No operations to report. No operations to report. 2/29/2020 - Saturday No operations to report. 3/3/2020 - Tuesday 3/1/2020 - Sunday Rig up Slb WL pressure control equipment. Pressure test WHE to 250 psi low, 4,700 psi high PT passed. RIH w/ 20' x 2-7/8" PJO (6 SPF - 60 deg phasing) perf gun and and perf interval @ 13,830'- 13,850' (correlated to PDC log dated April 11, 2005). POOH, rig down, secure and hand back well to Pad Operator - notified control room done for the night. 3/2/2020 - Monday 2/28/2020 - Friday No operations to report. 2/26/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/27/2020 - Thursday No operations to report. perf interval @ 13,830'- 13,850' THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field, Northstar Oil Pool, NS -05 Permit to Drill Number: 205-009 Sundry Number: 320-068 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a ce Chair DATED this` 0day of February, 2020. 1BDMSL64 FEB 112020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® FEB 0 5 2020 AOGCC0 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 205-009 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 50-029-23244-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 45M Will planned perforations require a spacing exception? Yes ❑ No y NORTHSTAR UNIT NS -05 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ,.'4 f(�c 3 jZ799 ADL0312808 NORTHSTAR / NORTHSTAR OIL PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,033' 11,336' 14,027' 11,330' 4,331 N/A N/A Casing Length Size MO TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,187' 13-3/8" 3,187' 3,183' 5,020psi 2,260psi Production 11,702' 9-5/8" 11,702' 9,402' 6,870psi 4,760psi Liner 2,011' 7" 13,537' 10,862' 8,160psi 7,020psi Liner 674' 4-1/2" 14,031' 11,334' 8,430psi 7,500psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / 13Cr-80 / Vam Top 13,366 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 9-5/8" x 7 " Liner Top 17" x 4-1/2" S-3 / 5" x 7" HRD ZXP Liner Top and 11,524 MD / 9,293 TVD, 13,316' MD / 10,650' TVD & 13,357' MD / 10,689' TVD and TRM-4E SSSV 994' MD / 994' TVD 12. Attachments: Proposal Summary L Wellbore schematic 141 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: 2/12/2020 OIL ❑a WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Gorm Authorized Title: Operations Manager Contact Email: d Orm hi1cor .coni -�`- Contact Phone: 777-8333 Authorized Signature. Date: February 4, 2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q �O U Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BDMS ('FEB 1 12020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / O 8 APPROVED BY a1 \O 'O Approved by: �r� COMMISSIONER THE COMMISSION Date: ` 0�31� '� — /O — Z O Submit Form and PC 1 403 ew ed /2017 Approved application s I r tr1 fr B date of a roval. Attachments in Duplicate K Hii.m Alaska, LG Perf Add Well: NS -05 PTD: 205-009 API: 50-029-23244-00 Well Name: NS -05 API Number: 50-029-23244-00 Current Status: Online Rig: EL Estimated Start Date: February 12, 2020 Estimated Duration: 2 days Reg.Approval Req'std? 2-3-2020 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 205-009 First Call Engineer: David Gorm (907) 777-8333 (0) (505) 215-2819 (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: Maximum Expected BHP: Max. Anticipated Surface Pressure: Last Sl WH P: Min ID: Reference Log: 5,441 psi @ 11,100' TVD (Based on Ivishak BHP on 12/9/2019) 5,441 psi @ 11,100' TVD (Based on Ivishak BHP on 12/9/2019) 4,331 psi (Based on 0.1 psi/ft. gas gradient) 4,136 psi (Taken on 09/01/19) 3.725" ID 4-1/2" XN Nipple at 13,351' MD Primary Depth Control Log dated April 11, 2005 Brief Well Summary: NS -05 had multiple stimulations (reperf & acid stimulations) throughout the well's life. Each stimulation shown production improvement from the well. The last perforation work was completed in March 2016. Objective: Using Eline, perforate the following Ivishak interval for increased oil production. Prior to perforation proposed gun run must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir Engineer: Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low/ 4,500psi high. 2. MU perforating tool string with 2-7/8", 6spf, 60 deg phasing guns with deep penetrating charges. 3. RIH and correlate gun run to reference log Perforation Depth Control Log dated April 11, 2005. Contact OE David Gorm at 1(505) 215-2819 prior to perforating for final approval of tie in. 4. Perforate gun run as per Table 1: NS -05 Proposed Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. Gun Perf Top Run # Perf Bottom Perf Length 1 ±13,830' ±13,850' 20 Total 20 Table 1: NS -05 Proposed Perf Gun Runs 6. RD Eline. Attachments: As -built / Well Schematic n Ifilcorp Alaska, MC Or!& KBE =56.37/ BFE=40.1' (B 15.9') 20" 45/8" 3 7 6 Mn IR 3.725" 13,351' B 9 11 &12 3 7' Top r2 Fill @13,918 WAhak Ta77l202016 41/r iS TD =14,033' (MD) /TD=11,336(TVD) PBfD =14,027 (MD) / PBFD=11,330'(TVD) PROPOSED TREE & WELLHEAD Tree I ABB-VGI 5-1/8" 5KSI Wellhead I ABB-VGI 13-5/8"Multibowl SK51 Northstar Unit Well: NS -05 Last Completed: 4/12/2005 PTD: 205-009 OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 419 sx PF "L", 457 sx Class "G" In 16" Hole 9-5/8" 755 sx Extended,595 sx Class "G" in 12-1/4" Hole 7" 469 sx Class "G" In 8-1/2" Hole 4-1/2" 89 sx Class "G" in 6" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top atm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68 / L-80 / Btrc. 12.415 Surface 3,187' 0.150 9-5/8" Production 47 / L-80 / Btrc. 9.535 Surface 11,702' 0.0732 7" Liner 29 / L-80 / Hydril 511 6.184 11,524' 13,537' 0.0372 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 13,357' 14,031' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 1 3.958 1 Surface 13,366' 0.0152 WELL INCLINATION DETAIL KOP @ 1,969' Maz Hof. Angle = 56 deg. @ 7,693' Max Angle at Top Pert: 17 Deg. @ 13,707' JEWELRY DETAIL No Depth Item 1 994' 4-1/2" TRM-4E SSSV w/ 4-1/2" x Profile - ID= 3.812" 2 3,997' GLM -MMG Dummy Valve - TVD @ 3,979'- Set 3/29/2005 3 11,524' 9-5/8" x 7" Liner top packer and Hanger 4 13,261' 4-1/2" X Nipple, ID= 3.813 5 13,292' 4-1/2" Cidra Fiber Optic Transducer, ID= 3.958 6 13,316' 7" x 4-1/2" Baker S-3 Packer, ID= 3.950" (13,310' ELMD) 7 13,340' 4-1/2" X Nipple, ID= 3.813 8 1 13,351' 1 4-1/2" XN Nipple, ID= 3.725" (13,368'ELMD) 9 13,357' Baker 5" x 7" HRD ZXP Liner Top Packer (11.76 TB) 30 13,362' 4-1/2" Self -aligning Mule Shoe, ID= 3.958" - Bottom @ 13,366' it 13,377' RS Pack -off Seal Nipple -ID=4.25" 12 13,379' Baker 5" x 7" Flex -Lock Liner Hanger M=4.41" 13 13,388' S"Vam Ace x4-1/2"Vam Top Cross-over-ID=3.9(r PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (ND) Btm (TVD) FT Date Status 13,707' 13,727' 11,024' 11,043' 20 6/28/05 Open 13,710' 13,740' 11,026' 11,055' 30 4/30/13 Open 13,733' 13,764' 11,048' 11,078' 31 8/22/08 Open 13,734' 13,764' 11,049' 11,078' 30 9/20/05 Open 13,735' 13,766' 11,050' 11,080' 31 8/22/08 Open Ivishak 13,739' 13,794' 11,054' 11,107' 55 4/12/05 Open 13,739' 13,794' 11,054' 11,107' S5 5/28/05 Open 13,759' 13,809' 11,073' 11,121' 50 3/4/2016 Open 13,763' 13,794' 11,077' 11,107' 31 8/22/05 Open 13,763' 13,794' 11,077' 11,107' 31 3/11/08 Open 13,810' 13,830' 11,122' 11,141' 20 8/22/08 Open i/ ±13,830' ±13,850' ±11,141' !11,160' ±20 Future I Future GENERAL WELL INFO API: 50-029-23244-00-00 Completed -4/12/2005 Re -perforate - 3-11-2008 Add Perforations -8/22/2008 Add Perforations -4/30/2013 Add Perforations -3/4/2016 SAFETY NOTE Well requires a safety valve, 4-1/2" Chrome Tubing & Liner Revised By: TDF In Progress • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIOION MAR 1 6 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate ❑ Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ ;rforate New Pool ❑ Repair Well ❑ Re-enter Susp Wel ❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 205-009 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23244-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312808 NORTHSTAR UNIT NS-05 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 14,033 feet Plugs measured N/A feet true vertical 11,336 feet Junk measured N/A feet 11,524, 13,316& Effective Depth measured 13,918 feet Packer measured 13,357 feet 9,293, 10,650& true vertical 11,225 feet true vertical 10,689 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,187' 13-3/8" 3,187' 3,183' 5,020psi 2,260psi Production 11,702' 9-5/8" 11,702' 9,402' 6,870psi 4,760psi Production 2,011' 7" 13,537' 10,862' 8,160psi 7,020psi Liner 674' 4-1/2" 14,031' 11,334' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED APR 0 .1 2016 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr-80/Vam Top 13,366' 10,698' 9-5/8"x 7"Liner Top 7"x 4-1/2"S-3 994,(MD) Packers and SSSV(type,measured and true vertical depth) HRD ZXP Liner Top TRM-4E SSSV See Above 994'(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - Prior to well operation: 957 61,886 1,136 616 1,102 Subsequent to operation: 945 65,439 1,313 830 1,161 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 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 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: 316-016 Contact Taylor Wellman i ..1 Email twellman@hilcorp.com c Printed Name Mike Dunn Title Operations Manager Signature Phone 777-8382Alt 38Date 3/15/2016 Form 10-404 Revised 5/2015 �j /� 3(� Submit Original Only RBDMS 1.-L MAR 1 6 2016 • • Northstar Unit Well: NS-05 II SCHEMATIC Last Completed: 4/12/2005 HHeorpAlaska,L1.0 PTD: 205 009 Orig.KBE 56.37'/BFE 40.1'(CB 15.9') TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree ABB-VGI 5-1/8"5KSI 20" Driven Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 13-3/8" 419 sx PF"L",457 sx Class"G"in 16"Hole 20'I I I I 9-5/8" 755 sx Extended,595 sx Class"G"in 12-1/4"Hole a, 7" 469 sx Class"G"in 8-1/2"Hole I. 1 4-1/2" 89 sx Class"G"in 6"Hole CASING DETAIL 13-3/g' • 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/Btrc. 12.415 Surface 3,187 0.150 2 9-5/8" Production 47/L-80/Btrc. 8.535 Surface 11,702' 0.0732 7" Liner 29/L-80/Hydril 511 6.184 11,524' 13,537' 0.0372 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 13,357' 14,031' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366 0.0152 WELL INCLINATION DETAIL KOP@1,969' Max Hole Angle=56 deg.@ 7,693' Max Angle at Top Perf:17 Deg.@ 13,707' JEWELRY DETAIL No Depth Item 1 994' 4-1/2"TRM-4E SSSV w/4-1/2"x Profile- ID=3.812" 2 3,997' GLM-MMG Dummy Valve-TVD @ 3,979'-Set 3/29/2005 3 11,524' 9-5/8"x 7"Liner top packer and Hanger 4 13,261' 4-1/2"X Nipple,ID=3.813 5 13,292' 4-1/2"Cidra Fiber Optic Transducer,ID=3.958 6 13,316' 7"x 4-1/2"Baker S-3 Packer,ID=3.950"(13,310'ELMD) [ 7 13,340' 4-1/2"X Nipple,ID=3.813 .I` ? 8 13,351' 4-1/2"XN Nipple,ID=3.725"(13,368'ELMD) 1 3 9 13,357' Baker 5"x 7"HRD ZXP Liner Top Packer(11.76 TB) 'iv [ ( 10 13,362' 4-1/2"Self-aligning Mule Shoe,ID=3.958"-Bottom @ 13,366' 11 13,377' RS Pack-off Seal Nipple-ID=4.25" 9-5/a' • 12 13,379' Baker 5"x 7"Flex-Lock Liner Hanger ID=4.41" 13 13,388' 5"Vam Ace x 4-1/2"Vam Top Cross-over-10=3.90" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 3 ? 4 13,707' 13,727' 11,024' 11,043' 20 6/28/05 Open laY;, 5 13,710' 13,740' 11,026' 11,055' 30 4/30/13 Open 13,733' 13,764' 11,048' 11,078' 31 8/22/08 Open 6 13,734' 13,764' 11,049' 11,078' 30 9/20/05 Open 13,735' 13,766' 11,050' 11,080' 31 8/22/08 Open Mn Io-3.725"@ Ivishak 13,739' 13,794' 11,054' 11,107' 55 4/12/05 Open 13,351' 8 13,739' 13,794' 11,054' 11,107' 55 5/28/05 Open 13,759' 13,809' 11,073' 11,121' 50 3/4/2016 Open 1 1�_ 9 13,763' 13,794' 11,077' 11,107' 31 8/22/08 Open • 13,763' 13,794' 11,077' 11,107' 31 3/11/08 Open ' '' 11&12 13,810' 13,830' 11,122' 11,141' 20 8/22/08 Open 136 7"I ‘ GENERAL WELL INFO API:50-029-23244-00-00 Completed-4/12/2005 Re-perforate-3-11-2008 Top of Fill @ 13,918' _ Ivishak Add Perforations-8/22/2008 Tag 2J242016 J Add Perforations-4/30/2013 Add Perforations-3/4/2016 41/2"4 -A SAFETY NOTE TD=14,033'(MD)/TD=11,336(1VD) PBTD 14,027'(MD)/PBTD=11,330'(TVD) Well requires a safety valve,4-1/2"Chrome Tubing&Liner Revised By:TDF 3/15/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-5 Slickline 50-02923244-00-00 205-009 2/20/16 3/4/16 Daily Operations: 2/17/2015 -Wednesday No activity to report. 2/18/2015-Thursday No activity to report. 2/19/2015 - Friday No activity to report. 2/20/2015 -Saturday PT 300 PSI LOW&4,000 PSI HIGH, GOOD TEST. RAN 2.84""CENT, 2' 1-7/8" STEM, 10'-3" BAILER, OAL=141" AND TAG BOTTOM @ 13,876' SLM, +42' CORRECTION FROM 8-11-15 = 13,918' MD. P/U WEIGHTS AT TAG DEPTH 1,025# RDMO. 2/21/2015 -Sunday No activity to report. 2/22/2015- Monday No activity to report. 2/23/2015 -Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP NS-5 E-Line 50-029-23244-00 205-009 2/20/16 3/4/16 Daily Operations: 3/2/2015 -Wednesday RU E-LINE AND PT SURFACE EQUIP 300 LP 4,750 HP. RIH W/30' X 2.75" MILLENIUM HMX GUNS, 6 SPF/60 DEG CORRELATE TO SLB USIT LOG 04/11/2005. PERFORATE INTERVAL 13,775'- 13,805'. ALL SHOTS FIRED. LDFN 3/3/2015 -Thursday RU E-LINE SURFACE EQUIP & PT QTS 300 LP 4,750 HP. RIH W/ 10' 2.75 MILLENIUM HMX GUNS 6SPF/60°. CORRELATE TO SLB USIT LOG 4/11/2005 PERFORATE INTERVAL 13,799'-13,809'. ALL SHOTS FIRED. LDFN. 3/4/2015 - Friday RU E-LINE SURFACE EQUIP & PT QTS 300 LP 4,750 HP. RIH W/20' 2.75 MILLENIUM HMX GUNS 6SPF 60°. CORRELATE TO SLB USIT LOG 4/11/2005. PERFORATE INTERVAL 13,759' - 13,779'. ALL SHOTS FIRED. RDMO. 3/5/2015-Saturday No activity to report. 3/6/2015 -Sunday No activity to report. 3/7/2015- Monday No activity to report. 3/8/2015 -Tuesday No activity to report. P� OF T�� • (• evi e �77, cv THE STATE Alaska Oil and Gas �, of Conservation Commission ALAS S ' 333 West Seventh Avenue _„ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 leXw,k. Main: 907.279.1433 �FALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager S ANN 1 1:FE; ` 4 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,Northstar Unit NS-05 Permit to Drill Number: 205-009 Sundry Number: 316-016 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 January, 2016. !MN§ LL JAN 1 9 2018 • • RECEIVEDSTATE OF ALASKA JAN 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS PIP/sic'+i& 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend ❑ ry,,-ID Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 205-009 . 3.Address. Stratigraphic ❑ Service ii 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23244-00-00 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 ❑ NORTHSTAR UNIT NS-05 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312808 • 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): 14,033' 11,336' 14,027' 11,330' 4,022 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,187' 13-3/8" 3,187' 3,183' 5,020psi 2,260psi Production 11,702' 9-5/8" 11,702' 9,402' 6,870psi 4,760psi Production 2,011' 7" 13,537' 10,862' 8,160psi 7,020psi Liner 674' 4-1/2" 14,031' 11,334' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/13Gr-80/Vam Top 13,366 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"Liner Top/7"x 4-1/2"S-3/5"x 7"HRD ZXP Liner Top and 11,524 MD/9,293 TVD, 13,316'MD/10,650'TVD& 13,357'MD/10,689'TVD and TRM-4E SSSV 994'MD/994'TVD 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development E✓]- Service [] 14. Estimated Date for 15.Well Status after proposed work: 2/1/2016 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Mike unn Title Operations Manager Signature ��%2/ Phone 777-8382 Date 117!2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\ 4— CALIZ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: l U -- 1 0 i APPROVED BY t_VeApproved by: /990.1_4444_ COMMISSIONER THE COMMISSION Date: /--/ _� Submit Form and Form 10-403 Revised 1.16015 a p i i n v lid for 12 mon s from the date of approval. Attachments in Duplicate RBDMS Lt- 9 201 ' R I (-11_-/C �4A, isle , . /1 16: • . Reperf Well: NS-05 PTD: 205-009 Hi!cora Alaska,LU API: 50-029-23244-00 Well Name: NS-05 API Number: 50-029-23244-00 Current Status: Online Rig: SL& EL Estimated Start Date: February 1, 2016 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 205-009 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) Current BHP (Ivishak): 5,074psi @ 11,100' TVD (Based on SBHPS on NS-05 08/23/15) MPSP: 4,022psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 3,840psi Recorded on 05/30/15 Min ID: 3.725" XN Nipple @ 13,351' and Brief Well Summary: NS-05 had multiple stimulations (reperf& acid stimulations)throughout the well's life. Each stimulation has shown production improvement from the well. The last stimulation work(30' or reperfs) was completed in - April 2013. Objective: Re-perforate and add perforations into the Ivishak sand. Procedure: Slickline 1. Spot slickline unit and RU. 2. Pressure test PCE to 300psi low/-4000psi high. 3. MU 2-7/8" dummy gun drift toolstring and drift&tag tubing. a. Last tag: 1-1/2" sample bailer @ 13,878' slm/13,928' elmd on 03/10/14 b. Well has a tubing retrievable SSSV. Ensure SL unit takes control of system and pressure is monitored for any signs of bleed down during entire operation. 4. RD SL. E-Line—email Todd Stone @ tstone@hilcorp.com to notify that perforating is beginning to arrange for water samples to be taken after completion. 5. Spot E-Line unit and RU. 6. Pressure test PCE to 300psi low/"'4000psi high. a. Use quick test sub for subsequent pressure tests. 7. MU 30'x 2-3/4" carrier guns."' a. 2-3/4", 6spf, 60 deg phasing, Millenium HMX guns to be used. b. Well has a tubing retrievable SSSV. Ensure SL unit takes control of system and pressure is monitored for any signs of bleed down during entire operation. 8. RIH and make an initial depth correlation pass above 13,707' and prior to dropping past the top perfs in the well. a. Note: During the 8/22/08 re-perforations, the guns became stuck in the middle of the perforated interval at 13,735'-13766' md. The guns were fired and became free. b. Tie-In Log to be used: SLB USIT 04/11/2005 3 9. Perforate the following interval: +/-13,779'—13,809' and `� 10. POOH and MU 20' x 2-3/4" carrier guns. 11. RIH and perforate the following interval: +/-13,759'—13,779' and 12. POOH, rig down and slide over to the next well. . 0 Reperf II Well: NS-05 PTD: 205-009 Hileorp Alaska.LLQ API: 50-029-23244-00 ATTACHMENTS: Schematic Proposed Schematic . ill . 0 Northstar Unit Well: NS-05 SCHEMATIC Last Completed: 4/12/2005 Iiilcorp Alaska,LLC PTD: 205-009 TREE&WELLHEAD Orig.KBE=56.37/BFE=40.1'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI WellheadOPEN ABB-VGIHOLE 13-5/8/CEME"MultibowlNTDETAIL 5KSI 20'41 I , ,_ -_ , 20" Driven 1 13-3/8" 419 sx PF"L",457 sx Class"G"in 16"Hole [ L9-5/8" 755 sx Extended,595 sx Class"G"in 12-1/4"Hole 13-3/8" 74-1/2" " 469 896sx sx ClassClass"G""G"in in68" 1/2Hole"Hole ;j 2 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/Btrc. 12.415 Surface 3,187' 0.150 9-5/8" Production 47/L-80/Btrc. 8.535 Surface 11,702' 0.0732 7" Liner 29/L-80/Hydril 511 6.184 11,524' 13,537' 0.0372 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 13,357 14,031' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366' 0.0152 WELL INCLINATION DETAIL KOP @ 1,969' Max Hole Angle=56 deg.@ 7,693' Max Angle at Top Perf:17 Deg.@ 13,707' JEWELRY DETAIL No Depth Item 1 994' 4-1/2"TRM-4E SSSV w/4-1/2"x Profile- ID=3.812" `/ 2 3,997' GLM-MMG Dummy Valve-TVD @ 3,979'-Set 3/29/2005 3 11,524' 9-5/8"x 7"Liner top packer and Hanger 4 13,261' 4-1/2"X Nipple,ID=3.813 'IL 3 5 13,292' 4-1/2"Cidra Fiber Optic Transducer,ID=3.958 6 13,316' 7"x 4-1/2"Baker S-3 Packer,ID=3.950"(13,310'ELMD) I 754321 13,340' 4-1/2"X Nipple,ID=3.813 9-5/8" 8 13,351' 4-1/2"XN Nipple,ID=3.725"(13,368'ELMD) • 9 13,357' Baker 5"x 7"HRD ZXP Liner Top Packer(11.76 TB) 10 13,362' 4-1/2"Self-aligning Mule Shoe,ID=3.958"-Bottom @ 13,366' 11 13,377' RS Pack-off Seal Nipple-ID=4.25" 12 13,379' Baker 5"x 7"Flex-Lock Liner Hanger ID=4.41" 4 13 13,388' 5"Vam Ace x 4-1/2"Vam Top Cross-over-ID=3.90" = 5 PERFORATION DETAIL s i F 6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7 13,707' 13,727' 11,024' 11,043' 20 6/28/05 Open Mn 113,3.725"@13,710' 13,740' 11,026' 11,055' 30 4/30/13 Open 13,351' 13,733' 13,764' 11,048' 11,078' 31 8/22/08 Open 8 13,734' 13,764' 11,049' 11,078' 30 9/20/05 Open 1 Ivishak 13,735' 13,766' 11,050' 11,080' 31 8/22/08 Open '' 9 13,739' 13,794' 11,054' 11,107' 55 4/12/05 Open Arir- 11&12 13,739' 13,794' 11,054' 11,107' 55 5/28/05 Open 13,763' 13,794' 11,077' 11,107' 31 8/22/08 Open 71 13 ‘ 13,763' 13,794' 11,077' 11,107' 31 3/11/08 Open 13,810' 13,830' 11,122' 11,141' 20 8/22/08 Open GENERAL WELL INFO API:50-029-23244-00-00 Ivishak Completed-4/12/2005 Re-perforate-3-11-2008 4-1/2" Add Perforations-8/22/2008 Add Perforations-4/30/2013 TD=14,033'(MD)/TD=11,336(TVD) ADDITIONAL INFORMATION SAFETY NOTE PBTD=14,027'(MD)/PBTD=11,330'(TVD) Location:SEC.11,T13N,R13E,1,089'FSL&642'FEL Well requires a safety valve,4-1/2"Chrome Tubing&Liner Datum MD=13,217'/Datum TVD=10,500'SS Revised By:TDF 12/14/2015 0 Northstar Unit n • Well: NS-05 PROPOSED Last Completed: 4/12/2005 Hilcorp Alaska,LLC PTD: 205-009 TREE&WELLHEAD Orig.KBE=56.37'/BFE=40.1'(CB 15.9') Tree ABB-VGI 5-1/8"SKSI r Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20" OPEN HOLE/CEMENT DETAIL 4-- 0, ., 20" Driven L 1 13-3/8" 419 sx PF"L",457 sx Class"G"in 16"Hole ' [ 9-5/8" 755 sx Extended,595 sx Class"G"in 12-1/4"Hole 13-3/8" 7" 469 sx Class"G"in 8-1/2"Hole 4-1/2" 89 sx Class"G"in 6"Hole 2 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/Btrc. 12.415 Surface 3,187' 0.150 9-5/8" Production 47/L-80/Btrc. 8.535 Surface 11,702' 0.0732 ' 7" Liner 29/L-80/Hydril 511 6.184 11,524' 13,537' 0.0372 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 13,357' 14,031' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 13,366' 0.0152 WELL INCLINATION DETAIL KOP @ 1,969' Max Hole Angle=56 deg.@ 7,693' Max Angle at Top Perf:17 Deg.@ 13,707' JEWELRY DETAIL No Depth Item 1 994' 4-1/2"TRM-4E SSSV w/4-1/2"x Profile- ID=3.812" 2 3,997' GLM-MMG Dummy Valve-TVD @ 3,979'-Set 3/29/2005 3 11,524' 9-5/8"x 7"Liner top packer and Hanger IL 4 13,261' 4-1/2"X Nipple,ID=3.813 '1 � 3 5 13,292' 4-1/2"Cidra Fiber Optic Transducer,ID=3.958 ', 6 13,316' 7"x 4-1/2"Baker S-3 Packer,ID=3.950"(13,310'ELMD) gl 7 13,340' 4-1/2"X Nipple,ID=3.813 9 5/8" 8 13,351' 4-1/2"XN Nipple,ID=3.725"(13,368'ELMD) 9 13,357' Baker 5"x 7"HRD ZXP Liner Top Packer(11.76 TB) 10 13,362' 4-1/2"Self-aligning Mule Shoe,ID=3.958"-Bottom @ 13,366' 11 13,377' RS Pack-off Seal Nipple-10=4.25" 12 13,379' Baker 5"x 7"Flex-Lock Liner Hanger ID=4.41" 4 13 13,388' 5"Vam Ace x 4-1/2"Vam Top Cross-over-ID=3.90" Agi 5 PERFORATION DETAIL 4 1,z 6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7 13,707' 13,727' 11,024' 11,043' 20 6/28/05 Open MnID=3.725"@ 13,710' 13,740' 11,026' 11,055' 30 4/30/13 Open 13,351' 13,733' 13,764' 11,048' 11,078' 31 8/22/08 Open 8 13,734' 13,764' 11,049' 11,078' 30 9/20/05 Open 13,735' 13,766' 11,050' 11,080' 31 8/22/08 Open Ivishak 13,739' 13,794' 11,054' 11,107' 55 4/12/05 Open -118,12 13,739' 13,794' 11,054' 11,107' 55 5/28/05 Open ±13,759' ±13,809' ±11,073' ±11,121' ±50 Future Future 13 7"1 ‘ 13,763' 13,794' 11,077' 11,107' 31 8/22/08 Open 13,763' 13,794' 11,077' 11,107' 31 3/11/08 Open 13,810' 13,830' 11,122' 11,141' 20 8/22/08 Open GENERAL WELL INFO Ivishak API:50-029-23244-00-00 Completed-4/12/2005 41/2 Re-perforate-3-11-2008 Add Perforations-8/22/2008 TD=14,033'(MD)/TD=11,336(TVD) Add Perforations-4/30/2013 PBTD=14,027'(MD)/PBTD=11,330'(TVD) ADDITIONAL INFORMATION SAFETY NOTE Location:SEC.11,T13N,R13E,1,089'FSL&642'FEL Well requires a safety valve,4-1/2"Chrome Tubing&Liner Datum MD=13,217'/Datum TVD=10,500'SS Revised By:TDF 12/14/2015 m STATE OF ALASKA AWKA OIL AND GAS CONSERVATION COM ION NIA1 2 9 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well Li Plug Perforations U Perforate k f Other Li 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 0 Exploratory ❑ 205-009-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-23244-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312808 NSTR NS05 • 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 14033 feet' Plugs measured None feet true vertical 11335.58 feet Junk measured None feet Effective Depth measured 14027 feet• Packer measured See Attachment feet true vertical 11329.83 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 201 20"169#X-56 40-241 40-240.98 4260 2590 Surface 3142 13-3/8"68#L-80 45-3187 45-3183.4 5020 2260 Intermediate None None None None None None Production 11663 9-5/8"53.5#L-80 39-11702 39-9401.36 7930 6620 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet woo True Vertical depth .7b��"` o o�` : i `I A s P See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 37-13366 37-10697.87 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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: 843 57851 1779 0 847 Subsequent to operation: 886 59130 1656 0 846 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 5 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U • Gas U WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCO 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: 313-015 Contact Nita Summerhays Email Nita.Summerhays a( ,BP.com Printed Name Nita Summerha s Title Petrotechnical Data Technician Signat - Phone 564-4035 Date 5/23/2013 z 119/ 16 r t MAY 29701 Form 10-404 Revised 10/2012 ,0�J2 Submit Original Only � l( • • Daily Report of Well Operations ADL0312808 ***WELL FLOWING ON ARRIVAL*** (perforating) RIG UP SWCP DSL-1 3/10/2013 ***CONTINUED ON 3/11/13 WSR*** ***CONTINUED FROM 3/10/13 WSR***(perforating) DRIFTED W/11' 8"X 2-7/8" DUMMY GUN, 1.25" SAMPLE BAILER- TAG TD @ 13864' SLM CURRENTLY DRIFTING W/ 11' 8"X 2-7/8" DUMMY GUN (using DSL tools to correlate) 3/11/2013 ***CONTINUED ON 3/12/13 WSR*** ***CONTINUED FROM 3/11/13 WSR***(perforating) LOGGED PERFORATING INTERVAL W/ DSL TOOLS & DUMMY GUN CURRENTLY IN HOLE W/ 10' PERF GUN & PERFORMING LOGGING INTERVAL FOR TIE IN 3/12/2013 ***CONTINUED ON 3/13/13 WSR*** *****WELL FLOWING UPON ARRIVAL***** (ELINE RE-PERF) ARRIVE AT NORTHSTAR AND START SPOTTING UP EQUIPMENT& RIGGING UP ELINE UNIT FOR PERFORATING JOB CURRENTLY MECHANIC IS REPLACING FUEL PUMP ON LOGGER SO THAT WE CAN CONTINUE ON WITH JOB 4/20/2013 ***CONTINUED ON 04/21/13 WSR*** ***JOB CONTINUED FROM 20-APR-2013*** (I_-LINE: PERFORATING) RIGGED UP ELINE UNIT AS MUCH AS POSSIBLE & STBY FOR HIGH WINDS JOB CANCELLED/POSTPONED DUE TO RIG SUPPORT NEEDED IN PRUDHOE 4/21/2013 ***WELL FLOWING UPON DEPARTURE *** ***JOB CONTINUED FROM 29-APR-2013*** (ELINE: PERFORATING) REACH SURFACE WITH FIRST GUN AND CONFIRM SHOTS. RIH W/ HEAD, ERS, 2 -2.13"WEIGHTS, UPCT, FIRING HEAD, 20' - 2.88" HSD 6SPF PJ2906 GUN, MOAL=43', MOAD = 2.88" PERFORATE INTERVAL 17310'-17320'/CCL TO TOP SHOT= 3.5'/ CCL STOP DEPTH = 17306.5' CORRELATE TO SLB USIT LOG DATED 11-APR-2005. CONFIRMED ALL SHOTS FIRED, RIG DOWN, MOVE TO NS-07 HAND OVER WITH DSO WELL SECURE, DSO POPPED WELL. FINAL T/I/O = 3900/60/20 4/30/2013 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 2 DIESEL 4 METH 6 TOTAL Perforation Attachment ADL0312808 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NS05 9/20/2005 APF 13704 13707 11020.74 11023.6 NS05 4/30/2013 APF 13707 " 13710 11023.6 11026.46 NS05 4/30/2013 APF 13710 13719 11026.46 11035.05 NS05 4/30/2013 APF 13719 13727 11035.05 11042.69 NS05 4/30/2013 APF 13727 13733 11042.69 11048.41 NS05 4/30/2013 APF 13733 13734 11048.41 11049.37 NS05 4/30/2013 APF 13734 13735 11049.37 11050.32 • NS05 4/30/2013 APF 13735 13739 11050.32 11054.14 NS05 4/30/2013 APF 13739 13740 , 11054.14 11055.1 NS05 4/30/2013 RPF 13740 13763 11055.1 11077.06 NS05 8/22/2008 RPF 13763 13764 11077.06 11078.02 NS05 8/22/2008 RPF 13764 13766 11078.02 11079.93 NS05 8/22/2008 RPF 13766 13794 11079.93 11106.67 NS05 8/21/2008 RPF 13810 13830 11121.96 11141.08 BPS BRIDGE 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 • Casing / Tubing Attachment ADL0312808 Casing Length Size MD TVD Burst Collapse CONDUCTOR 201 20" 169#X-56 40 - 241 40 - 240.98 4260 2590 LINER 2012 7"29# L-80 11524 - 13536 9293.39 - 10860.8 8160 7020 LINER 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.7 8430 7500 PRODUCTION 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 SURFACE 3142 13-3/8"68#L-80 45 - 3187 45 - 3183.4 5020 2260 TUBING 13329 4-1/2" 12.6# 13Cr80 37 - 13366 37 - 10697.9 8430 7500 • . 0 • Packers and SSV's Attachment ADL0312808 SW Name Type MD ND Depscription NS05 PACKER 11524 9237.02 7" Liner Top Packer NS05 PACKER 13316 10593.65 4-1/2" Baker S-3 Perm Packer NS05 PACKER 13357 10632.88 5-1/2" BAKER ZXP PACKER NS05 PACKER 13357 10632.88 4-1/2" Liner Top Packer NS05 PACKER 13369 10644.37 5-1/2" BAKER ZXP PACKER NS05 PACKER 13369 10644.37 4-1/2" Liner Top Packer TREE= ABB-VG15-1/8"110 WELLHEAD.= ABB-VG113-5/8"MULTEOWL NS05 SrY NOTES:WELL REQUIRES A SSSV. 4-1/2"CHROME TBG&LNR"*" AgJATOR= BAKER ivnaL KB.aE 56.37' BE ELEV= 40.1'((B 15.9') KOP= 1969' 994' —14-1/2"TRM-4E SSSV WI 4-1/2"X PROF =3.812" M3X Angle= 56° 7693' Oaken = 13217' Datum 1VD= 10500'SS 113-3/8"CSG,68#,L-80 BTC,D=12.415" H 3187' 1-4 GAS LET MANDRELS ST IVD TVD DEV TYPE VLV LATCH PORT DATE 1 3997 4000 10 IVIMG OW 03/29/05 Minimum ID =3.726" @ 13361' 4-1/2"XN NIPPLE TOP OF r u•Ft —I 11525' 9-5/8"CSG,53.5#,L-80 B1M-C 11702' 13261* H4-1/2-X NP, =3.813- 1 13202 - 4-1/2°FIBER opric TRANSDUCER,D=3.958" 1 1 13316' 1-17"X 4-1/2"BKR S-3 PKR,0=3.958* 1 13310' ELM) 13340' 4-1/2"X NP, =3.813' 1 13351' H4-1/2"XN MP,D=3.725" I TOP OF 4-1/2"LW H 13367' I 133ar H XN LOGGED ON 04/11/05_1 4-1t2"TBG,12.6#,13CR VAM-ACE, H 1336 6' C .0152 bpf,ID=3.958' 13366* 1-4-1/2'1-11ES SELF ALIGNING A&LESTIOE 17"LM,29#/ft L-80 Hydra 511,I3=6.184" H 13637' 1-4 =3.958' PERFORATION SUMM4RY REF LOG: SWS US1T 4/11/05 ANGLE AT TOP PERF: 17°@ 13707' 143te:Refer to Production DB for historical perf data SIZE 1 SPF 1 INTERVAL(MD) 1 Opn/Sqz J SHOT 1 SQZ SEE PAGE 2 FOR PERFORATION IT-ORMATTON I I H 14027' 4-1/2"LM,12.6#,13CRVAM-ACE, H 14031' VAA.AAAt .0152 bpf, =3.958' DATE REV BY COMMENTS EWE REV BY COMVENTS I NORTHSTAR 04/12105 TA C1G1NAL COMPLETION 06/14/09 RCT/TLH XN LOCK w/GAUGE SET(06/03/09) WI.: NS05 11/04/05 BIM DRLG DRAFT CORRECTIONS 06/28/09 WRRALH XN LOCK w/GAUGE PULL(06/22/09 PEAT Na: 2050090 02/22/06 ROY/TLH PEA CORRECTIONS 02/17/11 KAMM) ADDED SSSV SAFETY NOTE ARM,: 50-029-23244-00 11/27/07 VVRR/R1C LHD/LOCATION CORRECT1 05/10/13 SET/3/13 ADPERFS(04/30/13) SEC,11,T13N,R13E,1089'FSL&647 FB_ 03/11/013 WRR/TLH FE-PE09/05/03 WRR/PJC TURFS(08/22/08) BP Exploration(Alaska) NS05 • A • PERFORATION SUMMARY REF LOG: SAS USIT 4/11/05 _� ►� ANGLE AT TOP PERF: 17° • 1370T Note:Refer to Ftoduction OB for historical pert data SIZE SPF INTERVAL(MD) Opn/Sgz SHOT SOZ 2-7/8° 6 13707-13727 0 06/28/05 2-718" 6 13710-13740 0 04/30/13 2-718° 6 13733-13764 0 08/22/08 / C 6 13734-13764 0 09/20/05 2-78" 6 13735-13766 0 08/22/08 , 6 13739-13794 0 04/12/05 6 13739-13794 0 05/28/05 2-7/8" 6 13763-13794 0 08/22/08 6 13763-13794 0 03/11/08 2-7/8" 6 13810-13830 0 08/22/08 t k1E REV BY COMWENTS CATE REV BY COMMENTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 06/14/09 RCTRLH XN LOCK w/GAUGE SET(06/03/09) WELL: NS05 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRRITLH XN LOCK w/GAUGE PULL(06/22/09 PERMIT No: 2050090 02/22/06 ROY/11.H PELF C[IONS 02/17/11 MB/JMO ADDED SSSV SAFETY NOTE API No: 50-029-23244-00 11/27/07 WRR/PJC WaL 4Y LOCATION CORRECT] 05/10/13 SET/JM) ADPERFS(04/30/13) SEC.11,T13N,R13E,1089'FSL&647 FEL 03/11/08 WRR TLH REPERF 09/05/08 WRR/PJC PE FS(08/22/08) BP Exploration(Alaska) w wN71 % %y s THE STATE Alaska Oil and Gas F? ~ d �� °f l 1LA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 OF ALAS Main: 907.279.1433 Fax: 907.276.7542 Mark Sauve s aED FEB 2 6 nn Petroleum Engineer BP Exploration (Alaska), Inc. 001 P.O. Box 196612 �} _ Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS05 Sundry Number: 313 -015 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, Cathy P oerster Chair DATED this 2 day of January, 2013. Encl. • 0 RECEIVED STATE OF ALASKA JAN 15 2413 ALASKA OIL AND GAS CONSERVATION COMMISSION 07 1///1i3 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 ❑ Suspend ❑ Plug Perforations❑ Perforate Pull Tubing ❑ Time Extension. Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 4 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ,'3 BP Exploration (Alaska), Inc. Development In • Exploratory ❑ 205-009-0 • \ • 3. Address: 6. API Number. Stratigraphic E] Service ❑ P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23244 -00 -00 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458 '� NSTR NS05 . Will planned perforations require a spacing exception? Yes III No e t , r 6, t 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312808 ' NORTHSTAR, NORTHSTAR OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 14033 • 11336 • 14027 11330 None None Casing Length Size MD "ND Burst Collapse Structural Conductor 201 20" 169# X -56 40 - 241 40 - 240.98 Surface 3142 13 -3/8" 68# L -80 45 - 3187 45 - 3183.4 5020 2260 Intermediate None None None None None None Production 11663 9 -5/8" 53.5# L -80 39 - 11702 39 - 9401.36 7930 6620 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# 13Cr80 13Cr80 37 - 13366 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and ND (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 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 El • 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 f Phone 564 -4660 Date 01/14/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 5 V 6 Plug Integrity 171 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDIMS JAN 2 8 2013 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / C — 410 i APPROVED BY / ‘Y6 Approved by: �7 Y�-�_ COMMISSIONER THE COMMISSION Date: /— ZZ—/ 3 0 F r 0 -40 vjsed 1/2010 Approved application is valid for 12 months from the date of approval. Submit in Duplicate l.' V r''1 Ve //r7 /i.3 .,".G" 0,74j I . 1� • • PERFORATING PROCEDURE Ver 4 0 06/04/01 ROW WIRMUNIIRMIWIEUS Well: NS05 API #: 50- 029 - 23244 -00 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: Re- Perforate . WBL Entries IOR Type Work Description 100 S Drift to TD with 2 -7/8" Dummy Gun 100 E Perforate 13,710' - 13,740' MD Well Objectives and Logging Notes: The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by re- perforating 30' of the existing perforations. Please note that the perforations will be dependent on the drift information. Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Reference Log Tie in Log Add 0 feet Log: SWS USIT to the tie -in log to be on Date: 4/11/2005 depth with the reference log. Company: Schlumber9er Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re/lperf 13,710' - 13,740' 13,710' - 13,740' 30' 6 60° 0 Ivishak RePerf Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2.875 Charge: 2906 PJ HSD Desired Penetration: 27.7 Entry Hole Diam: 0.32 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, Backttow Through Drain or Hardline) Tie in to Jewelry @ MD Tie in using: Minimum ID: 3.725 in Min ID Type: 4.5" XN Nipple @ 13,351 'MD WLEG Depth: 13,366 ft MD Casing Size: 4.5 in 12.6# 13 -CR Liner Est Res. Pres. @ 13,846 MD - 11100' SS -5100 psi Last Tag: 13,932 ft ELMD on 11/14/2009 3.5" Bailer Well: NS05 Perforation Summary Date: API #: 50- 029 - 23244 -00 On -Site Prod Engr: PBTD General Comments: Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf 0/B/U - O O /B /U - O O /B /U - O O /B /U - O/B /U - (Th. • • Perforation Attachment ADL0312808 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS05 9/20/05 APF 13704. 13707 11021 11024 NS05 9/20/05 APF 13707 13719 11024 11035 NS05 9/20/05 RPF 13719 13727 11035 11043 NS05 8/22/08 RPF 13727 13733 11043 11048 NS05 8/22/08 RPF 13733 13734 11048 11049 NS05 8/22/08 RPF 13734 13735 11049 11050 NS05 8/22/08 RPF 13735 13739 11050 11054 NS05 8/22/08 RPF 13739 13763 11054 11077 NS05 8/22/08 RPF 13763 13764 11077 11078 NS05 8/22/08 RPF 13764 13766 11078 11080 NS05 8/22/08 RPF 13766 13794 11080 11107 NS05 8/21/08 RPF 13810 13830 11122 11141 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 • • Packers and SSV's Attachment ADL0312808 Well Facility Type MD Top Description TVD Top NS05 PACKER 11524 7" Liner Top Packer 9293 NS05 PACKER 13316 4 -1/2" Baker S -3 Perm Packer 10650 NS05 PACKER 13357 5 -1/2" BAKER ZXP PACKER 10689 NS05 PACKER 13357 4 -1/2" Liner Top Packer 10689 NS05 PACKER 13369 5 -1/2" BAKER ZXP PACKER 10701 NS05 PACKER 13369 4 -1/2" Liner Top Packer 10701 Casing Summary ADL0312808 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 201 20" 169# X -56 40 241 40 241 4260 2590 X -56 LINER 674 1 -1/2" 12.6# 13Cr8( 13357 14031 10689 11334 8430 7500 13Cr80 LINER 2012 7" 29# L -80 11524 13536 9293 10861 8160 7020 L -80 PRODUCTION 11663 9 -5/8" 53.5# L -80 39 11702 39 9401 7930 6620 L -80 SURFACE 3142 13 -3/8" 68# L -80 45 3187 45 3183 5020 2260 L -80 TUBING 13329 4 -1/2" 12.6# 13Cr8( 37 13366 37 10698 8430 7500 13Cr80 • 0 TREE _ ABB -V GI 5 -1/8" Y NOTES: WELL REQUIRES A SSSV. WELLHEAD= A,BB-VGI 13 -5/8" MULTIBOWL 5 N S 0 5 "*"4 -1/2" CHROM ETBG 8 LN R'"* ACTUATOR = BAKER KB. ELEV = 56.37' BF. ELEV = 40.1' (CB 15.9') KOP = 1969' • I 994' H 4 -1 /2" TRM-4E SSSV w / 4 -1 /2" X PROF ID = 3.812" I Max Angle = 56° @ 7693' [ Datum MD = 13217' Datum TV D = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" IH 3187' GAS LIFT MANDRELS I STI MD I TVD DEV I TYPE I VLV LATCH' PORT DATE 1 3997 4000 10 MMG DMY 03/29/05 Minimum ID = 3.725" @ 13351' 4 -1/2" XN NIPPLE TOP OF 7" LNR I-j 11525' I 9 -5/8" CSG, 53.5 #, L -80 BTM-C h 11702' 13261' H4-1/2" X NIP, ID = 3.813" I 13292' H 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I 13316' I- 7" X 4-1/2" BKR S -3 PKR, ID = 3.958" I 13310' I I ELMD I 13340' H4 -1/2" X NIP, ID = 3.813" I 13351' H4-1/2" XN NIP, ID = 3.725" I 'TOP OF 4-1/2" LNR H 13357' I ( 13368' H ELMD XN NIP LOGGED ON 04/11/05 I 4 -1/2" TBG, 12.6 #, 13CRVAM -ACE L 13366' I _ .0152 bpf, ID = 3.958" / �� 17" LNR, 29 # /ft L -80 Hydril 511, ID = 6.184" II 13537' I- 13366' I- I 4 -1/2" HES SELF ALIGNING MULESHOE ID = 3.958" PERFORATION SUMMARY — REF LOG: SWS USIT 4/11/05 ANGLE AT TOP PERF: 17 @ 13707' Note: Refer to R DB for historical pert data SIZE I SPF I INTERVAL (MD) I Opn /Sqz I DATE 1 SEE PAGE 2 FOR PERFORATION INFORMATION I I I I IPBTD H 14027' I ►••••••• 1�.�..1 4-1/2" LNR, 12.6 #, 13CR VAM -ACE, H 14031' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 06/14/09 RCT/TLH XN LOCK w /GAUGE SET (06/03/09) WELL: NS05 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRR/TLH XN LOCK w /GAUGE PULL (06/22/09) PERMIT No: '2050090 02/22/06 ROY/TLH PERF CORRECTIONS 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50 -029- 23244 -00 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS SEC. 11, T13N, R13E, 1089' FSL & 642' FEL 03/11/08 WRR/TLH RE PERF 09/05/08 WRR/PJC PERFS (08/22/08) BP Exploration (Alaska) • • NS05 • X PERFORATION SUMMARY / REF LOG: SWS USIT 4/11/05 ANGLE AT TOP PERF: 17° @ 13707' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 13707 - 13727 0 06/28/05 . 2 -7/8" 6 13733 - 13764 0 08/22/08 6 13734 - 13764 0 09/20/05 2 -7/8" 6 13735 - 13766 0 08/22/08 J 6 13739 - 13794 0 04/12/05 6 13739 - 13794 0 05/28/05 2 -7/8" 6 13763 - 13794 0 08/22/08 6 13763 - 13794 0 03/11/08 2 -7/8" 6 13810 - 13830 0 08/22/08 DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 06/14/09 RCT/TLH XN LOCK w /GAUGE SET (06/03/09) WELL: NS05 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRR/TLH XN LOCK w /GAUGE PULL (06/22/09) PERMIT No: 2050090 02/22/06 ROY/TLH PERF CORRECTIONS API No: 50- 029- 23244 -00 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS SEC. 11, T13N, R13E, 1089' FSL & 642' FEL 03/11/08 WRR/TLH RE -PERF 09/05/08 WRR/PJC PERFS (08/22/08) BP Exploration (Alaska) • • slrEE L IF Lx[I,AzIA 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 Petroleum Engineer BP Exploration (Alaska), Inc. �d 6'— P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS05 Sundry Number: 312 -004 SUMMED JAN 24 nZ 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, Daniel T. Seamount, Jr. Chair DATED this 6 day of January, 2012. Encl. • STATE OF ALASKA c6iift- 4 � ; � "` ALASKWL AND GAS CONSERVATION COMMISSIW FOR SUNDRY APPROVALS JAN 4 X01? 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ A. -a:' XbantviAnrbvIliciRrioffinnalgeP Suspend ❑ Plug Perforations ❑ Perforate IS - Pull Tubing ❑ i, ; ^, dtriser:: tension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 , Exploratory ❑ 205 -0090 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23244- 00 -00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ NS05 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 312808 NORTHSTAR Field / NORTHSTAR OIL Pool -4 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): 14033 • 11335.58 - 14027 11329.83 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 3147' 13 -3/8" 68# L -80 40 3187 40 3183 4930 2270 Production 11663' 9 -5/8" 53.5# L -80 39 11702 39 9401 7930 6620 Liner 2012' 7" 29# L -80 11525 13537 9294 10862 8160 7020 Liner 674' 4 -1/2" 12.6# 13CR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13Cr80 37 13366 Packers and SSSV Type: 4 -1/2" TRM -4E SSV Packers and SSSV MD and TVD (ft): 994 994 7" Top Packer 11525 9294 7" 13Cr80 Packer 13310 10644 4 -1/2" Liner Top Packer 13357 10689 12. Attachments: Description Summary of 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: 1/18/2012 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 Printed Name Mark Sauve Title PE Signature Phone Date 564 -4660 1/4/2012 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY 't Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6' 2... - l..J0u / Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / O — V 0 / / APPROVED BY J Approved by: . / COMMISSIONER THE COMMISSION Date: / (a RBD S JAN 0 6 2011 R 1 G 1 N A //9-(,2__ Form 10 -403 Revised 1/2010 > Submit in Duplicate NS05 205 -009 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 RPF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 RPF 13,734. 13,764. 11,049.37 11,078.02 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 RPF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 RPF 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 RPF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 RPF 13,733. 13,735. 11,048.41 11,050.32 • NS05 8/22/08 RPF 13,763. 13,766. 11,077.06 11,079.93 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 • • • ...... PERFORATING PROCEDURE Ver 4 0 06/04/01 ROW 6P616H666N166 aPAILS Well: NS05 API #: 50- 029 - 23244 -00 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: ANSFLDWL05 Detail Code: Description: Re- Perforate WBL Entries I IOR Type Work Description 200 S Drift to TD with 2 -7/8" Dummy Gun 200 E Perforate 13,710' - 13,730' and 13,810' - 13,830' MD Well Objectives and Loqqinq Notes: The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by re- perforating 50' of the existing perforations. t.- Please note that the perforations will be dependent on the drift information. Please contact Mark Sauve with any questions, comments, or concerns - 564 -4660 (w); 748 -2865 (c); 336 -6128 (h). Reference Log Tie in Log Add 0 feet Log: SWS USIT to the tie -in log to be on Date: 4/11/2005 depth with the reference log. Company: Schlumber9er Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re!Iperf 13,710' - 13,740' 13,710' - 13,740' 30' 6 60° 0 lvishak RePerf 13,810' - 13,830' 13,810' - 13,830' 20' 6 60° 0 Ivishak RePerf Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2.875 Charge: 2906 PJ HSD Desired Penetration: 27.7 Entry Hole Diam: 0.32 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 in to Jewelry @ MD Tie in using: Minimum ID: 3.725 in Min ID Type: 4.5" XN Nipple @ 13,351 'MD WLEG Depth: 13,366 ft MD Casing Size: 4.5 in 12.6# 13 -CR Liner Est Res. Pres. @ 13,846 MD - 11100' SS -5100 psi Last Tag: 13,932 ft ELMD on 11/14/2009 3.5" Bailer Well: NS05 Perforation Summary Date: API #: 50- 029 - 23244 -00 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 0 . 0 /B /U .. O 'TREE = ABB- VG15 -1/8" SKSI SAFET ES: WELL REQUIRES A SSSV. WELLHEAD = ABB -VGI 13 -5/8'' MULTIBOWL SKSI N ""*4 -1/2" ROME TBG & LNR*** ACTUATOR - BAKER S KB. ELEV = 56.37' BF. ELEV = 40.1' (CB 15.91 KOP = 1969' 1 994' H 4-1/2" TRM-4E SSSV w / 4-1/2" X PROF ID = 3.812" I Max Angle = 56",,@ 7693' _Datum MD = 13217' Datum TV D = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" I-1 3187' FA GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH' PORT I DATE 1 3997 4000 10 MMG DMY 03/29/05 Minimum ID = 3,725" @ 13351' 4 -1/2" XN NIPPLE (TOP OF 7" LNR l -- L 11525' 1 19-5/8" CSG, 53.5#, L -80 BTM-C I-I 11702' 13261' 1-14-1/2" X NIP, ID = 3.813" 1 13292' I- I4 -1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I 13316' H 7" X 4-1/2" BKR S -3 PKR, ID = 3,958" I 13310' H ELMD I 13340' 1-14-1/2" X NIP, ID = 3.813" I 13351' H 4 -1/2" XN NIP, ID = 3.725" I TOP OF 4 -1/2" LNR l-1 13357' I I 13368' H ELMD XN NIP LOGGED ON 04/11 /05 I 4 -1/2" TBG, 12.6 #, 13CRVAM- ACE, --1 13366' J L .0152 bpf, ID = 3.958" 13366' 1 4 -1/2" HES SELF ALIGNING MULESHOE 17" LNR, 29 # /ft L -80 Hydril 511, ID = 6.184" i-I 13537' PI 11' ID = 3.958" PERFORATION SUMMARY — REF LOG: SWS USfT 4/11/05 ANGLE AT TOP PERF: 17 @ 13707' Note: Refer to Production DB for historical perf data SIZE I SPF 1 INTERVAL (MD) 1 Opn /Sqz 1 DATE I SEE PAGE 2 FOR PERFORATION INFORMATION 1 1 1 1 PBTD 1-1 14027' r••••••IP 4 -1/2" LNR, 12.6 #, 13CRVAM -ACE, -- 14031' W.WA.. .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 06/14/09 RCT/TLH XN LOCK w /GAUGE SET (06/03/09) WELL: NS05 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRR/TLH XN LOCK w /GAUGE PULL (06/22/09) PERMIT No: P t050090 02/22/06 ROY/TLH PERF CORRECTIONS 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE API No: 50- 029 - 23244 -00 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS SEC. 11, T13N, R13E, 1089' FSL & 642' FEL 03/11/08 WRR/TLH RE -PERF 09/05/08 WRR/PJC PERFS (08/22/08) BP Exploration (Alaska) NSO5 • 4 PERFORATION SUMMARY REF LOG: SWS USff 4 /11/05 ANGLE AT TOP PERF: 17° @ 13707' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 13707 - 13727 0 06/28/05 2 -7/8" 6 13733 - 13764 0 08/22/08 6 13734 - 13764 0 09/20/05 2 -7/8" 6 13735 - 13766 0 08/22/08 J 6 13739 - 13794 0 04/12/05 6 13739 - 13794 0 05/28/05 2 -7/8" 6 13763 - 13794 0 08/22/08 6 13763 - 13794 0 03/11/08 2 -7/8" 6 13810 - 13830 0 08/22/08 DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 06/14/09 RCT/TLH XN LOCK w /GAUGE SET (06/03/09) WELL: NS05 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRR/TLH XN LOCK w /GAUGE FULL (06/22/09) PERMIT No: 2050090 02/22/06 ROY/TLH PERF CORRECTIONS API No: 50- 029 - 23244 -00 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIONS SEC. 11, T13N, R13E, 1089' FSL & 642' FEL 03/11/08 WRR/TLH RE -PERF 09/05/08 WRR/PJC PERFS (08/22/08) 1 BP Exploration (Alaska) • • Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~,<~~'~ o.~-~°9 a Re: Northstar Field, Northstar Oil Pool, NS05 Sundry Number: 310-262 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, Daniel T. Seamount, Jr. Chair DATED this ? 7day of August, 2010. Encl. . (/~-~ ~ ~ ~ STATE OF ALASKA ,~ ~, `~ ALAS LAND GAS CONSERVATION COMMISSI ~e~~ APPLICATION FOR SUNDRY APPROVALS ~~ v 20 AAC 25.280 ~~ ?-,asio 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate0 Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ^ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 205-0090 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ NS05 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-312808 - NORTHSTAR Field / NORTHSTAR OIC Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 14033 - 11335.58. 14027 - 11329.83 NONE NONE Casing Length Size MD ND Burst Collapse Structural Surface 3147 13-3/8" 2S# L-80 40 3187 40 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 Production Liner 2012 7"29# L-80 11525 13537 9294 10862 8160 7020 Liner 674 4-1/2" 12.6# 13CR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 4-1/2" 12.6# 13Cr80 37 13366 Packers and SSSV Tvoe: 4-1/2" TRM-4E SSV Packers and SSSV MD and ND (ftl: 994 994 7" Top Packer 11525 9294 7"13Cr80 Packer 13310 10644 4-1/2" Liner Top Packer 13357 10689 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~- Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/7/2010 Oil ^~ - 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 Printed Name Mark Sauve Title production Engineer Signature Phone Date 564-4660 8/24/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY itness Sund Numb diti l N tif i i th t t ti ma C f C er: ~/ V ~~ a ry on ons o approva : y omm on so a represen a ve y w o ss a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ._._. ~ ~ ~~ 3 • Other: `- ~~~~ Subsequent Form Required: /D _ ~~ Y 1 APPROVED BY ~ Approved by: COMMISSIONER THE COMMISSION Date: ~y I ~"~ ` Me~+~s au~ ~ o zo~o~0 R I G I~1 A L ~- ~z` ~'~° ~~~/ Form 10-403 Revised 1/2010 Submit in Duplicate NS05 205-0090 PERF ATTOC:HMFNT LJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 9/20/05 APF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 APF 13,734. 13,764. 11,049.37 11,078.02 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 APF 13,733. 13,735. 11,048.41 11,050.32 NS05 8/22/08 APF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 APF 13,763. 13,766. 11,077.06 11,079.93 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REM OVED 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 • ~~ w~utus~uwra~ts Well: NS05 ................... Date: 8124110 • PERFORATING PROCEDURE API #: 50-029-23244-00 Prod Engr.Mark.,Sauve ................ Office Ph: Home Ph: Cell Ph: CC or AFC: ANSFLDWL05 Detail Code: ................................................................ Description: Re-Perforate WBL Entries v~ a.o oaroaoi 564-4660 H2S ^~ „Level:.,.,.,.., 336-6128 None Anticipated 748-2865 IOR T e Work Descri tion 200 S Drift to TD with 2-7/8" Dummy Gun 200 E Perforate 13,810' -13,830' MD Well Objectives and Los~oino Notes: The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by re-pertorating 20' of the existing perforations. Please note that the perforations will be dependent on the drift information. Please contact Mark Sauve with any questions, comments, or concerns - 564-4880 (w); 748-2865 (c); 338-8128 (h). Reference Log Tie in log Add 0 feet ................... Log: .SWS USIT to the tie-in log to be on Date: 4/11/2005 depth with the reference log. .............................. ............................. Company: Schiumberger .......................... Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf / 13,810' - 13,830' 13,810' - 13,830' 20' 6 60° 0 ivishak RePerf Gas Jetting Expected? No At what DepthT N!A Requested Gun Size: 2:875 Charge: 2906 PJ HSD ............................. Desired Penetration: ,27.7 Entry Hole Diam: .0:32 Is Drawdown Necessary/Desired/Unnecessary During Perforating NA Dosc+ibe below how to achieve drawdown (ctwek wi Pad Operator to see if necessary pipiix} is installed) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . (e.g. N2 Lift, Hardline LiR Gas, Gas Llft, Flow Well, BackHOw Through Drain or Hardline) Tie in to Jewelry @ MD Tie in using: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Minimum ID: 3:725 in Min ID Type: 4:5" XN Nipple @ 13.351 'MD WLEG Depth: 13,366 ft MD Casing Size: 4.5 in 12.6# 13-CR Liner Est Res. Pres. @ 13 ;846 MD -11100' SS -5100 psi Last Tag: 13,932 ft ELMD on 11/14/2049 3.5" Bailer Well: NS05 Perforation Summary Date: API #: 50-029-23244-00 OnSite Prod Engr: General Comments: ...........................................:...... Depths Balance Referenced to BHCS O/B/U - O / B / U .......................... °......................,. O/B/U ...................'........................ O/B/U - O/B/U - Feet SPF Orient. Phasing PBTD ~O ~O 0 Zone Apert/Repert ~-_ ~ ~ ABB-VGI5-1/8" 5KSI WELLHEAD = RBB-VG113-5/8" MULTIBOWL SKSI ACTUATOR = BAKER KB. ELEV = 56.37' BF. ELEV = 40.1' (CB 15.9') KOP = 1969' Max Angle = 56° @ 7693' Datum MD = 13217' Datum TV D = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" SAFEf ES: ***4-1 /2" CHROME TBG &LNR*** 994' 4-112" TRM-4E SSSV w / 4-1/2" X PROF ID = 3.812" NS05 GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 13351' 4-112" XN NIPPLE (TOP OF 7" LNR 9-518" CSG, 53.5#, L-80 8TM•C ~TOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 29#Ift L-80 Hydril 511, ID = 6.184" PERFORATION SUMMARY REF LOG: SWS USfT 4/11105 ANGLE AT TOP PERF: 17 @ 13707' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION INFORMATION PBTD 4-1/2" LNR, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04112!05 TA ORIGINALCOMPLETION 06114/09 RCTiTLH XNLOCKw/GALIGESET(06/03/09} 11/04/05 BJM DRLG DRAFT CORRECTIONS 06/28/09 WRR/TLH XN LOCK w/GAUGE PULL (06/22/09) 02/22/06 ROY/TLH PERF CORRECTIONS 11/27/07 WRR/PJC WELLHD! LOCATION CORRECTIONS 03!11/08 WRR/TLH RE-PEKE 09/05/08 WRR/PJC PERFS (08/22/08) 13261' -i4-1t2" X NIP, ID = 3.813" 13292' 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 13316' 7" X 4-1/2" BKR S-3 PKR, ID = 3.958" 13310' ELMD 13340' 4-112" X NIP; ID = 3.813" 13351' 4-1/2" XN NIP, ID = 3.725" 1 13368' ELMD XN NIP LOGGED ON 04/11/05 $366' ~4-112" HES SELF ALIGNING MULESHOE ID = 3.958" NORTHSTA R WELL: NS05 PERMIT No: 2050090 API No: 50-029-23244-00 SEC. 11, T13N, R13E, 1089' FSL & 642' FEL BP Exploration (Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar • by ~ECEIVEI~ MAY0R52010 ill&~Cons.Gan+~~. Dear Mr. Maunder, ~S 0 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 4/20/2010 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 5002923068000p 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. • ~~ -~;.. ~~:,?~ ate: ! 2-17-2Q09 Transmittal Number: 931 !4 BP~A WELL DATA TRANSIVI~TTAL Enclosed are the materials listed below. if you have anv questions, please contact Joe L,astufka at (907)5b4-4091 Delivery Contents Bottom SW Name Date Contractor Run To De th De th Descri Lion MEMORY PRESSURE/ NS33A 11-11-2009 SCH 1 25380 25970 TEMPERATURE SURVEY CD-ROM -MEMORY PRESSURE/TEMPERATURE NS33A 11-11-2009 SCH SURVEY MEMORY PPRflF WITH DEFT NS05 11-16-2009 SCN 1 13101 13921 AND GHOST CD-ROM -MEMORY PPROF NS05 11-16-2009 SCH WITH DEFT AND GHOST MEMORY PRODUCTION NS11 11-20-2009 SCH 1 14008 14616 PROFILE W iTH DEFT CD-ROM -MEMORY PRODUCTION PROFILE WITH NS11 11-20-2009 SCH DEFT NS11 11-20-2009 SCH 1 13978 14614 MEMORY SBHPS NS11 11-20-2009 SCH CD-ROM -MEMORY SBHPS MEMORY PPROF WITH DEFT NS30 11-19-2009 SCH 1 15495 16195 AND GHOST CD-ROM -MEMORY PPROF NS30 11-19-2009 SCH WITH DEFT AND GHOST RESERVOIR SATURATION NS33A 11-10-2009 5CH 1 200 25873 AND WATER FLOW LOG CD-ROM -RESERVOIR SATURATION AND WATER NS33A 11-10-2009 SCH FLOW LOG i~ i ~~ `;/ nn ?et~ote~hnic:al ijai~ ~r~:11er~~ ~ 2-! t~.i74:310$ ale, ti; ~9J i {~-t7b ! • by Sry BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vnu have anv auesti~ns_ please contact Jae Lastufka at (907)564-4091 • Date: 12-02-2009 Transmittal Number: 93109 Deliver Contents Bottom SW Name Date Contractor Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER &MTT LOG NS05 11-13-2009 PDS 1 0 13537 RESULTS SUMMARY CD-ROM - MEMORYMULTI- FINGER CALIPER &MTT LOG NS05 11-13-2009 PDS RESULTS SUMMARY Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC Murphy Exploration MMS DNR i ~~~,~~ ~~~~ ~ 20Q~ David Fair Christine Mahnken Ignacio Herrera Doug Chromanski Corazon Manaois Petrotechnical Data Center LR2- i 900 E. Benson Blvd. PO Box 196612 Elnchorage, AK 99519-6612 7 • Memory Multi-Finger Caliper & MTf Log Results Summary Company: BP Exploration (Alaska), Inc. Well: NS - 05 Log Date: November 13, 2009 Field: Northstar Log No.: 7371 State: Alaska Run No.: 1 API No.: 50-029-23244-00 Pipet Desc.: 4.5" 12.6 Ib. 13CR VAM-ACE Top Log Intvl.: Surface Pipet Use: Tubing & Liner Bot. Log Intvl.: 13,916 Ft. (MD) Pipet Desc.: 7" 29 Ib. L-80 Hydril 5 11 Top Log Intvl.: 11,525 Ft. (MD) (MTT only) Pipet Use: Liner Bot. Log Intvl.: 13,537 Ft. (MD) (MTT only) Pipe3 Desc.: 9.625" 53.5 Ib. L-80 BTM-C Top Log Intvl.: 3,175 Ft. (MD) (MTT only) Pipe3 Use: Casing Bot. Log fntvl.: 11,702 Ft. (MD) (MTT only) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This Caliper /MTT data is tied into the XN Nipple @ 13,368 ft. (FEND). This is the first time this well has been logged with a PDS Caliper and a 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 4.5" tubing, 4.5" liner, 7" liner, and 9.625" casing. Passes at 5Hz and 10Hz were made at 20 fpm. Since the 10Hz passes are not interpretable, this report comprises the results from the 5Hz passes. ' The additional metal volume of the 933/8"surtace casino prevented the normal functioning of the MTT, so no interpretable results are available from the bottom of the 93 3/8"surtace casing to surtace. INTERPRETATION OF CALIPER LOG RESULTS: This log was run to assess the condition of the 4.5" 13CR VAM -ACE tubing and liner with respect to internal corrosive and mechanical damage. The tubing and liner logged appear to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. A 3-D log plot of the caliper recordings across the perforation intervals is included in this report. 4.5" TUBING 8< LINER -MAXIMUM RECORDED WALL PENETRATIONS ' No significant wall penetrations (> 18%) are recorded throughout the 4.5" tubing and liner togged. 4.5" TUBING $< LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Excluding eroded perforation intervals, no significant areas of cross-sectional wall loss (> 4%) are recorded throughout the 4.5" tubing and liner logged. 4.5" TUBING 8< LINER -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the 4.5" tubing and liner logged. f PraACtive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS@memoryfog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 1 ids-off r~~~ INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from 3,175' to 13,916'. No substantial overall metal volume loss is indicated throughout the interval logged. A plot of average metal thickness relative to the calibration points on a joint-by-joint basis is included in this report. Changes in metal volume are relative to the calibration points at 10,042', 11,700', 12,542' and 13,632", where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from 4.5" tubing and liner, 7" liner, and 9 5/8" casing. A maximum recorded overall metal volume loss of 6% is indicated in tubing joint 113 (4,756'-4,797'). This event occurs within a larger interval of minor overall metal volume loss (1% - 6%) recorded from 4,465' to _5,210', pointing to potential areas of minor casing damage. A log plot presentation of the MTT recordings over the interval (4,680'-4,850') is included in this report. Indications of intermittent lines of isolated metal loss are discernible from _4,860' to 11,540', sometimes broadening into wider areas of general metal loss. Although indications of metal loss are distinguishable on individual sensors within this interval, the MTT recordings do not indicate significant overall metal volume loss. The MTT recordings over the intervals (5,010'-5,370') and (10,500'-10,670'), showing the lines of isolated metal loss, are included in this report. The circumferential metal loss expressed in this summary is a percentage of the total metal volume the tool is responding to, which includes influences from 4.5" tubing and liner, 7" liner, and 9 5/8" casing. If all of the metal loss is specific to the tubing, liner, or casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Field Engineer: Wm. McCrossan Analyst: M. Lawrence (MIT)/HY. Yang (MTT) Witness: T. Atkinson/R. Mielke ProActive Diagnostic Services, Inc. / P.O, Box 1369, Stallard, TX 77497 Phone: (281} or (888) 565-9085 Fax: {281} 565-1369 E-mail: PDS@memarylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 • ~ PDS Multifinger Caliper 3D Log Plot .,_~ Company : BP Exploration (Alaska), Inc. Field : Northstar Well : NS - 05 Date : November 13, 2009 Description : Detail of Caliper Recordings Across Perforation Intervals Comments Depth Max. I.D. (ins.) 3-D Log Image Map 1ft:375ft 3.5 i 4.5 320° 0° 90° 180° 270° 0° Min. I.D. (ins.) 3.5 4.5 Nominal I.D. (ins.) i ...................................................................t 3.5 4.5 Joint 324 13675 t ~ ~:. Joint 325 ? x` 1 TI ~ I - 13700 Joint 326 Perforations 13725 13750 Joint 327 Pertorations 13775 Joint 328 Perforations 21% Cross- Sectional Wall Loss Joint 329 Pertorations 13850 Joint 330 13875 __~ .~. _ __ ~_ _ _= __ - - -- - ~,~~--- - - -- - _--~_-__ ax `-:~~- _ _s - ~_--_'.~._ ~. ._ ~' .~. _- `- ~_ ~. ~ a~ , _ -~~ Perforations .~,.r,": -: ~- _ _ ,~ ~ ,~ ,~ - ~ - ° Per oraf ns ~ ,. f ,~ ; fir: Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (21.0' - 13910.5') Well: NS - 05 Field: Northstar Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: Novernber 13, 2009 Approx. loot Deviation ;lppro~. Borcfiole Profile 1 21 2107 GLM 1 4215 6294 c 8376 s a a~ 10452 12522 331 13911 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 331 50 100 150 ,_l, ~ v - E Z 200 c ~ o 250 300 • PDS Report Overview ~-~~~-- ~.. Body Region Analysis Well: NS - 05 Survey Date: November 13, 2009 Field: Northstar Tool Type: UW MFC 40 No. 213120 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 4.5 ins 12.6 f 13CR VAM-ACE 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) s penetration body ,.-ax metal loss body 400 300 200 100 0 0 to 1 l0 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 348 pene. 5 330 8 1 0 4 loss 303 42 2 1 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 12 1 0 7 0 4 Damage Profile (% wall) ~ penetration body rnetal loss body 0 50 100 n GLM 1 Bottom of Survey = 330 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal LD.: 3.958 in Country: Survey Date: iLATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc USA November 13, 2009 Joint No. Jt. Depth (Ft.) I't~n. Utzsel (Ins.) Pen. Body (Ins.) I'~~n. % Metal Ions ?4. Min. LD- (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 18 a 0.01 3 I 3.95 PUP 1 21 t) 0.03 13 1 3.92 Shallow a arent wear. 1.1 65 l) 0.01 4 I 3.93 PUP 1.2 73 O 0.01 ~ 1 3.95 PUP 1.3 83 t) 0.01 4 I 3.94 PUP 2 93 U 0.01 s I 3.92 3 134 t) 0.01 3 I 3.92 4 176 t) 0.01 3 ? 3.92 t 5 217 U 0.01 , I 3.93 6 259 U 0.01 i 1 3.93 7 301 0 0.01 3 I 3.93 t 8 342 U 0.01 ~ I 3.91 9 384 t) 0.01 ; I 3.91 10 426 U 0.01 1 3.90 t 11 467 U 0.01 3 1 3.92 t 12 509 l) 0.01 4 1 3.93 13 550 U 0.01 _' 3.91 14 592 (1 0.01 a 1 3.91 15 634 i) 0.01 4 I 3.92 16 675 t1 0.01 3 I 3.92 17 717 U 0.01 ~~ 1 3.91 18 758 (~ 0.01 ~ I 3.93 19 800 U 0.01 3 3.92 20 842 U 0.01 3 1 3.91 21 883 a 0.01 ( 3.92 22 925 U 0.01 ~ i 3.92 22.1 966 ll 0.01 ~~ i 3.94 PUP 22.2 976 t) 0 tl ~) N A SSSV 22.3 981 U 0.01 1 I 3.95 PUP 23 991 l) 0.02 B 1 3.94 24 1033 l) 0.01 I 3.95 25 1074 r) 0.01 3 1 3.95 26 1116 t) 0.01 _' I 3.96 27 1157 U 0.01 4 I 3.95 28 1 196 U 0.01 3 I 3.96 29 1238 U 0.01 3 1 3.94 30 1279 (1 0.01 ~ :' 3.96 31 1321 i) 0.01 -1 I 3.95 32 1360 U 0.01 3.95 ~ 33 1401 U 0.01 _' I 3.96 34 1442 U 0.01 '> I 3.95 35 1483 l) 0.05 1 £3 1 3.94 Shallow a arent wear. 36 1525 t) 0.01 t I 3.94 37 1566 U 0.04 15 2 3.96 Shallow a arent wear. 38 1608 i) 0.01 3 1 3.95 39 1649 i~ 0.01 i 1 3.93 40 1691 U 0.01 3 I 3.94 41 1732 U 0.01 3 2 3.95 42 1774 (t 0.01 ~ I 3.95 43 1816 i t 0.01 3 1 3.94 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI., Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ELATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc USA November 13, 2009 Joint No. Jt. Depth (Ft) I'~~n. Ut~sc~l (Ins.) Pen. Body (Ins.) Pen. °io Mehl Loss °4. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 44 1858 U 0.01 3 1 3.95 45 1899 U 0.01 4 1 3.96 46 1941 O 0.01 4 I 3.93 47 1983 U 0.01 > 1 3.93 48 2024 li 0.01 3 I 3.95 49 2066 (~ 0.01 1 3.95 50 2107 l) 0.01 ~i 1 3.94 51 2149 t ~ 0.01 ~ I 3.95 52 2191 U 0.04 15 1 3.95 Shallow a arent wear. 53 2232 U 0.01 4 I 3.96 54 2274 l) 0.01 3 1 3.95 55 2315 U 0.02 8 I 3.94 56 2357 U 0.01 3 1 3.95 57 2399 U 0.01 3 1 3.95 58 2440 l) 0.01 3 I 3.96 59 2482 U 0.01 3 1 3.95 60 2524 U 0.01 4 1 3.96 61 2566 a 0.01 2 I 3.93 62 2607 i~ 0.01 3 1 3.95 63 2649 ti 0.04 1 7 1 3.94 Shallow a arent wear. 64 2690 tl 0.04 15 3.94 Shallow a arent wear. 65 2732 c) 0.01 4 3.95 66 2772 O 0.01 ~ I 3.94 67 2814 U 0.01 > 1 3.93 68 2855 (~ 0.01 3.94 69 2897 O 0.01 > I 3.94 ~ 70 2938 O 0.01 3 I 3.94 ~ 71 2980 0 0.01 ~~ i 3.94 ' 72 3022 U 0.01 ~' 1 3.93 73 3063 O 0.01 ~ I 3.95 74 3105 U 0.01 ~ 1 3.94 75 3147 1 ~ 0.01 3 1 3.95 76 3188 O 0.01 3 I 3.95 ` 77 3230 t1 0.01 3 I 3.94 78 3271 ~~ 0.02 6 ' 3.93 79 3313 U 0.01 ? I 3.95 80 3355 l1 0.01 .3 I 3.94 81 3397 U 0.01 3 I 3.95 82 3438 t~ 0.01 3 I 3.95 83 3480 U 0.01 3 1 3.94 84 3521 U 0.01 3 1 3.96 ~ 85 3563 U 0.04 13 I 3.94 Shallow a arent wear. 86 3604 U 0.01 ,~ I 3.95 87 3646 t) 0.01 3 3.96 88 3688 U 0.01 > i 3.94 89 3729 U 0.01 ; ! 3.95 90 3771 U 0.01 .3 1 3.94 91 3813 U 0.01 ~ 1 3.94 92 3854 i ~ 0.01 4 1 3.93 93 3896 (~ 0.01 4 I 3.95 __ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal LD.: 3.958 in Country: Survey Date: ILATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc USA November 13, 2009 Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) UPsc f Body % I oss LD• Comments (% wall) (In~.l (Ins.) `~'~~ (Ins.) 0 50 100 an ~02~ n n n~ i 2 ~~ 94.1 3979 c) 0.01 3 t 3.95 PUP 94.2 3989 (r 0 U U N A GLM 1 Latch @ 9:30 94.3 3998 tl 0.01 3 1 3.96 PUP 95 4008 t? 0.01 4 I 3.94 96 4049 U 0.01 3 I 3.93 ' u Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Eield: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • iLATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc. USA November 13, 2009 Joint No. Jt. Depth (Ft.) Pen. I Jpsc~t (Ins.) Pen. Body (Ins.) Pen. % Mc~t.~l Loss °'~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 141 5919 t) 0.01 1 3.94 142 5961 O 0.01 3 1 3.93 143 6002 t) 0.01 4 1 3.94 144 6044 t I 0.01 ; I 3.94 145 6085 a 0.01 > 1 3.94 146 6127 U 0.01 t I 3.95 147 6169 U 0.01 3 1 3.93 `' 148 6211 t) 0.01 3 1 3.94 149 6252 O 0.01 3 ~~ 3.94 t 150 6294 O 0.01 i I 3.94 t 151 6336 U 0.01 3 I 3.94 152 6377 U 0.01 3 I 3.94 153 6419 i) 0.01 2 t1 3.95 154 6461 t 3 0.01 3 I 3.95 155 6502 U 0.01 ', 1 3.94 156 6543 0 0.01 3 1 3.94 157 6585 0 0.01 ' 3.94 158 6627 U 0.01 3 I 3.95 159 6668 t) 0.01 - I 3.93 160 6710 U 0.01 4 I 3.94 161 6751 a 0.01 5 1 3.94 162 6793 t~ 0.01 4 1 3.94 163 6835 t l .O1 3 1 3.95 164 6877 (~ 0.01 3 1 3.94 165 691$ t a 0.01 3 1 3.94 166 6960 U 0.01 ~? I 3.93 167 7002 t I 0.01 3 I 3.94 168 7043 t I 0.01 ~ i 3.93 169 7085 a 0.00 1 1 3.93 170 712 7 u 0.01 1 3.93 171 7168 U 0.01 Z 1 3.93 172 7210 U 0.01 2 I 3.94 ~ 173 7252 ll 0.01 ~ 1 3.93 174 7294 C) 0.01 3 I 3.94 175 7335 t~ 0.01 3 I 3.94 176 7377 U 0.01 ? 1 3.94 177 7418 U 0.01 3 1 3.94 178 7460 U 0.01 3 1 3.93 179 7502 U 0.01 4 I 3.93 180 7544 U 0.01 I 3.93 ' 181 7585 f? 0.01 3 1 3.93 182 762 7 t t 0.01 i _' 3.94 183 7669 0 0.01 3 I 3.92 184 7710 (1 0.01 3 ~? 3.93 185 7752 i ~ 0.01 3 1 3.94 186 7793 U 0.01 , 1 3.93 187 7835 t) 0.01 1 3.94 188 7877 t I 0.01 3 I 3.94 189 7918 ~~ 0.01 3 1 3.93 190 7960 (t 0.01 4 I 3.93 _ Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • -LATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc USA November 13, 2009 Joint No. Jt. Depth (Ft.) I'c~n. Ul~s<~t (Ins.) Pen. Body (Ins.) PFn. °'° ~ti1~,t,~l Ic~ti~ "~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 191 8001 l) 0.01 3 I 3.93 192 8043 t 1 0.01 4 I 3.92 193 8085 t~ 0.01 i I 3.92 194 8126 t? 0.00 1 I 3.93 195 8168 t ~ 0.01 4 1 3.92 196 8209 U 0.01 ~' 1 3.93 197 8251 a 0.01 a 1 3.94 198 8293 t) 0.01 3 U 3.94 199 8334 t~ 0.01 s 1 3.93 200 8376 U 0.01 3 I 3.92 ~ 201 8418 U 0.01 3 1 3.95 202 8460 t) 0.01 2 I 3.92 203 8501 U 0.01 ~' 1 3.94 204 8542 t) 0.01 ~ 3.94 205 8584 U 0.01 3 1 3.92 206 862 6 (1 0.01 3 1 3.93 207 8667 l1 0.01 3 1 3.93 208 8708 i ~ 0.01 3 1 3.92 209 8750 C) 0.01 3 1 3.93 210 8792 t~ 0.01 3 1 3.92 211 8834 tt 0.01 3 3.94 212 8875 U 0.01 3 I 3.93 ~ I 213 8917 i) 0.01 ; 1 3.94 214 8958 a 0.01 ~ 1 3.92 215 9000 !) 0.01 S I 3.92 216 9041 ~: ~ 0.01 I 3.93 217 9083 c a 0.01 ~ 1 3.92 218 9125 t) 0.01 ? I 3.93 219 9166 a 0.01 1 3.93 ' 220 9208 U 0.01 I 3.93 221 9249 t1 0.01 3 1 3.92 222 9291 t~ 0.01 ~ t 3.92 223 9332 ~? 0.01 3 3.93 224 9374 O 0.01 3 ? 3.93 225 9415 a 0.01 I 3.93 226 9457 U 0.01 3 I 3.94 227 9498 n 0.01 3 I 3.93 228 9538 (1 0.01 2 I 3.92 229 9579 c) 0.01 ~ I 3.92 230 9621 l~ 0.01 1 t) 3.93 231 9662 (1 0.01 3 I 3.93 232 9703 O 0.01 3 1 3.91 233 9745 U 0.01 I 3.93 234 9786 0 0.01 3 1 3.93 235 9828 U 0.01 3 1 3.92 236 9870 t) 0.01 1 3.92 237 9912 ti 0.01 3 3.92 238 9953 n 0.01 4 I 3.91 239 9995 i? 0.01 4 1 3.92 240 10036 i1 0.01 > 1 3.93 Penetration Body ~~letal Loss Body Page 5 PDS REPORT JOINT TABI. Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ELATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc. USA November 13, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Ill~sc~l (Ins.) Pen. Body (Ins.) Pen. % Metal Loss ",4 Min. LD• (Ins.) Comments Darnage Profile (%wall) 0 50 100 241 10078 U 0.01 ~ 1 3.92 242 10120 U 0.01 4 1 3.92 243 10162 U 0.01 ; 1 3.92 244 10203 a 0.01 ~t I 3.93 245 10245 (~ 0.01 ~t 1 3.92 246 10286 O 0.01 1 3.92 247 10328 ~) 0.01 4 1 3.92 248 10369 ~) 0.01 3 1 3.93 249 1041 1 O 0.02 8 1 3.93 250 10452 a 0.01 ~ I 3.93 251 10494 U 0.01 S ( 3.93 252 10535 n 0.01 3 I 3.92 253 10577 c! 0.01 i 3.93 ~ 254 10619 ~) 0.01 _' I 3.93 255 10660 U 0.01 4 I 3.92 256 10701 (? 0.01 ; I 3.92 257 10742 a 0.01 I 3.93 ~ 258 10784 (? 0.01 3.92 ` 259 10825 (1 0.01 1 3.92 260 10867 U 0.01 ~ ,' 3.91 261 10908 t) 0.01 1 1 3.94 262 10950 U 0.01 1 3.92 263 10991 tl 0.01 4 1 3.92 264 11033 t) 0.01 3 I 3.91 265 11075 U 0.01 3 1 3.92 266 1 1 1 16 U 0.01 3 1 3.91 267 11157 t t 0.01 4 1 3.92 268 11199 i~ 0.01 4 3.93 269 11240 a 0.01 4 1 3.92 2 70 112 82 U 0.01 4 2 3.93 271 11324 (~ 0.01 3 1 3.92 272 11365 li 0.01 3 1 3.94 273 11406 I? 0.01 3 1 3.92 274 11447 t~ 0.01 S I 3.93 75 11488 (~ 0.01 ~ 1 3.92 a 276 11530 (~ 0.01 I 3.93 277 11572 U 0.01 5 1 3.92 278 11613 (a 0.01 ~ 1 3.93 279 11655 t~ 0.01 i 1 3.92 280 11696 U 0.01 ~ I 3.93 281 11738 U 0.01 =1 1 3.92 282 11780 U 0.01 4 I 3.92 283 11821 U 0.01 -~ 2 3.93 284 11863 U 0.01 3 .' 3.92 285 11904 U 0.01 2 1 3.92 286 11946 U 0.01 ~3 1 3.93 287 11987 l) 0.01 .3 I 3.92 288 12029 ti 0.01 3 I 3.92 289 12070 U 0.01 4 1 3.92 290 12112 (? 0.01 3 I 3.93 Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ELATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc USA November 13, 2009 Joint No. Jt. Depth (Ft) I'en. UEsc~t (InS.i Pen. Body (Ins.) Pen. `i~> Metal I~>ss "~~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 291 12153 U 0.01 3 I 3.93 292 12194 U 0.01 } 1 3.92 293 12236 l1 0.01 3 1 3.94 294 12275 U 0.01 S 1 3.92 295 12316 !? 0.01 i I 3.93 296 12358 It 0.01 ~ 1 3.93 297 12400 a 0.01 3 1 3.93 298 12441 a 0.01 ~ 1 3.91 299 12481 (? 0.01 ~ 1 3.92 300 12522 U 0.01 1 3.93 301 12564 U 0.01 ; 2 3.93 302 12606 (1 0.01 3 1 3.93 303 12647 0 0.01 ~ 1 3.92 304 12689 U 0.01 ~1 I 3.93 305 12730 U 0.01 4 ~ 3.92 306 12771 t) 0.01 5 ~ 3.93 307 12813 0 0.01 _' I 3.93 308 12854 l) 0.01 4 I 3.91 309 12895 U 0.01 3 1 3.93 310 12936 U 0.01 3 1 3.93 311 12977 l) 0.01 ~ Z 3.93 312 13019 t) 0.01 3 I 3.91 13 13060 0 0.01 3 1 3.92 314 13102 t1 0.01 4 1 3.92 315 13143 It 0.01 ' 1 3.93 316 13184 it 0.01 ~ 1 3.91 317 13226 !) 0.01 3 3.91 317.1 13268 U 0.00 1 1 3.92 PUP 317.2 13277 (1 0 0 ~! 3.81 X Ni le 317.3 13278 O 0.03 10 1 3.94 PUP 317.4 13288 tl 0.01 ~; {~ 3.94 PUP 317.5 13298 (1 0.01 3 u 3.95 PUP 317.6 13308 (1 0 0 tt N A Fiber O tic Transducer 317.7 13313 !> 0.01 ~ U 3.92 PUP 317.8 13323 (~ 0.01 3 1 3.93 PUP 317.9 13333 O 0 0 U 3.96 7" x 4.5" Baker S-3 Packer 318.1 13335 U 0.01 3 I 3.93 NUN 318.2 13345 U 0.01 i 1 3.93 PUP 318.3 13352 O 0 0 t) .81 X Ni le 318.4 13358 !~ 0.01 1 3.92 PUP 318.5 13368 ! ~ 0 it U 3.73 XN Ni le 318.6 13369 (? 0.03 II 1 3.93 PUP 318.7 13380 t) 0 O U N A 318.8 13396 U 0 U U N A 4.5" Liner Han er 318.9 13407 (~ 0.01 ~ 1 3.92 PUP 319 13411 a 0.01 ~ I 3.92 320 13451 U 0.01 ~ I 3.90 321 13494 U 0.01 3 I 3.93 322 13534 U 0.01 5 ~ 3.92 323 13576 1 t 0.01 4 I 3.91 _ Penetration Body Metal Loss Body Page 7 PDS REPORT JOINT TABI, Pipe: 4.5 in 12.6 ppf 13CR VAM-ACE Well: Body Wall: 0.271 in Field: Upset Wail: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: !CATION SHEET NS-05 Northstar BP Exploration (Alaska), Inc. USA November 13, 2009 Joint No. Jt. Depth (Ft) Pc~n. ULsel (Ins.j Pen. Body (Ins.) Pen. % :~1clal Loss °%~ Min. LD. (Ins.) Comments Damage Profile (% `Fall) 0 50 100 324 13618 O 0.01 4 3 3.91 325 13660 U 0.09 34 2 3.90 Perforations. 326 13701 U 0.31 10U 14 3.81 Perforations. 327 13742 t t.! ; 0.28 1O0 13 3.84 Perforations. 28 13784 U.~(, 0.27 ~)r) ? 1 3.87 Perforations. 329 1 827 ! ~. 1 r, 0.23 fib 7 3.87 Perforations. 330 13870 i) 0.01 4 3.89 _ Penetration Body Metal Loss Body Page 8 • Average Recorded Metal Thickness Relative to Calibration Point 4.5" Tubing & Liner / 7" Liner / 9.625" Casing Well: NS - 05 Field: Northstar Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: November 13, 2009 ® D ecrease ^ In crease GLM 1 100 4215 125 5254 150 6294 175 7335 200 8376 ~ .c Z s • c -0 225 + ~ 9415 °i 250 10452 Top of 7" Liner 2 75 11488 300 12522 X-Ni~lc Tranaductt Packtt X-Ni~lc/XN-Nipplc/limigtt 325 13660 331 13911 - 50% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Survey = 331 a` w WEt(aA~~~ De~f 5Hz MTT Recordings Showing Pote Minor Casing Damage ~ ~ (4,680' - 4,850') t- ,~ r~.~~E o~,~.tc s~K~ NS-05 November Database File: pfot1.db Dataset Pathname: 5HzR2.1 Presentation Format: 1.2 scale Dataset Creation: Wed Nov 1818:52:11 2009 Charted by: Depth in Feet scaled 1:240 -50 Delta Metal Thickness (%) 5i) 1.2 MTT Phase Sfiift -Sensor 01 (5 Hz} (rad} 11.2 0 Line Speed (ftJmin) -200 -7.6 MTT Phase Shift - Sensar 12 (5Hz) (rad) 2.4 Tut~ng Jt. 111 4700 4720 Tubing Jt. 112 4740 4760 Tubing Jt. 113 4780 4800 Tubing Jt. 114 4820 ~~._~T~~_Casing Collar Tubi Co lia -50 Delta Met al T hickness (%) 50 0 Line Speed (ftJmin) -200 12 -7.6 Isolated Isolated Metal MTT Phase Shift -Sensor 01 (5 Hz) (rad) 112 MTT Phase Shift -Sensor 12 (5Hz) (rad} 2.4 a~o~'~wEu~A~c~ Deta~SHz MTT Recordings Showing Appare ine of Isolated Metal Loss ~ ~ (1(1,500` -10,670') i~ N ~dl-crivF o~w~,k Scrniccs _ NS-05 November 1 Database File: plot2.db Dataset Pathname: 5HzPas.1 Presentation Format: 1.2b&w Dataset Creation: Wed Nov 18 18:49:42 2009 Charted by: Depth in Feet scaled 1:240 -50 Delta Metal Thickness (%) 50 1.2 MTT Phase Shift -Sensor 01 (5 Hz) (rod} 11.2 0 Line Speed (ftlmin) -200 -7.6 MTT Phase Shift -Sensor 12 {5HZ) {rod) 2.4 Thickness Tubing Jt. 251 10520 CApRarent Line of Isolated Metal Loss -50 Delta Metal Thickness (%) 50 1.2 0 Line Speed (ft/min) -200 7.6 MTT Pt~se Shift -Sensor 01 {5 Hz) {rod} 11.2 MTT Phase Shift -Sensor 12 {5Hz) {rod) 2.4 ~~ ~E((s Quo ~~ Detail ~-Iz MTT Recordings Showing Appa~ Line of Isolated Metal Loss {5,010' - 5,370') ra°acrivt Di,uyn°srit SE°vius NS-05 November 13, 2009. Database File: plot3.db Dataset Pathname: 5MzR2.1 Presentation Format: 1.2 scale Dataset Creation: Wed Nov 1818:52:11 2009 Charted by: Depth in Feet Scaled 1:240 -50 Delta Metal Thickness (°to) 50 1.2 MTT Phase Shift -Sensor 01 (5 Hz) (rad) 11.2 0 Line Speed (ftlmin) -200 -7.6 MTT Phase Shift -Sensor 12 (5Hz} (rad) 2.4 Metal Thickness 5020 Tubing Jt. 119 5040 5060 Tubing Jt. 120 5080 I Tubins~ Collar +---1"~ I I I I 5100 Tuk~ing J#. 121 5120 5140 Tuning Jt. 122 5160 ;,~.; -~; ; Apparent Line of Isolated Metal Loss poarent Line of Isolated Metal Loss Line of Isolated Metal Line of Isolated Metal Collar WELLHEAD= ABB-VGI13-5 ACTUATOR- BAKER ~_.~~ __.,_ 56.3T BF. REV - 40.1' (CB 15.9') K~ - 1969' Max An le = _ 56° @ 7693' Datum MD = 13217 Datum ND = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, D =12.415" N S 0 5 S~TES: ***4-112" CHROME TBG &LNR'"`* ® ~ 994.' -14-1 /2" TRM-4E SSSV w / 4-112" XPROF D = 3.812" GAS LIFT MANDRELS ~ TYPE VLV LA Minimum ID = 3.725" @ 13351' 4-1/2" XN NIPPLE TOP OF 7" LNR 9-5/8" CSG, 53.5#, L-80 BTM•C 4-1 /2" X NIP. D = 3.813" 13292' ~-~ 4-112" FBER OPTIC TRA NSDUCER, D = 3.958" ABB-VGI5-1/8" 5KS1 /8" MULTBOWL SKSI TOP OF 4-112" LNR 4-1/2" TBG, 12.6#, 13CR VAM-ACE, .0152 bpf, D = 3.958" ~7" LNR, 29#/ft L-80 Hydril 511, D = 6.184" ~ PERFORATION SUMMARY REF LOG: SWS USIT4/11105 ANGLE AT TOP Pff2F: 17 @ 13707' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-718 6 13707 - 13727 O 06!28!05 2-7/$' 6 13734 - 13764 O 09/20/05 2-7/8" 6 13739 - 13794 O 04/12/05 2-7/8" 6 13739 - 13794 O 05/28/05 2-7/8" 6 13763 - 13794 O 03/11/08 PBTD 4-1/2" LNR, 12.6#, 13CR VAM-ACE .0152 bpf, ID = 3.95$" ~ 13316' H 7" X 4-1 /2" BKR S-3 PKR, D = 3.958" I 13310' ELMD 13340' 4-1/2" X NIP, D = 3.813" 13351' 4-1 /2" XN NIP, iD = 3.725" 13368' ELWD XN NIP LOGGED ON 04/11 /05 13366' 4-1/2" HES SELF ALIGN~VG MULESHOE D = 3.958" DATE REV BY COMMENTS DATE REV BY COMNHdTS NORTHSTAR 04/12/05 TA ORIGINAL COMPLETION 11/27/07 WRR/PJ WELLHD/ LOCATION CORRECTS WELL: NS05 05/05/05 GJB/PJC CORRECTION SSSV 03/11/08 WRR/TLH REPERF PERMff No: 2050090 04/12/05 GJR/PJC PERF API No: 50-029-23244-00 05/28/05 WRR/PJC RE-PEKE SEC. 11, T13N, R13E, 1089' FSL &642' F~ 11/04/05 BJM DRLG DRAFT CORRECTIONS 02/22/06 ROY/TLH PERF CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMIS~J REPORT OF SUNDRY WELL OPERATIONS ~~G"~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q, 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. Well Class Before Work: 5. Permit to Driii Number: Name: Development Q- Exploratory ^ 205-0090 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage,AK 99519-6612 50-029-23244-00-00- 8. Property Designation (Lease Number) : , 9. Well Name and Number: ADLO-312808 - NS05 - 10. Field/Pool(s): NORTHSTAR FIELD / NORTHSTAR OIL POOL- 11. Present Weil Condition Summary: Total Depth measured 14033 - feet Plugs (measured) None feet true vertical 11335.58 - feet Junk (measured) None feet Effective Depth measured 14027 - feet Packer (measured) 994 11525 13310 13357 true vertical 11329.83 - feet (true vertical) 994 9294 10644 10689 Casing Length Size MD TVD Burst Coliapse Structural Conductor Surface 3147 13-3/8"28# L-80 40 - 3187 40 - 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# 1-80 39 - 11702 39 - 9401 7930 6620 Production Liner 2012 7" 29# L-80 11525 - 13537 9294 - 10862 8160 7020 Liner 674 4-1/2" 12.6# 13CR80 13357 - 14031 10689 - 11334 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# 13Cr80 37 - 13366 37 - 10698 Packers and SSSV (type, measured and true vertical depth) 4-1/2" TRM-4E SSV ""'^'~~'°"""" " 9J~t'' "'" 994 7" Too Packer 11525 9294 7" 13Cr80 Packer 13310 10644 4-1/2" Liner To~ Packer 13357 10689 12. Stimulation or cement squeeze summary: Intervals treated (measured): a=`t; 6~~j~~~~'};. ~„~ ~,~ ~~~~C~ €:?~''~.~ ..», 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: 2338 40257 1669 913 Subsequent to operation: 14. Attachments: 15. Weli Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q- Service ~ Daily Report of Well Operations X 16. 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: 309-222 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 9/23/2009 Form 10-404 Revised 7/2009 ~`'~ ~'~~„ ~"~~ ' ~' '~~~E' ~l,`~ Submit Original Only NS05 205-0090 PERF ~4TT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 9/20/05 APF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 APF 13,734. 13,764. 11,049.37 11,078.02 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 APF 13,733. 13,735. 11,048.41 11,050.32 NS05 8/22/08 APF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 APF 13,763. 13,766. 11,077.06 11,079.93 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REM OVED 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 • ~ • NSOS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/19/2009?Bullhead Mud Acid Treatment Pump 25 bbl 10% HCI tbg pickle treatment ~and displace w/ 182 bbls H20/Diesel. Intitial treating pressure 3350 psi, Final ~treating pressure 1300 psi @ 2 bpm. Turn over to production f/ flowback. i"""* Cont. on WSR 9/20/09 *'"" ""'' WSR Continued from 09-19-09""* Assist Schlumberger with Acid Treatment. Pumped into the Tbg with 70 bbls of diesel. Operator to POP. After 210 bbls flowed start to Slip stream Magnesium Oxide into the well while flowing to the facility. Maintain 0.2 BPM Magnesium Oxide per 1 BPM returns. Pumped a total of 182 bbls of Magnesium Oxide. Flushed lines with 5 bbls of diesel. Final WHP's = 2450/40/40 Well flowing at the time of departure. 9/20/2009~Bullhead Acid Treatment Continue to flowback well after tubing pickle. Si `well after 300 bbls returns. Pump acid treatment w/ 230 bbls 10% HCI and 230 bbls 6:1 Mud Acid in 4 staqes w/ wax bead diversion. All three diversions ~were seen clearly. Flowback well to disposal well through the test separator. t**""* Cont. on WSR 9/21/09 """** 9/21 /2009' Standby for the two, 6 hour test after the well has flowed back. 9/21/2009jBullhead Scale Inhibition Treatment Continue flowback after acid ; treatment to disposal well through the test separator. Standby for stabilization ' period and two 6 hr well tests. Start scale inhibition treatment. ''''** Cont. on ; WSR 9/22/09 '"`*"'` 9/22/2009~Bullhead Scale Inhibition Treatment (Cont. from WSR 9/21/09) 'Scale Inhib treatment . Pumped 72 bbls EC5526A scale inhibitc Min. pressure @ 5 bpm 1300 psi, Max urn we over to Production or 4 hr s< ****Job Complete"*** FLUIDS PUMPED 1975 psi. RD SLB pump. en open to production BBLS 145 DIESEL 182 MAGNESIUM OXIDE 25 10% HCI 352 TOTAL • • r ~ ; `g ~"~ ` ~"~, ~ ~,~~ , ~ ~ ~` ~ k; " " ' ~ ~- r~ t`~ ~ ' ~ ~ ~ '~~. ~ ~ ; ~~ a ~ ~'~ ~~;~ ' SARAH PAUN; GOVERNOR . .' ta ~ i ~ ~ d ~' A € ~ ~~ ? ~ a ~ .¢`~ ~ ~~~ ~ ~a ~ p. ?, ~ _ _ ~ ;~ ~. L~LC~S~~ ~~ ~-`D ~~ ,t~~ 333 W. 7thAVENUE, SUITE 100 COluSERQATI011T COl-II-II5SIOI~T ~ ANCHORAGE, ALASKA 99501-3539 ~a PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Brad Gatham Wells Engineer BP E~Ioration (Alaska) Inc. P.O. Box 196612 ~+~:~~~ ~ ~ a-~ ~~ ~~~ ~ Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS05 a,~ ~~~ Sundry Number: 309-222 Dear Mr. Gatham: 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 ne~ working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Comrnission decision to Superior Court unl.ess rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~~ Chair DATED this ~ day of July, 2009 Encl. • STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 y~s~ es-O~ ~h l~ 1. Type of Request: Abandon Suspend Operationai shutdown Perforate Waiver Othe Aiter casing ~ Repair well ~ Plug Pertorations~ Stimulate Q~ Time Extension ~ Acid Change approved program ~ Pull Tubing ^ Pertorate New Pool^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Expioration (Alaska), Inc. Developmen~ - Exploratory ^ 205-0090 ~ 3. Address: P.O. Box 196612 Stratigraphic~ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 ~ 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS05 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): _ ADLO-312808 - 56.37 RT - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 14033 ~ 11335.58 ~ 14027 - 11329.83 ~ NONE NONE Casing Length Size MD ND Burst Collapse Surtace 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 Liner 2012 7" 29# L-80 11525 13537 9294 10862 8160 7020 Liner 674 4-1/2" 12.6# 13cR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED 4-1/2" 12.6# 13CRVAM-ACE 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packe~ 13357 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. Weti Status after proposed work: Commencing Operations: 7/14/2009 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 Brad Gathman Printed Name Brad Gatham Title Weiis Engineer Signature /~ Phone 564-5778 Date 6/30/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n~-~~i , Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ~ ~~~r ~~ 1/ ~~ othe~: ~iUN ~ p 2QQ9 ~iask~ pid ~ C~a~ Cons. CQmmissi Subsequent Form Required: ~~ ~,~G~~~a4~ APPROVED BY / ~j ~ Approved by: COMMISSIONER THE COMMISSION Date: l l Form 10 403 Revised 06/2,066 ~ R~~~~ A L Submit in Du : i ~~ ~ ~ ~ ~~ ~Ut ~`1 ~ 2D09 ~l~' NS05 205-009 PFRF ATTA(_NMFNIT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 RPF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 RPF 13,734. 13,764. 11,049.37 11,078.02 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 RPF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 RPF 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 RPF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 RPF 93,733. 13,735. 11,048.41 11,050.32 NS05 8/22/08 RPF 13,763. 13,766. 11,077.06 11,079.93 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 PWG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED S4Z SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • No portion of the below work should be performed w/out first taking time to ensure ~n No Accidents, No harm to People, and No damage to the Environment F' To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE Subject: NS05 Bullhead Mud Acid SIT Treatment AFE: NSFLDWL05-C Date: June 29, 2009 (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Cost: $200M IOR: 200 Please perform a bullhead mud acid treatment on NS05 per the below procedure. 1 F Bullhead Mud Acid and SIT w/ Diversion I Current Status: Online Operable Producer Last Test: 06/14/09: 2,013 BOPD, 1,812 BWPD, & 37,445 MSCFD Max Inclination: 56° at 7,693'; ~17° at Perfs Max Dog Leg: 5.0 at 9,386'MD Minimum ID: 3.725" at the 4~h" XN Nip C~? 13,351' MD Last TD tag: 02/07/09: 13,893' SLM w/ 2-7/8" DMY gun Last Downhole Op: 06/03/09: Set Petrodat mem gauges in XN-Nip at 13,351'MD Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP/BHT: 05/05/08: 5,058 psia / 253°F @ 11,100 ft ss Obiective Based on the historical scale issues at Northstar and the indication of skin, the below mud acid and 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 Historv NS05 was completed in April 2005. Prior to a large water based scale inhibition treatment in May 2005, the well was tested at 8900 BOPD and 8% WC. Following the 05/20/05 stand alone scale inhibition treatment consisting of Baker SCW-4004 Phosponate/Polymer, the rate dropped to 2300 BOPD. The well was re-perforated on 05/28/05 in an attempt to restore production. The production increased to 4200 BOPD at 18% WC. In June 2005, additional adperfs shot higher in the section increased production to 6000 BOPD at 16% WC. A combination acid/scale inhibitor treatment was completed in August 2005. The initial test post treatment was 5350 BOPD with a 16% WC. At this point the well started a sharp decline and by September the rate had fallen to 2500 BOPD at a 1% WC. On NSOS Bullhead Acid & SIT Treatment Page 1 of 9 • • No portion of the below work should be performed wlout first taking time to ensure No Accidents, No harm to People, and No damage to the Environment 09/20/05 re-perfs and ad-perfs were shot in an attempt to bypass the damage and increase rate. The reperfs/adperfs increased the rate to 4700 BOPD at a 1% WC. NS05 was identified as a coil acid candidate due to loss of water following the August 2005 bullhead treatment. The 04/01/06 coil treatment increased the oil rate by 1500 BOPD and also returned the water production. Another combination CTU acid treatment/scale inhibitor treatment was completed 03/13/07 resulting in a 2200 BOPD increase. Based on the historical rate benefits from treating NS05, the treating frequency was increased and another CTU acid treatment was performed 08/09/07 resulting in a~800 BOPD increase. Subsequent reperf of the bottom 30' increased oil production by 800 BOPD on 03/18/08. The last CTU acid treatment was performed on 4/06/2008 resulting in minimal change. Perfs added closer to the OWC on 8/22/08 resulted in ~500 BOPD increase. Based on the declining historical rate benefits of treating NS05 with HCI, the below mud acid/scale inhibition treatment is proposed. Risk Discussion A risk review was held 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. 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 HCt jobs. It is critical to have twice the volume of MagOx necessary to neutratize the treatment volume of acid on site. Action Items from 2/17/09 risk review. • Pump and other process components were verified to be resistant to acid. • Soft PSV components can be susceptible to HCl and HF. 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 faciliry 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 acid treatments. • CIC inspection of water injection header before and after acid 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 Page 2 of 9 ~ • No portion of the below work should be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment • Schlumberger will provide Slicker Suits and associated acid resistant PPE for Northstar Ops • r1 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 acid at the ~vellhead. • HF Neutralization - Mag Oxide slurry Injection at Wellhead Please review the following sections of the PE manual. <htt~ /~11~k1 b~web b~ com/5~t diillin~ lvells pemamial > Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back A summary of well work activity is outlined below. Operational Highlights [Add f'J~,',] [Vie1~v All] Comments D ate 08l22I2008 AdPerf Closer to OWC & RePerfs --~ ~500 bbl oil inc. Ed,Y [?~~e[e 08/21/2008 Ad/Re Perf: On Final Gun Run, Gun became stuck and fired gun at stuck depth in perF intarual. E~~it C:~elrt~ well, 04/06/2408 CT AcidISIT --? minimal change Edit D~I~tr 03,J/1$~2008i RePerF bottom 30' --} rv800 bbl oil inc. E ~J It ~.I F''Y I_F'. 08J09/2007 CT Acid (No L066} --~ 800 bbl oil inc. Edit Delet~ Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Bob Younger 564-5392 (w); 830-4920 (c); 677-2599 (h) with any questions, comments, or concerns. Open Perforations Zone MDT MDB H Status TSHD 13,704 13,707 3 O en TSHD/TZE 13,707 13,727 20 O en NSOS Bullhead Acid & SIT Treatment Page 3 of 9 , ~ • No portion of the below work should be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment TZE 13,727 13,734 7 O en TZE 13,734 13,739 5 O en TZE/TZD/TZC3 13,739 13,794 55 O en TZC3 13,810 13,830 20 O en Ilacinn I~PtAils ~ 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 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 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 NS05 oil sample and deliver to Schlumberger Well Services lab for pre- iob emulsion/sludge testing at least 5 days prior to acid stim. Verify acid desig Pa~e 4 of 9 • • No portion of the below work should be performed wlout first taking time to ensure No Accidents, No harm to People, and No damage to the Environment is acceptable for application. Test both live and spent acid with the crude oil, to ensure there is no sludge or emulsions. Surfactant/Mutual Solvent/Anti-sludge treatment should be designed based on lab testing whenever is possible. 2. Arrange DHD to shoot IA FL. If the IA FL is deeper than 500' top off IA. 3. Mobilize pumps, tanks, portable acid shower and acid transport to Northstar. • Ensure Schlumberger provides Slicker Suits and associated acid resistant PPE for Northstar Operations personnel that will be sampling returns during flow back. 4. Order out necessary volume of seawater, 2% KCL and diesel to flush both the pickle and the acid treatment. See attached Volumes table. 5. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption. Bullhead Acid and Scale Inhibition Treatment ll fluids that will enter the perforations to 3 microns absolute. Filt er a • • Do Not exceed maximum pump pressure of 4000 psi when sweepinq qas out of the tubing and Do Not exceed 3500 psi when the wellbore is liquid packed. • NS05 is equipped with 13-CR 4'h" tubing and 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. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to Robert.Younqer@bp.com and IaujiO@bp.com. 6. MIRU. Page; 5 of 9 ,_ , ~ ~ No portion of the below work should be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment 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 arocedures are followed. 8. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. 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. 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 durinq pickle treatment. It is critical that the acid not reach perfs. Wellbore volume to top perf is 208.3 bbls. Stage Fluid Type Vol, bbls Acid - Tubing Pickle (~100ga1/1000') 12% HCI 25 KCI or SW - Displacement Fluid Filtered 2% KCI 112 Diesel cap Diesel 70 12% Acid Mixture Desiqn: 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 0.5 % F078 Foaming Agent 10.0 ppt L041 Chelating Agent 12. Produce pickle back to test separator and well clean up tank. Total pickle volume to flowback is 300 Bbls, tubing + flowline + 10 bbls (208+82+10). ~ ~-°t ~~~__V / ~IT T......#w.e~r~+ I _ . . Page 6 of 9 NSOS Bullhead Acid & SIT Treatment ~ • No portion of the below work should be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment 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 190°F. Note: It is crucial that the water temperature does not exceed the melting temperature of the wax beads of 190°F. 100°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. 14. Bullhead four stage acid treatment with wax bead diversion 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 be~ow 0.70 psi/ frac gradient). Do not exceed 4000 psi when sweeping gas out of the tubing. Maintain pump rate as high as feasible below frac gradient after the wax beads are in the tubing. It is critical to keep the pumping pressure high after diversion breakover is observed. Record pump rates, tubing, IA and OA pressures throughout the job. Note: If the diversion locks up causing loss of injectivity, 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: Acid strength to be verified and documented via titration before leaving Schlumberqer. 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 reci itate ~<<Acid Flowback 16.After the 4 hour shut-in, line-up the well to flow into the test separator and well cleanu tank for flowback. 17. RU triplex to swab for Mag OX slurry injection. 18. Produce ~280 bbls (tubing + flowline volumes = 290 bbls) P~t~,~ ~ ~~r a ~ ~ No portion of the below work shouid be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment 19. Pump Mag Ox slurry (1 Ib/gal) at ~2.17 gpm (0.05 bpm). Mag Ox Slurry rate based on the following calculation: Mg0 Slurry Loading (Ib/gal): 1 Treatment Volume (bbls): 323.00 Return Fluid pH: 1 Flowback Time (at 3 bpm): 107.67 Return Fluid Flow Rate (bbls/min): 3 Minimum Volume of Mg0 required (gal): 233.44 Mg0 Slurry Required (gal/min): 2.17 Minimum Volume of Mg0 required(bbls): 5.56 Note: Have twice the required volume of Mg0 on site See the attached excel calculation to adjust Mag Ox slurry rate based on pH of un- neutralized flow back samples taken at test separator. The frequency of these samples is at the discretion of the PE. Northstar Operations will be taking the samples because of their familiarity with the process equipment. Ensure pre-job risk assessment is completed and appropriate PPE is dawned before sampling. Take samples using acid resistant container and work with SLB to determine sam le H. 20.Once clean-up volume of 603 bbls is produced (Tubing 208 bbl + Treatment 313 bbl + Flowline 82 bbls) divert back to the plant and get two 6-hour tests. 21. Start sampling returns for analysis at Prudhoe Bay lab 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. Flowback Samplinq 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: • Well: NS05 • 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 Note: There are two separate flow back sampling programs occurring; the first is to determine the pH for Mag Ox calculations, the second is for analysis at Prudhoe Bay lab. Page 8 of 9 ~ ~ , No portion of the below work should be performed w/out first taking time to ensure No Accidents, No harm to People, and No damage to the Environment 22. Post flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. 23.Obtain produced fluid samples once per day for 1 week 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, sulfates. Add well to GPB lab sampling request list. 24. Perform complete water analysis on the sample taken 1 week after treatment. Procedure Contacts: Mark Sauve W K: 564-4660 Cell: 748-2865 Jack Lau WK: 564-5102 Cell: 227-2760 NSOS Bullhead Acid & SIT Treatment Page 9 of 9 • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~~; ~~~~f ~' ~tla~J May 26, 2009 ~r g iA~l~,~ ~}p~ ~ f`i;~ W~li~~ Sc il~f „ ':StQ~? ~nohgr~pp Mr. Tom Maunder Alaska Oil an d Gas Conservation Commission ;~ .. ~~~~,~ 333 West 7 Avenue ~~~ ,, ,, ~~ Anchorage, Alaska 99501 ~`~ 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, l ~NNnn ~,~_ Andrea Hughes BPXA, Well Integrity Coordinator '. Y~~Y 4~~ i ~~ j ~t ~ ,.g L. 41/o-~ ~~ • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~-6\ Date Northstar 5/26/2009 ell Name TD # Initial top of cement Vol. of cement um ed i 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 /~ 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. ._ ~ ,i ~?~ ~~ ~ 2009 >~ . , Date: 02-25-2009 Transmittal Number: 93041 BPXA WELL DATA TRANS~IIT"TAL r °~ Enclosed are the materials listed below. Ja`J~~~.~~~ ~~,r~N " ~~~"~ L~ ,~. ~'~,.~ G~ ~l,~i~~ _~... 11.1 ~ r~ ~~~ 1 J~~ ~~~'' is .~yD ~~ ` +~~ \~ .~ Fb'",~`1 \~~ .~- _,'~ J `L~\ \~~ ~/ If you have anv questions. please contact Joe Lastuflca at (9071564-4091 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 WITH 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 ~ ,..~ a y' ~~ 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 u. Revisions: NS Acid Treatments - NS05,11,16, 19 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 7:11 PM To: Lau, John, Jack Cc: Younger, Robert O Subject: RE: Revisions: NS Acid Treatments - NS05,11,16, 19 Jack and Bob, No issues with the diverter. ~„1,q;`<~~~y,'~,A ~~ ~iL 1<~ ~~)~J Tom Maunder, PE AOGCC From: Lau, John, Jack [mailto:Jack.Lau@bp.com] Sent: Mon 2/9/2009 4:56 PM To: Maunder, Thomas E (DOA) Cc: Younger, Robert O Subject: Revisions: NS Acid Treatments - NS 5,11,16, 19 Tom, aOS-CEO As you are aware we are planning divererted acid treatments on NS05, NS11, NS16, and NS19 during ice road season. Originally we planned to use wax beads to divert between stages, however we have revised the programs to use benzoic acid flakes (BAF) in place of wax beads. We see no negative effects of using BAF, as BAF is extremely soluble in hydrocarbons and slightly soluble in water which should facilitate cleanup. Let me know if you have any questions, concerns, or requests. Thanks! ~TCXC~t I.,Cili wells 1_ngirteer BP FAploration (:~laska) Inc;. Office: 90756.5102 Cell.: 907.227.2760 2/10/2009 ~- t k r~ t ~ ~ ~ r M~ . I ~m ~a~ ~~ ~~ ~ ~' ALASSA OIL A1~TD GA.S COI~TSERQATIOI~T CO1rII-IIS5IOI~T Jose Solo PE BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Wield, Northstar Oil Pool, NS05 Sundry Number: 308-462 • SARAH PALlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Solo: ~~~ ~' ~ l ~~ ~ ~ ~QG 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, G~o~ Daniel T. Seamount, Jr. Chair DATED this23 day of December, 2008 Encl. ~~ ~ ~~~~ ~~ ,~: i • ,~,~, ~~~'~ ,~~o~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25280 ~c~*llf'+~! 1. Type of Request: Abandon Suspend Operational shutdown Perfo Waiver ~) Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimu~ ~ Time Extension ^ C~J Ac d? Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ Treatment - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ' Exploratory ^ 205-0090 ' 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS05 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312808 ~ 56.37 RT ~ NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESE NT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14033 ~ 11335.58 ' 14027 - 11329.83 ~ NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 Liner 2012 7" 29# L-80 11525 13537 9294 10862 8160 7020 Liner 674 4-1/2" 12.6# 13cR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13704 - 13794 11021 - 11107 4-1/2" 12.6# 13CRVAM-ACE 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 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 Jose 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: -' APPROVED BY ~~ / Approved by COMMISSIONER THE COMMISSION Date: o -" r - -' F t Submit in Duplicate Form 10-403 Revised 06/2006 ° ` ~ ~ ~ ~ ~~~, ~ ~ r~~~ 'zips NS05 205-0090 PERF OTTArHMFNT • Sw Name Operation Date Perf Operation Code ----- --- Meas Depth Top ------------- Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 9/20/05 APF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 APF 13,734. 13,764. 11,049.37 11,078.02 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 APF 13,733. 13,735. 11,048.41 11,050.32 NS05 8/22/08 APF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 APF 13,763. 13,766. 11,077.06 11,079.93 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REM OVED 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 taking time to ensure No Accidents~o harm to People, and No damag the Environment p To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Robert Younger, Northstar PE Subject: NS05 Bullhead Acid SIT Treatment AFE: NSFLDWL05 Date: December 18, 2008 (w: 564-5102 c: 227-2760) (w: 564-5972, c: 244-0529) Cost: $100M IOR: 200 Please perform a bullhead acid treatment on NS05 per the below procedure. 1 F Bullhead Acid Treatment w/ Diversion Current Status: Producer Last Test: 11/09/08: 2,278 BOPD, 2,176 BWPD, & 31,357 MSCFD Max Inclination: 56° at 7,693'; ~17° at Perfs Max Dog Leg: 5.0 at 9,386'MD Minimum ID: 3.725" at the 4'/i" XN Nip @ 13,351' MD Last TD tag: 05/04/08: 13,960' SLM w/ 2.5" Cent Last Downhole Op: 08/22/08: RePerf (13,735-13,766) Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 05/05/08: 5,058 psia / 253°F @ 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 NS05 was completed in April 2005. Prior to a large water based scale inhibition treatment in May 2005, the well was tested at 8900 BOPD and 8% WC. Following the 05/20/05 stand alone scale inhibition treatment consisting of Baker SCW-4004 Phosponate/Polymer, the rate dropped to 2300 BOPD. The well was re-perforated on 05/28/05 in an attempt to restore production. The production increased to 4200 BOPD at 18% WC. In June 2005, additional adperfs shot higher in the section increased production to 6000 BOPD at 16% WC. A combination acid/scale inhibitor treatment was completed in August 2005. The initial test post treatment was 5350 BOPD with a 16% WC. At this point the well started a sharp decline and by September the rate had fallen to 2500 BOPD at a 1 % WC. On 09/20/05 re-perfs and ad-perfs were shot in an attempt to bypass the damage and increase rate. The reperfs/adperfs increased the rate to 4700 BOPD at a 1 % WC. 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 NS05 was identified as a coil acid candidate due to loss of water following the August 2005 bullhead treatment. The 04/01 /06 coil treatment increased the oil rate by 1500 BOPD and also returned the water production. Another combination CTU acid treatment/scale inhibitor treatment was completed 03/13/07 resulting in a 2200 BOPD increase. Based on the historical rate benefits from treating NS05, the treating frequency was increased and another CTU acid treatment was performed 08/09/07 resulting in a 800 BOPD increase. Subsequent reperf of the bottom 30' increased oil production by 800 BOPD on 03/18/08. The last CTU acid treatment was performed on 4/06/2008 resulting in minimal change. Perfs added closer to the OWC on 8/22/08 resulted in 500 BOPD increase. Based on the historical rate benefits of treating NS05, the below CTU acid/scale inhibition treatment is proposed. A summary of well work activity is outlined below. Operational Highlights [Add hE!?tiv] [View All] Date Comments 08!22/2008 AdPerf Closer to OUdC & RePerfs --~ X500 bbl oil inc. Edit C?rlate 08!2112008 AdIRe Perf: On Final Gun Run, Gun became stuck and fired gun at stuck depth in perF interval. Edit C7alct~ well. 0410612008 CT AcidISIT --> minimal change Edit G~el,te 0 311 812 0 0 8 RePerf bottom 30' --~ X800 bbl oil inc. Edit C~clete 0 810 912 0 0 7 CT Acid {Alo L066~ --~ 800 bbl oil inc. Edit DelYte 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). Open Perforations Zone MDT MDB H Status TSHD 13,704 1.3,707 3 O en TSHD/TZE 13,707 13,727 20 O en TZE 13,727 .13,734 7 O en TZE 13,734 13,739 5 O en TZE/TZD/TZC3 13,739 13,794 55 Open 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 TZC3 13,810 1.3,830 20 Design Details Total Footage 110' # of Perforations 2300 Wellbore Volume 208.3 bbl (to top perf) Acid Design 60 gpf for perfs Acid Volume 155 bbls total Diversion Design 6#/ft at 0.5-1 ppg in 30# HEC gel Diversion Volume 10 bbls total wax beads Reservoir Pressure 5,058 psia / 253°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 NS05 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. No portion of the belo~rk should be performed w/out fir~aking time to ensure No Accidents, o harm to People, and No damage the Environment 4. Order out necessary volume of seawater, 2% KCL and diesel to flush both the pickle and the acid treatment. See attached Volumes table. 5. Ensure that the well is ready to be flowed to the test separator after the tubing pickle and scale inhibitor absorption. Bullhead Acid and State Inhibition Tr.~atmertt: • 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. • NS05 is equipped with 13-CR 41h" tubing and 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. • 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 Iauit0@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 rocedures are followed. 8. Review IA fluid level (step 2). Ensure IA FL is within 500' of surface. 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. 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 Tubing PictCle`T~r~a#t~~it;:: 4 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 208.3 bbls, Stage Fluid Type Vol,. bbls Acid -Tubing Pickle (~100ga1/1000') 12% acid 25 KCI - Dsiplacement Fluid Filtered 2% KCI 112 Diesel cap Diesel 70 12% Acid Mixture Design: 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 . Surfactant, EZEFLO 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 313 Bbls, ~1.5 times wellbore volume. HCf 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 paint. 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 Accidents, o 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 Design Schedule Stage Fluid Type von (bbfs) 1 Liquid pack -cool wellbore 2% KCI +F103 240 2 Acid 12% HCI +8.4% L066 77 4 Over Flush (5' radial displacement) 2% KCI +L066+F103 60 5 1.5 PPA Wax Beads +30# HEC Wax Beads 10 6 Spacer 2% KCI + L066+F103 5 7 Acid 12% HCI +8.4% L066 78 8 Over Flush (5' radial displacement) 2% KCI +L066+F103 63 10 Displacement 2% KCI 138 11 Displacement/Freeze Protect Diesel 70 12% HCL Acid Design: 5.2 % L066 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 No portion of the belo~ork should be performed w/out fi~taking time to ensure No Accidents~Ro harm to People, and No damag the Environment Acid Flowba+ck 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 600 bbls (Tubing 208 bbl + Treatment 293 bbl + Flowline). After clean-up, divert back to the plant and et 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 post acid treatment. 19.Obtain produced fluid samples once per day for. 1 week 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, sulfates. 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 WK: 564-5392 WK: 564-5102 HM: 677-2599 Cell: 227-2760 Cell: 830-4920 TREE = ABB-VGI 5-118" WELLHEAD= ABB-_VGI 13-5/8" MULTIBOWL: ACTUATOR = BA KB. ELEV = 56.37' BF, ELEV = 40.1' (CB 15.9') KOP = 1969' Max Angle = 56° @ 7693' Datum MD = 13217' Datum TV D = 10500' SS 13-318" CSG, 68#, L-80 BTC, ID = 12.415" 318. Minimum ID = 3.725" @ 13351' 4-112" XN NIPPLE TOP OF 7" LNR 9-5/8" CSG, 53.5#, L-80 BTM-C TOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR VAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 29#Ift L-80 Hydril 511, ID = 6.184" PERFORATION SUMMARY REF LOG: SWS USfT 4/11105 ANGLE AT TOP PERF: 17 @ 13707' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION INFORMATION 4-1/2" LNR, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" N ~ O C SA~ NOTES: ***4-112" CHROME TBG &LNR*** 994' 4-1/2" TRM-4E SSSV w / 4-1/2" X PROF ID = 3.812" GAS LIFT MANDRELS ' TYPE VLV LA' MMG DMY ' 1~4-1/2" X NIP, ID = 3.813" (4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" ~ 13~ 316, I- j 7" X 4-112" BKR S-3 PKR, ID = 3.958" I 13310' ELMD 13340' 4-1/2" X NIP, ID = 3.813" 13351' 4-1/2" XN NIP, ID = 3.72 13368' ELMD XN NIP LOGGED ON 04111 /05 13366' 4-112" HES SELF ALIGNING MULESHOE ID - 3.958" DATE REV BY COMMENTS DATE REV BY COMMEMS 04!12/05 TA ORIGINAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTIC 05/05/05 GJB/PJC CORRECTION SSSV 03/11108 WRR/TLH RE PERF 04/12/05 GJR/PJC PERF 09/05J08 WRR/PJC PERFS (08/22108) 05128/05 WRRIPJC RE-PEKE 11/04/05 8JM DRLG DRAFT CORRECTIONS 02/22/06 ROY/TLH PERF CORRECTIONS NORTHSTA R WELL: NS05 PERMIT No: 2050090 API No: 50-029-23244-00 SC-C. 11, T13N, R13E, 1089' FSL & 642' FEL BP Exploration (Alaska) ~ . Page 1 of 1 Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, December 22, 2008 3:54 PM To: Maunder, Thomas E (DOA) Subject: RE: NS05 (205-009) Bullhead is correct. From: Maunder, Thomas E (DOA) {mailtoaom.maunder@alaska.gov] Sent: Monday, December 22, 2008 3:38 PM To: Preble, Gary B (SAIC) Subject: RE: NS05 (205-009) Gary, I am reviewing the sundry submitted to treat this well. The 403 shows that a GTU acid treatment is planned, however the procedure provided is for a bullhead treatment. How is it planned to treat this well. If a new procedure is needed, please send via email. Tom Maunder, PE AOGCC 12/22/2008 t STATE OF ALASKA ~9~~ AL/'~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~~ lid AUG 2 7 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated BS 8 8S COf1S. COi116'i1SS Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~!'fC~it31'c~g8 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 205-0090 3. Address: P.O. Box 196612 Stratigraphic L Service 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 56.37 KB ~ NS05 ' 8. Property Designation: 10. Field/Pool(s): ADLO-312808 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14033 feet Plugs (measured) None true vertical 11335.58 ~ feet Junk (measured) None Effective Depth measured 14027 ' feet true vertical 11329.83 ~ feet Casing Length Size MD TVD Burst.. Collapse Surface 3147' 13-3/8" 68# L-80 40' - 3187' 40' - 3183' 4930 2270 Intermediate 11663' 9-5/8" 53.5# L-80 39' - 11702' 39' - 9401' 7930 6620 Liner 2012' 7" 29# L-80 11525' - 13537' 9294' - 10682' 8160 7020 Liner 674' 4-1/2" 12.6# 13Cr80 13357' - 14031' 10689' - 11334' 8430 7500 ~~,'~~~~~' ~~F ~, ~ 20C~~ Perforation depth: Measured depth: See Attached True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 13366 0 0 - Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 2924 29533 2132 790 Subsequent to operation: 3430 31335 2697 816 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: 308-272 Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date 8/26/2008 Form 10-404 Revised 04/2006 @ ~ ~ '" ~ 2~~~ Submit Original Onty ,t NS05 205-0090 DFRF ATTA(_H1IAFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tv d D epth Base NS05 __ _ 4/12/05 PER __ 13,739. 13,794. 11,054.14 _ __ _ 11,106.67 NS05 _ 5/28/05 RPF ___ _ 13,739. E 13,794. _ E 11,054.14 _____ 11,106.67 _ NS05 6/28/05 APF 13 707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 APF ~ 13,704. 13,719. 11,020.74 11,035.05 __ __ NS05 9/20/05 APF _ 13,719. 13,734. 11,035.05 _ 11,049.37 NS05 9/20/05 APF 13,734. 13,764. 11,049.37 11,078.02 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 _ 8/21/08 APF 13,763. 13,794. 11,077.06 11,106.67 NS05 8/21/08 APF _ 13,810. 13,830. 11,121.96 11,141.08 NS05 8/22/08 APF 13,733. ~/ 13,735. 11,048.41 11,050.32 NS05 8/22/08 APF 13,735. 13,763. 11,050.32 11,077.06 NS05 8/22/08 APF __ 13,763. 13,766. 11,077.06 11,079.93 AB ABANDONED ` PER PERF APF ADD PERF _ _ _ RPF ____ REPERF BPP BRIDGE PLUG P ULLED __ __ _ __ _ ___ _ SL SLOTTED LINER ~ _ BPS __ BRIDGE PLUG SET SPR SAND PLUG REM OVED FCO FILL CLEAN OUT __ _ _ SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MIS MECHANICAL ISOLATED REMOVED MECHANICAL ISOLATED ~ SQZ STC SQUEEZE STRADDLE PACK, CLOSED MLK MECHANICAL LEAK _ STO STRADDLE PACK, OPEN OH OPEN HOLE ___ ~ • • ,~, • NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/20/2008 '*'ARRIVE AT NORTH STAR, JOB SCOPE, ADD PERF/RE-PERF""` START JOB PREP AND RIG UP FOR ELINE *'*JOB CONTINUED ON WSR DATED 21-AUG-2008*"" 8/21/2008 **"JOB CONTINUED FROM 20-AUG-2008`*' ADD PERF/RE-PERF CONTINUE RIG UP FOR ELINE, TIE INTO SCHLUMBERGER USIT DATED 4/11 /05 PERFORATE INTERVALS 13810'-13830' 13794'-13763', WITH 2.88" 2606PJ, 6 SPF, 60 DEG PHASING, TTP=25.3", EHD=0.38". *""JOB CONTINUED ON WSR DATED 22-AUG-2008''`* 8/22/2008 "'*JOB CONTINUED FROM 21-AUG-2008*~" TIED INTO SLB USIT DATED 4- 11-05. PERFORATED INTERVAL 13733-13764 STUCK GUN #4 DURING TIE IN. INTENDED PERF INTERVAL 13704-13735. DECIDED TO SHOOT GUN AT STUCK DEPTH, IN THE MIDDLE OF PERF ZONE. STUCK GUN WAS SHOT FROM 13735.4'-13766.4'. TOWN ENGINEER DECIDED NOT TO SHOOT UPPER SECTION FROM 13704'-13735', CAME FREE AFTER SHOOTING. POOH. NO VISUAL INDICATION ON TOOLS CAUSING GUN TO GET STUCK. ALL SHOTS FIRED. ', DSO NOTIFIED WHEN OOH, POPPED WELL PRIOR TO SLB LEAVING LOCATION. ALL VALVES NORMAL FOR FLOWING WELL. MOVE TO NS-11 FOR RE-PERF. *'`'*'`JOB COMPLETE."*"`* FLUIDS PUMPED BBLS 1 diesel 1 Total • ~~ ~ ~ f-~. ALASSA OIL Ai1TD GA.S CO1~T5ERQATIOI~T CO1~II-II5SIOI~T Robert Younger Production Engineer BP Exploration Alaska Inc. PO Box 196612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage AK 99519-6612 ~ / ~ ~ ~, Re: Northstar Field, Northstar Oil Pool, NS05 Sundry Number: 308-272 ~~$~~ AUG :~ :~ 2008 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 ff 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 August, 2008 Encl. G(~',~~ ~ .,,. p ~ • STATE OF ALASKA • V ALASKA OIL AND GAS CONSERVATION COMMISSION =~~.~_~ ~~~5 ~~~ ~v~ APPLICATION FOR SUNDRY APPROVAL ~`~p 20 AAC 25.280 '; 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ ~ ~Naiver ^ 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 r Exploratory ^ 205-0090 ' 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS05 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312808 - 56.37 KB 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): 14033 - 11335.58 ~ 14027' 11329.83 ~ NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3147' 13-3/8" 68# L-80 40' 3187' 40' 3183' 4930 2270 Intermediate 11663' 9-5/8" 53.5# L-80 39' 11702' 39' 9401' 7930 6620 Liner 2012' 7" 29# L-80 11525' 13537' 9294' 10682 8160 7020 Liner 674' 4-1/2" 12.6# 13Cr80 13357' 14031' 10689' 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 8/11/2008 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 e Younger Title Production Engineer Signature Phone 564-5392 Date 7/28/2008 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 R uired: ~~\ ~ ~~ v ~ ~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ;; Submit in Duplicate NS05 205-0090 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS05 4/12/05 PER 13,739. 13,794. 11,054.14 11,106.67 NS05 5/28/05 RPF 13,739. 13,794. 11,054.14 11,106.67 NS05 6/28/05 APF 13,707. 13,727. 11,023.6 11,042.69 NS05 9/20/05 APF 13,704. 13,719. 11,020.74 11,035.05 NS05 9/20/05 APF 13,719. 13,734. 11,035.05 11,049.37 NS05 9/20/05 APF 13,734. 13,764. 11,049.37 11,078.02 NS05 3/11/08 APF 13,763. 13,794. 11,077.06 11,106.67 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 • . • • PERFORATING PROCEDURE Ve,4oos,oaa' A~ ..~m..~ Well: NS05 API #: 50-029-23244-00 ............................................................... g ...............................9............ Date: 07/28/08 Prod En r Robert Youn er Office Ph: 564-5392 H2S Level: Home Ph: 677-2599 None Anticipated Cell Ph: 830-4920 ........................................................ CC or AFC: NSFLDWL05 Detail Code: Description:.Drift_ to_ TD. with. Dummy. Gun,. Perforate ................................................................. WBL Entries IOR Type Work Description 400 S Drift to TD with Dummy Gun -Slope discretion last tag 05/04/08 400 E Perforate 13,704'-13,794' MD & 13,810'-13,830' MD Well Objectives and Loaaing Notes: The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by re-perforating the existing perforation interval and adding 20' of perforations closer to the Oil Water Contact. Please note that the perforations will be dependent on the drift information. Please contact Bob Younger with any questions, comments, or concerns - 564-5392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated perforations. Log: SWS USIT ............................. .............................. Date: 4/11 /2005 Company: ..... ......................... Schlumber9er .............................. Depths (from-to) Depths (from-to) Feet SPF 13,704' - 13,794' - 90' 6 13,810' 13,830' 20' 6 Gas Jetting Expected? No At what Depth? Requested Gun Size: 2.875 Charge: .2906 PJ Desired Penetration: 25.3 ...................................... Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check w/ Pad Operator to see it necessary piping is installed) (e.g. N2 Lift, Hardline Lilt Gas, Gas Lilt, Flow Well, BacMlow Through Drain or Hardline) Tie in to Jewelry ~ MD Tie in using: ..................... Minimum ID: .3:725.....,.,,in Min ID Type: WLEG Depth: 13.366 tt MD Casing Size: Est Res. Pres. ~ Last Tag: 13,960 ft SLMD on 5/4/2008 ............................... to the tie-in log to be on depth with the reference log. Phasing Zone Ad/Re/Iperf 60° 0 Ivishak RePerf 60° Ivishak AdPerf 0 0 ................... 0 ....................................................................................... N/A Orient. Entry Hole Diam: 0.38 .................... NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .............4:5".XN..NiPPIe,....,_....,. ~ 13,351 'MD ................... .4:5 in 12.6# 13-CR Liner ............ 13:846 MD :11100: SS -5100 psi Zone Aperf/Reperf O/B/U - O 13300 GiAUGE 13400 13700 1 -1 it Water Contact 13846' M TREE _ . WELLHEAD = ABB-VGI 13-5/8 MULTIBOWL 5K~. ACTUATOR = BAKER KB. ELEV..- 56.37 BF. ELEV = __ 40.1' (CB 15.9') KOP - 1969' Max Angle 56` @ 7693' Datum MD = 1321 T Datum TV D = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" Minimum ID = 3.725" @ 13351' 4-1 /2" XN NIPPLE ITOPOF7" LNR 9-5/8" CSG, 53.5#, L-80 BTM-C GAS LIFT MANDRELS ~TY,-PE VLV LATCH PORT DATE IVIIVIG DMY 03!29/05 13261' I-{4-1/2" X NIP, ID = 3.813" 13292' I-14-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" TOP OF 4-1 /2" LNR ~-L 4-1/2" TBG, 12.6#, 13CR VAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 29#/ft L-80 Hydril 511, ID = 6.184" -r 1 PERFORATION SUMMARY REF LOG: SWS USff 4/11/05 ANGLE AT TOP PERF: 17 @ 13707' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 13707 - 13727 O 06/28/05 2-7/8" 6 13734 - 13764 O 09/20/05 2-7l8" 6 13739 - 13794 O 04/12/05 2-7/8" 6 13739 - 13794 O 05/28/05 2-7/8" 6 13763 - 13794 O 03/11/08 PBTD 4-1/2" LNR, 12.6#, 13CRVAM-ACE, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/12/05 TA ORIGINAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTI< 05/05/05 GJB/PJC CORRECTION SSSV 03/11/08 WRRITLH RE-PEKE 04/12/05 GJR/PJC PERF 05/28/05 WRR/PJC RE-PEKE 11/04/05 BJM DRLG DRAFT CORRECTIONS 02/22/06 ROY/TLH PERF CORRECTIONS N S 0 5 S NOTES: ***4-112" CHROME TBG &LNR*** ABB-VGI5-1/8" 5 994' ~4-112" TRM-4ESSSV w/ 4-1/2" X PROF ID = 3.812" 13~ 316' I-j 7" X 4-1/2" BKR S-3 PKR, ID = 3.958" 13310' ELMD 13340' 4-1/2" X NIP, ID = 3.813" 13351' 4-1/2" XN NIP, ID = 3.725" 13368' ELMD XN NIP LOGGED ON 04/11!05 13366' 4-1/2" HES SELF ALIGNING MULESHOE ID = 3.958" NORTHSTAR WELL: NS05 PERMff No: 2050090 API No: 50-029-23244-00 SEC. 11, T13N, R13E, 1089' FSL & 642' FEL BP Exploration (Alaska) by L z„ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastufka at (9071564-4091 Date OS-08-2008 Transmittal Number:92965 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion NS05 05-04-2008 PDS 1 13096 13988 CORRELATION LOG STATIC TEMPERATURE / NS05 05-04-2008 PDS PRESSURE SURVEY CD-ROM CORRELATION LOG STATIC TEMPERATURE NS05 05-04-2008 PDS /PRESSURE SURVEY NS22 05-03-2008 PDS 1 12138 12852 CORRELATION LOG STATIC TEMPERATURE / NS22 05-03-2008 PDS PRESSURE SURVEY CD-ROM CORRELATION LOG STATIC TEMPERATURE NS22 0 -03-2008 PDS /PRESSURE SURVEY Please Si d Return one copy of this transmittal. `.'~ ~, 1 Thank You, Joe Lastufka Petrotechnical Data Center BPXA David Fair AOGCC Christine Mahnken Murphy Exploration Ignacio Herrera DNR Kristin Dirks MMS Doug Chromanski V .1 O Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 AnchoraJe, AK 99~ 19-6612 B,P. Exploration (A/askaJ. lna static Temperature/ Pressure Survey NS-05 North Star North Slope Surface -Before R/H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 37.2 3478.87 0.5 36.8 3478.92 1.0 36.5 3478.99 1.5 36.4 3479.05 2.0 36.4 3479.10 2.5 36.1 3479.13 3.0 35.8 3479.15 3.5 35.8 3479.18 4.0 35.9 3479.18 4.5 35.9 3479.19 5.0 35.8 3479.19 5.5 35.7 3479.21 6.0 35.6 3479.19 6.5 35.3 3479.18 7.0 34.9 3479.17 7.5 35.1 3479.17 8.0 35.3 3479.16 8.5 35.4 3479.15 9.0 34.8 3479.13 9.5 34.6 3479.12 10.0 34.8 3479.11 AVERAGE 35.7 3479.12 Current Wellhead Read in s Wellhead Pressure (psig) : 3,450 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure (sig) : N/A Date: May 4, 2008 ob~F,M WE(( sAce' a, c,. Q 9~ s ~ PROACTIVE DII1CjNOSTIC SERVICES Start time: 18:20:00 Temperature Data 40 35 .................................... . ......................................................................................... ..... .. ... ..... ...... LL ~i 30 ..........._ ........................................................................................................................ 0 25 ..................................................................................................................................................................................................................................... 20 0 1 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 3600 3575 ............_.._ .................... -- ......._.._............_................................................_............................_.._............_........................................._._.._._....... I 3550 .... .................... ................................................................................................................................................................. 3525 ...................................................................................................................................................................................................................................... a rn 3500 ............................... ...................................................................................... a 3475 ........................................... ...................................................................................... ...-.... 3450 ..................................................................................................................................................... ......................................................................... 3425 ............................ ............................................................................. ........................................................................................................ 3400 0 1 2 3 4 5 6 7 8 9 10 Minutes Page 1 ~~~~ o S ~' ~ ~ B.P. Exploration (A/askaJ. lnc. Stat~C TER7pE1'c~i tU!'E~ P/'ESSU/'E SU/'VEy lVS - 05 North Star North Slope 9 9,072' TVDss M.D, = 93,877' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 254.7 5,061.83 1.0 254.5 5,061.70 2.0 254.4 5,061.76 3.0 254.4 5,061.94 4.0 254.3 5,062.17 5.0 254.2 5,062.43 6.0 254.2 5,062.69 7.0 254.2 5,062.93 8.0 254.3 5,063.16 9.0 254.3 5,063.35 10.0 254.3 5,063.53 11.0 254.3 5,063.71 12.0 254.4 5,063.87 13.0 254.4 5,064.02 14.0 254.4 5,064.18 15.0 254.4 5,064.33 16.0 254.4 5,064.47 17.0 254.4 5,064.61 18.0 254.4 5,064.74 19.0 254.5 5,064.86 20.0 254.5 5,064.97 21.0 254.5 5,065.09 22.0 254.5 5,065.19 23.0 254.5 5,065.29 24.0 254.5 5,065.38 25.0 254.5 5,065.47 26.0 254.5 5,065.55 27.0 254.5 5,065.62 28.0 254.6 5,065.69 29.0 254.6 5,065.76 30.0 254.6 5,065.78 AVERAGE 254.4 5.064.07 Date: May 4, 2008 257 255 a 253 ~' ~ 251 249 247 Temperature Data Ob`EM WE~( spy ~ ~: Q 9~ f" N PROACT{VE DIAfjNMTIC Sf RVICEf Start time: 20:14:00 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes 5070 5060 a a 5050 5040 5030 0 Page 2 Pressure Data 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes B.P. Exploration (A/askaJ. lnc. NS-05 North Star North Slope 7 7,023' TI/Dss M.D. = 93,765' Static Temperature /Pressure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 253.5 5,057.42 0.5 253.4 5,057.48 1.0 253.4 5,057.53 1.5 253.4 5,057.58 2.0 253.4 5,057.62 2.5 253.4 5,057.66 3.0 253.4 5,057.69 3.5 253.4 5,057.72 4.0 253.4 5,057.74 4.5 253.4 5,057.76 5.0 253.4 5,057.78 5.5 253.4 5,057.80 6.0 253.4 5,057.81 6.5 253.4 5,057.82 7.0 253.4 5,057.83 7.5 253.4 5,057.84 8.0 253.4 5,057.85 8.5 253.4 5,057.86 9.0 253.4 5,057.87 9.5 253.4 5,057.88 10.0 253.4 5,057.89 10.5 253.4 5,057.89 11.0 253.4 5,057.90 11.5 253.4 5,057.91 12.0 253.4 5,057.91 12.5 253.4 5,057.92 13.0 253.4 5,057.92 13.5 253.4 5,057.93 14.0 253.4 5,057.94 14.5 253.4 5,057.94 15.0 253.4 5,057.94 AVERAGE 253.40 5,057.80 Date: May 4, 2008 Ob`EM WE ~~ SpF 4°- c~v i ~- PROACTIVE DIAC,NOfTIC SE RVItEf Start time: 20:47:00 Temperature Data 257 255 a 253 ~' ~ 251 249 247 Page 3 B.P. Exp/oration (A/askaJ. lnc. NS-05 North Star North Slope 90,973' TVDss M.D. = 93,793' Static Temperature /Pressure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.3 5,051.71 0.5 250.2 5,051.80 1.0 250.2 5,051.88 1.5 250.2 5,051.94 2.0 250.2 5,051.98 2.5 250.2 5,052.01 3.0 250.1 5,052.03 3.5 250.1 5,052.03 4.0 250.1 5,052.03 4.5 250.1 5,052.03 5.0 250.1 5,052.02 5.5 250.1 5,052.01 6.0 250.1 5,052.00 6.5 250.1 5,051.98 7.0 250.1 5,051.97 7.5 250.1 5,051.95 8.0 250.1 5,051.94 8.5 250.1 5,051.92 9.0 250.1 5,051.91 9.5 250.1 5,051.89 10.0 250.1 5,051.88 10.5 250.1 5,051.87 11.0 250.0 5,051.85 11.5 250.0 5,051.84 12.0 250.0 5,051.83 12.5 250.0 5,051.82 13.0 250.0 5,051.81 13.5 250.0 5,051.80 14.0 250.0 5,051.79 14.5 250.0 5,051.78 15.0 250.0 5,051.77 AVERAGE 250.1 5,051.90 Date: May 4, 2008 Temperature Data L~/ 255 a 253 ~' ~ 251 249 247 obtEM WEl( SAF 4~ c~v ,,, %. s ~ PROACTIVE DI~QNOSTIC SFRVICFf Start time: 21:06:00 0 1 2 3 4 5 s 7 8 9 10 11 12 13 14 15 Minutes 5070 Soso a vs 5050 a so4o 5030 ~ i ~+ i i ~-~-{ ++ i i+~ ~ ~ i i i i ~~ i i i i i i 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 4 Pressure Data e.P Exp~oratlon ~AlaskaJ.1~~. Static Temperature/ Pressure Survey NS-05 North Star North Slope 7 9,023' TVDss M.D. = 93,765' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 253.0 5,058.27 0.5 252.9 5,058.18 1.0 253.0 5,058.10 1.5 253.0 5,058.01 2.0 253.0 5,057.94 2.5 253.0 5,057.88 3.0 253.1 5,057.83 3.5 253.1 5,057.80 4.0 253.1 5,057.77 4.5 253.1 5,057.76 5.0 253.1 5,057.74 5.5 253.1 5,057.74 6.0 253.1 5,057.74 6.5 253.1 5,057.74 7.0 253.1 5,057.74 7.5 253.1 5,057.75 8.0 253.1 5,057.76 8.5 253.1 5,057.77 9.0 253.1 5,057.78 9.5 253.1 5,057.79 10.0 253.1 5,057.80 10.5 253.1 5,057.81 11.0 253.1 5,057.82 11.5 253.1 5,057.83 12.0 253.1 5,057.84 12.5 253.2 5,057.85 13.0 253.2 5,057.86 13.5 253.2 5,057.87 14.0 253.2 5,057.88 14.5 253.2 5,057.89 15.0 253.2 5,057.90 AVERAGE 253.1 5.057.85 Date: May 4, 2008 Ob~EM WE[( SAF 4~ c~9 s ~• l'roAcrive Di~yNOSric scavices Start time: 21:24:00 Temperature Data 257 255 .......................................................................................................................................................................................................................................... a 253 ... ... ... .... ... .. ... ... ... ... ~' ~ 251 ..................................... .................................................................................................................................................................................... ........ 249 ...................................................................................... ~ ..................................... ~ ................................................................................ 247 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5070 5060 a us 5050 a 5040 5030 I i i !T+ -r i+ i! i t+ t+! i i i i t+ FTi i!! i 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Page 5 Pressure Data B.P. Exploration (A/askaJ. lnc. Static Temperature/ Pressure Survey NS-05 North Star North Slope 90,872' TVDss M.D, = 93,607' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 249.2 5,038.58 0.5 249.2 5,038.71 1.0 249.2 5,038.83 1.5 249.1 5,038.91 2.0 249.1 5, 038.97 2.5 249.1 5,039.02 3.0 249.0 5,039.04 3.5 249.0 5,039.06 4.0 249.0 5,039.06 4.5 249.0 5,039.05 5.0 249.0 5,039.04 5.5 249.0 5,039.03 6.0 249.0 5,039.02 6.5 249.0 5,039.00 7.0 249.0 5,038.98 7.5 249.0 5,038.96 8.0 249.0 5,038.94 8.5 248.9 5,038.93 9.0 249.0 5,038.91 9.5 248.9 5,038.89 10.0 248.9 5,038.88 10.5 248.9 5,038.86 11.0 248.9 5,038.85 11.5 248.9 5,038.83 12.0 248.9 5,038.82 12.5 248.9 5,038.81 13.0 248.9 5,038.79 13.5 248.9 5,038.78 14.0 248.9 5,038.77 14.5 248.9 5,038,76 15.0 248.9 5,038.75 AVERAGE 249.0 5.038.90 Date: May 4, 2008 Ob`EN- WE[[ SAF QQ.. °~v s ~- PlOACTIVE UTAfjMOITIC SERVICES Start time: 21:42:00 Temperature Data 257 I 255 ...................................................................................................... ................-.......-...-... ~ ....-..............-.-.................................... LL 253 ............................................................................................ ..................................................................................................................................... ~' ~ 251 ................................................................................................................................................................................_.........................-...- 249 ... .... ... ... 247 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5070 5060 a rn 5050 a 5040 5030 0 1 Page 6 Pressure Data 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes B.P. Exploration (A/askaJ. lna StC~tiC T@/17~78/'c7tU/'e~ P/'G'SSU/'E SU/'VBJ/ NS-05 North Star North Slope Surface -After POOH Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 29.1 3,478.98 0.5 29.2 3,479.17 1.0 29.1 3,479.36 1.5 28.8 3,479.52 2.0 28.9 3,479.67 2.5 28.7 3,479.80 3.0 28.3 3,479.91 3.5 28.2 3,480.01 4.0 28.2 3,480.09 4.5 28.2 3,480.16 5.0 28.1 3,480.21 5.5 27.9 3,480.25 6.0 27.8 3,480.27 6.5 27.7 3,480.28 7.0 27.6 3,480.29 7.5 27.7 3,480.28 8.0 27.6 3,480.27 8.5 27.5 3,480.25 9.0 27.5 3,480.22 9.5 27.3 3,480.19 10.0 27.3 3,480.15 AVERAGE 28.1 3,479.97 Current Wellhead Read in s Wellhead Pressure (psig) : 3,450 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : N/A Outer Annulus Pressure ( sig) : N/A Date: May 5, 2008 Temperature Data 35 LL ~+ 30 D 25 20 Ob~EM WEl(SA6 Qa c~v s -- N PRO/tCTIVE ~IACjROSTIC sERVICES Start time: 0:13:00 0 1 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 3600 3575 ................................................................................................................................................................................................................................... ~ 3550 ................................................................................................................................................................................................ .......................... 3525 ......................................................................................................................................................................................................................................... a v~ 3500 ............. .................................... a 3475 .............................................................................................. ........................................................................................................ 3aso ......................................................................................................................... ........................................................................................... 3425 ............................................................................................................................. 3400 0 1 2 3 4 5 6 7 8 9 10 Minutes Page 7 B.P. Exploration (A/askaJ. /na Statii~ TB/I7~f7iB/'c~tU/'E~ PrieSSU/'B SU/'VBJ/ Nar7' DJr ob~EM WE([ fpE' North Star p c' = v~ North Slope i- Downho% Temp/P~ess PRaACTivE DIAfjNOSTIC SERVICES Date: May 4, 2008 Start time: 18:20:00 End time: 0:24:00 257 255 aL 253 ci m ~ 251 249 247 Temperature Data -200 0 200 400 600 800 1000 1200 1400 1600 Minutes Page 8 • •i by • Date 04-15-2008 Transmittal Number:92956 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf crn„ haves anv rniactinnc nla~acc ~nntact TnP T .actnfka at (9(171564-4n91 Delive Contents Well Name Date Contractor Lo Run Top De th Bottom De th Lo T e NS05 03-11-2008 SCH 1 13600 13850 PERFORATION RECORD NS16 03-06-2008 SCH 1 0 12200 FREE POINT INDICATION LOG ~:~ a Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka ~~p 3 ~~~~ Petrotechnical Data Center ;~t~ BPXA David Fair AOGCC Christine Mahnken Murphy Exploration Ignacio Herrera DNR Kristin Dirks MMS Doug Chromanski ~~s os ~~1~NNE~ APR 2 4 200 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~.~~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SIOf~ RECEfVE[~ APR 1 6 2008 REPORT OF SUNDRY WELL OPERA,,~IQI~J,~Q „_ ~__ „ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulat ~ r en Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ aiver [] Time xL~1Y~~ acid treatment 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 205-0090 3. Address: P.O. Box 196612 Stratigraphic S8MC8 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.37 KB ( NS05 ' 8. Property Designation: 10. Field(Pool(s): ADLO-312808. NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14033 ' feet Plugs (measured) None true vertical 11335.58 ~ feet Junk (measured) None y f~ APR `~~ ~ ~ 2008 Effective Depth measured 14027 ~ feet true vertical 11329.83 feet Casing Length Size MD TVD Burst Collapse Surface 3147' 13-318" 68# L-80 40' - 3187' 40' - 3183' 4930 2270 Intermediate 11663' 9-5/8" 53.5# L-80 39' - 11702' 39' - 9401' 7930 6620 Liner 2012' 7" 29# L-80 11525' - 13537' 9294' - 10682' 8160 7020 Liner 674' 4-1/2" 12.6# 13Cr80 13357' - 14031' 10689' - 11334' 8430 7500 Perforation depth: Measured depth: 13704 - 13794 True Vertical depth: 11021 - 11107 _ _ _ _ Tubing: (size, grade, and measured depth) 4-1%2" 12.6# 13Cr80 37 - 13366 0 0 - Packers and SSSV (type and measured depth) 4-112" TRM-4E SSV 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: , a Y , ~ ~ ry 1(} 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3918 26418 2350 786 Subsequent to operation: 4006 28503 2381 797 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: 308-055 Contact Robert Younger Printed Name Robert Yot er Title Production Engineer Signature Phone 564-5392 Date 4/16/2008 Form 10-404 Revised 04!2006 ~ ~ ~ ~ ~ ~~ ~ L Submit Original Only l 'lam CJ NSOS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARIT - - ` ACTIVITYDATE ~ SUMMARY 3/11/2008??****WELL SHUT IN UPON ARRIVAL**** JOB SCOPE - RE-PERF ';:'INITIAL T/I/O = 3300/350/400 PSI. TIED INTO SCHLUMBERGER USIT DATED ' 4-11-2005 RE-PERF INTERVAL: 13763'-13794', SHOT 2-7/8" PJ 2906, 6 SPF, 60 DEG PI-I4C1~I(2 API DATA: EHD: 0.36", TTP: 27.7". ALL SHOTS FIRED. FINAL T/I/O = 3400/3501400 PSI. DSO POPPED WELL ON DEPARTURE ***JOB COMPLETE*** 4/4/2008CTU #5. Acid Stimulation. Standby on well, rigged up while e-line finishes working on NS-16A. Perform BOP test. Continue standby waiting for e-line to complete ;operations on NS-16. *** Job continued on WSR 04/05/2008 *** 4/5/2008:;CTU #5, Acid Treatment; Cont' from WSR 4/04/08 ... Standby for completion of '!,NS-16 perforating. Complete rig up with LRS and CH2MHill. *** Continued on WSR 04106/08 *"* 4/6/2008CTU #5. Acid Stimulation. *** Continued from WSR 04/05/08 *** Finish rig up with ;.LRS. InterACT publishing. Shut in well and load well with 10 bbls of 60/40 meth, 225 bbls of 2% KCI, 50 bbls of 2% KCI with 0.6% Safelube and 50 bbls of diesel, ''RIH with 2.5" JSN. Dry tag down at 13962' ctmd. PUH, PU clean at 13953' ctmd. :'..Pump 44 bbls of 12% HGL w/ 10% L66 inhibitor while jettinglreciprocating from ~ ~iuu to ~ ~uuu taKln no returns. uveniusn aclo to rormatlon wlcn ~ 4u Dols or 2% KCL w/ 10% L66 in ibitor.'~I7FiP climbed steadily while pumping overflush into formation. POOH replacing voidage. Initial injectivity = 1.5 bpm @ 850 psi WHP. Final injectivity = 1.5 bpm @ 1575 psi WHP. Soak well for 5 hrs. Turn well over to N* control. RD CTU #5. *** Job Complete *** FLUIDS PUMPED BBLS 274 2%KCL 50 2% KCL W/SAFELUBE 50 DIESEL 60 60/40 METH 44 12% HCL W/10% L66 INHIBITOR (TITRATION=12.7%; IRON<50 PPM) 140 2% HCL W/10% L66 INHIBITOR 614 TOTAL + STATE OF ALASKA /~~ ZOOS MAR 1 7 AL A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~aska Oil & Gas Cons. CwnrYt 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 205-0090 ' 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number. Anchorage, AK 99519-6612 50-029-23244-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.37 RT ' NS05 ' 8. Property Designation: 10. Field/Pool(s): _ ADLO-312808 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14033 ~ feet Plugs (measured) None true vertical 11335.58 , feet Junk (measured) None Effective Depth measured 14027 _ feet true vertical 11329.83 ; feet Casing Length Size MD TVD Burst Collapse SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 INTERMEDIATE 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 LINER 2012 7" 29# L-80 11525 - 13537 9294 - 10861.72 8160 7020 LINER 674 4-1 /2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 ~ APR f~ ~ 2RD Perforation depth: Measured depth: SEE ATTACHMENT True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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 welt operation: 3812 23832 2060 0 785 Subsequent to operation: 4687 29879 2455 0 808 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: 308-055 Contact Robert Younger Printed Name Robert Younger Title Production Engineer ~.,..._ Signature Phone 564-5392 Date 311712008 Form 10-404 Revised 04!2006 ,~' ~~ ~,~ Submit Original Only • NS05 205-0090 PERFORATION ATTACHMENT MD MD H TVD TVD 4/12/2005 5/28/2005 6/28/2005 9/20/2005 3/11/2008 13,704 13,707 3 11,021.00 11,024.00 APF 13,707 13,719 12 11,024.00 11,035.00 APF 13,707 13,727 20 11,024.00 11,043.00 APF 13,719 13,727 8 11,035.00 11,043.00 APF 13,727 13,734 7 11,043.00 11,049.00 APF 13,734 13,739 5 11,049.00 11,054.00 APF 13,739 13,764 25 11,054.00 11,078.00 APF 13,739 13,794 55 11,054.00 11,107.00 PER RPF ~ 13,763 13,764 1 11,078.00. 11,078.00- APF 13,764 13,794 30 11,078.00 11,107.00 RPF APF • NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTfVITYIJATE SUMMARY 3/10/2008 *"*WELL FLOWING ON ARRIVAL'`"" DRIFT WITH 2 7/8" DG, XN LOCATOR AND SAMPLE BAILER FOR UPCOMING RE-PERF. TAG CLEAN BOTTOM AT 13988' MD. NO OBSTRUCTIONS. BAILER EMPTY. `. "**WELL S/I, TURNED OVER TO DSO''*" 3/11/2008 "'""`WELL SHUT IN UPON ARRIVAL'''''* JOB SCOPE - RE-PERF :INITIAL T/I/O = 3300/350/400 PSI. TIED INTO SCHLUMBERGER USIT DATED 4-11-2005 ~ RE-PERF INTERVAL: 13763'-13794', SHOT 2-7/8" PJ 2906, 6 SPF, 60 DEG `PHASING. ',API DATA: EHD: 0.36", TTP: 27.7". ALL SHOTS FIRED. FINAL T/I/O = :3400/350/400 PSI. DSO POPPED WELL ON DEPARTURE """JOB COMPLETE""` FLUIDS PUMPED BBLS 1 diesel 1 Total • • MICROFIL~AED 03/01 /2008 DO NOT PLACE ANY NEW ~IIATERIAL UNDER THIS PAGE ~: F:1LaserFiche\CvrPgs_InsertslMicrofilm Marksr.doc • ~lG,ls~~ ~G ~'~I~~,sf,~Q /,.,,,T..Po~..o. ~-7SA OIL taisil GAS 333 W. 7th AVENUE SUITE 100 C01~5ERQA'rIO1~T COMI-IIS5I01'1T , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer D ~ BP Exploration Alaska, Inc. ~~~~ PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, North Star Oil Pool, NS05. Sundry Number: 308-055 ~~~ FEB ~ 0 2Q0~ 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 ft 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 February, 2008 Encl. • RECEIVED STATE OF ALASKA FEB Y ~ 20~~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Alaska q~ & Gas Cons. Commission 20 AAC 25.280 Snchnrona 1. Type of Request: Abandon Suspend Operational shutdown Perfo ~ Waiver Othe Alter casing ^ Repair well ^ Plug Perforations ^ Stimu~ Time Extension ^ CTU Acid Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development0 Exploratory ^ 205-0090 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS05 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312808 56.37 RT 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): 14033 11335.58 14027 11329.83 NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 Liner 2012 7"29# L-80 11525 13537 9294 10862 8160 7020 Liner 674 4-1J2" 12.6# 13cR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13704 - 13794 11021 - 11107 4-1/2" 12.6# 13CRVAM-ACE 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 2/28/2008 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 Ro Yo ger Title Production Engineer Signature Phone 564-5392 Date 2/14/2008 COMMISSION USE ONLY mb r ~ ^O diti N tif i th S d N C f l C i t t ti it : on ons o approva y omm un ry e : o ss on so a a represen a ve may w ness u Plug Integrity ^ BOP Test ^ Mech anical Integrity Test ^ Location Clearance ^ - `~ Other: 7J~D~ psi M~h~ r'`~~t~~_~`! ~ P ~ ~'~' ~~, i=ER 2 ~ 2DOD Subsequent Form Required: APPROVED BY 7 1 1 ~ ~ ` F Approved by: COMMISSIONER THE COMMISSION Date. L• v Form 10-403 Revised 06/2006 uuNUCATE Submit in Duplicate ' • • PERFORATING PROCEDURE VB"e0~ea01 RDW r~~us.~ea Well: NS05 ...................................................... API #: 50-029-23244-00 ......... ................... ..... ....... .. . Date: 02/08/08 g g . .... . ... Prod En r Robert Youn er Office Ph: 564-5392 H2S Level: Home Ph: 677-2599 None Anticipated Cell Ph: ............... 830-4920 ......................................... CC or AFC: NSFLDWL05 Detail Code: Description: Drift,to.TD.with,Dummy.Gun,.Perforate WBL Entries IOR Type Work Description 400 S Drift to TD with Dummy Gun -Coordinate w/ per-coil drift currently on the WBL. 400 E Perforate 13,764'-13,794' MD Well Objectives and Logaing Notes: For the a detailed NS05 well history, please see Coil Acid Treatment currently on the WBL. If possible, please incorporate the dummy gun run drift into the pre-coil drift. Please plan to perforate the proposed RePerfs prior to the planned coil tubing acid treatment, which will likely be mid- March. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed pertorations are an attempt to increase production by re-perforating the lower 30' of the existing perforations. The proposed reperfs will provide insight into the potential of adperfs closer to the Oil Water Contact. Please note that the perforations will be dependent on the drift information. Please contact Bob Younger with any questions, comments, or concerns - 564-5392 (w); 830-4920 (c); 677-2599 (h). Attachment: Reference Log with annotated pertorations. to the tie-in log to be on depth with the reference log. Feet SPF Orient. Phasing Zone 30' 6 60° 0 Ivishak 0 0 0 Gas Jetting Expected? No At what Depth? N/A Ad/Re/Iperf RePerf Requested Gun Size: 2.875 Charge: 2906 PJ Desired Penetration: 25.3 Entry Hole Diam: .0:38 Is Drawdown Necessary/Desired/Unnecessary During Perforating NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Describe below how to achieve drawdown (check w/ Pad Operator to see it necessary piping is installed) (e.g. N2 Li/t, Hardline Liff Gas, Gas Liff, Flow Well, BacMlow Through Drain or Hardline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tie into Jewelry ~ MD Tie in using: Minimum ID: 3.725 in Min ID Type: .4:5".XN NiPPIe C~ 13,351 'MD WLEG Depth: 13.366 ft MD Casing Size: 4:5 in 12.6# 13-CR Liner Est Res. Pres. ~ 13,646 MD -11100' SS -5100 psi Last Tag: ,13,950 ft SLMD on .2/14/2007 3.5" Bailer well: Nsos Perforation Summary Date: API #: 50-029-23244-00 On-Site Prod Engr: General Comments: PBTD O/B/U - O CN ULTRA SONIC IMAGING LOG ~ ~ CEMENT BOND LOG WITH PDC GAMMA RAY J ~' z 11-APRIL-2005 ~ O 1089' FSL & 641' FEL Elev.: K.B. 56.37 ft ¢ G.L. 15.67ft s LL a ~ SURFACE LOCATION D.F. 56.37 ft ~ c> o w U Permanent Datum: MSL Elev.: O ft O z c .- m z a m p ~ Log Measured From: RKB 56.4 ft above Perm. Datum c W Drilling Measured From: RKB ~ ~ m a E API Serial No. Section Township N Range 13E i~ 3 Cg 50-029-23244-00 11 13 in Date 11- r-2005 Run Number - 1 De t h Dr iller - - - - `-- _- 14027 ft SChl umb er e r 14015 ft Bottom Log Interval 14008 ft From 1 ft ft PUP PUP 13300 PUP GAUGE PUP PUP PKR PUP PUP X-NIP PUP iU!-NIP PUP 13400 ~~ ~~. 13700 Exist as of 1370 1373 Proposed Perfs 13764'-13794` 13800 Oil Water Contact 13846' M 13900 14000 u~U~7~ ~ J1 ~ ~!~~u~ ~ I ~l ~U n ALASSA OIL AHD G -~i' COH5ERQA'TIOH COM1~II551OH Robert Younger Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS05 Sundry Number: 308-037 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~5~~~~ Dear Mr. Younger: '~ ~ ~ FED ~ ~~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of February, 2008 Encl. Sincerely, ~C~,,,C1~/CV • ~ ,~ ~' JAN ~ 1 ~p(?$ ~( ~~ STATE OF ALASKA AI ska Oil & Gas Cpns. Corr~rnss;t~~ ALASKA OIL AND GAS CONSERVATION COMMISSION - APPLICATION FOR SUNDRY APPROVAL ~(~ ~'~~~`~~~~ ~n AAC: ~~ ~Rn 1. Type of Request: Abandon Suspend Operational shutdown Perfo Waiver ^ Othe Alter casing ^ Repair well ^ Plug Perforations ^ Stimu~ Time Extension ^ CTU Acid Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Treatment 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development0 Exploratory ^ 205-0090 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: NS05 / Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): s ADLO-312808 ~ 56.37 RT , 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): 14033 11335.58 ~ 14027 i 11329.83 - NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 Liner 2012 7"29# L-80 11525 13537 9294 10862 8160 7020 Liner 674 4-1/2" 12.6# 13cR80 13357 14031 10689 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13704 - 13794 11021 - 11107 4-1/2" 12.6# 13CRVAM-ACE 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Top Packer 11525 7" 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 2/12/2008 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 Ro Younger Title Production Engineer Signature Phone 564-5392 Date 1/29/2008 COMMISSION USE ONLY Number: ~~ ~ ~~ nditi f r l N tif m Sund C C t ti it i i th t ova : y ry o ons o app o o a represen ve may w ness m ss on so a a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: L1A~~ PS l 2 0~ ~~ Subsequent Form Required: ~U~ APPROVED BY o Q ~r Approved by: CO ISSIONER THE COMMISSION Date: ~ (f Form 10-403 Revised 06/2006 G ~ n' n ~ Submit in Duplicate No portion of the belo~ork should be performed w/out fi~aking time to ensure No Accidents, o harm to People, and No damag the Environment To: Jerry Bixby/Clark Olsen -Well Operations Supervisor January 28, 2008 From: Robert Younger - Northstar Production Engineer Subject: NS05 CTU Acid Treatment AFE NSFLDWL05 Est. Cost: $150 M Est. IOR: 1000 BOPD Please perform a coil tubing acid treatment on NS05 per the below procedure: Type IOR PR N DSWL AFE Job Description S 1000 NS05 NSFLDWL05 Drift to TD -Slope Discretion C 1000 NS05 NSFLDWL05 Pump Acid Treatment Current Status: Producer Last Test: 01/22/08: BOPD: 3552, BWPD: 2119; MMCFPD: 25.6 Max Inclination: 55° at 7693' md; 26° at Perfs Max Dog Leg: 4.6° at 4,953' and Perforations: 13,707' - 13,794' and Minimum ID: 3.725" C 13351' md, 4.5" XN Nipple Last TD tag: 02/14/07: Ran 3.50" cent. w/ 3.80" xn locator tagged td @ 13,950' slm + 21' correction = 13,971' and Last Downhole Op: 03/19/07: CTU Acid Scale Inhibition Treatment Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP: 5,062 psi @ 11,100 ft ss, 7/23/06 NS05 was completed in April 2005. Prior to a large water based scale inhibition treatment in May 2005, the well was tested at 8900 BOPD and 8% WC. Following the 05/20/05 stand alone scale inhibition treatment consisting of Baker SCW-4004 Phosponate/Polymer, the rate dropped to 2300 BOPD. The well was re-perforated on 05/28/05 in an attempt to restore production. The production increased to 4200 BOPD at 18% WC. In June 2005, additional adperfs shot higher in the section increased production to 6000 BOPD at 16% WC. A combination acid/scale inhibitor treatment was completed in August 2005. The initial test post treatment was 5350 BOPD with a 16% WC. At this point the well started a sharp decline and by September the rate had fallen to 2500 BOPD at a 1 % WC. On 09/20/05 re-perfs and ad-perfs were shot in an attempt to bypass the damage and increase rate. The reperfs/adperfs increased the rate to 4700 BOPD at a 1 % WC. NS05 was identified as a coil acid candidate due to loss of water following the August 2005 bullhead treatment. The 04/01/06 coil treatment increased the oil rate by 1500 BOPD and also returned the water production. Another combination CTU acid treatment/scale inhibitor treatment was completed 03/13/07 resulting in a 2200 BOPD increase. Based on the historical rate benefits from treating NS05, the treating frequency was increased and another CTU acid treatment was performed 08/09/07 resulting in a 800 BOPD increase. Based on the historical rate benefits of treating NS05, the below CTU acid/scale inhibition treatment is proposed. No portion of the belo~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment 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 Rigfess Operations Manual: Coiled Tubing Operations Section: CTU Operations at Northstar Island DRIFT WITH SLICKLINE: Slope discretion 02/14/07: Ran 3.50" cent. w/ 3.80" xn locator tagged td C~ 13,950' slm + 21' correction = 13,971' and 2. RU slickline. 3. RIH with slickline to TD. Note if scale is encountered. COIL TUBING ACID/SCALE INHIBITION TREATMENT: 4. Mobilize coil unit, pumps, tanks and acid transport to Northstar. 5. MIRU. 6. 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. 7. 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. 8. PT Dowell surface lines to 5000 psi. 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 9. Bullhead kill with filtered 2% KCI (volume to top pert is 208 bbls). Please leave a 50 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 10. RIH with jetted nozzle (min ID = 3.725"). Drift to below perforations to insure no obstructions exist. 11. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 50 bbls Acid w/ 10% L66 b) 140 bbls 2% KCI w/ 10% L66 (90 bbls provides 5' radial displacement, but 140 bbls required to meet scale inhibitor meet L66 ) 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. 12. Shut well in for 4 hours after injection to allow scale inhibitor to precipitate. 13. 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: 14. After 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 480 bbls (Tubing 208 bbl + Treatment 190 bbl + Flowline 82 bbl). After clean-up, divert back to the plant and get 2 6-hour tests. 15. Post Flowback, please notify Mark Isam with Vetco at 907-262-5606 to service the tree post acid treatment. No portion of the bel~ork should be performed w/out f~taking time to ensure No Accidents, o harm to People, and No damag the Environment P, Exploration hort Well Name: NSOS Name:NORTHSTAR NO05 Op 500292324400 Dri ~d Date: 2005-02-16 00:00:00 X C asurement Ref: RT y C Elevation: 56.37 De m r - m m < i' m D .Z ] m _~ r [ n O y ~ 0 Z r m .D ~ best _pef ' I rn ~ m O I ~ ~ 2 ~ ~. HHST.GI 1 ~~- 13'00 TSHD __ --- TSH '--- = ~ .11000 13'50 ---- Taa --- ~ ua5o 13800 -- Ta ca - IJ850 11100 ---- TZ C2 ~~~ 13900 ~ 1 11.=.0 Procedure Contacts: Robert Younger W K: 564-5392 H M: 677-2599 Cell: 830-492 I STATE OF ALASKA - ALAS A Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56.37 RT / 8. Property Designation: ADLO-312808 ( 11. Present Well Condition Summary: Total Depth measured true vertical 14033 I feet 11335.58' feet Ø;;1 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate D Other 0 ACID TREATMENT Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 205-0090 / Exploratory SeiV1ce 6. API Number: 50-029-23244-00-00 - 9. Well Name and Number: NS05 / 10. Field/Pool(s): . _.. NÇ)RTHSTAR Field/ NORTHSTAR OIL Pool Plugs (measured) Junk (measured) D AUG 2 2 2007 None None SCANNED AUG 2 8 2007 Alaska Oil & Gas Cons. Commi ,. Effective Depth measured 14027 , feet Anchorage true vertical 11329.83 , feet Casing Length Size MD TVD Burst Collapse SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 INTERMEDIATE 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 .:..7930 6620 IV\ LINER 2012 7" 29# L -80 11525 13537 9294 - 10881 :'12 ~160 7020 LINER 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 Perforation depth: Measured depth: 13704 - 13707 True Vertical depth: 11021 - 11024 Measured depth: 13739 - 13764 True Vertical depth: 11054 - 11078 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations QiI-Bbl 4424 5243 x 13707 - 13719 11024 - 11035 13764 - 13794 11078 -11107 4-1/2" 12.6# 13727 - 13734 11043 - 11049 13734 - 13739 11049 - 11054 13719 - 13727 11035 - 11043 13C r80 37 - 13366 4-1/2" TRM-4E SSV 7" Top Packer 7" 13Cr80 Packer 4-1/2" Liner Top Packer 994 11525 13310 13357 RBDMS BFL AUG 2 7 Z007 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 16865 2083 0 19441 2878 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 755 771 SeiV1ce WDSPl WINJ 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: 307 -235 Contact Robert Younger Printed Name Robert Yoµ.o§er ß# Signature GINAI I' Title Production Engineer Phone 564-5392 Date 8/21/2007 . . .. NSOS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY *** Job In Progress*** MIRU CTU#5, Acid Treatment, *** drift of coil. Perform BOPE test(pass) not publishing***Pump 1.25" ball for Job Continued on 8-09-07 8/9/200 ssist CTU as directed w/Acid Treatment #5 Acid Treatment ***Job Continued From 8-08-07 WSR***Hold ATP with all on location, Bullhead kill well with 2% KCL, complete Acid Treatment into perfs as per procedure. Return well to Control Room to put on production. *** Job Completed*** FLUIDS PUMPED BBLS 315 2% KCL 80 2% KCL w/0.6% SAFELUBE 7 METHANOL 50 12% HCL 50 DIESEL 502 TOTAL . ~1f~1fŒ (ID~ ~~~~æ~ . AI1ASIiA. OILA5D GAS CONSERVATION COMMISSION / SARAH PAUN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 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, NS05 Sundry Number: 307 -235 SCANNED JUL 1 8 2007 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, DATED this /hay of July, 2007 Encl. c9b 6--0 C)O¡ Abandon Alter casing 0 Change approved program 0 ~. " . 1. Type of Request: 2. Operator Name: I STATE OF ALASKA 1;-17"'01. ~ ALA A Oil AND GAS CONSERVATION COMMI N I." APPLICATION FOR SUNDRY APPROVAL H- h~ 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Developm ent ø Suspend Repair well 0 Pull Tubing 0 Perforate Waiver Stimulate 0 ~ Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: tlfr1fl¡'ç.. . I,;SiO, Exploratory 0 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Stratigraphic 0 6. API Number: Service 0 Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer DescriDtive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 11. Total Depth MD (ft): 14033 Casing SURFACE INTERMEDIATE LINER LINER Perforation Depth MD (ft): 13704 - 13794 Packers and SSSV Type: 12. Attachments: Commencing Operations: 16. Verbal Approval: Commission Representative: 205-0090 50-029-23244-00-00 8. Well Name and Number: NS05 . ADLO-312808 No 0 10. KB Elevation (ft): 11. Field/Pools(s): 56.37 RT NORTHSTAR Field / NORTHSTAR OIL Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11336 14027 11329.83 - None None Length Size TVD Burst Collapse 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 11663 9-5/8" 53.5# L-80 39 11702 39 9401 7930 6620 2012 7" 29# L -80 11525 13537 9294 10862 8160 7020 674 4-1/2" 12.6# 13Cr80 13357 14031 10689.25 11334 8430 7500 Perforation Depth TVD (ft): 11021 ·11106.67 Tubing MD (ft): 37 - 13366 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 994 11525 13310 13357 13. Well Class after proposed work: Exploratory 0 Developm ent ø Service 0 7/20/2007 Date: 15. Well Status after proposed work: Oil ø Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by Ui:lry ....rtmle 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert Younger Title Contact Robert Younger Production Engineer 6/29/2007 Signature Date Phone 564-5392 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2/)7 - ~35 Plug Integrity 0 BOP Test þZJ Mechanical Integrity Test 0 Location Clearance 0 Other: ~(J()O{>c;:\ N\.\ f\..\ ........-..)~ <..."\ '3t)~ ~~~ Approved by: APPROVED BY THE COMMISSION ,rJf JUL 1. 82007 ¿ ~ 7/Í' ~ Submit in Duplicate Date: · No portion of the belo!Ork should be performed w/out r.aking time to ensure d No Aceldem., 0 hann to Poopl., and No damag tho Environment To: Jerry Bixby/Clark Olsen - Well Operations Supervisor July 12, 2007 From: Robert Younger - Northstar Production Engineer Subject: NS05 CTU Acid Treatment AFE NSFLDWL05 Est. Cost: $150 M Est. lOR: 1500 BOPD Please perform a coil tubing acid treatment on NS05 per the below procedure: Current Status: Last Test: Max Inclination: Max Oog Leg: Perforations: Minimum 10: Last TO tag: AFE Job Descri tion NSFLDWL05 Pum Acid Treatment Producer 07/01/07: BOPO: 3.930, BWPO: 1,908; MMCFPO: 17.28 55° at 7693' md; 26° at Perfs 4.6° at 4,953' md 13,707' - 13,794' md 3.725" @ 13351' md, 4.5" XN Nipple 02/14/07: Ran 3.50" cent. w/ 3.80" xn locator tagged td @ 13,950' slm + 21' correction = 13,971' md Last Oownhole Op: 03/19/07: CTU Acid Scale Inhibition Treatment Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 06/11/07 BHP: 5,062 psi @ 11,100 ft ss, 7/23/06 NS05 was completed in April 2005. Prior to a large water based scale inhibition treatment in May 2005, the well was tested at 8900 BOPO and 8% WC. Following the May 20,2005 stand alone scale inhibition treatment consisting of Baker SCW-4004 Phosponate/Polymer, the rate dropped to 2300 BOPO. The well was re-perforated on May 28, 2005 in an attempt to restore production. The production increased to 4200 BOPO at 18% WC. In June 2005, additional adperfs shot higher in the section increased production to 6000 BOPO at 16% WC. A combination acid/scale inhibitor treatment was completed in August 2005. The initial test post treatment was 5350 BOPO with a 16% WC. At this point the well started a sharp decline and by September 16 the rate had fallen to 2500 BOPO at a 1 % WC. On September 20, 2005 re-perfs and ad-perfs were shot in an attempt to bypass the damage and increase rate. The reperfs/adperfs increased the rate to 4700 BOPO at a 1%WC. NS05 was identified as a coil acid candidate due to loss of water following the August 2005 bullhead treatment. The April 1, 2006 coil treatment increased the oil rate by 1500 BOPO and also returned the water production. Another combination CTU acid treatment/scale inhibitor treatment was completed 03/13/07 resulting in a 2200 BOPO increase. Based on the historical rate benefits from treating this well the below CTU acid treatment is proposed. No portion of the bel.Ork should be performed w/out tAtaklng time to ensure . No Acclden 0 harm to People, and No damagX the Environment _ 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 add friction reducer to water that will contact the formation due to formation plugging issues. Prep Work: 1. Mobilize coil unit, pumps, tanks and acid transport to Northstar. Order out necessary volume of seawater, 2% KCl, acid, and diesel. COIL TUBING ACID/SCALE INHIBITION TREATMENT: 2. Mobilize coil unit, pumps, tanks and acid transport to Northstar. 3. MIRU. 4. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 5. 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. 6. PT Dowell surface lines to 5000 psi. 7. Bullhead kill with filtered 2% KCI (volume to top perf is 208 bbls). Please leave a 49 bbls diesel cap for an under-balanced flowback. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 8. RIH with jetted nozzle (min ID = 3.725"). Drift to below perforations to insure no obstructions exist. 9. Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 50 bbls Acid b) 90 bbls 2% filtered KCI (Overflush for 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. 12% Acid to contain: 25.0 ppt A 153 4.0 ppt A179 0.6 % A261 0.2 % F103 20.0 ppt l058 0.5 % W054 0.5 % W060 Inhibitor Aid Inhibitor Aid Inhibitor Surfactant, EZEFlO Iron Stabilizer Non-Emulsifying Agent Sludge and Emulsion Preventer · No portion of the No Accidents, should be performed w/out fl harm to People, and No dam ng time to ensure the Environment Note: Acid strength be verified and documented titration leaving Schlumberger~ Please note the acid t¡trations on the WSR and have results available on location. 10. Sch!umberger. Flowback Procedure: 11 . the well to flow into flowback. Produce clean-up volume of the plant and get 2 6-hour separator and well cleanup tank for After clean-up, divert back to 1 Flowback, the tree post acid notify Mark with Vetco at Op Dri xc YC De Ve 1) m ;¡¡ " 00 " ¡= C o m .,,1) '"-I !'.¡::r: 13100 IM50 13-7'$0 r381)O 1~390(I Procedure Contacts: Robert Younger WK: 564-5392 HM: 677-2599 Cel!: 830-492 ~=., . ABB-VGI5-1/S" 51( ~NOTES:***4-1Jr CHROME TBG & LNR""'* W8..lì"!EAO ~ 'ABB-VGI13-5I8" M.1..TBOWt... 5KS NS05 ACTUATOR = KB. REV - 56' BF. REV - 40.1' (CB 15.9') KOP= . 994' 4-112" TRM-4ESSSV w/4-112" X PROFLE. D = 3.S12" Max Angle = 56 @ 7693' Datum M) = Datum TVD- 13-318- CSG, 68#,l-80 BTC, D= 12.415" 3187' µ .. GAS lFT MANJRElS 1ST! MJ 1 TVO DEV 1 TYÆ I VlV ILATCHI roRT 1 DATE 1 L 11 1399714000 10 1 M\«3 I [)MY I 1 103129/051 Minimum ID = 3,725" @ 13351' 4-112" XN NIPPLE TOP OF 1" Lt'R 11525' ið 8~ 19-5IS" CSG, 53.5#, l-SO BTM-C 11702' ~ I I 13261' 4-112" x NP, D= 3.S13" I I 13292" 4-112" FBER OPOC TRANSDUCER. D = 3.958" I tg 13316' I- 1" X 4-112" BKRS-3 PKR. D= 3.958" I ~ 13310' I-~ I · 13340' ... 4-112" X NP, D= 3.S13"I · I - I 13351' 4-112"XNNP,D=3.725"I · I TOP OF 4-112"lJIR 13357' I- ....... I 13366' 4-112"1-ES SB.F AUGNNG M.1..ESHOE I 14-112" TBG. 1~6#, 1~RVAM-ACE. 13366' t- ~ ~ .0152 bpf, D - 3.958 D = 3.958" 11" Lr-R, 29#1ft l-80 Hydri 511, D= 6.184" 13537' -µ .. PERFORATION SlM1ARY ] REF lOG: SWS USIT 4/11/05 ANGLE AT TOP Pffif: 17@ 13707' f'.bte: Refer to Production DB for historical perf data ~ SIZE SPF MffiV Al (M» Opn!Sqz DATE 2-718 6 13707 - 13727 0 06128105 2-7!8 6 13734 - 13764 0 09120105 ~ 2-718 6 13739 - 13794 0 04/12105 2-T!8' 6 13739 - 13794 0 05128105 ~ ~ 14027' I 4-112'lr-R, 12.6#, 13CRVAM-ACE 14031' I .0152 bpf, D = 3.958' DATE REV BY COM\ENTS DATE REV BY COM\ENTS NORTHSTAR 04110105 TA ORIGINAL COM PLETION WB.l: NS05 05105105 GJBIPJC CORRECOON SSSV PffiMT f'.b: "2050090 0012105 GJRlPJC Pffif API f'.b: 50-29-23244 05<'2&'05 WRRIPJC RE-Pffif SEe TNRE 1110005 BJM ORlG DRAFT CORRECTIONS 02!22i06 ROYnLH Pffif CORRECTIONS BP Exploration (Alaska) ;1¡M~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2050090 Well Name/No. NORTHSTAR UNIT NS-05 Operator BP EXPLORATION (ALASKA) INC ~/",J I W Fe.~ )¿~~- API No. 50-029-23244-00-00 MD 14033 /' TVD 11336 ""'- Completion Date 4/12/2005 .; Completion Status 1-01L Current Status 1-01L UIC N ~..._._----~ -~~ ~~~~-_.~--~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -..--,-,-~--_.",..--.------. -~- _._--~...~-~---~._._~--~ .~.~~-- _._.~--.-..--~-~.._-- --~"----_.- DATA INFORMATION Types Electric or Other Logs Run: MWD, LWD, DIR, GR, GYRO, PWD, RES, DEN, NEU, SONIC (ISONI (data taken from Logs Portion of Master Well Data Maint Well Log Information: e Log/ Electr Data Digital Dataset Log Log Run Interval OH/ .ffi: MedlF~t Number Name Scale Media No Start Stop CH Received Comments I nd uction/Resistivity 25 Blu 130 14033 Open 8/24/2005 Vision Service ----------, og Log I nd uction/Resistivity 25 Blu 130 14033 Open 8/24/2005 Vision Service .,.( D C Lis 13184 I ndu ction/Resistivity 179 14049 Open 8/24/2005 MWD & MAD rD 13185 Cement Evaluation 14008 14015 Case 8/24/2005 USIT Cement Bond Log w/PDC GR, 11 April 2005 ~ 13185 Cement Evaluation Blu 14008 14015 Case 8/24/2005 USIT Cement Bond Log I w/PDC GR, 11 April 2005 Jt 'og I nd uction/Resistivity 25 Blu kl) 200 11991 Open 3/16/2006 PB 1 Vision Service og Induction/Resistivity 25 Blu .,...,,, 200 11991 Open 3/16/2006 PB 1 Vision Service t: Perforation 5 Blu 13210 14002 Case 3/16/2006 Perforation Record 2 1/2" Powerjet-Pure C Lis 13758 I nd uction/Resistivity 136 11991 Open 3/16/2006 PB 1 Vision Service, Resistivity, Density, - ~~ Porosity plus Graphics Perforation 5 Blu 13260 13835 Case 5/10/2006 27/8" Power Jet Log Perforation 5 Blu 13330 13985 Case 5/10/2006 Perf Record: HSD 6SPF Ii PJ 2906 Charges 60 DEG Phased 12-Apr-2005 ~ Perforation 5 Blu 13220 13713 Case 5/10/2006 27/8" Power Jet 28-Jun- 2005 I Þ Cement Evaluation 5 Col 11530 13310 Case 5/10/2006 USI DSLC 26-Mar-2005 D Asc Directional Survey 0 14033 Open 5/10/2006 J I Rpt Directional Survey 0 14033 Open 5/10/2006 -"~~_._-_._~-_.._~~."~- ""~-- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2050090 Well Name/No. NORTHSTAR UNIT NS-05 Operator BP EXPLORATION (ALASKA) INC MD 14033 TVD 11336 Completion Status 1-01L Completion Date 4/12/2005 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? .~ Analysis YíN" Received? Daily History Received? Formation Tops -. ~._-~ --~--~--~~~~~ ~~~~~-~_. Comments: Current Status 1-01L éi)N œ~N -- API No. 50-029-23244-00-00 UIC N ~-~- -^-~"-~~~~ --______:__---~-......~----~--~------.---~--------:----~-c::::----------------- . ---__--- Compliance ReVi~wed B~:-~________~~~~~----~- Date: ;).} f~ z ò~ 7 - - "\ iECEIVED .~~ STATE OF ALASKA .f~7-d~ ALAS~IL AND GAS CONSERVATION COMMI ~ Wf:'.R 2 7 2007 REPORT OF SUNDRY WELL OP AT. S o o o Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimu a e ..I WaiverD ~~~~ion 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0090 ./ TREATMENT 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: Exploratory Service 6. API Number: 50-029-23244-00-00 ./ P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (It): 9. Well Name and Number: 56.37" RT NS05 ~ 10. Field/Pool(s): / NORTHSTAR Field/ NORTHSTAR OIL Pool 8. Property Designation: ADLO-312808 ' 11. Present Well Condition Summary: Total Depth measured true vertical 14033 ( feet 11335.58 ¡.. feet Plugs (measured) Junk (measured) None None Effective Depth measured 14027 - feet true vertical 11329.83 - feet Casing Length Size MD TVD Burst Collapse SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 INTERMEDIATE 11663 9-518" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 LINER 2012 7" 29# L -80 11525 13537 9294-10861.72 8160 7020 LINER 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 Perforation depth: Measured depth: 13739 - 13794 True Vertical depth: 11054.14 - 11106.67 - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 994 11525 13310 13357 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 4070 5361 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 10969 1276 0 13742 1246 0 15. Well Class alter proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 751 1101 13. Service x Contact Robert Younger WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert Younger Signature Title Production Engineer Phone 564-5392 Date 3/27/2007 ORIGI~~i~L Submit Original Only It e '.. NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/9/2007 T/I/O= 730/250/340. Temp=164*. WHP's & IA FL. (Pre-Acid Stim). IA FL @ Surface. ***NOTE*** NO info in FIP's for this well. 3/10/2007 CTU #5 - On standby for equipment mobilization to Northstar until 12:00. Cross the ice road and arrive on island at 8:00 PM. Start spotting equipment. ***Job in progress*** 3/11/2 Acid Treatment*** Travel to N*, not enough room to spot leave island. 3/11/2007 ***Continue WSR from 3/10/07*** MIRU CTU & continue spotting equipment. Shut down for weather @ 11 :OOam -43 below zero. Temp up to -35 below zero at 15:30 hrs. Attempt to set stabilizers. Blew hydraulic hose in rear stabilizer. Call for mechanics. *** Job in progress*** 3/1 ***CTU #5 from 3/11/2007*** MIRU. Perform BOP test to 200 psi 5000 psi. MU BHA w/ 2.5" JSN. RIH with well flowing at 738 psi. Start kill / fluid pack well. *** Job in progress*** 3/13/2007 ***CTU #5 - Job continued from 3-12-07 WSR*** Kill / load well with 2% KCL. Cap with diesel. Pump acid / scale inhibitor treatment per program. Reciprocate across perfs during job. WHP declined from 1500 psi to 1000 psi after acid hit perfs. POOH freeze protecting CT. Hand over well to pad operator & facility for flow back of acid. *** Job Complete*** FLUIDS PUMPED BBLS 47 60/40 METH 244 2% KCL 100 2% KCL W /10% L66 50 12% HCL 45 DIESEL 486 TOTAL ,_;~; ~, - „~ z, '-t I - i _ S,4RAW ~,4L1N, GOVERNOR ~T~~++~t~a -~r ~T ® 333 W. 7th AVENUE, SUITE 100 (~eAeaadi ~~~~.aA~s ~ y~I 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, NS05 ~,Q~`'~c~~' Sundry Number: 306-411 ~E~ 2 2008 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. DATED thisday of January, 2007 Encl. Sincerely, ' V~ /~ ` ~ ~ ~ STATE OF ALAS~f ~ ~,3'a ~ ALASt AND GAS CONSERVATION COMMISS{y~ APPLI ATION FOR SUNDRY APPROVAL 20 AAC 25.280 rte, t -®~cl ~~~ l~3 ~~~ pEC Alaska 2 ~ 2006 ®f0 ~ fan n 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver A~Ch °ra~e 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 0 ` Exploratory ^ 205-0090 ~ 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6 . API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 56.37 KB NS05 8. Property Designation: 10. Field/Pools(s): ADL-312808 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): 14033 11335.58 14027 11329.83 None None Casing Length Size MD TVD Burst Collapse Surface 3147 13-3/8" 68# L-80 40 3187 40 3183 4930 2270 Production 11663 9-5/S" 53.5# L-80 39 11702 39 9401 7930 6620 Liner 2012 7" 29# L-SO 11525 13537 9294 10862 8160 7020 Liner 674 4-1/2" 12.6# 13Cr80 13357 14031 10689.25 11334 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13739 - 13794 11054.14 - 11106.67 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SSSV MD (ft): 994 7" Liner Top Packer 11525 7" Baker 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 12. Attachments: Descriptive Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Developm ent Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/5/2007 Oil ~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Robert Younger Title production Engineer Signature Phone 564-5392 Date 12/22/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~„ s ~' Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: J ~~ p~ ~ ~~~ ~ ~ 'C~~j~" Subsequent Form Required: ~O APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /• ~ra ~~ ( F~,. J~~f ~1 ~ 2007 Form 10-403 Revised 7/2005 I V Submit in Duplicate rssep~ No portion of the below work should be performed w/out first faking time to ensure No Accidents, unarm to People, and No damage te.~,ie Environment To: Jerry Bixby/Clark Olsen -Well Operations Supervisor .December 15, 2006 From: Robert Younger/Carolyn Kirchner - Northstar Production Engineer subject: NS05 CTU Acid Treatment & SIT Est. Cost: $100 M AFE NSFLDWL05 Est. IOR: 1500 BOPD Please perform an acid stimulation on NS05 per the below procedure including a coil tubing acid/scale inhibition treatment: Type IOR PR N DSWL AFE Job Description S 1500 NS05 NSFLDWL05 Drift to TD F 1500 NS05 NSFLDWL05 Pump Acid for Liner Pickle CorttlncJent on Drift Results CT 1500 NS05 NSFLDWL05 Acid Treatment & Scale Inhibition Treatment (SIT) Current Status: Producer Last Test: 12/03/06: BOPD: 3,754, BWPD: 1,383; MMCFPD: 10.66 Max Inclination: 55° at 7693' md; 26° at Perfs Max Dog Leg: 4.6° at 4,953' and Perforations: 13,707' - 13,794' and Minimum ID: 3.725" @ 13351' md, 4.5" XN Nipple Last TD tag: 03/31/06: 13,820' ctmd - not a TD tag 10/07/05: Tag TD @ 13,935' SLM with 3.5" drift Last Downhole Op: 03/31/06: CTU Acid SIT Latest H2S value: None anticipated BHP: 5,062 psi @ 11,100 ft ss, 7/23/06 NS05 was completed in April 2005. Prior to a large water based scale inhibition treatment in May 2005, the well was tested at 8900 BOPD and 8% WC. Following the May 20, 2005 stand alone scale inhibition treatment consisting of Baker SCW-4004 Phosponate/Polymer, the rate dropped to 2300 BOPD. The well was re-perforated on May 28, 2005 in an attempt to restore production. The production increased to 4200 BOPD at 18% WC. In June 2005, additional adperfs shot higher in the section increased production to 6000 BOPD at 16% WC. A combination acid/scale inhibitor treatment was completed in August 2005. The initial test post treatment was 5350 BOPD and a 16% WC. At this point the well started a sharp decline and by September 16 the rate had fallen to 2500 BOPD at a 1 % WC. On September 20, 2005 re-perfs and ad-perfs were shot in an attempt to bypass the damage and increase rate. The reperfs/adperfs increased the rate to 4700 BOPD at a 1 % WC. NS05 was identified as a coil acid candidate due to loss of water following the August 2005 bullhead treatment. The April 1, 2006 coil treatment increased the oil rate by 1500 BOPD and also returned the water production. No portion of the below work should be pertormea wiout i~rst taK~ng time to ensure No Accidents, +narm to People, and No damage t~,e Environment A combination CTU acid treatment/scale inhibitor treatment is proposed to help clear & prevent any scale built up. 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 the water 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. DRIFT WITH SLICKLINE: 1. RU slickline. 2. RIH with slickline to TD. Note if scale is encountered. FULLBORE LINER PICKLE TI E T IFT LT' : ~'klf scale is encountered during the slickline drift, please pickle liner~~ 3. Order out volume of seawater, acid, and diesel for both the pickle and acid/SIT treatment. See attached volumes table. 4. RU pumping equipment. 5. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 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. Pump the following fluids to wash the production liner at 3 bpm, 3500 psi max pressure. a) 15 Bbls 12% DAD acid per below recipe b) 147 Bbls seawater c) 46 Bbls diesel No portion of the below work should be performed wlout first taking time to ensure No Accidents, 1~T~narm to People, and No damage t,~;re Environment 90:10 DAD Acid (12% HCL) to contain: 0.6% A261 Corrosion Inhibitor 4 ppt A179 Corrosion Inhibitor 8 ppt A153 Corrosion Inhibitor 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control 0.5% W60 Anti-sludge Flowback Procedure: 9. Produce liner wash fluid to test separator and well clean up tank. The volume of flowback is 208 Bbls. 10. RD slickline. COIL TUBING ACID/SCALE INHIBITION TREATMENT: 11. Mobilize coil unit, pumps, tanks and acid transport to Northstar. 12. MIRU. 13. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface. 14. 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. 15. PT Dowell surface lines to 5000 psi. 16. Bullhead kill with filtered 2% KCI. Once liquid packed, the maximum recommended WHP during treatment is 3500psi. 17. RIH with jetted nozzle (min ID = 3.725"). Drift to below perforations to insure no obstructions exist. 18.Jet perforations reciprocating across perforations multiple times at a maximum rate or 3500 psi max pressure. a) 50 bbls Acid w/ 10% L66 b) 101 bbls 2% KCI w/ 10% L66 c) 90 bbls 2% filtered KCI (Overflush for 5' radial displacement) d) 46 bbls Diesel (for displacement and under-balance) 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. 12% Acid to contain: No portion of the below u•~rk should be pertormed w/out first *aK~ng time to ensure No Accidents, ,,,,,harm to People, and No damage t~,~,~e Environment 10% L66 Scale Inhibitor 0.5% A261 Corrosion Inhibitor 4 ppt A179 Corrosion Inhibitor 8 ppt A153 Corrosion Inhibitor 0.5% W060 Anti-Sludge 0.5% W54 Non-Emulsifier 0.2% F103 Surfactant 20 ppt L58 Iron Control 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. 19. Shut well in for 4 hours after injection to allow scale inhibitor to precipitate. 20. RD Schlumberger. Flowback Procedure: 21. 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 287 bbls. After clean- up, divert back to the plant and get 2 6-hour tests. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or ECEL, copy of the pur~nping rates end pressures} to Robert.YoungrC~ bp.com. Procedure Contacts: Robert Younger W K: 564-5392 H M : 677-2599 Cel I: 830-4920 r Ilv >IL . STATE OF ALASKA . .'fJ/dG ALAi OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS .: ·.CiC'·:': 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 !"t)m. 8" ::; Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 ) ',i Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P1 Exploratory 205-0090 3. Address: P.O. Box 196612 Stratigraphic D Service 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.37 KB NS05 8. Property Designation: 10. Field/Pool(s): ADL-312808 NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 14033 feet Plugs (measured) None true vertical 11335.58 feet Junk (measured) None Effective Depth measured 14027 feet true vertical 11329.83 feet Casing Length Size MD TVD Burst Collapse SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 INTERMEDIATE 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 LINER 2012 7" 29# L-80 11525 - 13537 9294 - 10861.72 8160 7020 LINER 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 Perforation depth: Measured depth: 13707 - 13727 13734 - 13764 13739 - 13794 True Vertical depth: 11023.6 - 11042.69 11049.37 - 11078.02 11054.14 -11106.67 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 994 7" Liner Top Packer 11525 7" Baker 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft MAY 1 6 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2485 4581 99 208 739 Subsequent to operation: 2528 4675 98 287 754 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development P1 Service Daily Report of Well Operations X 16. Well Status after proposed work: ';., Oil P1 Gas D WAG D GINJ D 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: 306-055 Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr ~?Lt7 Signat..., ...' Phone 564-4424 Date 5/9/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only .. . . .. NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY I 3/30/2006 CTU #5, Acid Stim; Standby while VECO rigs down NS-15 and rigs up NS- 05. Spot unit on well. Move UR tanks and wait on fluids. ... Job in Progress - Cont' on WSR 03/31/06... 3/31/2006 CTU #5, Acid Stim; ... Cant' from WSR 03/30/06... Continue RIH down to 13820' ctmd (did not tag TO). Established initial injectivity of 1.4 bbls at 1650 psi. Jet 50 bbls of 12% HCL with 10% L66 scale inhibitor across perfs (perf interval is 13707-13794). Jet 50 bbls of 2% KCL with 10% L66 across perfs. PUH to 13660' ctmd and flush acid and inhibitor with 90 bbls of filtered 2% KCL. Saw immeadiate drop in WHP as acid went in to the formation. Injectivity increased to 1.8 bpm at 750 psi. POOH while pumping 90 bbls of diesel down the backside. Control room notified to keep well shut in for 4 hours. *** Job Complete *** (see fluid summary for acid properties) 4/1/2006 CTU #5, Acid Stim; Fixing injector. FLUIDS PUMPED BBLS 90 Diesel 50 12% HCL 140 2% KCL 280 TOTAL . . Date: 05 -10- 2006 Transmittal Number:92787 [)O6 -œF} BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Loq Run Top Depth Bottom Deoth Loa Tvoe NS05 05-28-2005 SCH 1 13260 13835 PERFORATING RECORD NS05 04-12-2005 SCH 1 13330 13985 PERFORATING RECORD NS05 06-28-2005 SCH 1 13220 13713 PERFORATING RECORD NS05 03-26-2005 SCH 1 11530 13310 USIT CEMENT LOG NS10 05-25-2005 SCH 1 4750 7960 RST W A TERFLOW NS10 05-09-2005 SCH 1 4800 8004 RST W A TERFLOW Pìease Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center Attn: Doug Chromanski Tim Ryherd Ignacio Herrera Howard Okland Cheryl Ploegstra Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . Date: 05-10-2006 Transmittal Number:92785 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Loq Run Top Depth Bottom Depth Loq T vpe NS11 05-04-2006 SCH 1 0 14800 DIRECTIONAL SURVEY NS29 06-03-2005 SCH 1 0 13679 DIRECTIONAL SURVEY NS20 06-10-2003 SCH 1 0 18531 DIRECTIONAL SURVEY NS05 03-24-2005 SCH 1 0 14033 DIRECTIONAL SURVEY NS30 03-19-2006 SCH 1 0 16398 DIRECTIONAL SURVEY ~ obj I () /11., ^ Ò D '" Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Jim Seccombe Ignacio Herrera Howard Okland Tim Ryherd Cheryl Ploegstra Terrie Hubble (Report only) (Report + disk) (2 Reports + disk) (Report + disk) (Report only) (Report only) Petrotechnical Data Center LR2-J 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Àò )- - ~ 0 tt r::'(~ ').Þ) -~\\ « ~f.)~' -~ v'- ~ ~f _òð 9. . . Date: 03-15-2006 Transmittal Number:92763 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Loq Run Top Depth Bottom Depth Loq Tvpe VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07-2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11 500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 111 30 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07-31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~or, CJÖ<{ F;(~ . . BPXA WELL DATA TRANSMITTAL P ase Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug Chromanski Ignacio Herrera Petro technical Data Center LR2- I 900 E. Benson Blvd. PO Box 1966 I 2 Anchorage, AK 995 19-66 I 2 Date: 03-15-2006 Transmittal Number:92763 . ~lT~1fŒ [ûJ~ . AI,ASBA. OIL AND GAS CONSERVATION COlWlISSION FRANK H. MURKOWSKI, GOVERNOR Robert Younger Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar Field, NS05 Sundry Number: 306-055 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, DATED thiskz&'y of February, 2006 Encl. bp . . .6. .&\t..,.. ...~ ~~. 111I!i~·~~' .,.- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 February 15, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RECEIVED FEB 1 7 2006 Alaska Oil & Gas Cons. Commission Anchorage Re: Sundry Notice for NS05 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS05 well. A combination acid/scale inhibitor treatment was completed in August 2005 and adperf/reperfs were shot in September 2005. Following the August 2005 acid/scale inhibitor treatment, NS05's water-cut went to zero and the production dropped likely due to inefficiencies associated with the bullhead conveyance method. Therefore, a . coil conveyed acid treatment is proposed as an attempt to insure all perforation / intervals are treated. The procedure includes the following major steps: . Coil Tubing conveyed HCI based acid treatment . Flowback Sincerely, ¡ßJ~ Robert Younger Production Engineer BPXA, ACT, Northstar .." 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U c::J....aS ¡;Ons, ^"'" Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension anchorage Change approved program 0 Pull Tubing 0 Perforate New Pool [h Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: / /' BP Exploration (Alaska), Inc. Development 8 / Exploratory D 205-0090 3. Address: P.O. Box 196612 Stratigraphic D Service D 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 / 7. KB Elevation (ft): 9. Well Name a d Number: 56.37 KB NS05 /' 8. Property Designation: 10. Field/Pools( ): ADL-312808 Northstar Field Northstar Oil Pool 11. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): ¡rota I Depth TVD (ft): IEffective Depth MD (ft): Effective Depth [TVD (ft): rlUgS (measured): \JUnk (measured): 14033 11335.58 14027 1132983 None None Casing Length Size MD /' TVD Burst Collapse Surface 3147 13-318' 68# L-BO 40 3187 40 31B3 4930 2270 Intermediate 11663 9-5/8" 53.5# L-BO 39 11702 39 9401 7930 6620 Liner 2012 7" 29# L-BO 11525 13537 9294 10862 B160 7020 Liner 674 4-1/2" 12.6# 13Cr80 13357 14031 1068 .25 11334 6430 7500 Perforation Qepth MD (ft): Perforation Depth TVD (ft): Tubing Size: ¡Tubing Grade: Tubing MD (ft): 13739 - 13794 / 11054.14 - 11106.67 4-1/2" 12.6# ./' 13CrBO 37 - 13366 13707 - 13727 11023.6 - 11042.69 Packers and SSSV Type: 4-1/2" TRM-4E SSV Packers and SS V MD (ft): 994 7" Liner Top Packer 11525 "'-' G A- 7" Baker 13CrBO Packer ~ I ~ S '" 4-1/2" Liner Top Packer 13357 12. Attachments: DescriDtive Sum maryof Proposal 8 13. Well Class a er proposed work: / Detailed Operations Program D BOP Sketch D Exploratory I ] Development 8 Service D 14. Estimated Date for 15. Well Status ~ fter proposed work: Commencing Operations: 31312006 / Oil 8 Gas D Plugged [J Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJD WDSPL D Commission Representative: Prepared bv Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ontact Robert Younç¡er Printed Name Robert Younger Title Production Engin ger - Signature L? 2/17/2006 r~ "'LÞC? Phone 564-5392 ate /" COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: -3o~-p55 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Locat i n Clearance 0 Other: RBDMS BFl FEB .2 3 2006 S"b'~"m ¡J¡0 4· APPROVED BY z,- Z, 2- ".()6 Approved Dy:'" T:; . ~ COMMISSIONER THE COMMISSION Date: - -V '- -'OR\G\NAL Form 10-403 Revised 7/2005 Submit in Duplicate cPr'].., ')/~ ¿, _ STATE OF ALASKA .p~/ A~ OIL AND GAS CONSERVATION cm.í1MI.r-4 2<;/6 APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 WGA- t/ u I '¿o ()(, RECEIVED FEB 1 7 2006 Ion TREE = ABB-VGI5-1/8" .- ~ NOTES: ***4-112" CHROME TBG & LNR*** WELLHEAD = A BB- V GI13-5/8" MUL TIBOWL 5 . NS05 ACTUA TOR = KB. ELEV = 56' _._-"--._-"~------_.._--"" 40.1' (CB 15.9') SF 8_EV = -4-1!2" TRM-4E SSSV wI 4-1/2" X PROFILE, 10 = 3.812" KOP= ø 994' ~---~-'--'~---~~-- Max Angle = 56 @ 7693' Datum MD = Datum ND = 113-3/8" CSG, 68#, L-80 BTC. ID = 12.415" I 3187' 1---4 ~ GAS LIFT MANDRELS STI MD I ND I DEV I TYPE I VLV 1 LA TCHI PORT I DATE 1 U 1 I 39971 4000 I 10 I MMG I DMY I I 103/29/051 Minimum ID = 3.725" @ 13351' 4-1/2" XN NIPPLE I TOP OF 7" LNR I 11525' ~ 19-5/8" CSG, 535#, L-80 BTM-C H 11702' l~ ~ I I 13261' -14-1/2" X NIP, ID = 3.813" I 13292' -14-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I ß 13316' ~1/2" BKR S-3 PKR, ID = 3.958" I ¿S; 13310' ELMO I · 13340' -14-1/2" X NIP, 10 = 3.813" I · I · 13351' -14-1/2" XN NIP, ID = 3.725" I ¡TOP OF 4-1/2" LNR I 13357' ~ ~ 14-1/2" TBG, 12.6#, 13CR VAM-ACE. 13366' 1- 8: 13366' 4-1/2" HES SELF ALIGNING MULESHOE I .0152 bpf, ID 3.958" 10 = 3.958" 17" LNR. 29#/ft L-80 Hydril511, ID = 6.184" I 13537' -µ ... PERFORA TION SUMMARY REF LOG: SWS USIT 4/11/05 A NGLE A T TOP PERF: 53 @ 13739' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 13739 - 13794 0 04/12/05 2-7/8" 6 13739 - 13794 0 05/28/05 2-7/8" 6 13734 - 13764 0 09/20/05 ::2-1'r (0 1311>1-- 13111- D DI.1.It.ii'lbS 11 ! J I PBTD H 14027' I 14-1/2" LNR, 126#, 13CRVAM-ACE. 14031' I .0152 bpf. ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/10/05 TA ORIGINAL COMPLETION WELL: NS05 05/05105 GJB/PJC CORRECTION SSSV ÆRMIT No: 11'2050090 04/12/05 GJRlPJC PERF API No: 50-29-23244 05/28/05 WRRlPJC RE-PERF SEC T N R E 11/04/05 SJM DRLG DRAFT CORRECTIONS BP Exploration (Alaska) - . STATE OF ALASKA . ALASØ'OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS Kt:\."t:IVt:U DEC 1 6 2005 Alaska Oil & Gas Cons. Gommlt:;mi 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development M Exploratory 205-0090 3. Address: P.O. Box 196612 Stratigraphic D Service D 6. API Number: Anchorage, AK 99519-6612 50-029-23244-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.37 KB NS05 8. Property Designation: 10. Field/Pool(s): ADL-312808 Northstar Field/ Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 14033 feet Plugs (measured) None true vertical 11335.58 feet Junk (measured) None Effective Depth measured 14027 feet true vertical 11329.83 feet Casing Length Size MD TVD Burst Collapse Surface 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 Intermediate 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 Liner 2012 7" 29# L-80 11525 - 13537 9294 - 10861.72 8160 7020 Liner 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 Perforation depth: Measured depth: 13734 - 13794 True Vertical depth: 11049.37 - 11106.67 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37 - 13366 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 994 7" Liner Top Packer 11525 7" Baker 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 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: 5838 12561 933 0 741 Subsequent to operation: 5338 11179 947 0 735 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development M' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil M Gas WAG D GINJ D WINJ WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my, knOWledg~. .. SUndry Number or N/A if C.O. Exempt: RBDMS BFL DEC 192005 305-173 Contact Sharmaine Vestal Printed Name Sharmaine Vestal I Title Data Mgmt Engr ~ r;:;j ,?,1 Signatur . ~././ Au7 A v..y Phone 564-4424 Date 12/13/2005 Form 10-404 Revised 04/2004 ORtG t\( Submit Original Only {,~AL . . NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ~CIIVIT)'gA IE I SlLMM.Y~\~" ..~·~i,,::~· i}~ itJl~1 8/9/2005 Acid/SI Treatment; pumped 5 bbl meth spear, 12 bbl of 12% HCL, 130 bbl s- water, 61 bbl diesel. Flowed pickel back to well cleanup tank. (208 bbl's) Pumped 35 bbl's of EC9610A (mutual solvent), 10 bbl's L64 wtr, 36 bbl's of 12%HCL with 10% L66 wtr, 129 bbl's of L64 wtr and 10 % L66, 84 bb'ls L64 wtr, 148 bbl's s-water, 61 bbl's diesel. turned well over to production to let soak for four hours before flowing back 458 bb's to test clean up tank. FLUIDS PUMPED BBLS 36 12% HCL w/1 0% L66 278 SW 5 Meth 94 L64 water 36 L64 water w/1 0% L66 wtr 122 Diesel 35 EC9610 (mutual solvent) 606 TOTAL ~ " . STATE OF ALASKA _ ALA' OIL AND GAS CONSERVATION COMMf!!!I!fION REPORT OF SUNDRY WELL OPERATIONS o o o RECEIVED OCT 1 9 2005 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic D Stimulate 0 ~th~~'1 & G Cons Commi sion W· 0 T· E a~ I as alver Ime x ~11 Re-enter Suspended Well 0 Anchorage 5. Permit to Drill Number: 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 205-0090 6. API Number: 50-029-23244-00-00 9. Well Name and Number: Exploratory Service 56.37 KB NS05 ADL-312808 11. Present Well Condition Summary: 10. Field/Pool(s): NORTH STAR Field/ NORTH STAR OIL Pool 8. Property Designation: Total Depth measured 14033 true vertical 11335.58 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 14027 true vertical 11329.83 feet feet Surface Intermediate Liner Liner Length Size MD TVD Burst Collapse 3147 13-3/8" 68# L-80 40 - 3187 40 - 3183.4 4930 2270 11663 9-5/8" 53.5# L-80 39 - 11702 39 - 9401.36 7930 6620 2012 7" 29# L-80 11525 - 13537 9294 - 10861.72 8160 7020 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.25 - 11333.66 8430 7500 Casing Perforation depth: Measured depth: 13704 - 13764 13739 - 13794 True Vertical depth: 11020.74 - 11078.02 11054.14 - 11106.67 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 37-13366 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 994 11525 13310 13357 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 2773 5278 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 5202 32 0 10207 49 0 15. Well Class after proposed work: Exploratory Development R1 16. Well Status after proposed work: Oil R1¡ Gas D WAG Tubing pressure 800 2650 13. Service x Contact Sharmaine Vestal WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /L.r~ Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 10/14/2005 Form 10-404 Revised 04/2004 ORIGINAL it Original Only .. . . r NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACîlVITYD~"PElSlJjl~"RI 9/18/2005 *****Well flowing upon arrival***** Logged GR/CCL across interval 13,650-14,002 (PBTD). Perforate interval 13,704-13,719' elmd (15') with 2.5" 2506 PJOmega, HMX guns with "PURE" technology. (Ref GR/CCL/USIT 04/11/05) BHA with memory pressure/temp gauge. Shut down due to high winds. Wait on Weather. Put well back on production. ... Job in Progress - Cont' on 09/19/05 WSR ." 9/19/2005 ... Cont' from 09/18/05 WSR ... Perforate interval 13,719-13,734 elmd (15') with 2.875" 2906 PJ HMX guns. (Ref GR/CCL/USIT 04/11/05) BHA with memory pressure/temp gauge. ... Job in Progress - Cont' on 09/20/05 WSR ... 9/20/2005 .,. Cont' from 09/19/05 WSR ... Perforate interval 13,734-13,749' elmd (15') Perforate interval 13,749-13,764' elmd (15') All runs shot with 2.5" 2506 PJOmega, HMX guns with "PURE" technology. All shots fired. (Ref GR/CCL/USIT 04/11/05) All runs had memory pressure / temp tool with "rapid capture" for high resolution pressure data while guns were fired. *** JOB COMPLETE *** FLUIDS PUMPED I BBLS I TOTAL ¡".... , ¡ i " II U e rrD fb LWu e n L6 (fù \\.. '\.'- '\ '\ n,:¡ o If\ l.l..J\.\ ......\ UU FRANK H. MURKOWSKI, GOVERNOR A....ASIiA ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Senior Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~ Re: Northstar NS05 Sundry Number: 305-265 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (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 decisio t Superior Court unless rehearing has been requested. Encl. ... e e "tAft. _.l-"""~.-- ~...- ~...~ ...~ ~.... ·'i~.§\" BP Exploration (Alaska) Inc. ". 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 - bp August 8, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS05 to Perforate BP Exploration Alaska, Inc. proposes to re-perforate the NS05 well. This well _ has suffered a recent severe decline in productivity. Reperforating is - recommended to bypass any near wellbore damage a few feet of additional perforations are also recommended.. The procedure includes the following major steps: T e Slickline Electric Line Work Descri tion DrifVta wi dumm un Add 3' of Ivishak perforations 13,704' -13,707' MDrkb Re-perforate 20' of Ivishak 13,707' - 13,727' MDrkb __. Add 12' of Ivishak perforations 13,727' - 13,739' MDrkb Re-perforate 25' of Ivishak 13,739' - 13,764' MDrkb Sincerely, qYj,~ ~ ;f~i0 MichÇel J. Fµ:P.~. Senior Petroleum Engineer BPXA, ACT, Northstar CI1.f q ---7 ~fß s. \dQ.A- 't /, I lOO) e STATE OF ALASKA Ð V1t 7" /7'..ð- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUN DR V APPROVA~(:p 20 AAC 25.280 StratigraphicD Service 0 9. Well Name and Numbo/: NS05 /' 10. FieldlPool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11276.0 14027 11270.0 Size MD TVD . .~. 1. Type of Request: Abandon 0 Suspend 0 Alter Casing 0 Repair Well 0 Change Approved Program 0 Pull Tubing 0 2. Operator Name: Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 00 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.37 KB 8. Property Designation: ADL-312808 11. Present Total Depth MD (ft): 14033 Casing PerforateŒ] / wåilfêr[J:'j" StimulateD Time ExtensiOn 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0090 ~.. Other 0 'c: ""'r":-~ ~; ;-.-..:1' "., Exploratory D 6. API Number 50-029·232~00-00 /' Plugs (md): None Burst Junk (md): None Collapse SURFACE INTERMEDIATE LINER PRODUCTION to bottom to bottom 3147 13-318" 68# L-80 40 3187 40.0 3183.4 4930 2270 11663 9-518" 53.5# L·80 39 11702 39.0 9401.4 7930 6620 2012 7" 29# L-80 11525 13537 9294.0 10861.7 8160 7020 674 4-1/2" 12.6# 13Cr80 13357 14031 10689.3 11333.7 8430 7500 Perforation Depth MD (ft): 13739 - 13794 13707 - 13727 Perforation Depth TVDss (ft): 10998 - 11050 10967 - 10986 Tubing Size: 4-1/2 " Tubing Grade: Tubing MD (ft): 12.6 # 13CrSO 37 13366 Packers and SSSV MD (ft): Packers and SSSV Type: 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 4-1/2" TRM-4E SSV 12. Attachments: 11525 13310 13357 994 13. Well Class after proposed work: Description Summary of Proposal ŒI Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencin 0 eration: September 13. 2005 Exploratory D Development(! ServiceD 15. Well Status after proposed work: Oil ŒJ GasD PluggedD AbandonedD 16. Verbal Approval: Date: WAG 0 Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature ? t!... Commission Use Onl so that a representative may witness BOP TestD Mechanciallntegrity Test D RBDMS BFL SEP 1 9 2005 Other: Appro ORIGINAL -- GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Michael Francis Title Phone Senior Petroleum Engineer 564-4240 918105 Location Clearance 0 BY ORDER OF THE COMMISSION Date: SUBMIT IN DUPLICATE . . Date: 08-24-2005 TransmÌttal Number:92666 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the fd fa! t If h fIt t . th PDC t 5644091 :of'" O&er con I en I na ure. you aye any ques Ions, pJ ease con ac me III e a - SW Name Date Contractor LOQ Run IT op Depth Bottom Depth LOQ Type ULTRA SONIC IMAGING LOG; NS05 04-11-2005 SCH 1 0 14008 CEMENT BOND LOG; --" RST BORAX CHANNEL .. NS24 /' 03-27-2005 SCH 1 12200 12473 DETECTION LOG; &./". MEASURE DEPTH L.·/ NS05 02-15-2005 SCH 1 200 14033 COMPOSITE LOG; - /' NS05 02-15-2005 SCH 1 200 14033 TVD COMPOSITE LOG; L/ PRODUCTION PROFILE .... NS13 .../ 10-04-2005 SCH 1 11500 11888 W/DEFT AND GHOST; [,./ NS05 02-16-2005 SCH 1 179.5 14049 CD-ROM /JIK'i ---" NS24/' 03-27-2005 SCH 1 12200 12473 CD-ROM /31 ~J r...""..... ¡~ I gj.- .---. NS05 04-11-2005 SCH 1 0 14003 CD-ROM to,. -I ~ .., !.s-. bC>'I ¡ ~oI - 08" lb S" ... t. '1 lb~~(,~ ¡'f"...6'~ )..~...1! 1. ()~. iÌ1 //1 ~,{ ~i~ Pleàse Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnica! Data Center Attn: Ken Lemley MB3-6 Attn: Ester Fueg MB3-6 Attn: Jason Smith (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 " ALASJtIL AND ~:~~g~S~~;A~ON COM.SION ~~~~/2Yo~D REPORT OF SUNDRY WELL OPERATIðN-SJiI&G as Cnn". (\ 1. Operations Performed: Anch8f~·"'·Iß'IISSii.; Abandon 0 Repair WellD Plug Perforations 0 Stimulate 0 Alter Casing D Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate ŒJ Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 205-0090 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23244-00-00 7. KB Elevation (It): 9. Well Name and Number: 56.37 NS05 8. Property Designation: 10. Field/Pool(s): ADL-312808 Northstar Field I Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 14033 feet true vertical 11279.0 feet Plugs (measured) None Effective Depth measured 14027 feet Junk (measured) None true vertical 11273.0 feet Casing Length Size MD TVD Burst Collapse SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40.0 - 3127.0 5020 2270 INTERMEDIATE 11663 9-5/8" 53.5# L-80 39 - 11702 39.0 - 9345.0 7930 6620 LINER 2012 7" 29# L-80 11525 - 13537 9294.0 - 10862.0 8160 7020 PRODUCTION 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10633.0 - 11277.0 8430 7500 Perforation depth: Measured depth: 13707 - 13727, 13739 -13794 True vertical depth: 10967· 10986, 10998 - 11050 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 37 - 13366 Packers & SSSV (type & measured depth): 7" Liner Top Packer @ 11525 7" Baker 13Cr80 Packer @ 13310 4-1/2" Liner Top Packer @ 13357 4-1/2" TRM-4E SSV @ 994 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4898 9460 999 733 Subsequent to operation: 6746 13250 988 743 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒI ServiceD Copies of Logs and Surveys run _ 16. Well Status alter proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 305-154 Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A-: ?L .#? J!.. /l Phone 564-5174 Date 7/14/05 lj \.. Form 10-404 Revised 4/2004 OR RBDMS BFL JUL 1 9 2005 . . NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/28/05 ***WELL FLOWING UPON ARRIVAL*** SHOT PERF INTERVAL 13707' to 13727' On GOOD INDICATION ON SURFACE. TIED IN USING USIT DATED 04-11-2005. ***GAVE WELL BACK TO CONTROL ROOM*** FLUIDS PUMPED BBLS o ¡NO FLUIDS PUMPED TOTAL o Page 1 TREE: ABB-VGI 5 1/8" 5k psi . WELLHEAD: ABB-VGI 13-5/8" Multibowl 5k psi NS05 - DRAFT 133/8", 68#/ft, L-80, BTC @ 3181' MO 41/2", 12.6#/ft, 13-Cr, Vam-TOP TUBING 10: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 53.5# L-80 BTM-C @ 11702' MD 4.5" X NIPPLE, @ 13261' MD 3.813" 10 4.5" X NIPPLE, @ 13340' MD 3.813" 10 4.5" XN NIPPLE, @ 13351' MD 3.725" 10 4.5 Self Aligning WLEG @13366'MD 3.958" 10 7", 29#/ft L-80, Hydril 511 @ 13531' MO ÆRFORA TION SUMMA RY REF LOG: SWS usrr 4/11/05 ANGLE AT TOP ÆRF: @ 13739 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.875' 6 13739 - 13794 Opn/Sqz 04/12/05 2.875' 6 13739 - 13794 Opn/Sqz OS/27/05 PBTO @ 14027' MO TO @ 14031' MO .IGINAL KB. ELEV = 56' -BF. ELEV = 40.1' CB. ELEV = 15.9' 4 1/2" TRM-4E SSSV @ 994' MD w/4-1/2" X PROFILE=3.812' 10 41/2" GLM @ 3997' MD (4000' TVD) w/ 4.62" 10 - T' LINER TOP @ 11525' MD 4.5" Fiber Optic Transducer 3.958" 10 @ 13292 MD _ T'PACKER,13Cr@13316'MD 4.5" LINER TOP @ 13357' MO 4.5",12.6#, 13Cr Vam TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/05 DJA PROPOSED 03/30105 TA FINAL 05/05/05 GJB/PJC CORRECTION SSSV 04/12/05 GJRlPJC ÆRF 05/28/05 WRRlPJC RE-ÆRF NORTHSTAR WELL: NS05 ÆRMrr No: XXXXXXX Apt No: 50-29-23244 SEC T N R E BP Exploration (Alaska) . ~ rr® II rE [DJ. IT: ./K\ ~ .../il\. ..~ n.w @ ULn.\U lb U If iJ u~LrÙæJL~~ .... . ~ôS-ð-O( AItASIiA OIL AND GAS CONSERVATION COltDlISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska). Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS05 Sundry Number: 305-173 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (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 liday or weekend. A person may not appeal a Commission decisio 0 S" perior Court unless rehearing has been requested. DATED thisJ.L day of July, 2005 Encl. bp . . ..\tt~.'. ...~~ ~~.- ,.,- ~...""" .~ .¡;..~ .~,.~~\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 5, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NSOS to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NSOS well. This well has recently been reperforated and needs a combination acid / scale inhibitor treatment to clean and treat the new perforations. The procedure includes the following major steps: · Pickle the tubing Bullhead HCI based acid treatment (which includes scale inhibitor) /' Flowback · · Sincerely, ÚJ1It~ MiclÇel J. F. " P.E. Senior Petr eum Engineer BPXA, ACT, Northstar WL/,\ 7/7/200) " . STATE OF ALASKA . RECEIVEu ALASKA OIL AND GAS CONSERVATION COM~SION APPLICATION FOR SUNDRY APPROVAL JUL 06 Z005 20 MC 25.280 . 'ska Oil & Gas Cons. COlM1ission 1. Type of Request: Anch~rage Abandon 0 Suspend 0 Operation Shutdown D PerforateD Waiver 0 Other 0 Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 00 Time Extension 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. ~ploratory D 205-0090// Development 00 3. Address: P.O. Box 196612 6. API Number / Anchorage, Ak 99519-6612 StratigraphicD Service D 5~2~23244-o0-00 7. KB Elevation (ft): 9. Well Name and Nu~r: 56.37 KB NS05 8. Property Designation: 10. FieldlPool(s): ADL-312808 Northstar Field / Northstar Oil Pool 11. Present PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): Plugs (md): Junk (md): 14033 11276.0 14027 11270.0 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom SURFACE 3147 13-3/8" 68# L-80 40 - 3187 40.0 - 3183.4 4930 2270 INTERMEDIATE 11663 9-5/8" 53.5# L-80 39 - 11702 39.0 - 9401.4 7930 6620 LINER 2012 7" 29# L-80 11525 - 13537 9294.0 - 10861.7 8160 7020 PRODUCTION 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.3 - 11333.7 8430 7500 Perforation Depth MD (ft): Perforation Depth TVDss (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13739 - 13794 10998 - 11050 4-1/2 " 12.6 # 13Cr80 37 - 13366 13707 - 13727 10967 - 10986 Packers and SSSV Type: Packers and SSSV MD (ft): 7" Liner Top Packer 11525 7" Baker 13Cr80 Packer 13310 4-1/2" Liner Top Packer 13357 4-1/2" TRM-4E SSV 994 12. Attachments: 13. Well Class after proposed work: / Description Summary of Proposal ŒI Detailed Operations Prowam D BOP Sketch D Exploratory D DevelopmentŒJ ServiceD 14. Estimated Date for July 15. 2005 15. Well Status after proposed work: Commencinq Operation: Oil Œ] / GasD PluggedD Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJD WINJD WDSPLD Commission Representative: Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Francis Printed Name Michael Francis .... Title Petroleum Engineer Signature C/fY\.A~ ., I A<.ø "" J \.... P£,. Phone 564-4240 7/1/05 ~ f\...1 J Commission Use On Iv Conditions of approval: Notify Comm' . n so that a representative may witness Sundry Number: j 3oý/7.3 i BOP TestD MechanciallntegrityTest D Location Clearance 0 Plug In grity Other: RBDMS 8FL .JUt 1 to 404· ' 2D05 ~/ Subseque t For Re i ,~ , ~ BY ORDER OF 1¡/ jtJ5 Approved~,..;.. J THE COMMISSION Date: ~ \.../ ' I I r~"";, ¡ -. Form 10-403 Revised 11/2004 p~ I f " "'- SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5k psi . VVEl"LHEAO: ABB-VGI 13-5/S" ~ . Multibowl 5k psi NS05 ~. alGINAl KB. ElEV = 56' -BF. ElEV = 40.1' CB. ElEV = 15.9' 4 1/2" TRM-4E SSSV @ 994' MD w/4-1/2" X PROFILE=3.812' 10 DRLG - 133/8", 68#/ft, l-SO, BTC @ 3187' MD 4 1/2" GlM @ 3997' MD (4000' TVD) w/ 4,62" 10 41/2", 12.6#/ft, 13-Cr, Vam-TOP TUBING 10: 3.95S" CAPACITY: 0.01522 BBLlFT 9-5/S" 53.5# L-80 BTM-C @ 11702' MD - 7" LINER TOP @ 11525' MD 4.5" X NIPPLE, @ 13261' MD 3.813" 10 4.5" Fiber Optic Transducer 3.95S" 10 @ 13292 MD _ 7"PACKER,13Cr@13316'MD 4.5" X NIPPLE, @ 13340' MD 3.813" 10 4,5" XN NIPPLE, @ 13351' MD 3.725" 10 4.5 Self Aligning WlEG @13366'MD 3.958" 10 4.5" LINER TOP @ 13357' MO 7", 29#/ft L-SO, Hydril 511 @ 13537' MO ÆRFORA TION SUMMARY REF LOG: SWS usrr 4/11/05 ANGLEATTOPÆRF: @ 13739 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.S75' 6 13739 - 13794 Opn/Sqz 04/12/05 2.875' 6 -1~733 - 13Y~4 Opn/Sqz OS/27/05 tHOl' j':>1l1 WGk PBTO @ 14027' MO TO @ 14031' MO 4.5",12.6#, 13CrVam TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/05 DJA PROPOSED 03/30/05 TA FINAL 05/05/05 GJB/PJC CORRECTION SSSV 04/12/05 GJRlPJC ÆRF OS/28/05 WRRlPJC RE-ÆRF NORTHSTAR WELL: NS05 ÆRMrr No: XXXXXXX API No: 50-29-23244 SEC T N R E BP Exploration (Alaska) .. STATE OF ALASKA . ALAS~OILAND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: . ... Abandon 0 Repair WellD Pluq Perforations D Stimulate 0 OtherO Alter CasingD Pull TubingD Perforate New Pool D WaiverD Time Extension D Change Approved ProgramD Operation Shutdown 0 Perforate 00 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 205-0090 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-23244-00-00 7. KB Elevation (It): 9. Well Name and Number: 56.37 NS05 8. Property Designation: 10. FieldlPool(s): ADL-312808 Northstar Field / Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 14033 feet true vertical 11335.6 feet Plugs (measured) None Effective Depth measured 14027 feet Junk (measured) None true vertical 11329.8 feet Casing Length Size MD TVD Burst Collapse LINER 2012 7" 29# L-80 11525 - 13537 9294.0 - 10861.7 8160 7020 LINER 674 4-1/2" 12.6# 13Cr80 13357 - 14031 10689.3 - 11333.7 8430 7500 PRODUCTION 11687 9-5/8" 53.5# L-80 15 - 11702 15.0 - 9401.4 7930 6620 SURFACE 13-3/8" 68# L-80 16 - 3187 16.0 - 3183.4 4930 2270 Perforation depth: Measured depth: 13739 -13794 True vertical depth: 11054.14 -11106.67 Tubinq ( size, qrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 13 - 13366 Packers & SSSV (type & measured depth): 4-112" TRM-4E 5SV @ 994 7" Liner Top Packer @ 11525 4-1/2" Baker 5-3 Perm Packer @ 13316 12. Stimulation or cement squeeze summary: RBOMS 8FL JUN 2 2 20D5 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2608 5617 979 0 735 Subsequent to operation: 4796 9555 841 0 736 14. Attachments: 15. Well Class alter proposed work: ExploratoryD Development ŒI ServiceD Copies of Logs and Surveys run _ 16. Well Status alter proposed work: Daily Report of Well Operations_ ð. OilŒ] GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne Schnorr 305-132 Printed Name DeWayne Schnorr Title Petroleum Engineer Signature ~?A úP.J r /J / Phone 564-5174 Date 6/15/05 Form 10-404 Revised 4/2004 I~L . . NS05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY OS/28/05 PJSM - SIMOPS - RU TO PERORATE - TIE INTO SCHLUMBERGER USIT/GR/CCL 4-11- 2005. RE-PERFORATED 13739' MD - 13794' MD. RD. TURNED WELL OVER TO TENDER TO POP. 06/06/05 TEST EVENT - BOPD: 4,289, BWPD: 895, MCFPD: 10,309, AL Rate: 0 FLUIDS PUMPED BBLS o ¡NO Fluids Pumped TOTAL o Page 1 TREE: ABB-VGI51/8" 5k psi . WELLHEAD: ABB-VGI13-5/8" Multibowl 5k psi NS05 . FROM - DRAFT 133/8", 68#/ft, L-80, BTC @ 3187' MD 41/2", 12.6#/ft, 13-Cr, Vam-TOP TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 53.5# L-80 BTM-C @ 11702' MD 4.5" X NIPPLE, @ 13261' MD 3.813" ID 4.5" X NIPPLE, @ 13340' MD 3.813" 10 4.5" XN NIPPLE, @ 13351' MD 3.725" ID 4.5 Self Aligning WLEG @13366'MD 3.958" ID 7", 29#/ft L-80, Hydril 511 @ 13537' MD ÆRFORA TION SUMMARY REF LOG: SWS usrr 4/11/05 ANGLEATTOPÆRF: @ 13739 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.875' 6 13739 - 13794 Opn/Sqz 04/12/05 2.875' 6 13739 - 13794 Opn/Sqz OS/27/05 PBTD @ 14027' MD TO @ 14031' MD .IGINAL KB. ELEV = 56' -BF. ELEV = 40.1' CB. ELEV = 15.9' 4 1/2" TRM-4E SSSV @ 994' MD w/4-1/2" X PROFILE=3.812' ID 41/2" GLM @ 3997' MD (4000' TVD) w/ 4.62" 10 - 7" LINER TOP @ 11525' MD 4.5" Fiber Optic Transducer 3.958" 10 @ 13292 MD _ 7"PACKER,13Cr@13316'MD 4.5" LINER TOP @ 13357' MD 4.5",12.6#, 13Cr Vam TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10105 DJA PROPOSED 03/30/05 TA FINAL 05/05/05 GJB/PJC CORRECTION SSSV 04/12/05 GJRlPJC ÆRF 05/28/05 WRRlPJC RE-ÆRF NORTHSTAR WELL: NS05 ÆRMrr No: XXXXXXX API No: 50-29-23244 SEC T N R E BP Exploration (Alaska) , . . ~ '~u ~ u Œ lID ~ ~ ~ ~ ~ ~ L% II FRANK H. MURKOWSKI, GOVERNOR AI.lASIiA OIL AND GAS CONSERVADON COMMISSION I ! '/ -"'" =- c:?f OJ - ¿J-z) 7 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Senior Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519--6612 Re: Northstar NS05 Sundry Number: 305-154 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (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 holiday or weekend. A person may not appeal a Commission decisio t Superior Court unless rehearing has been requested. DATED this1t/ day of June, 2005 Encl. « . . ,\tl". ......... ~~. ....~ ~~. ~t...~" ·'~~t'\" BP Exploration (Alaska) Inc. ". 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 " bp ,'..'. j.'-t June 21, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡lh Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS05 to Add Perforations BP Exploration Alaska, Inc. proposes to add perforations in the NS05 well./This well suffered a production loss after a scale inhibition treatment (SIT). The well was subsequently reperforated. This doubled the rate, but the well is still only /' making half of what it was before the SIT. These additionally perforations are proposed to recover additional lost rate. The procedure includes the following major steps: T e Slickline Electric Line Sincerely, ~ o/Y1(;1wj'~ ~ië'~el J. Fr is P.E. Senior Petrol m Engineer BPXA, ACT, Northstar (" \..J I; L (jfJ'f ~ ~-¿.¡ "'!)5 \i...J~'+ "/2.1 (ZðDS" . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMrðSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 StratigraphicD Service D 9. Well Name and Number: NS05 /' 10. FieldlPool(s): Northstar Field I Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): j'Effective Depth MD (ft): IEffective Depth TVD (ft): 11335.6 14027 I 11273.5 Size MD TVD .. 1. Type of Request: [] Suspend [] [] Repair Well 0 o Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. Development ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.37 KB 8. Property Designation: ADL-312808 11. Present Total Depth MD (ft): 14033 Casing Length 'ì. 4"5 :.0. o. -'0 ,» ' _0 0.0 PerforateliJ / Waivet[] StimulateD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0090 /' Other 0 / Exploratory D 6. API Number / 50-029-23244-00-00 Plugs (md): Junk (md): None None Burst Collapse bottom 10861.7 8160 7020 11333.7 8430· 7500 9401.4 7930· 6620 3183.4 4930 2270 LINER LINER PRODUCTION SURFACE top bottom top 2012 7" 29# L-80 11525 - 13537 9294.0 - 674 4-1/2" 12.6# 13CrSO 13357 - 14031 10689.3 - 11687 9-518" 53.5# L-80 15 - 11702 15.0 - 3171 13-318" 68# L-80 16 - 3187 16.0 - Perforation Depth MD (ft): 13739 - 13794 701'- 11.7' Perforation Depth TVD (ft): 11054 - 11106.7 Tubing Size: 4-1/2 " Tubing Grade: Tubing MD (ft): 12.6 # 13Cr80 13- 13366 Packers and SSSV MD (ft): Packers and SSSV Type: 4-1/2" TRM-4E SSV 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: 994 11525 13316 13. Well Class after proposed work: ~/ ServiceD Description Summary of Proposal Œ1 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: June 25, 2005 Exploratory D DevelopmentOO 15. Well Status after proposed work: Oil ŒJ /GasD PluggedD Abandoned 0 16. Verbal Approval: Date: WAG 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Michael Francis o/YJ/I--A¿;_ 0 A Ý... "'L~ fJ. ,E. \ t1 J v Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness Plug I egrity BOP TestD Mechanciallntegrity Test 0 Other: SUbSeqUr orm edj, I I ð - 404- APprov~ j', A For~3 Re~ 11/~ o R \ G l "'0. Ji \ Ii GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Michael Francis Title Phone Senior Petroleum Engineer 564-4240 6/21/05 I Sundry Number: -~...,ç -I S-t./ Location Clearance 0 RBDMS BFL JUN 2 2 2005 Þ! BY ORDER OF / '/" , THE COMMISSION Date: ,¡:; /U () S I SUBMIT IN DUPLICATE TREE: ABB-VGI5 1/8" 5k psi . WELLHEAD: ABB-VGI13-5/8" fiVlultibowl 5k psi NS05 133/8", 68#/ft, L-80, BTC @ 3187' MD 41/2", 12.6#/ft, 13-Cr, Vam-TOP TUBING 10: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 53.5# L-80 BTM-C@ 11702' MD 4.5" X NIPPLE, @ 13261' MD 3.813" 10 4.5" X NIPPLE, @ 13340' MD 3.813" ID 4.5" XN NIPPLE, @ 13351' MD 3.725" 10 4.5 Self Aligning WLEG @13366'MD 3.958" ID 7", 29#/ft L-80, Hydril 511 @ 13537' MD PERFORA TION SUMMARY REF LOG: SWS usrr 4/11 /05 ANGLE AT TOP PERF: @ 13739 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2.875' 6 13739 - 13794 Opn/Sqz 04/12/05 2.875' 6 13739 - 13794 Opn/Sqz OS/27/05 PBTD @ 14027' MD TO @ 14031' MD .IGINAL KB. ELEV == 56' -BF. ELEV == 40.1' CB. ELEV '" 15.9' 4 1/2" TRM-4E SSSV @ 994' MD w/4-1/2" X PROFILE=3.812' ID 4 1/2" GLM @ 3997' MD (4000' TVD) w/ 4.62" ID - T' LINER TOP @ 11525' MD 4.5" Fiber Optic Transducer 3.958" ID @ 13292 MD _ T'PACKER,13Cr@13316'MD 4.5" LINER TOP @ 13357' MD 4.5",12.6#, 13Cr Vam TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/05 DJA PROPOSED 03/30/05 TA FINAL 05/05/05 GJB/PJC CORRECTION SSSV 04/12/05 GJRlPJC PERF OS/28/05 WRRlPJC RE- PERF NORTHSTAR W8.L NS05 PERMrr No: XXXXXXX API No: 50-29-23244 SEC T N R E BP Exploration (Alaska) .... @~Ir "\1 n æJU . r?... r'.I· í~n 1""";::1 11-, H !~b ~,·.i F HI! I L:!'.:::v u . ~oc5 ~ rJ-ð { AIIASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS05 Sundry Number: 305-132 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (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 0 unless rehearing has been requested. DATED this t(y of May, 2005 Encl. .. * S''U-05 \tJGA- SI¿(ç/àoS- f)7s; ~Ç/5 RËr~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY)~ ¿005 APPLICATION FOR SUNDRY APPROVAL.n¡/8. (;íi$ Con?J 20 AAC 25.280 ". / . .. 1. Type of Request; Alter Casing Change Approved Program Abandon 0 o o Repair Well Pull Tubing Suspend 0 o o Operation Shutdown Plug Perforations Perforate New Pool o o o Perforate[i] Waiver 0 StimulateD Time Extension 0 Re·enter Suspended Well 0 5. Permit to Drill Number: 205-0090 r- Other 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 / Exploratory D 11, Present Total Depth MD (ft): 14033 Casing Total Depth TVD (It): 11335.6 StratigraptlicD Service D 9. Well Name and Number: NS05 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14027 11273.5 MD ~D 6. API Number .; 50-029-23244-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.37 KB B. Property Designation: ADL-312808 Plugs (md): None Burst Junk (md): None Collapse 15.0 9294.0 10689.3 16.0 bottom 9401.4 10861.7 11333.7 3183.4 Tubing Grade: 13Cr80 7930 8160 8430 4930 Tubing MD (ft): 6620 7020 7500 2270 to INTERMEDIATE 11687 9-5/8" 53.5# L-80 15 LINER 2012 7" 29# L·80 11525 LINER 674 4-1/2" 12.6# 13Cr80 13357 SURFACE 3171 13-3/6" 68# L-80 16 Perforation Depth MPift): - Perforation Depth TVD (ft): 1~7ª9 . 13794 11054 - 11106.7 Packers a ö SS8V Type' , Nipple 4-1/2"J3aker S-3 Perm Pac(er 12. Attachments: 13366 994 13316 Description Summary of Proposal lEI Detailed Operations Proqram D BOP Sketch D 14. Estimated Date for idGÃ- Commeocin 0 eration: 13. Well Class after proposed work: / ServiceD Exploratory D Development[&] 15. Well Status after proposed work: Oil Œ! GasD PluggedO Abandoned 0 Contac1 WINJD WDSPLD f'(e),,,.re_~ by ~<ir'Y Ciltron .5.64.4657. Michael Francis 16. Verbal Approval: Date: WAG 0 ºgmmi$_?IQn Ae resentat!Y,,:_ 17. I hereby certify that the foregoing is trur! and correct to the best of my knowledge. GINJD Commiª~ion Use Onl Conditions of approval: Notify Commission so that a representative may witness .~. Title Phone Petroleum Engineer 564-4240 5/25/05 Printed Name Signature Sundry Number; 3oS:- I ;?:;ì... BOP TestO Mechanciallntegrity Tes1 0 Location Clearance ,0 Other: Approved by: BY ORDER OF THE COMMISSION RBDMS 8FL M4 V 9. (; ?D05 Form 10·403 Hevised 11/2004 ORIGINAL SUBMIT IN DUPLICATE . . , bp B, .._,"'" IAI.....I '00. 0 900 East Benson Boulevard P. O. Box 196612 Anchorage. Alaska 99519·6612 (907) 561·5111 May 24, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡lh Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS05 to Re-Perforate BP Exploration Alaska, Inc. proposes to re-perforate the NS05 well. This well suffered a production loss after a scale inhibition treatment. Pumping records /' indicate that there was a pressure increase as soon as the injected fluids reached the reservoir. Perforation plugging is suspected and reperforating is recommended. The procedure includes the following major steps: T e Slickline un Electric Line Sincerely, '171M~'~ ·Míðhael J. s, P .E. Senior Pet leum Engineer BPXA, ACT, Northstar . ~ . lHEE: ABBVGI 51/8" 5k psi WELLHEAD: ABB-VGI 135/8'" Multìbowl 5k psI . NS05 _INN KB, ELEV ~ 56 KB-BF. ELEV ~ 40,-1' CB. LLEV ~ 158' Dr~ [) 1/2" SSSV @ 994' TVD TRM-4E w/4-'j/2" X Pfi.OFlLE'3J3"12' 10 G.8PPG DIESEL FREEZE PROTECTIOf'J AT +/- 3000' TVD (3000'MD) 13 ;,/8", G8tt/ft, L-80, GTC @ 3181' MO 4 1/2" GLM @ 4000' TVD (3881' MD) w/ 4,62" 10 41/2" -¡2,6#/ft. 13-Cr, Varn,TOP TUBING If): 3,9£)8" CAPACITY: 0,01522 BBLlFT 4.5" X NIPPLE, @ 13261' MD 3,813" ID - T' LINER TOP @ 11525' MD 4.5" Fiber Optic Transducer 3,958" 10 ({ý '13292 MD 4,5" X NIPPLE. @ 13340' fv1D 3,813" If) 4.5" XN NiPPLE. @ 13351' MD 3>725" If) 45 Self Aligning INLEG @13360'MD 3.958"' ID ~ l"PACKER,13Cr@1331G'MD 45" LINER TOP @ 1:3357' MD 7", 29#/ft L-80. Hydril 511 @13537' MD .,~J?f" ~J " ... ~1 c;lAv¡ pE3TD @ 14021' MD TI) @ 14031' MD 45", 12,6#, 13Cr Varn TOP DATE REV BY COMMENTS DATE REV BY COMMEi'HS 02/10/05 DJA PROPOSED 03/30/05 TA FINAL 05105/05 GJBIPJC CORRECTK)N SSSV NORTHSTAR WELL NS05 ÆRMfT No XXXXXXX API No 50-29,23244 SEe T N R E BP Exploration (Alaska) · STATE OF ALASKA . ALASKA oiL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG rVE,D 2 () 2005 r O'11m\ssícn .".'c,i{A L;, '-'± jt''S. \"un,>. · I , 1a. Well Status: ~ Oil DGas D Plugged D Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development 1j Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/12/2005 205-009 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/16/2005 50- 029-23244-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 3/23/2005 NSOS 1089' NSL, 641' WEL, SEC. 11, T13N, R13E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 90' NSL, 1936' WEL, SEC. 14, T13N, R13E, UM 56.37' Northstar Unit Total Depth: 9. Plug Back Depth (MD+ TVD) 5268' NSL, 1764' WEL, SEC. 23, T13N, R13E, UM 14027 + 11330 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 659835 y- 6030861 Zone- ASP4 14033 + 11336 Ft ADL 312808 ~--- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 658861 y- 6024557 Zone- ASP4 Total Depth: x- --- 994' MD 658856 y- 6024459 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ~Yes DNo 39' MSL 1545' (Approx.) 21. Logs Run: MWD , LWD , DIR , GR , GYRO, PWD , RES, DEN, NEU , SONIC (ISONIC) , SCMT , CBL , US IT 22. CASING, liNER AND CEMENTING RECORD CASING SETTINQ DEPTH MD SETTING DEPTHTV') HOLE AMOUNT SIZE WT. PER FT. GRADE TOp BOTTOM Top I BOnOM SIZE PUllED 20" 169# X-56 Surface 201' Surface 201' 20" Driven 13-3/8" 68# L-80 45' 3187' 45' 3183' 16" 419 sx PF 'L', 457 sx Class 'G' 9-5/8" 53.5# L-80 42' 11702' 42' 9401' 12-1/4" 755 sx Extended, 595 sx 'G' 7" 29# L-80 11524' 13536' 9293' 10861 ' 8-12" 469 sx Class 'G' 4-1/2" 12.6# 13CR-80 13357' 14031' 10689' 11334' 6" 89 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD ",..,. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6SPF 4-1/2", 12.6#, 13Cr-80 13366' 13316' MD TVD MD TVD 13739' - 13794' 11054' - 11107' 25. ACID, FRACTURE, CEMENT SaUEE4iS, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 78 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 13, 2005 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF W A TER-BSl OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". - None GUMFLET:Óii RBDMS 8FL MAY 2 5 2005 MiJ~. (~) ~ """,,,.I I ~ (' .~ \;d~' Form 10-407 Revised iM"003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD Top of Kuparuk 10980' Kuparuk 'C' 11235' Top of Miluveach 11757' Top of Kingak 12528' Top of Sag River 13496' Top of Shublik 13605' Top of Ivishak 13696' 29. ORMATION TESTS TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3965' None 9119' 9435' 9967' 10822' 10927' 11013' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date NS05 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 David Johnson, 564-4171 205-009 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE: ABB-VGI 5 1/8" 5k psi . WELLHEAD: ABB-VGI13-5/8" Multibowl 5k psi DRLG - DRAFT 13 3/8", 68#/ft, L-80, BTC @ 3187' MD 41/2", 12.6#/ft, 13-Cr, Vam-TOP TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 53.5# L-80 BTM-C @ 11702' MD 4.5" X NIPPLE, @ 13261' MD 3.813" 10 4.5" X NIPPLE, @ 13340' MD 3.813" 10 4.5" XN NIPPLE, @ 13351' MD 3.725" ID 4.5 Self Aligning WLEG @13366'MD 3.958" 10 7", 29#/ft L-80, Hydril 511 @ 13537' MD PBTD @ 14027' MD TD @ 14031' MD NS05 eRIGINAL KB. ELEV = 56' B-BF. ELEV = 40.1' CB. ELEV = 15.9' 4 1/2" SSSV @ 994' TVD TRM-4E w/4-1/2" X PROFILE=3.812' ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 3000' TVD (3000'MD) 41/2" GLM @ 4000' TVD (3997' MD) w/ 4.62" 10 - 7" LINER TOP @ 11525' MD 4.5" Fiber Optic Transducer 3.958" ID @ 13292 MD _ 7" PACKER,13 Cr@ 13316' MD 4.5" LINER TOP @ 13357' MD 4.5",12.6#, 13CrVam TOP DATE REV BY COMMENTS DATE REV BY COMMENTS 02/10/05 DJA PROPOSED 03/30/05 TA FINAL 05/05/05 GJB/PJC CORRECTION SSSV NORTHSTAR WELL: NS05 ÆRMIT No: XXXXXXX API No: 50-29-23244 SEC T N R E BP Exploration (Alaska) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/12/2005 00:00 - 00:30 0.50 MOB P PRE -RIU Rig Floor To P/U Drill Pipe -PJSM wI AIC Crane Operator On Setting Four High Rig Mats Between Flowlines 00:30 - 02:00 1.50 MOB P PRE -Prep 5" DP f/ P/U -Mix Spud Mud 02:00 - 10:00 8.00 MOB P PRE -P/U 5" DP & Stand Back In Derrick-Torque To 30K -Mix Spud Mud 10:00 - 11 :00 1.00 MOB P PRE -Rig Service-Drawworks & Top Drive -Mix Spud Mud 11 :00 - 14:30 3.50 MOB P PRE -Load 5" DP In Pipe Shed & Prep f/ P/U -Mix Spud Mud 14:30 - 22:30 8.00 MOB P PRE -P/U 5" DP & Stand Back In Derrick -Mix Spud Mud 22:30 - 00:00 1.50 MOB P PRE -Load 5" DP In Pipe Shed & Prep f/ P/U -Mix Spud Mud 2/13/2005 00:00 - 06:00 6.00 MOB P PRE -P/U Drill Pipe -Total of 134 Stands 06:00 - 07:30 1.50 MOB P PRE -P/U 7 Stands HWDP 07:30 - 09:30 2.00 MOB P PRE -Remove Lower Spool f/ Stack 09:30 - 10:30 1.00 MOB P PRE -Load Pipe Shed wI 4" HT 40 DP & Clear Rig Floor 10:30 - 11 :30 1.00 MOB P PRE -Prep II Pull Highline Power 11 :30 - 12:00 0.50 MOB P PRE -Cleaning Rig & Prep f/ Rig Move 12:00 - 13:30 1.50 MOB P PRE -String 13,800 Volt Cable Through Rig 13:30 - 00:00 10.50 MOB P PRE -Load Pipe Shed w/13 3/8 Casing-Set Mats Between Flowlines-Prepare Pad fl Rig Move-Install Gas Lines-Install Riser Adapter onto NS05 Conductor-Spread Gravel In NS05 Cellar & Cover w/ Herculite 2/14/2005 00:00 - 06:00 6.00 MOB P PRE -Load 13318 Casing In Pipe Shed (Total 83 Joints) -Prep Rig f/ Move-Warm Hydraulics-Seperate PUTZ -PJSM & Rig Move Checklist Review 06:00 - 00:00 18.00 MOB P PRE -Move Rig fl NS31 To NS05 2/15/2005 00:00 - 04:00 4.00 MOB P PRE - Skid Rig from NS31 to NS05. 04:00 - 06:00 2.00 MOB P PRE - Level rig & berm outside of rig. - Accept rig @ 06:002-15-05. 06:00 - 12:00 6.00 RIGU P PRE - Safe out NS-05 cellar. - Made modification to toe board to keep tuggers from hanging up. - Clean up around NS-31. - Put mud cleaner together. - Repair dresser sleeve in pits. - Test connections on lower riser. - N/U surface riser. 12:00 - 13:30 1.50 RIGU P PRE - Hook up water & diesel lines from piperack to rig. 13:30 - 17:30 4.00 RIGU P PRE - Skid rig floor & install surface riser. - Repair dresser sleeves in pits. - Continue clean up around NS-31 17:30 - 21:00 3.50 RIGU P PRE - RIU turnbuckles on riser. - Install mouse hole. - Install iron roughneck floor track. - Bring BHA & gyro tools to rig floor. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/15/2005 17:30 - 21 :00 3.50 RIGU P PRE - Install 4" ball valve on conductor outlet. 21 :00 - 22:30 1.50 RIGU P PRE - Test riser w/ SIW. Riser leaked. Adjust riser & retest. Good test w/ SIW. 22:30 - 00:00 1.50 RIGU P PRE - Prep for BHA. Bring sheaves to rig floor & spot E-line unit. 2/16/2005 00:00 - 01 :00 1.00 RIGU P PRE - Bring gyro tools to rig floor. - Fill swivel wI gear oil. 01 :00 - 03:00 2.00 RIGU P PRE - P/U & M/U BHA #1.16" MXC-1, 95/8" XP motor, orienting sub, NM stab, 2 NMLC's, NM stab, & XO. 03:00 - 04:00 1.00 RIGU P PRE - R/U E-line sheaves for gyro. 04:00 - 04:30 0.50 RIGU P PRE - Held pre-spud meeting & discussed hazards associated wI surface hole. Reviewed roles & responsibilities for 0-7 drill. 04:30 - 05:00 0.50 RIGU P PRE - P/U remaining BHA. 05:00 - 08:30 3.50 RIGU N RREP PRE - Thaw out goose neck on TO. 08:30 - 10:30 2.00 DRILL P SURF - Clean out conductor & drill 16" hole to 245'. 1 0:30 - 11 :30 1.00 DRILL P SURF - Survey wI gyro & UD BHA # 1. 11 :30 - 14:00 2.50 DRILL P SURF - P/U & M/U BHA # 2. 16" MXC-1, 9 5/8" XP motor, 2 NMLC's, NM stab, MWD, orienting sub, NM stab, 28" NMDC's, NM stab, 8" NMDC, jars, & HWDP. 14:00 - 00:00 10.00 DRILL P SURF - Drill 16" surface hole from 245' to 1250' pumping red mud sweeps as required. - P/U wt 120K, S/O wt 123K, Rot wt 125K. - AST .25 hrs, ART 5.0 hrs, ADT 5.25 hrs. 2/17/2005 00:00 - 00:30 0.50 DRILL P SURF - Drill 16" surface hole from 1250' to 1291'. 00:30 - 02:00 1.50 DRILL N SFAL SURF - CIO liner & swab on # 2 mud pump. Both pumps were equipped w/ new 6" swabs & liners before spudding. 02:00 - 07:30 5.50 DRILL P SURF - Drill 16" surface hole from 1291' to 1950'. 07:30 - 08:30 1.00 DRILL P SURF - BID TD & take gyro surveys every 100' from 1000' to current depth. 08:30 - 09:30 1.00 DRILL P SURF - RID gyro tools & Schlumberger. Clear floor of tools. 09:30 - 21 :30 12.00 DRILL P SURF - Drill 16" surface hole from 1950' to TD @ 3207'. - Drilling parameters: 900 GPM, pressure on bottom 2200 psi, off bottom 2000 psi, 50 RPM, on bottom Tq 8K, off bottom Tq 2.5K, P/U wt 160K, S/O wt 160K, Rot wt 160K. - AST 1.0 hrs, ART 11.6 hrs, ADT 12.6 hrs. 21 :30 - 23:00 1.50 DRILL P SURF - Pump red mud sweep & circ surface to surface x 2 @ 900 GPM, 2200 psi. 23:00 - 00:00 1.00 DRILL P SURF - POH wI single & 5 stands DP to 2709'. Hole slick. 2/18/2005 00:00 - 02:30 2.50 DRILL P SURF - POH to BHA. Hole in good condition wI occassional 20K drag on 3 stands. 02:30 - 05:30 3.00 DRILL P SURF - UD BHA # 2. 05:30 - 06:30 1.00 DRILL P SURF - Clean & clear floor of tools. 06:30 - 08:00 1.50 CASE P SURF - MIU LJ & make dummy run w/13 3/8" mandrel hanger. 08:00 - 10:00 2.00 CASE P SURF - RlU Frank's fill up tool & 13 3/8" casing tools. 10:00 - 19:00 9.00 CASE P SURF - Run 76 jts 133/8" 68# L-80 BTC casing utilizing BOL 2000 thread compound. Avg. M/U Tq 9800 ftIlb.s. Work through tight spots @ 940', 2520', 2600', & 2630'. - RID Frank's fill up tool. - M/U 13 3/8" mandrel hanger & land casing wI 170K. 19:00 - 21 :30 2.50 CASE P SURF - Circulate & condition mud prior to cement job as follows: BPM ICP FCP TOTAL STKS (running total) 1 245 220 345 Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/1812005 19:00 - 21 :30 2.50 CASE P SURF 1.5 230 215 465 2.0 220 200 600 2.5 205 195 725 3.0 200 190 950 4.0 215 190 1250 5.0 225 210 2100 6.0 255 240 3230 7.0 300 300 4100 8.0 355 350 4720 9.0 425 420 5100 10.0 485 460 5930 11.0 520 500 6880 - Hold PJSM for cement job while circulating. 21 :30 - 22:30 1.00 CASE P SURF - Pump 5 bbls S/W & test lines to 5000 psi. Developed leak @ 4500 psi on cement line manifold hammer union. Bleed off pressure & replace hammer union gasket. Retest lines to 5000 psi. 22:30 - 00:00 1.50 CEMT P SURF - Pump 25 bbls CW-101 followed by 75 bbls 10.3 Mud Push. Drop bottom plug & pump 364 bbls 10.7 ppg Arctic Set lead cement. 2/19/2005 00:00 - 00:30 0.50 CEMT P SURF - Pump 97 bbls 15.9 ppg Class G tail cement @ 6-7 BPM, 1400 - 1620 psi. Drop top plug & wash up on top of plug w/15 bbls S/W. 00:30 - 01 :30 1.00 CEMT P SURF - Turn over to rig pumps & displace cement @ 10 BPM. Slow down pump to 5 BPM 15 bbls prior to bumping plug. Bump plug wI 451 bbls mud @ 95% pump efficiency. Pressure up to 500 psi over bump pressure to 1600 psi & hold for 3 minutes. Bleed off pressure & check floats - floats held. - Total of 115 bbls cement returned. 01 :30 - 03:30 2.00 CEMT P SURF - RID cement head & LJ. 03:30 - 05:00 1.50 CEMT P SURF - CIO long bails to short bails. 05:00 - 08:00 3.00 BOPSU P SURF - NID surface riser. 08:00 - 10:00 2.00 WHSUR P SURF - Clean & prep 133/8" mandrel hanger. NU & test 'speed head'. 5 k x 10 mins. 10:00 - 18:30 8.50 BOPSU P SURF - NU BOP, choke lines, set riser. - Function test all rams. - Change lower pipe rams to 2 7/8" x 5" VBR 18:30 - 20:00 1.50 BOPSU SURF - PU & install test jt. - Set Iron Roughneck track. 20:00 - 22:00 2.00 BOPSU SURF - Test BOPE to BP & AOGCC regs. Annular 250 low 13500 psi high. 5 mins each test. Test witness by WSL & witness of test waived by AOGCC Rep Jeff Jones. - Attempt to test upper pipe rams. Leak. 22:00 - 23:30 1.50 BOPSU SURF - Drain stack & CIO upper pipe rams. 23:30 - 00:00 0.50 BOPSU SURF - Test BOPE to BP & AOGCC regs. 250 psi 14800 - 5 mins. each test. 2/20/2005 00:00 - 05:00 5.00 BOPSU SURF - Test BOPE to BP & AOGCC regs. 250 psi I 4800 psi - 5 mins for each test. No failures. 100% of test witnessed by WSL. - Witness of test waived by AOGCC Rep Jeff Jones. 05:00 - 05:30 0.50 BOPSU SURF - BID all lines & R/D test equip't. 05:30 - 06:00 0.50 BOPSU SURF - Install bowl protector. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 - Install mouse hole. - MIU 121/4" drilling assy - BHA # 3 - 12 1/4" RSX 238 PDC bit, bias unit, ext sub, control collar, float sub, NM stab, ARC collar, MWD, Sonic collar, NM stab, 2 NMDC's, NM stab, NMDC, jars, & ADN collar. - Shallow test MWD & RSS. - Installed nuclear source in BHA. 11 :00 - 14:00 3.00 CASE P SURF - RIH w/ HWDP - P/U 2 singles off skate. - M/U reamer & dart sub. - RIH wI 21 stands DP. 14:00 - 17:00 3.00 CASE P SURF - Cut & slip drilling line. - Inspect brakes, service TO, & lubricate rig. 17:00 - 18:00 1.00 CASE P SURF - Wash down to float collar & tag FC on depth @ 3102'. 18:00 - 19:30 1.50 CASE P SURF - Pressure test 13 318" casing to 3480 psi wI 8.8 ppg. Chart test & hold for 30 minutes. - Review 01, 02, & 05 drills while holding casing test. - BID kill line. 19:30 - 21 :30 2.00 CEMT P SURF - Drill plugs & shoe track. 675 GPM, 1300 psi, 75 RPM. 21 :30 - 23:00 1.50 CEMT P SURF - Drill 20' new hole to 3227' while displacing to new 8.6 ppg drilling fluid. 23:00 - 00:00 1.00 CEMT P SURF - Perform FIT to 12.5 EMW (650 psi) w/8.6 ppg drilling fluid. Chart & hold for 10 mins. - Change shaker screens & clean suction screens. - B/D kill line. 2/21/2005 00:00 - 01 :00 1.00 CEMT P SURF - UD single & make connection. IBOP not opening - rack back stand & thaw out IBOP. 01 :00 - 12:00 11.00 DRILL P INT1 - Drill directional in 12 1/4" wI RSS from 3227' to 4500' pumping sweeps every 500' to clean hole. - Drilling parameters: WOB 10K, 900 GPM, 2000 psi, Tq on bottom 6K, Tq off bottom 3.5K, P/U wt 193K, S/O wt 190K, Rot wt 191K - Actual ECD's running .2 -.3 ppg over calculated clean hole ECD. - ART 7.33 hrs. - Screen up to 35's & 50's on shakers temporarily until mud sheared. 12:00 - 00:00 12.00 DRILL P INT1 - Drill directional in 12 1/4" hole wI RSS from 4500' to 5601' pumping sweeps every 500' to clean hole. - Drilling parameters: WOB 10K, 920 GPM, 2050 psi, Tq on bottom 8K, Tq off bottom 5K, P/U wt 215K, S/O wt 205K, Rot wt 210K. - Actual ECD's running .2 -.3 ppg over calculated clean hole ECD. - ART 7.87 hrs. 2/22/2005 00:00 - 10:30 10.50 DRILL P INT1 - Drill directional in 12 1/4" hole from 5601' to 6524' pumping hi-vis sweeps every 400' to 500'. Sweeps bringing back 10% to 20% excess cuttings. - Drilling parameters: WOB 10K, 950 GPM, 2350 psi, Tq on bottom 8K, off bottom 6K, P/U wt 230K, SIO wt 205K, Rot wt 210K. ART 9.02 hrs. 10:30 - 11 :00 0.50 DRILL P INT1 - Service TO. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/22/2005 11 :00 - 00:00 13.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 6524' to 7380' pumping hi-vis sweeps every 500'. Sweeps bringing back 10% to 20% excess cuttings. - Drilling parameters: WOB 10-13K, 950 GPM, 2550 psi, Tq on bottom 11 K, off bottom 9K, P/U wt 240K, 8/0 wt 21 OK, Rot WI 220K. ART 8.78 hrs. - Actual ECD's running .25 ppg - .4 ppg over calculated clean hole ECD. 2/23/2005 00:00 - 01 :30 1.50 DRILL P INT1 - Drill directional in 12 1/4" hole from 7380' to 7470'. 01 :30 - 02:00 0.50 DRILL P INT1 - Service TO. 02:00 - 12:00 10.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 7470' to 8702' pumping hi-vis sweeps every 400'. - Drilling parameters: WOB 13K-25K, 920 GPM, 3100 psi, Tq on bottom 17K, Tq off bottom 10K, P/U WI 260K, S/O wt 210K, Rot wt. 225K. - ART for last 12 hrs = 7.51 hrs. 12:00 - 19:00 7.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 8702' to 9553' pumping hi-vis seeps every 400'. 19:00 - 19:30 0.50 DRILL P INT1 - Service TD. 19:30 - 00:00 4.50 DRILL P INT1 - Drill directional in 12 1/4" hole from 9553' to 9975' pumping hi-vis sweeps every 400'. - Drilling parameters: WOB 15K-20K, 850 GPM, 3250 psi, Tq on bottom 17K, Tq off bottom 13K, P/U WI 270K, SIO WI 220K, Rot wt 240K. - ART for last 12 hrs = 8.35 hrs - ECD's running .5-.7 ppg over calculated clean hole ECD. Circulate as required to maintain ECD's below.7 ppg over calculated clean hole ECD. 2/24/2005 00:00 - 06:30 6.50 DRILL P INT1 - Drill directional in 12 1/4" hole from 9975' to 10592'. - Reduce surface volume & add 600 bbls 12.3 ppg spike fluid 500' above prognosed top of HRZ. Current MW 10.1 + ppg. 06:30 - 07:00 0.50 DRILL P INT1 - Service TD. 07:00 - 13:00 6.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 10592' to 11067' pumping hi vis sweeps every 400' to 500'. - Drilling parameters: WOB 10K in Kuparuk, 20K in Colville, 850 GPM, 3400 psi, 130 RPM, Tq on bottom 17K, Tq off bottom 12K, P/U WI 280K, 8/0 WI 225K, Rot wt 250K. 13:00 - 14:00 1.00 DRILL P INT1 - Circulate to bring ECD below .7 ppg below calculated clean hole ECD. 14:00 - 22:00 8.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 11067' to 11352'. - Drilling parameters: WOB 10K, 850 GPM, 3500 psi, 130 RPM, Tq on bottom 18K, Tq off bottom 12K, P/U wt 295K, SIO WI 230K, Rot wt 260K. 22:00 - 22:30 0.50 DRILL P INT1 - Lubricate rig, service TD & drawworks. 22:30 - 00:00 1.50 DRILL P INT1 - Drill directional in 12 1/4" hole from 11352' to 11435'. - ART for last 24 hrs = 17.5 hrs. 2/25/2005 00:00 - 12:00 12.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 11435' to TO @ 11993'. - Drilling parameters: WOB 20K, 750 GPM, 3350 psi, 130 RPM, Tq on bottom 20K, Tq off bottom 17K, P/U wt 315K, S/O wt 260K, Rot wt 265K. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/2512005 00:00 - 12:00 12.00 DRILL P INT1 - ART 9.20 hrs. 12:00 - 16:30 4.50 DRILL P INT1 - Circulate hi-vis weighted sweep surface to surface and addittinal B/U x 2 @ 800 GPM, 3100 psi, 130 RPM. 16:30 - 00:00 7.50 DRILL N FLU 0 INT1 - Attempt to POH, hole tight wI 75K overpull. Backream to above HRZ. Made several attempts to pull wlo backreaming or pumps wlo success due to overpulls of 75K+. Packed off @ 10592' while attempting to POH w/ pumps only. 2/26/2005 00:00 - 18:00 18.00 DRILL N FLUD INT1 - Backream from 10,592' to 3973'. Attempt to pull w/o backreaming or pumps every 200' to 300' w/o success due to excessive overpulls or swab. 18:00 - 00:00 6.00 DRILL N FLUD INT1 - With ghost reamer -150 above shoe, circulated up mud ring that completely packed off flowline & filled drip pan to 50% capacity. Excellent catch by Driller & Crew to recognize & shut down operations before filling drip pan to maximum capacity. Filling drip pan would have caused a spill in the cellar. - Clean & clear flowline & drip pan. Flowline had to be partially removed to be cleaned. - Moved pipe every 15 - 20 minutes while cleaning flowline & drip pan. 2/27/2005 00:00 - 02:30 2.50 DRILL N FLUD INT1 - Clean flowline & drip pan. 02:30 - 04:00 1.50 DRILL N FLUD INT1 - CBU x 2, slowly increasing pump rate to 875 GPM, 2550 psi, & 140 RPM while jetting flowline. Large clay balls the size of footballs @ shakers. 04:00 - 05:30 1.50 DRILL N FLUD INT1 - Backream from 3973' to 3180'. 05:30 - 07:00 1.50 DRILL N FLUD INT1 - Clean suction screens on mud pumps. - Pump hi-vis sweep wI nut plug surface to surface @ 890 GPM, 2540 psi, 120 RPM. Continued pumping until shakers cleaned up. 07:00 - 10:00 3.00 DRILL N FLUD INT1 - PUMP out of hole to 2500' & POH to 1500' wlo pumps. No swabbing. 10:00 - 11 :00 1.00 DRILL N FLUD INT1 - Service TO & drawworks, & lubricate rig. 11 :00 - 11 :30 0.50 DRILL N FLUD INT1 - Continue POH to BHA @ 949'. 11 :30 - 17:30 6.00 DRILL N FLUD INT1 - UD ghost reamer - ghost reamer had wear & tear at the top of the blade from backreaming, but was in gage. - Rack back HWDP. - Pump 20 bbls fresh water through tools. - PJSM for removing source - remove same. UD directional tools. Removed ADN, sonic tool, & rotary steerable for upcoming wiper trip. 17:30 - 18:00 0.50 DRILL N FLUD INT1 - Clear & clean floor. 18:00 - 20:00 2.00 DRILL N FLUD INT1 - M/U & RIH wI BHA # 4 - same 12 1/4" RSX238 PDC bit, NB stab, 2 NMLC's, NM stab, PWD, MWD, NM stab, 2 NMDC's, NM stab, NMDC, jars, & 23 jts HWDP. 20:00 - 20:30 0.50 DRILL N FLUD INT1 - Shallow hole test MWD - okay. BID lines. 20:30 - 21 :00 0.50 DRILL P INT1 - MIU ghost reamer & dart sub. 21 :00 - 22:00 1.00 DRILL N RREP INT1 - CIO elevators due to wear. Service new elevators. 22:00 - 23:00 1.00 DRILL N FLUD INT1 - RIH to 3180'. 23:00 - 00:00 1.00 DRILL N FLUD INT1 - CBU before exiting shoe @ 800 GPM, 1380 psi. Shakers clean. P/U wt 155K, S/O wt 160K, Rot wt 160K @ 100 RPM. 2/28/2005 00:00 - 06:30 6.50 DRILL N FLUD INT1 - RIH to 10,142' filling every 30 stands. - Wipe through tight spot @ 9950'. - Tight spot @ 10142' - stack up 30K. M/U TD & wash through 700 GPM, 2400 psi. RIH to 10365'. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 2/28/2005 06:30 - 07:30 1.00 DRILL N FLUD INT1 - Wash & ream through tight spots from 10365' to 10600', 780 GPM 2830 psi, 100 RPM, Tq 11K. Tq erratic @ 10600'. 07:30 - 08:30 1.00 DRILL N FLUD INT1 - CBU @ 800 GPM, 2400 psi, ECD=10.93 ppg. 08:30 - 09:30 1.00 DRILL N FLUD INT1 - Ream from 10,600' to 10,900'. Tq up & stall rotary I pack off @ 10,900. Work tight hole & establish rotation & circulation @ 10,858'. - Stage up pumps to 800 GPM, 2800 psi, ECD=10.94 ppg. 09:30 - 11 :00 1.50 DRILL N FLUD INT1 - Circ surface to surface @ 800 GPM, 2800 psi, 100 RPM, Tq 13K. 11 :00 - 21 :00 10.00 DRILL N FLUD INT1 - Ream from 10,858' to 11,032' 700 GPM, 2500 psi, 100 RPM. - Attempt to work stand after reaming down - stall rotary & packoff @ 11012'. Attempt to establish circ slowly, only to packoff again. Work pipe & establish rotation @ 100 RPM. Establish circulation wlo losses, but unable to exceed 5 BPM wlo packing off. - Up & down movement minimal & packed off x 2 when trying to increase pump rate above 5 BPM. 21 :00 - 23:00 2.00 DRILL N FLU 0 INT1 - Backream slowly to 10902' @ 100 RPM. Max pump rate wlo packing off 2 BPM. - At 10,902' Tq & drag reduced & was able to slowly bring up pump rate to 19 BPM, 2975 psi. Increasing MW to 10.7 ppg. 23:00 - 00:00 1.00 DRILL N FLUD INT1 - Circulate 10.7 ppg mud around w/lubes & sapp @ 21 BPM, 3300 psi, 100 RPM. 3/1/2005 00:00 - 02:00 2.00 DRILL N FLUD INT1 - Wash & Ream f/10906' to 11010'. Pack Off & Stall Rotary. Establish Circulation @ Low Rate & Increase Pump Rate to 8 BPM-750 PSI @ 100 RPM - Discuss options wI Anchorage 02:00 - 07:30 5.50 DRILL N FLUD INT1 - Backream f/11 012' to 10460'. - Attempt to Pump Out of Hole @ 10839' w/ 0 Success. -Resume backreaming 15 BPM, 2050 psi, 115 RPM. - Packed off @ 10463' - Establish pump rate @ 18 BPM, 2700 psi, 120 RPM, Trq Ranged f/12/20K -Continue Backreaming to 9800' 07:30 - 10:30 3.00 DRILL N FLUD INT1 -Pump SIS Volume @ 20 BPM-3030 PSI-Rotate @ 120 RPM wI Torque @ 11K -Pump 70 BBL Hi-Vis Sweep S/S wI Above Parameters -Reciprocated Pipe f/9800'-9893 While Pumping Sweeps -ECD Dropped f/1 0.96 to 10.9 10:30 - 00:00 13.50 DRILL N FLUD INT1 -Ream fl 9893' to 11015' @ 10 MinlStand -Pump @ 20 BPM-3080 PSI, ECD @ 10.69 EMW -Ream f/11 015' to 11035' While Packing Off & Stalling Top Drive -Established Circulation @ 2-3 BPM & Backreamed to 10987' -Raised Pump Rate to 19 BPM-3000 PSI @ 10987' -Discussed Plan Foward wI ODE-Decision Made to POOH to P/U BHA f/ Open Hole Side Track 3/2/2005 00:00 - 05:00 5.00 DRILL N FLUD INT1 -Backream f/11 015' to 9800' -Pump @ 20 BPM-2950 PSI -Rotary @ 120 RPM 05:00 - 09:30 4.50 DRILL N FLUD INT1 -Pump Sweep S/S-Continue Pumping f/3X BU -Pump @ 20 BPM-2950 PSI 09:30 - 15:00 5.50 DRILL N FLUD INT1 -Monitor Well-POOH to Shoe 15:00 - 16:30 1.50 DRILL N FLUD INT1 -Cut & Slip Drill Line Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/212005 15:00 - 16:30 1.50 DRILL N FLUD INT1 -Inspect Brakes 16:30 - 18:00 1.50 DRILL N FLUD INT1 -POOH fl Shoe to BHA 18:00 - 20:00 2.00 DRILL N FLUD INT1 -Stand Back Jars & Collars in Derrick -UD MWD, ARC & Stabilizers-Break Off Bit 20:00 - 20:30 0.50 DRILL N FLUD INT1 -Clean Rig Floor 20:30 - 21 :30 1.00 BOPSU P INT1 -Pull Wear Bushing-M/U Test Joint & Set Test Plug 21 :30 - 00:00 2.50 BOPSU P INT1 -Test BOPE-Test Annular to 250/3500 psi/5min-Test Upper Pipe Rams-HCR & Manual Kill & Choke Line Valves-Choke Manifold-TIW & Dart Valve to 250/4800 psi/5min-AII Equipment Passed -Witness Waived by AOGCC-Chuck Scheve -Witnessed by Well Site Leader 3/3/2005 00:00 - 02:30 2.50 BOPSU P INT1 -Test BOPE-Test Lower Pipe Rams-Kelly Cock Valves-Blind Rams to 250/4800 psi/5minutes-AII Equipment Passed -Witness Waived by AOGCC-Chuck Scheve -Witnessed by Well Site Leader 02:30 - 03:30 1.00 BOPSU P INT1 -Blow Down Surface Equipment -Pulled Test Plug & Ran Wear Bushing 03:30 - 05:00 1.50 BOPSU FLUD INT1 -Clear Tools & Clean Rig Floor 05:00 - 06:00 1.00 STKOH FLUD INT1 -Change Saver Sub on Top Drive 06:00 - 10:30 4.50 STKOH FLUD INT1 -M/U BHA #5-Adjust Motor to 1.5 Deg.-Orient MWD -RIH wI Collars, Jars & HWDP 10:30 -11:30 1.00 STKOH N FLUD INT1 -Shallow Test MWD @ 750 GPM-1230 PSI -Blow Down Mud Lines 11 :30 - 12:00 0.50 STKOH N FLUD INT1 -RIH wI Drill Pipe 12:00 - 12:30 0.50 STKOH N FLUD INT1 -Service Top Drive & Blocks 12:30 - 16:00 3.50 STKOH N FLUD INT1 -RIH wI Drill Pipe-Fill Pipe & Blow Down @ 3,000' Intervals 16:00 - 17:00 1.00 STKOH N RREP INT1 -TroubleshootTop Drive IBOP 17:00 - 18:00 1.00 STKOH N FLUD INT1 -RIH w/ Drill Pipe to 9,340' 18:00 - 21 :00 3.00 STKOH N FLUD INT1 -Circulate & Condition Mud-Perform 50% Mud Dilution wI Glycol 21 :00 - 23:00 2.00 STKOH N FLUD INT1 -Orient Bit to Low Side & Begin Troughing f/9,350'-9,400' 23:00 - 00:00 1.00 STKOH N FLUD INT1 -Time Drill f/9400' @ 5min/inch 3/4/2005 00:00 - 10:00 10.00 STKOH N FLUD INT1 -Troughing & Time Drilling f/9,400'-9,410' in Attempt to Open Hole Sidetrack-100% Sliding-Unable to Sidetrack 10:00 - 12:00 2.00 STKOH N FLUD INT1 -P/U to 9,380' & Rotate @ 40 rpm to Build Ledge fl Trenching & Sliding-Pump @ 800 gpm wI 2,900 psi On Bottom-2,890 Off Bottom-Up WI. 243K-Down WI. 223K-Rol. WI. 236K -Calc. ECD=10.72 ppg-Actual ECD=10.94 ppg 12:00 - 15:30 3.50 STKOH N FLUD INT1 -Time Drill f/9,380'-9,410'-Sidetracking Operation Unsuccessful 15:30 - 16:30 1.00 STKOH N FLUD INT1 -Circulate & Build Slug-Monitor Well 16:30 - 21 :30 5.00 STKOH N FLUD INT1 -POOH tJ HWDP -Monitor Well @ HWDP 21 :30 - 00:00 2.50 STKOH N FLUD INT1 -POOH wI BHA #5 3/5/2005 00:00 - 03:00 3.00 STKOH N FLUD INT1 -M/U BHA #6 -Adust Motor to 2.12 Deg.-Change Out Stab. Blade-UD ARC-Orient MWD -RIH wI Jars & HWDP 03:00 - 05:30 2.50 STKOH N FLUD INT1 -RIH w/ DP to Shoe @ 3,187' -Test MWD @ 720 gpm-1860 psi 05:30 - 06:30 1.00 STKOH N FLUD INT1 -Service Top Drive & Blocks-P/U & S/O WI. @ Shoe = 160K 06:30 - 10:00 3.50 STKOH N FLUD INT1 -RIH wI DP-FiII Pipe @ 2800' Intervals-Blow Down Top Drive & Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/512005 06:30 - 10:00 3.50 STKOH N FLUD INT1 Mud Lines 10:00 - 10:30 0.50 STKOH N FLUD INT1 -Break Circulation & Stage Pumps Up To Rate -3188 psi @ 730 gpm 10:30 - 00:00 13.50 STKOH N FLUD INT1 -Open Hole Sidetrack f/9,321 '-9337' -P/U Wt.=250K-S/0 Wt.=220K 3/6/2005 00:00 - 11 :00 11.00 STKOH N FLUD INT1 -Open Hole Sidetrack-Trench & Time Drill f/9,337' to 9,435' -Pump @ 760 gpm-3246 psi, Rotary @ 10 rpm-Torque=7K -P/U Wt.=248K, S/O Wt.=222K, Rot. Wt.=226K 11 :00 - 16:30 5.50 STKOH N FLUD INT1 -Monitor Well-POOH t/ 8,893'-Hole in Good Shape-Pump Slug & B/D Mud Lines-POOH t/ 876' 16:30 - 19:00 2.50 STKOH N FLU 0 INT1 -POOH w/ BHA #6-UD Motor 19:00 - 22:00 3.00 STKOH N FLUD INT1 -RIH w/ BHA #7 RSS-P/U ARC, Rearrange MWD & Stabilizers -Test MWD & Power Drive 22:00 - 23:00 1.00 STKOH N FLUD INT1 -RIH t/3,168' w/DP 23:00 - 00:00 1.00 STKOH N FLUD INT1 -Cut & Slip Drill Line-68' 3/7/2005 00:00 - 02:00 2.00 STKOH N FLUD INT1 -Cut & Slip Drilling Line -Service Rig, Top Drive & Blocks 02:00 - 06:00 4.00 STKOH N FLUD INT1 -RIH w/ BHA #7 f/3,168' on DP-Fill Pipe & Break Circulation Every 2800'-Blow Down Top Drive & Mud Line 06:00 - 06:30 0.50 STKOH N FLUD INT1 -Break Circulation & Stage Pumps Up to 800 gpm-3400 psi -Pump Commands to RSS Bias Tool 06:30 - 13:00 6.50 STKOH N FLUD INT1 -Drill f/9.435' to 9,784'-Pump @ 800 gpm-3300 psi, 130 rpm,Tq. On Bottom=15K, Tq. Off Bottom=12K, PIU Wt.=252K, S/O Wt.=220K, Rot. Wt.=234K, Bit Wt.=20K-30K, Calc. ECD=11.1 ppg, Act. ECD=11.5 ppg 13:00 - 14:30 1.50 STKOH N DFAL INT1 -Circulate Sweep Surface to Surface -RSS Tool Not Responding t/ Commands-Troubleshoot & Consult w/ ODE 14:30 - 17:00 2.50 STKOH N FLU 0 INT1 -Drill f/9,784' to 9,973-RSS Tool Not Responding to Commands-Monitor Well-Pump Slug 17:00 - 23:00 6.00 STKOH N DFAL INT1 -POOH to HWDP-Monitor Well -Tight Spots f/9,973' to 9,500-P/U Wt.= 310K-320K-Wiped Out OK 23:00 - 00:00 1.00 STKOH N DFAL INT1 POOH wI BHA #7 3/8/2005 00:00 - 02:00 2.00 STKOH N DFAL INT1 -POOH w/ BHA # 7-Stand Back MWD & ARC In Derrick-B/O Bit-UD RSS -Download MWD 02:00 - 05:00 3.00 STKOH N DFAL INT1 -M/U BHA # 8-P/U Mud Motor & Ajust Angle to 1.5 Deg.-M/U MWD & Orient-M/U Bit-RIH w/ Jars & HWDP-Surface Test MWD-Blow Down Mud Lines 05:00 - 07:00 2.00 STKOH N DFAL INT1 RIH wI BHA # 8 on DP t/3,174'-Fill Pipe-Blow Down Mud Line 07:00 - 07:30 0.50 STKOH N DFAL INT1 -Service Top Drive & Blocks 07:30 - 11 :30 4.00 STKOH N DFAL INT1 -RIH w/ DP-FiII Pipe & Blow Down @ 30 Stand Intervals -Break Circulation & Orient to Low Side @ 9,300' 11 :30 - 12:00 0.50 STKOH N DFAL INT1 -RIH w/ DP-Break Circulation & Wash Last Stand t/ Bottom @ 9,973'-No Fill On Bottom-Hole In Good Shape 12:00 - 13:00 1.00 STKOH N FLUD INT1 -CBU & Circulate Gas f/ Well (2025 Units Max @ 1 1/2 BU) 13:00 - 00:00 11.00 STKOH N FLUD INT1 -Drill 12 1/4 Hole f/9,973' t/1 0,364'-AST =2.25 Hrs./ ART =4.45Hrs.-Up Wt.=265K, Down Wt.=225K, Rot. Wt.=242K, WOB=16K Torque On Bottom=14K/Off Bottom=10.5K @ 60 RPM 3/9/2005 00:00 - 02:30 2.50 STKOH N FLUD INT1 -Drill 12 1/4 Hole f/10,364" t/10,380' -Up Wt.=265K, Down Wt.=225K, Rot. Wt.=242K, WOB=30K -Torque On Bottom=11 K, Off Bottom=9K @ 65 rpm Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/9/2005 00:00 - 02:30 2.50 STKOH N FLUD INT1 -Pump @ 800 gpmlOn Bottom=3490 psi Off Bottom=3220 psi -Calculated ECD=11.2 ppg, Actual ECD=11.23 ppg 02:30 - 04:30 2.00 STKOH N RREP INT1 -Change Liner & Wash Plate On #1 Pump-#3 Cylinder -Circulate w/ #2 Pump @ 500 gpm-1380 psi 04:30 - 15:00 10.50 STKOH N FLUD INT1 -Drill 12 1/4 Hole f/1 0,380' V 10,564' -ROP Reduced to 8-15 fph @ 10,440'-Decision Made to POOH f/ Bit 15:00 - 16:00 1.00 STKOH N DFAL INT1 -Circulate Well Clean-Monitor Well 16:00 - 21 :30 5.50 STKOH N DFAL INT1 -POOH V HWDP-Monitor Well-Hole In Good Shape 21 :30 - 00:00 2.50 STKOH N DFAL INT1 -POOH w/ BHA #8, UD Stabilizers, Break Bit, UD MM, ARC & MWD-Bit In Good Condition 3/10/2005 00:00 - 00:30 0.50 STKOH N DFAL INT1 -Handle BHA #8-UD ARC & Motor 00:30 - 01 :00 0.50 STKOH N DFAL INT1 -Clean & Clear Rig Floor 01 :00 - 03:00 2.00 STKOH N DFAL INT1 -M/U BHA # 9-P/U MM & Adjust Angle V 1.15 Deg-C/O Stabilizer Sleeve V 12 1/4-P/U ARC-P/U MWD & Orient-M/U DS69 Bit 03:00 - 04:00 1.00 STKOH N DFAL INT1 -RIH w/ Collars, Jars & HWDP-P/U Ghost Reamer 04:00 - 04:30 0.50 STKOH N DFAL INT1 -Break Circulation & Shallow Test MWD (OK) -Blow Down Top Drive & Mud Line 04:30 - 06:00 1.50 STKOH N DFAL INT1 -RIH V Shoe @ 3,187'-Fill Pipe & Blow Down Top Drive 06:00 - 08:00 2.00 STKOH N DFAL INT1 -Cut & Slip Drill Line (55')-Adjust Breaks - ATP held for High line connect - Elec safe out power supply lines / junction buses. 08:00 - 14:00 6.00 STKOH N DFAL INT1 -Hook Rig Up V Hi-Line Power -Serviced Top Drive, Blocks, Drawworks & Iron Roughneck-Cleaned Rig 14:00 - 18:30 4.50 STKOH N DFAL INT1 -RIH f/3, 187' V 10,466" 18:30 - 20:00 1.50 STKOH N DFAL INT1 -Wash f/10,466' V 10,564' -Gas Maxed @ 2000 Units-1.5 BU -Remove Rig fl Hi-line Power-Problems wI Island Power Supply 20:00 - 00:00 4.00 STKOH N FLUD INT1 -Drill 12 1/4 Hole f/10,564' V 10,890' -Up Wt.=270K, Down Wt.=21 OK, Rot. Wt.=243K -Pump @ 760 gpm-3550 psi, ECD Calc.=11.15, ECD Act.=11.41 -Torque On Bottom=18K, Off Bottom=12K @ 90 rpm 3/11/2005 00:00 - 08:30 8.50 STKOH N FLUD INT1 -Drill 12 1/4 Hole f/10,890' V 11,368' -Up Wt.=288K, Down Wt.=230K, Rot. Wt.=258K -Pump @ 760 gpm-3450 psi/OnBottom, 3220 psilOff Bottom -ECD Calc.=11.02, ECD Act.=11.1 -Torque On Bottom=19K, Off Bottom=14K @ 100 rpm 08:30 - 09:30 1.00 STKOH N RREP INT1 -Replace Swab, Liner & Liner Wash Plate on #1 Mud Pump 09:30 - 18:00 8.50 STKOH N FLU 0 INT1 -Drill 12 1/4 Hole f/11 ,368' V 11,704' 18:00 - 22:30 4.50 STKOH N FLU 0 INT1 -Circulate Hi-Vis Weighted Sweep S/S-Continue Circulating f/ Total of 3XBU-43,000 Stks.-Shakers Cleaned Up 22:30 - 00:00 1.50 STKOH P INT1 -POH f/11 ,704 V 10,753'- Avg.P/U Wt. 310K-320K-Overpulls to 50K f/11 ,500' V 10,900'-Wiped Clean 3/12/2005 00:00 - 01 :30 1.50 STKOH P INT1 -POH f/1 0,753' V 9,237' -Hole in Good Condition 01 :30 - 03:00 1.50 STKOH P INT1 -RIH f/9,250' V 10,600' -Wiped Tight Spots f/1 0,900 V 11 ,600-Wiped Clean 03:00 - 03:30 0.50 STKOH P INT1 -Break Circulation-Wash f/11 ,600' V 11,704' 03:30 - 08:30 5.00 STKOH P INT1 -Circulate & Condition Mud fl Casing-3 Bottoms Up-43,000 Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/12/2005 03:30 - 08:30 5.00 STKOH P INT1 Stks. -Max Gas 1600 Units @ 13,670 Stks (1 BU) 08:30 - 10:00 1.50 STKOH P INT1 -POH f/11 ,704' tJ 10,659'-Monitor Well -Average P/U Wt.=320K, SIO Wt.=205K -Tight Spots f/11 ,365 tJ 10, nO-Maximum Overpull-60K 10:00 - 10:30 0.50 STKOH P INT1 -Pump Slug- Blow Down Top Drive & Mud Lines 10:30 - 13:00 2.50 STKOH P INT1 -POH f/1 0,659' tJ 7600' 13:00 - 14:00 1.00 STKOH P INT1 -Spot G-Seal Pill f/7,600' tJ 6,600' 14:00 - 17:30 3.50 STKOH P INT1 -POH f/7,600' tJ HWDP-Monitor Well 17:30 - 21 :00 3.50 STKOH P INT1 -POH w/ HWDP -UD BHA #9 21 :00 - 21 :30 0.50 STKOH P INT1 -Clean Rig Floor & Clear BHA Tools 21 :30 - 22:00 0.50 CASE P INT1 -Pull Wear Bushing & Run Test Plug-Open Upper Annulus Valve 22:00 - 23:45 1.75 CASE P INT1 -Change Upper Pipe Rams f/4 1/2"X7" tJ 9 5/8" 23:45 - 00:00 0.25 CASE P INT1 -Fire Drill In Doghouse 3/13/2005 00:00 - 01 :30 1.50 CASE P INT1 -Rig Up & Pressure Test Upper Pipe Ram Door Seals tJ 3500 psi "Pull Test Plug & UD Test Joint 01 :30 - 04:00 2.50 CASE P INT1 -Rig Up II Run 9 5/8 Casing 04:00 - 10:00 6.00 CASE P INT1 -PJSM-RIH w/9 5/8 53.5# L-80 BTC-M Casing 113,175' 10:00 - 10:30 0.50 CASE P INT1 -Circulate One Casing Volume (225 bbl) @ 10 bpm-800 psi -No Losses @ This Rate 10:30 - 22:00 11.50 CASE P INT1 -PJSM-RIH w/9 5/8 53.5# L-80 BTC-M Casing f/3, 175' II 11 ,660'-Wash f/11 ,660' 1111 ,700'-IP @ 4 bpm - 730 psi - 10,900 - 11,700 required SOW of 250 k in intermittent spots 22:00 - 23:00 1.00 CASE P INT1 -Circulate @ 11,700' thru Franks T 001-1 P @ 4 bpm=729 psi, FP @ 8 bpm=1080 psi-Confirm Ability II P/U String-P/U @ 600K-Tagged Bottom @ 11 ,704'-P/U 1111,702' 23:00 - 00:00 1.00 CASE P INT1 -R/D Franks Tool-Blown Down Top Drive-R/U Cement Head 3/14/2005 00:00 - 02:00 2.00 CEMT P INT1 -Circulate & Condition Mud fl Cement Job @ 8 bpm=630 psi w/ No Losses -RIU Dowell Cementers-Held PJSM wI All Personnel Involved wI Cement Job 02:00 - 04:30 2.50 CEMT P INT1 -Cement 9 5/8 Casing wI Dowell -Pump 10 bbl H20-Pressure Test Lines II 4000 psi-Pump 35 bbl CW1 00, 75 bbl Mud Push @ 5 bpm-Pump 433 bb111.3 ppg Lead Cement, 126 bb115.8 Tail Cement @ 6 bpm 04:30 - 07:00 2.50 CEMT P INT1 -Displace Cement wI Rig Pumps @ 5 bpm - Did Not Bump Plug-FP=690 psi 07:00 - 10:30 3.50 CEMT P INT1 -Wait on Cement -Held 500 psi on casing (Floats Leaking by a Small Amount)-Pump 200 bbl Down 13 3/8 X 9 5/8 Annulus-Blow Down Mud Lines 10:30 - 14:00 3.50 BOPSU P INT1 -Remove Riser-N/D BOPE @ Bottom Wellhead Flange -Remove Cement Head 14:00 - 15:00 1.00 BOPSU P INT1 -Lift BOPE-Set Slips on Casing wI 350,000 String WI. 15:00 - 16:30 1.50 BOPSU P INT1 -Cut & Drain Landing Joint-UD Landing Joint 16:30 - 18:30 2.00 BOPSU P INT1 -Rig Down Casing Elevators-Clean Rotary Table Drip Pan -Change Out Bails 18:30 - 19:30 1.00 BOPSU P INT1 -Make Final Cut On 9 5/8 Casing 19:30 - 20:30 1.00 BOPSU P INT1 -Install 9518 Packoff. OK-Set Down BOPE 20:30 - 22:30 2.00 BOPSU P INT1 -N/U BOPE @ Bottom Flange & Install Riser 22:30 - 00:00 1.50 BOPSU P INT1 -Install Test Plug & UD Test Joint-Change Top Pipe Rams f/ Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 95/8" tI 4 1/2" X 7" - Test pack off 5000 psi, 10 mins. 3/15/2005 00:00 - 01 :00 INT1 - Install 4 1/2" X 7" Rams in Top Pipe Rams-Close Ram Doors. 01 :00 - 06:00 INT1 - RIU & Test BOPE. No failures - Good test. - Witness waived by AOGCC Inspector Jeff Jones - Witnessed by WSL - JM I LV. 06:00 - 07:30 INT1 - Pull test plug & install bowl protector. - B/D all mud lines. 07:30 - 11 :00 3.50 CASE P INT1 - M/U 81/2" drilling BHA while changing liners in pumps to 5 1/2". - Shallow test rotary steerable & MWD. - Unable to get good test on MWD w/ only one pump available. Pump being changed over to 5 1/2" liners. 11 :00 - 12:00 1.00 CASE P INT1 - PJSM & RIU to freeze protect 133/8" x 9 5/8" annulus. - Pumps redressed to 5 1/2" liners completed. 12:00 - 15:00 3.00 CASE P INT1 - Shallow test MWD - OK - continue MIU BHA. 15:00 - 21 :30 6.50 CASE P INT1 - RIH w/8 1/2" drilling ass'y to 11226' filling every 25 stands. 21 :30 - 00:00 2.50 WHSUR P INT1 - PJSM for freeze protect. - Pressure test lines to 2000 psi. - C/O valve between kill line & lower annulus valve. - Pump freeze protect down 133/8" x 9 5/8" annulus @ 1 BPM. 3/16/2005 00:00 - 01 :30 1.50 WHSUR P INT1 - Freeze protect 13 318" x 9 5/8' annulus wI 120 bbls diesel @ 1 BPM. Maximum & final pressure 650 psi. 01 :30 - 02:30 1.00 WHSUR P INT1 - BID lines, RID & R/U kill line. 02:30 - 04:00 1.50 CASE P INT1 - Slip & cut drilling line. 04:00 - 05:00 1.00 CASE P INT1 - Service TO & drawworks. 05:00 - 06:00 1.00 CASE P INT1 - Wash down from 11,226' to 11607'. 06:00 - 06:30 0.50 CASE P INT1 - Circulate & condition mud for casing test @ 340 GPM. Lower pump rates to prevent from shearing pins & opening up Rhino Reamer. 06:30 - 08:00 1.50 CASE P INT1 - Test kill line to 4800 psi. - Pressure test 9 5/8" casing to 4500 psi w/1 0.8 ppg MW & hold for 30 minutes. 08:00 - 09:00 1.00 CEMT P INT1 - Wash down & tag FC on depth @ 11,620'. - Drilled & pushed plug to 11,697'. No evidence of cement in shoe track. 09:00 - 13:00 4.00 CEMT P INT1 - Displace to 12.3 ppg drilling fluid & clean L pits. 13:00 - 14:00 1.00 DRILL P INT1 - Drill plugs & 20' of new hole to 11,724'. 14:00 - 14:30 0.50 DRILL P INT1 - Perform FIT to 14.5 ppg EMW wI 12.3 ppg drilling fluid. 1080 psi. 14:30 - 00:00 9.50 DRILL P INT1 - Drill directional in 8 1/2" hole from 11,724' to 11,930'. Wiping full stand w/ no rotary & full pump rate on upstroke, & no rotary w/2/3 pump rate on downstroke. - Sheared pins & opened up Rhino reamer once reamer exited 9 5/8" shoe wI increased pump rate I pressure. Pulled reamer up above shoe to ensure pins sheared & reamer open - OK. - Drilling parameters: WOB 20K, 565 GPM, 3400 psi, 145 RPM, Tq on bottom 17K, Tq off bottom 15K, P/U wt 270K, S/O wt 230K, Rot wt 240K. - Calc ECD 13.07 ppg, actual ECD 13.35 ppg. - ART 8..25 hrs. 3/17/2005 00:00 - 12:00 12.00 DRILL P INT1 - Drill directional in 81/2" hole from 11,930' to 12,368'. Wiping full stand w/ no rotary & full pump rate on upstroke, & no rotary Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/17/2005 00:00 - 12:00 12.00 DRILL P INT1 wI 2/3 pump rate on downstroke. - Drilling parameters: WOB 20-30K, 600 GPM, 3650 psi, 150 RPM, Tq on bottom 18K, off bottom 15.5K, P/U wt 275K, SIO wt 235K, Rot wt 245K. - Pump weighted sweeps as needed. 12:00 - 00:00 12.00 DRILL P INT1 - Drill directional in 81/2" hole from 12,368' to 12,750'. Wiping full stands w/ no rotary & full pump rate on upstroke, & no rotary wI 2/3 pump rate on downstroke. - Drilling parameters: WOB 20-30K, 600 GPM, 3700 psi, 150 RPM, Tq on bottom 18K, Tq off bottom 17K, P/U wt 300K, 8/0 wt 235K, Rot wt 250K. - ECD's .15 to .2 ppg over calculated ECD. Last calculated ECD 13.2 ppg. - ART for last 24 hrs = 19.55 hrs. 3/18/2005 00:00 - 12:00 12.00 DRILL P INT1 - Drill directional in 8 1/2" hole from 12750' to 13160'. Wiping full stands wI no rotary & full pump rate on upstroke, & no rotary w/ 2/3 pump rate on downstroke. - Drilling parameters: WOB 20K, 600 GPM, 3700 psi, Tq on bottom 20K, Tq off bottom 18K, PIU wt 325K, SIO wt 240K, Rot wt 260K. - Increased MW to 12.45 ppg to coincide w/ polar plot data. 12:00 - 23:00 11.00 DRILL P INT1 - Drill directional in 81/2" hole from 13160' to TO @ 13550'. (41' into top of Sag) No losses. Wiping full stands wI no rotary & full pump rate on upstroke, & no rotary wI 2/3 pump rate on downstroke. Pumped 2.0 ppg over weighted sweep 50' above Sag, wI approx 5% excess cuttings seen @ shakers on B/U. - Drilling parameters: WOB 20K, 600 GPM, 3700 psi, 155 RPM, Tq on bottom 20K, Tq off bottom 18K, P/U wt 325K, SIO wt 245K, Rot wt 265K. - ART last 24 hrs = 18.6 hrs. 23:00 - 00:00 1.00 DRILL P INT1 - Circulate @ 600 GPM, 3675 psi, 150 RPM & reciprocating drill string. 3/19/2005 00:00 - 01 :30 1.50 DRILL P INT1 - CBU x 3 @ 600 GPM, 3675 psi, 150 RPM, & reciprocating. Maintain bit below top of Sag at all times while circulating & reciprocating. - Monitor well - static. 01 :30 - 04:00 2.50 DRILL P INT1 - Wiper trip back to shoe. First 14 stands pulled excellent wI no drag. Wiped tight spots (40K drag) at 12,230' & 12,135; on next 2 stands. Final 4 stands okay w/ 20K drag. Hole fill showing well static. 04:00 - 05:00 1.00 DRILL P INT1 - Service TO & drawworks. 05:00 - 06:00 1.00 DRILL P INT1 - RIH from 95/8" shoe to TO @ 13,550'. Wash down last stand. No fill. 06:00 - 08:30 2.50 DRILL P INT1 - CBU x 3 @ 600 GPM, 3675 psi, 130 RPM, & reciprocating. Maintain bit below top of Sag at all times while circulating & reciprocating. - Monitor well - static. 08:30 - 11 :00 2.50 DRILL P INT1 - BID lines & POH to 9 5/8" shoe. - Wipe tight spots @ 12520' & 12356'. 60K drag. Wiped once & cleaned up. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/19/2005 11 :00 - 15:30 4.50 DRILL P INT1 - Monitor well, pump dry job, drop 2.5" rabbit, & B/D lines. - POH to HWDP. 15:30 - 16:30 1.00 DRILL P INT1 - UD 23 jts HWDP. 16:30 - 19:30 3.00 DRILL P INT1 - Flush BHA w/15 bbls SIW. BID lines. - POH & UD BHA. Normal wear on Rhino reamer wI 5 chipped teeth. 8 1/2" bit missing one center cutter that might partially explain lower ROP for this hole section. 19:30 - 20:00 0.50 DRILL P INT1 - Clear & clean rig floor. 20:00 - 21 :00 1.00 CASE P INT1 - PJSM - R/U to run 7" liner. 21 :00 - 00:00 3.00 CASE P INT1 - M/U reamer shoe, 1 jt 7" 29# L-80 Hydril 511 liner, F/C, 1 jt 7" 29# L-80 Hydril 511 liner, XO, UC, XO, & 1 jt 7" 29# L-80 Hydril 511 liner. Bakerlok conns. through pin end on jt # 3. Fill pipe & check floats. - Continue M/U & RIH w 7" 29# L-80 Hydril 511 liner. Ran a total of 37 jts out of a toatal of 50 jts. Utilizing Jet Lube Seal Guard thread compound. MIU Tq-15K ftIlbs. 3/20/2005 00:00 - 01 :30 1.50 CASE P INT1 - M/U remaining 13 jts 7" 29# L-80 Hydril 511 liner & RIH. Utilizing Jet Lube Seal Guard thread compound. M/U Tq - 15K ftIlbs. - Ran 50 jts total of 7" 29# L-80 Hydril 511 liner. 01 :30 - 03:00 1.50 CASE P INT1 - C/O elevators & M/U liner hanger / packer. - R/D casing handling equip't. - M/U headpin & circ liner volume @ 5.5 BPM, 420 psi, P/U wt 118K, SIO wt 120K. 03:00 - 08:30 5.50 CASE P INT1 - RIH w/7" liner on 5" DP filling every 11 stands to 9 5/8" csg shoe @ 11,702' 08:30 - 10:00 1.50 CASE P INT1 - M/U cement head on single. UD on skate. - Circulate liner & DP volume @ 6 BPM, 640 psi. - PIU wt 255K, SIO wt 230K, Rot wt 240K, 15 RPM, Tq 8K 10:00 - 12:00 2.00 CASE P INT1 - Continue running in OH wI liner to 13,535' w/ no problems. - Top of Sag @ 13,509'. 12:00 - 12:30 0.50 CASE P INT1 - MIU cement head & attempt to work tight pipe. 12:30 - 14:00 1.50 CASE P INT1 - Stage up pump in 1/2 bbl increments & circulate in preparation for cement job. ICP @ 1/2 BPM 315 psi, FCP @ 5.5 BPM, 975 psi. Unable to increase pump rate over 5.5 BPM w/o packing off. - Washed liner down an addittional 2' while circulating. - Liner set 13' off bottom. Objective met wI liner set depth @ 13,537' & top of Sag formation @ 13,509'. 14:00 - 17:00 3.00 CEMT P INT1 - Pump 10 bbls SIW & test cement lines to 4500 psi. Pump 55 bbls 13.5 ppg Mud Push II followed by 130 bbls (469 sx) 15.8 ppg Class G tail cement. - Drop wiper dart & displace wI rig pump @ 5-6 BPM. Pressure increase throughout displacement indicating good lift of cement. Bump plug wI 276 bbls of mud. Increase pressure to 4200 psi to set hanger. S/O 80K to ensure hanger set. Bleed off pressure & check floats - floats holding. - P/U 10' & release packer setting dogs. SIO 80K & initiate rotation @ 15 RPM, Tq 12K & set packer. Pressure up to 1000 psi & P/U string 17'. Observe pressure loss & increase pump rate while P/U string an additional 11 '. 17:00 - 18:30 1.50 CEMT P INT1 - CBU @ 15 BPM, 3150 psi. Approximately 40 bbls contaminated cement on B/U. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/20/2005 18:30 - 19:30 1.00 CEMT P INT1 - RID cement head & UD 2 singles DP. - Monitor well. 19:30 - 20:00 0.50 CASE P INT1 - Pump dry job & BID lines. 20:00 - 23:30 3.50 CASE P INT1 - POH wI 5" DP. 23:30 - 00:00 0.50 CASE P INT1 - Break down & UD liner hanger I packer setting tool. 3/21/2005 00:00 - 00:30 0.50 CASE P INT1 - Break out & UD liner hanger setting tool. - Dog sub sheared on setting tool, 00:30 - 01 :00 0.50 CASE P INT1 - Clean & clear rig floor. 01 :00 - 01 :30 0.50 BOPSU P INT1 - Pull bowl protector & install test plug. 01 :30 - 02:30 1.00 BOPSU P INT1 - R/U 4" test it wi x-overs & 5" DP pup jts. 02:30 - 04:00 1.50 BOPSU P INT1 - Test lower pipe rams, annular, & 4" TIW valve wI 4" test it. Lower pipe rams & TIW valve tested to 250 psi 14800 psi. Annular preventer tested to 250 psi / 3500 psi. Each test charted & held for 5 min per test & witnessed by WSL - MD. AOGCC Rep. Chuck Sheve notified in advance - full BOPE test not due until 3/29. 04:00 - 04:30 0.50 BOPSU P INT1 - Pull test plug & install bowl protector. 04:30 - 05:30 1.00 BOPSU P INT1 - Remove x-overs & 5" drill pipe pup jts from 4" test jt. 05:30 - 10:00 4.50 CASE P INT1 - PJSM - P/U & M/U BHA for drilling 6" hole. 6" Smith XR 30 bit, 4 3/4" motor wI 1.5 deg bend, NM Stab, ADN, MWD, NM Stab, 3 NM flex collars, circ sub, XO & jars. - P/U 17 its 4" HWDP from pipeshed & RIH. - Shallow hole test MWD & B/D lines. 10:00 - 12:30 2.50 CASE P INT1 - P/U 60 jts 4" DP from pipeshed & RIH. - C/O jaws in iron roughneck & install air slips. 12:30 - 13:00 0.50 CASE P INT1 - Clear air line for clutch kick out on crown-o-matic. 13:00 - 15:30 2.50 CASE P INT1 - RIH wI 5" DP filling every 30 stands. 15:30 - 16:30 1.00 CASE P INT1 - P/U cement heat & break out 10' DP pup. UD same. 16:30 - 17:30 1.00 CASE P INT1 - RIH w/5" DP to 11,424'. 17:30 - 19:30 2.00 CASE P INT1 - CBU @ 250 GPM, 1800 psi. 19:30 - 21 :00 1.50 CASE P INT1 - Pressure test 95/8" x 7" casing to 3670 psi wI 12.3 ppg MW. Hold & chart test for 30 minutes. - BID kill line & TO. 21 :00 - 22:30 1.50 CASE P INT1 - RIH w/5" DP to 13226'. - Wash down from 13226' & tag UC on depth @ 13454'. 22:30 - 00:00 1.50 DRILL P INT1 - Drill plug / UC to 13456'. WOB 20K, 250 GPM, 2200 psi, 50 RPM, Tq 10K. 3/22/2005 00:00 - 01 :30 1.50 DRILL P INT1 - Drill shoe track from 13456' to 13510'. No evidence of cement in shoe track. - PJSM for displacement to 9.1 ppg flo-pro. 01 :30 - 05:30 4.00 DRILL P INT1 - Pump 200 bbls S/W, 100 bbl hi-vis flo-pro sweep followed by new 9.1 ppg flo-pro drilling fluid @ 250 GPM, 1600 psi, 50 RPM 05:30 - 07:00 1.50 DRILL P INT1 - Slip & cut drilling line. - Clean L pits. 07:00 - 09:30 2.50 DRILL P INT1 - Continue cleaning L pits - hatches removed. - Service TO & drawworks while cleaning pits. 09:30 - 11 :00 1.50 DRILL P INT1 - Drill FIS & clean out rathole to 13550'. No evidence of cement in shoe track. 11 :00 - 12:00 1.00 DRILL P INT1 - Drill 20' of new hole to 13570'. 12:00 - 13:00 1.00 DRILL P INT1 - P/U inside 7" shoe. - Close annular preventer & pump down kill line & string & Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/22/2005 12:00 - 13:00 1.00 DRilL P INT1 perform FIT to 11.5 ppg EMW w/9.1 ppg. Hold test for 10 minutes - Initial pressure 1390 psi - Final pressure 1340 psi. 13:00 - 00:00 11.00 DRILL P INT1 - Drill directional in 6" hole from 13570' to 13760'. - Drilling parameters: WOB 10-15K, 275 GPM, pressure on bottom 1600 psi, off bottom 1450 psi, 90 RPM, Tq on bottom 15K, off bottom 12K, P/U wt 295K, S/O wt 255K, Rot wt 280K. - AST 2.2 hrs ART 7.6 hrs ADT 9.8 hrs. 3/23/2005 00:00 - 13:30 13.50 DRilL P INT1 - Drill directional in 6" hole from 13760' to TO @ 14033' md, 11336' TVD. Drilling parameters: WOB 10-20K, 280 GPM, 1650 psi, 100 RPM, Tq on bottom 14K, Tq off bottom 10K, P/U wt 310K, SIO wt 265K, Rot wt 280K. ART 10.27 hrs, ADT 10.27 hrs - Circulate 2 OH vols. 13:30 - 17:30 4.00 DRILL P INT1 - Madd pass back to 7" shoe @ 150 FPH, 270 GPM, 80 RPM. 17:30 - 18:00 0.50 DRILL P INT1 - RIH to TO @ 14033'. Hole slick. - Circ 3 OH vols. 18:00 - 19:00 1.00 DRILL P INT1 - Pump out to shoe @ 270 GPM, 1400 psi. 19:00 - 20:00 1.00 DRILL P INT1 - Drop dart & open circ sub. Circulate 7" x 4" annulus X 1.5 @ 700 GPM, 2000 psi. 20:00 - 21 :00 1.00 DRILL P INT1 - POH to top of 7" liner wi circ sub placed @ TOl. 21 :00 - 22:00 1.00 DRILL P INT1 - Pump hi-vis weighted sweep & circ surface to surface. 700 GPM, 2000 psi, 15 RPM. 22:00 - 23:00 1.00 DRILL P INT1 - Monitor well for 30 min - pump dry job - drop rabbit - BID TO. 23:00 - 00:00 1.00 DRILL P INT1 - POH. 3/24/2005 00:00 - 04:00 4.00 DRILL P INT1 - POH wI 5" DP - C/O to 4" handling equip't & POH w/4" DP. 04:00 - 05:00 1.00 DRilL P INT1 - POH & UD 17 its HWDP 1 x 1. 05:00 - 08:00 3.00 DRILL P INT1 - PJSM - UD nuclear source. - UD BHA & flush tools. 08:00 - 08:30 0.50 DRILL P INT1 - Clear & clean rig floor. 08:30 - 09:30 1.00 CASE P INT1 - R/U to run 4 1/2" liner. 09:30 - 11 :30 2.00 CASE P INT1 - Run 15 its 41/2" 13CR80 12.6# Vam Top liner. 11 :30 - 12:00 0.50 CASE P INT1 - RID liner handling equip'!. - RIU to run 2 7/8" inner string. 12:00 - 14:00 2.00 CASE P INT1 - PJSM - P/U & RIH w/19 its 2 7/8" inner string & 3 space out pup jts. 14:00 - 14:30 0.50 CASE P INT1 - Top off 4 1/2" x 2 7/8" annulus wI 9.3 viscous mud & M/U liner hanger assy. 14:30 - 15:30 1.00 CASE P INT1 - Mix & set Baker packer gel & allow 30 min set up time. - Clear floor of 2 7/8" tools. - C/O to 4" handling equip'!. 15:30 - 16:00 0.50 CASE P INT1 - MIU XO & 1 stand 4" DP - Circulate string volume. 16:00 - 17:30 1.50 CASE P INT1 - RIH w/4 1/2" liner on 4" DP. 17:30 - 00:00 6.50 CASE P INT1 - C/O to 5" handling equip'!. - RIH w/4 1/2" liner on 5" DP filling pipe every row. 3/25/2005 00:00 - 02:00 2.00 CASE P INT1 - RIH wi 4 1/2" liner on 5" DP. 02:00 - 03:30 1.50 CASE P INT1 - CBU @ 7" shoe - 7 BPM, 1000 psi. - P/U wt 290K, S/O 250K. 03:30 - 04:30 1.00 CASE P INT1 - M/U cement head valves, & hose. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/25/2005 03:30 - 04:30 1.00 CASE P INT1 - Run in OH to 14,033' & tag bottom. P/U 10' & wash to bottom. Tag @ 14,033'. PIU off bottom 2'. 04:30 - 08:00 3.50 CASE P INT1 - Stage up pumps & circulate in preparation for cement job. - ICP @ 1/2 BPM 430 psi, FCP @ 8 BPM 1450 psi. 08:00 - 09:30 1.50 CEMT P INT1 - Pump 5 bbls S/W & test lines to 4500 psi. - Pump 10 bbls CW-100, 25 bbls 10.3 ppg Mud push II followed by 25 bbls (89 sx) 15.9 ppg Class G cement. Drop dart & displace w/227 bbls mud & bump plug @ 6.5 BPM 1700 psi. Increase pressure to 3500 psi to set hanger. Initial 25 bbls of fluid used to bump plug was 9.3 ppg viscosified brine. - SIO 50K on hanger. - Bleed off pressure & check floats. - Pressure up to 4200 psi to release HRD tool. Bleed off pressure. - P/U 6' off of liner to release dogs - SIO 55K to set packer. Indication of set @ 30K. - Pressure up to 1000 psi & P/U an additional 1 0' until pressue decreased. Increase pump pressure while P/U string additional 19'. 09:30 - 11 :00 1.50 CEMT P INT1 - Circ out cement 17 BPM, 3300 psi. - Approximate 12 bbls cement @ surface on B/U. 11 :00 - 11 :30 0.50 CEMT P INT1 - Close pipe rams & test 9 5/8" x 7" x 4 1/2" casing /Iiner to 1500 psi. Chart & hold for 30 minutes. 11 :30 - 12:00 0.50 CEMT P INT1 - B/D kill line & RID cement head. 12:00 - 12:30 0.50 CASE P INT1 - Build sweeps for swapping over to clean S/W. 12:30 - 16:00 3.50 CASE P INT1 - Displace well to clean S/W. - Pump 100 bbls S/W, 50 bbls caustic wash, 50 bbls Safe Surf W, 100 bbls hi-vis Duovis sweep followed by -1200 bbls S/W. Circulated until clean fluids @ surface. Last 2 NTU readings were 63 & 66 respectively. 16:00 - 16:30 0.50 CASE P INT1 - Monitor well for 30 min - static. - BID lines. 16:30 - 22:00 5.50 CASE P INT1 - POH wI 5" DP. 22:00 - 00:00 2.00 CASE P INT1 - C/O to 4" handling equip't & UD 4" DP 1 x 1. 3/26/2005 00:00 - 00:30 0.50 CASE P INT1 - UD 4" DP 1 x 1. 00:30 - 01 :30 1.00 CASE P INT1 - C/O to 31/2" elevators & UD Baker hanger I packer setting tool. - Dog sub sheared. 01 :30 - 03:30 2.00 CASE P INT1 - CIO to 2 718" handling equip't & UD 2 7/8" inner string & x-overs. 03:30 - 04:30 1.00 CASE P INT1 - P/U cement head & B/O pup jts & TIW valve. 04:30 - 06:00 1.50 CASE P INT1 - Clear floor of tools & clean floor. - Bring up Schlumberger tools to rig floor. 06:00 - 07:00 1.00 CASE P INT1 - RlU Schlumberger for GR / US IT I CBL. 07:00 - 12:00 5.00 EV AL P INT1 - Run GR / US IT I CBL through 7" liner section. Log shows enough cement to meet requirement of 50' above Sag. - POH & RID Schlumberger. 12:00 - 12:30 0.50 BOPSU P INT1 - Pull bowl protector. 12:30 - 14:00 1.50 BOPSU P INT1 - M/U BOPE flushing tool & flush stack w/50 bbls S/W. 14:00 - 15:30 1.50 CASE P INT1 - Close blind rams & test 9 5/8" x 7" x 4 1/2" casing /Iiners to 4200 psi. Chart & hold test 30 minutes. Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 3/26/2005 15:30 - 21 :00 5.50 CASE P INT1 - R/D elevators & bails - install long bails & compensator. Bring Canon clamps, spooling unit, control line, power tongs, 350T spider, & Weatherford equip't to rig floor. Spot Weatherford units & plug into piperack. - RIU & hang sheaves & fiber optic cable in derrick. 21 :00 - 22:00 1.00 CASE P INT1 - MIU tailpipe ass'y, packer, & Cidra mandel. Bakerlok connection below packer. Utilizing Torque Turn - MIU tq 3620 Nibs for Vam Ace conns, 4440 Nibs for Vam Top conns. 22:00 - 00:00 2.00 CASE P INT1 - Connect fiber optics cable & pressure I temperature gauge to Cidra mandrel & test seals, gauge, & mandrel to 7500 psi. Three separate tests for 15 minutes each. 3/27/2005 00:00 - 21 :30 21.50 RUNCO RUNCMP - Complete testing Weatherford Equipment & M/U X Nipple Assembly - MIU & RIH w/4 1/2" 12.6# 13CR80 Vam Top Tubing wI Fiber Optic Cable 1111 ,622'-Tagged 7" Liner w/10K-Pulled 12K Over P/U Wt. II Pull Free -M/U utilizing API Mod Thread Compound & Torque Turn- M/U Tq 4440 Nibs -One Canon Clamp Per Joint-One Stainless Steel Band Directly Above Gauge Mandrel 21 :30 - 22:30 DPRB RUNCMP -Troubleshoot Liner Entry Problem-Determined that most likely caused by 00 of Cannon Clamp on Pup Joints Directly Above Gauge Mandrel is Greater Than Diameter of Liner Top @ 11 ,522' -UplWt= 184K, DnlWt=154K 22:30 - 23:30 DPRB RUNCMP -R/U Tubing Handling Tools II POH 23:30 - 00:00 DPRB RUNCMP -Service Dies On BJ Slips 3/28/2005 00:00 - 17:30 DPRB RUNCMP -POH w/4 1/2" 12.6# 13Cr80 Vam Top Completion 17:30 - 19:00 DPRB RUNCMP -POH wI Tail Pipe Assmebly -Inspect Clamp on Vam Ace Connection f/ Damage & Remove f/ String -Inspect Packer fl Damage -UD X Nipple Assembly-P/U 10' Pup-Stand Pack Tail & Packer Assembly 19:00 - 20:00 1.00 RUNCO DPRB RUNCMP -Clean & Clear Rig Floor 20:00 - 21 :00 1.00 BOPSU N DPRB RUNCMP -M/U Test Joint-Set Test Plug-Open Upper Annulus Valve 21 :00 - 00:00 3.00 BOPSU N DPRB RUNCMP -Test BOPE-Test Annular II 250psi/Lo, 3500psi/High f/5 Minutes -Test Upper Pipe Rams, Kill HCR Valve, Choke Manifold & NC50 Floor Valve II 250psi/Lo, 4800psi/High fl 5 Minutes-No Failures (Repaired Leaks on Test Hose Connections @ Manifold) -AOGC Witness Waived by Inspector John Crisp -Test Witnessed by WSL 3/29/2005 00:00 - 04:00 DPRB RUNCMP -Test BOPE II 250psi/Lo, 4800psi/Hi f/5/Minutes-Tested Lower Pipe Rams, Blind Rams, HT40 Floor & Dart Valves-Accumulator Test -Witnessed by WSL -AOGC Witness Waived by John Crisp 04:00 - 05:00 1.00 DPRB RUNCMP -Pull Test Plug-Blow Down Choke & Kill Lines-UD Test Joint 05:00 - 06:00 1.00 DPRB RUNCMP -R/U to Run Completion String w/ Torque Turn 06:00 - 23:00 17.00 DPRB RUNCMP -RIH w/4 1/2" Vam Tailpipe Assembly-Allow Weatherford Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 Gauge Mandrel II Warm Up -RIH w/4 1/2" 12.6# 13Cr80 Vam Top Completion to 7" Liner @ 11,522' -No Problems Entering 7" Liner 23:00 - 00:00 RUNCMP -RIH w/4 1/2" Vam Top Completion f/11 ,522' 1112,068' 3/30/2005 00:00 - 01 :00 RUNCMP -RIH w/4 1/2" 12.6# 13Cr80 Vam Top Completion f/12,068' II 12,356' 01 :00 - 01 :30 0.50 RUNCMP -M/U SSSV & Test Control Line to 6000 psi f/15 Minutes 01 :30 - 03:30 2.00 RUNCMP -RIH w/4 1/2" 12.6# 13Cr80 Vam Top Completion f/12,356' II Liner Tieback @ 13,372'-Set Down 20K -Space Out 6'-Up Wt.=205K. Down Wt.=170K 03:30 - 05:00 RUNCMP -Lay Down 3 Joints Tubing-M/U Space Out Pups (3 Pups-Total Length 27.57')-M/U 1 Joint Tubing & RIH 05:00 - 06:00 1.00 RUNCMP -P/U Landing Joint & M/U Hanger-R/U Head Pin & Floor Valve 06:00 - 07:30 1.50 RUNCMP -Terminate SSSV Control Line -Perform Hanger Splice f/ Weatherford Fiber Optic Cable 07:30 - 08:00 0.50 RUNCMP -Land Hanger-Maintain 6000 psi on SSSV Control Line-Monitor Fiber Optics While Landing -RILDS-Test Hanger Seals 115000 psi 08:00 - 09:00 1.00 RUNCMP -R/U II Reverse Circulate 09:00 - 16:30 7.50 RUNCMP -Pressure Test Lines 114200 psi -Reverse Circulate 470 bbl Corrosion Inhibited Brine@ 3 bpm -Dispace w/ 200 bbl Seawater @ 3 bpm 16:30 - 17:30 RUNCMP -Drop Ball & Rod (1 7/8" Ball) -Pressure II 4200 psi II Set Packer -Chart fl 30 Minutes II Confirm No Tubing Leak 17:30 - 19:00 RUNCMP -Bleed Tubing II 2650 psi-Blow Down Out Side Mud Line -Pressure IA to 4200 psi-Tubing Pressure Increased 113450 psi -Chart f/30 Minutes II Confirm No Packer Leak-Bled Down Annulus & Tubing 19:00 - 20:00 RUNCMP -Pressure IA to 2500 psi II Shear RP Valve in GLM-Pump II Confirm Sheared -Release Pressure on SSSV Control Line-Pressure 111000 psi on IA II Test SSSV-Tested OK 20:00 - 21 :00 1.00 RUNCMP -R/U II Pump Diesel Freeze Protection & U-tube 21 :00 - 23:00 2.00 RUNCMP -Pump 78 bbl Corrosion Inhibited Heated Diesel Down IA -Taking Returns Up Tubing II G&I-G&I Confirming Volume Pumped wI Tank Strap 23:00 - 00:00 HMAN RUNCMP -Shut Down Pump & Secure Well-Ops Has Diesel Spill @ Heated Diesel Tank -Rig Crew Responded II Assist Ops as Needed 3/31/2005 00:00 - 01 :00 1.00 HMAN RUNCMP -Wait on Ops II Transfer Diesel II Rig 01 :00 - 03:00 2.00 RUNCMP -Reverse Circulate 122 bbl of Corrosion Inhibited Diesel @ 1.3 bpm-220 psi -Line Up II U-Tube 03:00 - 04:30 RUNCMP -U-Tube Corrosion Inhibited Diesel-SITP @ Start=390 psi, Complete=O psi -Get Tools Ready II NID Stack 04:30 - 05:30 RUNCMP -RID Hoses & UD Landing Joint -Blow Down Surface Equipment 05:30 - 06:30 1.00 RUNCMP -Install TWC & Test 111000 psi f/ Below (OK) 06:30 - 07:00 0.50 RUNCMP -R/D Halliburton Control Line & Clear Rig Floor Printed: 4/4/2005 8:28:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS05 NS05 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 2/2/2005 Rig Release: 3/31/2005 Rig Number: Spud Date: 2/16/2005 End: 3/31/2005 16:30 - 18:00 1.50 WHSUR P -N/D Riser & Clean Drip Pan Under Rotary Table -UD Mousehole & Riser RUNCMP -N/D BOPE-Remove Turnbuckles & Choke Line -Rack Back BOP & Remove Spacer Spool RUNCMP -Run SSSV Control Line Through Tree -Splice Fiber Optic Cable @ Wellhead Junction RUNCMP -N/U Dry Hole Tree -Test Void & Tree tJ 5000 psi 1/15 min -Release Rig @ 1800 hrs-3/31/2005 08:00 - 12:30 12:30 - 16:30 4.00 WHSUR P Printed: 4/4/2005 8:28:59 AM WELL SERVICE REPORT WELL NS-05 DATE 4/12/2005 AFE NSD831344 JOB SCOPE NEW WELL POST DAILY WORK PERFORATING KEY PERSON SWS-DICKINSON MINID 3.725 " DEPTH 13261 FT UNIT SWS 2158 DAY SUPV BOYLES NIGHT SUPV BOYLES TTL SIZE 4.5 " DAILY SUMMARY SHOT 2.88" HSD 6SPF 60DEG PHASED PJ2906 CHARGE GUNS FROM 13739'-13794'. DOUBLE SHOT FROM 13754'- 13759' AS PER PROGRAM. ALL SHOTS FIRED. TIED INTO SLB USIT PDC LOG DATED 11-APR-05 Init Tba. IA OA -> 1 01 01 01 TIME COMMENT 06:30 SAFETY MEETING, SIMOPS, GET PERMIT SIGNED 08:00 START RU 09:00 RIGGED UP, PRESSURE TEST SURFACE EQUIPMENT 09:30 PT 300 LOW, 3000 HIGH, PT GOOD, BLEED DOWN AND UNSTAB AT QTS 10:00 SLOP TANK FULL SWAP TANKS 10:30 TEST TOOLS SURFACE, TOOLS CHECK GOOD, POWER DOWN AND ARM GUN 10:45 STAB WELL, PT QTS 3500, PT GOOD, RIH WITH HEAD, CCL, 20' 2.88" GUN. MAX OD = 3.08" AFTER SHOOTING, MAX LENGTH = 26' 11 :27 ON BOTTOM, TIE-IN TO SLB US IT PDC LOG DATED 11-APR-05 11:40 IN POSITION, DEPTH VERIFIED, WHP = 0 PSI BEFORE SHOOTING, 500 PSI AFTER SHOOTING, GOOD SHOT INDICATION, LOG OFF, POOH 12:30 AT 800', FLOW FLOW PLUGGING OFF, STOP WIRE AND PUMP MEOH TO CLEAR HOSE 13:00 FLOW HOSE CLEAR, AT SURFACE, SHUT SWAB, BLEED DOWN TUBING PRESSURE UP TO 500 PSI, UNSTAB AND CONFIRMED ALL SHOTS FIRED. TEST TOOLS SURFACE, TOOLS CHECK GOOD. 13:45 ARM GUN #2, STAB WELL, PT QTS 4000 PSI, PT GOOD, RIH WITH SECOND GUN 14:50 ON BOTTOM, SET DOWN IN PERFS, PICKED A LITTLE STICKY, TIE-IN 15:39 IN POSITION, ABLE TO GO THRU PERFS ON SECOND ATTEMPT, DEPTH VERIFIED, SHOOT 13754'-13774', GOOD SHOT INDICATION, LOG OFF, POOH, TRICKLE IN MEOH 16:45 OOH, SHUT DOWN MEOH, SHUT SWAB, BLEED DOWN, UNSTAB, CONFIRMED ALL SHOTS FIRED, RE- HEAD 17:51 RE-HEAD COMPLETE, TEST TOOLS SURFACE, TOOLS CHECK GOOD, POWER DOWN AND ARM GUN #3 18:24 STAB WELL, PT QTS 4000, PT GOOD, RIH WITH GUN #3 19:12 ON BOTTOM, TIE-IN 19:32 IN POSITION, DEPTH VERIFIED, SHOOT 13739'-13759', GOOD SHOT INDICATION, TRICKLE MEOH, LOG OFF, POOH 20:45 OOH, WHEN SHUTTING IN WELL, NOTICED HYDRAULIC CONTROL SYSTEM ON TREE WAS LEAKING FLUID, MADE CALLS TO PE AND SLB MANAGEMENT, FOUND SOURCE OF LEAK WAS PRESSURE BEING BLEED FROM ANOTHER WELL THAT THE DSO WAS WORKING ON. GOT LINES ISOLATED AND STOPPED LEAK, CALLED ENVIRONMENTAL AND REPORTED LEAK. ALL LINES ON TREE DOUBLE CHECKED FOR TIGHT FITTINGS AND CAPS, NO OTHER LEAKS WERE FOUND. LEAK WAS DEAMED NOT SLB'S FAULT. 22:00 CONTINUE RIGDOWN TO SAFE POINT AND SHUT-DOWN FOR NIGHT SINCE 16HR RULE GOING INTO EFFECT. 22:30 WELL CAP ON AND TESTED, SSV CONTROL LINE REMOVED, PRESSURE GEAR STOWED AWAY, GUNS SECURED FOR NIGHT AND TRANSPORTATION. ABSORB UNDER GUNS PICKED UP, WELL RELEASED TO ENVIRONMENTAL FOR FURTHER ASSESSMENT/CLEAN-UP. Final Tbç¡, IA OA -> 1 5501 01 01 FLUID SUMMARY 0.5 BBLS DIESEL FOR PT 4 BBLS MEOH FOR FREEZE PROTECT .. SERVICE COMPANY - SERVICE DAILY COST CUMULTOTAL ASRC $230 $1,730 SCHLUMBERGER $20,190 $48,746 CAMCO $0 $705 TOTAL FIELD ESTIMATE: $20,420 $51,181 Printed: 4/4/2005 8:28:53 AM -, Schlumberger u () NS05 Survey Report -:J I Report Date: 24·Mar-05 Survey I DLS Computation Method: Minimum CUNature I Lubinski ,- Client: BP Exploration Alaska Vertical Section Azimuth: 190.010' j Field: Northstar Vertical Section Drigin: N 0.000 ft, E 0.000 ft ~ Structure I Slot: Northstar PF / NS05 TVD Reference Datum: Rotary Table Well: NS05 TVD Reference Elevation: 56.37ft relative to MSL Borehole: NS05 Sea Bed I Ground Level Elevation: 15.67ft relative to MSL UWI/API#: 500292324400 Magnetic Declination: 24.968' Survey Name I Date: NS05/ March 24, 2005 Total Field Strength: 57642.861 n T Tort I AHD I DDII ERD ratio: 142.057' / 6493.88ft/6.058 / 0.573 Magnetic Dip: 80.977' . Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 14, 2005 Location Lal/Long: N 70.49085943, W 148.69327224 Magnetic Declination Model: BGGM 2004 Location Grid NlE Y/X: N 6030861.820 ftUS, E 659835.490 ftUS North Reference: True North Grid Convergence Angle: +1.23173007' Total Corr Mag North -> True North: +24.968' Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Comments Measured Sub-Sea TVD TVD NS EW DLS Easting Latitude Longitude Depth It RTE 0.00 N 70.49085943 W 148.69327224 First GYD-GC-SS 50.00 N 70.49085930 W 148.69327312 100.00 N 70.49085899 W 148.69327239 150.00 N 70.49085939 W 148.69326729 200.00 N 70.49086052 W 148.69326128 276.00 0.92 49.34 219.61 275.98 -1.49 3.00 2.53 1.11 2.28 0.18 6030862.98 659837.74 N 70.49086245 W 148.69325364 370.00 0.37 47.92 313.60 369.97 -2.31 4.06 3.56 1.80 3.07 0.59 6030863.69 659838.52 N 70.49086435 W 148.69324712 470.00 0.30 152.39 413.60 469.97 -2.36 4.50 3.87 1.79 3.43 0.53 6030863.68 659838.88 N 70.49086431 W 148.69324417 570.00 0.17 150.24 513.60 569.97 -2.03 4.91 3.90 1.43 3.63 0.13 6030863.32 659839.09 N 70.49086332 W 148.69324257 670.00 0.19 159.89 613.60 669.97 -1.78 5.22 3.93 1.14 3.76 0.04 6030863.04 659839.22 N 70.49086254 W 148.69324150 . 770.00 0.19 187.25 713.60 769.97 -1.47 5.55 3.88 0.82 3.80 0.09 6030862.72 659839.27 N 70.49086167 W 148.69324121 870.00 0.14 172.66 813.60 869.97 -1.19 5.84 3.83 0.54 3.79 0.06 6030862.44 659839.27 N 70.49086089 W 148.69324125 970.00 0.33 210.66 913.60 969.97 -0.80 6.23 3.66 0.17 3.66 0.24 6030862.06 659839.14 N 70.49085988 W 148.69324232 1070.00 0.12 164.59 1013.60 1069.97 -0.44 6.61 3.55 -0.18 3.54 0.26 6030861.71 659839.03 N 70.49085893 W 148.69324330 1170.00 0.11 201.19 1113.60 1169.97 -0.25 6.80 3.55 -0.37 3.53 0.07 6030861.52 659839.03 N 70.49085841 W 148.69324335 1270.00 0.17 153.68 1213.60 1269.97 -0.03 7.03 3.61 -0.60 3.56 0.13 6030861.30 659839.07 N 70.49085780 W 148.69324310 1370.00 0.15 102.85 1313.60 1369.97 0.09 7.30 3.83 -0.76 3.76 0.14 6030861.14 659839.26 N 70.49085736 W 148.69324152 1470.00 0.20 101.19 1413.60 1469.97 0.10 7.60 4.14 -0.82 4.06 0.05 6030861.09 659839.56 N 70.49085719 W 148.69323908 1570.00 0.32 96.37 1513.59 1569.96 0.09 8.05 4.59 -0.89 4.51 0.12 6030861.03 659840.01 N 70.49085701 W 148.69323541 1670.00 0.44 100.03 1613.59 1669.96 0.07 8.72 5.25 -0.98 5.16 0.12 6030860.95 659840.67 N 70.49085674 W 148.69323005 1770.00 0.62 77.03 1713.59 1769.96 -0.14 9.63 6.14 -0.93 6.07 0.28 6030861.02 659841.57 N 70.49085689 W 148.69322265 Last GYD-GC-SS 1850.00 0.55 126.36 1793.58 1849.95 -0.14 10.40 6.88 -1.06 6.80 0.62 6030860.91 659842.31 N 70.49085653 W 148.69321667 First MWD+IFR+MS 1968.52 1.16 192.23 1912.09 1968.46 1.31 12.00 7.46 -2.57 7.00 0.90 6030859.40 659842.54 N 70.49085241 W 148.69321501 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05\NS05 Generated 12/9/20056:25 PM Page 1 of 5 Comments Latitude Longitude N 70.49084733 W 148.69322026 N 70.49084254 W 148.69322731 2251.99 1.29 204.03 2195.50 2251.87 7.02 17.89 9.22 -7.95 4.66 0.20 6030853.97 659840.32 N 70.49083770 W 148.69323417 2344.68 1.21 209.37 2288.17 2344.54 8.96 19.91 10.46 -9.76 3.75 0.15 6030852.15 659839.45 N 70.49083277 W 148.69324156 2439.21 1.23 211.00 2382.68 2439.05 10.85 21.92 11.82 -11.50 2.74 0.04 6030850.38 659838.48 N 70.49082802 W 148.69324984 2535.92 1.33 208.35 2479.36 2535.73 12.88 24.08 13.48 -13.38 1.67 0.12 6030848.48 659837.45 N 70.49082289 W 148.69325856 2630.19 1.38 217.74 2573.61 2629.98 14.92 26.30 15.24 -15.24 0.46 0.24 6030846.60 659836.28 N 70.49081780 W 148.69326849 2725.51 1.45 216.66 2668.90 2725.27 17.02 28.66 17.14 -17.11 -0.96 0.08 6030844.69 659834.89 N 70.49081268 W 148.69328012 2818.85 2.62 199.38 2762.18 2818.55 20.18 31.95 20.21 -20.07 -2.38 1.40 6030841.70 659833.54 N 70.49080460 W 148.69329167 2913.09 6.42 183.45 2856.11 2912.48 27.54 39.33 27.58 -27.37 -3.41 4.21 6030834.39 659832.67 N 70.49078467 W 148.69330011 . 3007.90 7.94 182.41 2950.18 3006.55 39.30 51.18 39.40 -39.20 -4.00 1.61 6030822.55 659832.33 N 70.49075234 W 148.69330496 3101.16 9.30 187.10 3042.38 3098.75 53.21 65.15 53.37 -53.11 -5.21 1.64 6030808.61 659831.43 N 70.49071433 W 148.69331479 3133.57 9.45 188.03 3074.36 3130.73 58.48 70.43 58.64 -58.35 -5.90 0.66 6030803.36 659830.84 N 70.49070003 W 148.69332048 3247.52 10.45 189.11 3186.59 3242.96 78.17 90.12 78.31 -77.81 -8.84 0.89 6030783.84 659828.32 N 70.49064685 W 148.69334453 3342.20 11.13 189.40 3279.60 3335.97 95.89 107.85 96.02 -95.31 -11.70 0.72 6030766.29 659825.85 N 70.49059906 W 148.69336784 3435.59 11.90 187.59 3371.11 3427.48 114.52 126.49 114.66 -113.75 -14.44 0.91 6030747.80 659823.50 N 70.49054869 W 148.69339027 3529.65 12.12 186.61 3463.11 3519.48 134.07 146.06 134.23 -133.17 -16.86 0.32 6030728.33 659821.50 N 70.49049563 W 148.69341003 3624.53 11.46 188.18 3555.99 3612.36 153.43 165.44 153.61 -152.39 -19.35 0.77 6030709.06 659819.43 N 70.49044312 W 148.69343037 3719.65 10.56 189.53 3649.36 3705.73 171.59 183.61 171.77 -170.34 -22.13 0.98 6030691.06 659817.02 N 70.49039408 W 148.69345315 3815.32 9.80 192.29 3743.52 3799.89 188.50 200.51 188.65 -186.94 -25.32 0.94 6030674.39 659814.20 N 70.49034873 W 148.69347918 3911.41 10.00 192.03 3838.18 3894.55 205.01 217.03 205.12 -203.09 -28.80 0.21 6030658.17 659811.07 N 70.49030461 W 148.69350762 4005.28 10.44 192.06 3930.56 3986.93 221.65 233.69 221.74 -219.38 -32.27 0.47 6030641.81 659807.94 N 70.49026011 W 148.69353603 4101.82 10.67 190.10 4025.47 4081.84 239.33 251.37 239.40 -236.73 -35.67 0.44 6030624.39 659804.92 N 70.49021270 W 148.69356378 4195.72 10.75 186.81 4117.73 4174.10 256.77 268.82 256.85 -253.99 -38.23 0.66 6030607.09 659802.73 N 70.49016557 W 148.69358473 4291.48 10.69 184.29 4211.82 4268.19 274.52 286.63 274.63 -271.71 -39.95 0.49 6030589.33 659801.39 N 70.49011715 W 148.69359882 4385.69 9.36 186.29 4304.59 4360.96 290.86 303.03 291.01 -288.04 -41.45 1.46 6030572.98 659800.25 N 70.49007254 W 148.69361102 4481.71 8.80 189.07 4399.41 4455.78 306.00 318.18 306.15 -303.05 -43.46 0.74 6030557.92 659798.56 N 70.49003152 W 148.69362747 4575.19 9.01 188.81 4491.76 4548.13 320.46 332.65 320.62 -317.35 -45.71 0.23 6030543.58 659796.62 N 70.48999247 W 148.69364585 . 4669.99 9.34 189.26 4585.35 4641.72 335.58 347.76 335.74 -332.28 -48.08 0.36 6030528.61 659794.56 N 70.48995169 W 148.69366526 4763.91 9.57 188.62 4677.99 4734.36 351.00 363.19 351.17 -347.52 -50.48 0.27 6030513.32 659792.49 N 70.48991005 W 148.69368485 4867.69 11.56 191.69 4780.01 4836.38 370.02 382.21 370.17 -366.23 -53.88 1.99 6030494.54 659789.50 N 70.48985893 W 148.69371264 4953.25 15.46 194.88 4863.19 4919.56 389.96 402.19 390.08 -385.66 -58.55 4.64 6030475.02 659785.25 N 70.48980587 W 148.69375079 5047.25 18.21 195.68 4953.15 5009.52 417.07 429.41 417.12 -411.91 -65.74 2.94 6030448.62 659778.63 N 70.48973414 W 148.69380954 5142.27 20.72 196.81 5042.73 5099.10 448.54 461.07 448.55 -442.30 -74.61 2.67 6030418.05 659770.41 N 70.48965112 W 148.69388208 5238.45 22.43 197.43 5132.17 5188.54 483.63 496.44 483.63 -476.10 -85.03 1.79 6030384.04 659760.72 N 70.48955879 W 148.69396722 5329.78 23.33 196.28 5216.31 5272.68 518.88 531.95 518.91 -510.08 -95.32 1.10 6030349.85 659751.17 N 70.48946595 W 148.69405132 5425.44 24.66 195.21 5303.70 5360.07 557.59 570.85 557.66 -547.52 -105.86 1.46 6030312.19 659741.43 N 70.48936367 W 148.69413751 5519.93 26.30 192.57 5389.00 5445.37 598.14 611.49 598.25 -586.98 -115.59 2.11 6030272.53 659732.55 N 70.48925588 W 148.69421702 5614.17 27.79 190.84 5472.94 5529.31 640.96 654.33 641.10 -628.94 -124.27 1.79 6030230.40 659724.78 N 70.48914125 W 148.69428793 5707.62 30.50 190.90 5554.55 5610.92 686.47 699.84 686.60 -673.63 -132.85 2.90 6030185.54 659717.16 N 70.48901916 W 148.69435807 5802.98 32.75 190.09 5635.74 5692.11 736.46 749.84 736.60 -722.79 -141.95 2.40 6030136.20 659709.12 N 70.48888485 W 148.69443241 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05\NS05 Generated 12/9/20056:25 PM Page 2 of 5 Comments Latitude Longitude N 70.48874212 W 148.69450808 5992.22 36.90 189.61 5791.10 5847.47 844.45 857.83 844.57 -829.16 -160.56 2.25 6030029.46 659692.80 N 70.48859426 W 148.69458452 6086.39 39.18 189.92 5865.26 5921.63 902.47 915.85 902.58 -886.35 -170.40 2.43 6029972.08 659684.19 N 70.48843804 W 148.69466497 6179.30 40.53 189.17 5936.58 5992.95 962.01 975.39 962.10 -945.06 -180.27 1.54 6029913.17 659675.59 N 70.48827764 W 148.69474561 6273.93 41.31 189.39 6008.09 6064.46 1023.99 1037.38 1024.06 -1006.23 -190.27 0.84 6029851.80 659666.91 N 70.48811053 W 148.69482729 6368.65 41.69 188.75 6079.03 6135.40 1086.74 1100.14 1086.80 -1068.21 -200.16 0.60 6029789.63 659658.35 N 70.48794121 W 148.69490813 6462.24 42.01 188.62 6148.74 6205.11 1149.17 1162.58 1149.21 -1129.94 -209.59 0.35 6029727.72 659650.25 N 70.48777259 W 148.69498518 6556.11 42.63 189.02 6218.15 6274.52 1212.35 1225.78 1212.38 -1192.39 -219.28 0.72 6029665.08 659641.91 N 70.48760198 W 148.69506437 6649.90 43.25 188.65 6286.81 6343.18 1276.23 1289.67 1276.25 -1255.52 -229.09 0.71 6029601.76 659633.45 N 70.48742950 W 148.69514454 6743.95 43.98 188.02 6354.90 6411.27 1341.08 1354.55 1341.09 -1319.71 -238.50 0.90 6029537.38 659625.43 N 70.48725414 W 148.69522137 . 6839.45 44.90 187.63 6423.08 6479.45 1407.89 1421.41 1407.90 -1385.96 -247.60 1.00 6029470.96 659617.76 N 70.48707317 W 148.69529573 6934.32 45.45 187.37 6489.96 6546.33 1475.12 1488.70 1475.12 -1452.67 -256.38 0.61 6029404.08 659610.41 N 70.48689093 W 148.69536749 7028.37 46.49 187.42 6555.33 6611.70 1542.67 1556.32 1542.67 -1519.72 -265.08 1.11 6029336.86 659603.15 N 70.48670773 W 148.69543859 7123.62 49.90 189.08 6618.82 6675.19 1613.62 1627.31 1613.63 -1589.97 -275.30 3.81 6029266.42 659594.45 N 70.48651583 W 148.69552204 7217.65 52.91 189.88 6677.47 6733.84 1687.10 1700.79 1687.11 -1662.45 -287.41 3.27 6029193.70 659583.90 N 70.48631783 W 148.69562101 7313.05 54.71 189.54 6733.79 6790.16 1764.09 1777.78 1764.10 -1738.33 -300.39 1.91 6029117.56 659572.55 N 70.48611051 W 148.69572708 7408.99 54.93 189.55 6789.07 6845.44 1842.50 1856.20 1842.51 -1815.67 -313.39 0.23 6029039.97 659561.22 N 70.48589925 W 148.69583332 7503.39 55.33 189.66 6843.04 6899.41 1919.95 1933.65 1919.96 -1892.03 -326.32 0.43 6028963.35 659549.94 N 70.48569063 W 148.69593890 7597.57 55.67 189.78 6896.38 6952.75 1997.56 2011.26 1997.58 -1968.53 -339.42 0.38 6028886.59 659538.48 N 70.48548164 W 148.69604596 7692.63 55.89 190.16 6949.84 7006.21 2076.17 2089.87 2076.18 -2045.95 -353.03 0.40 6028808.91 659526.54 N 70.48527015 W 148.69615714 7784.74 55.79 190.09 7001.56 7057.93 2152.39 2166.08 2152.40 -2120.98 -366.43 0.13 6028733.61 659514.76 N 70.48506517 W 148.69626660 7878.92 55.67 189.85 7054.60 7110.97 2230.22 2243.91 2230.23 -2197.63 -379.91 0.25 6028656.69 659502.94 N 70.48485576 W 148.69637669 7974.09 55.53 190.10 7108.36 7164.73 2308.74 2322.44 2308.75 -2274.97 -393.51 0.26 6028579.08 659491.00 N 70.48464448 W 148.69648780 8068.77 55.43 190.15 7162.02 7218.39 2386.75 2400.45 2386.76 -2351.77 -407.22 0.11 6028502.01 659478.94 N 70.48443468 W 148.69659983 8164.47 55.33 190.22 7216.39 7272.76 2465.51 2479.20 2465.52 -2429.28 -421.15 0.12 6028424.22 659466.69 N 70.48422292 W 148.69671359 8260.20 55.24 190.34 7270.91 7327.28 2544.19 2557.89 2544.20 -2506.71 -435.19 0.14 6028346.52 659454.31 N 70.48401140 W 148.69682830 8355.69 55.21 190.07 7325.37 7381.74 2622.63 2636.33 2622.64 -2583.90 -449.09 0.23 6028269.05 659442.08 N 70.48380051 W 148.69694182 8450.18 54.95 190.39 7379.46 7435.83 2700.11 2713.81 2700.11 -2660.15 -462.85 0.39 6028192.53 659429.96 N 70.48359222 W 148.69705421 . 8545.03 54.81 190.08 7434.03 7490.40 2777.69 2791.39 2777.69 -2736.50 -476.63 0.31 6028115.91 659417.82 N 70.48338364 W 148.69716681 8640.04 54.69 190.33 7488.86 7545.23 2855.28 2868.98 2855.28 -2812.86 -490.38 0.25 6028039.28 659405.72 N 70.48317503 W 148.69727909 8733.74 54.51 190.10 7543.14 7599.51 2931.65 2945.36 2931.66 -2888.02 -503.92 0.28 6027963.84 659393.80 N 70.48296968 W 148.69738973 8827.86 54.52 190.29 7597.77 7654.14 3008.29 3021.99 3008.30 -2963.45 -517.49 0.16 6027888.14 659381.86 N 70.48276362 W 148.69750052 8923.49 54.64 190.03 7653.20 7709.57 3086.22 3099.93 3086.23 -3040.16 -531.23 0.25 6027811.16 659369.76 N 70.48255406 W 148.69761280 9017.25 54.65 190.01 7707.45 7763.82 3162.69 3176.39 3162.70 -3115.46 -544.54 0.02 6027735.60 659358.08 N 70.48234834 W 148.69772146 9110.99 54.77 189.50 7761.61 7817.98 3239.20 3252.91 3239.21 -3190.87 -557.50 0.46 6027659.93 659346.74 N 70.48214233 W 148.69782734 9206.04 54.87 188.92 7816.37 7872.74 3316.88 3330.60 3316.89 -3267.56 -569.94 0.51 6027583.00 659335.96 N 70.48193283 W 148.69792888 Tie-In Survey 9301.87 55.02 189.11 7871.41 7927.78 3395.32 3409.04 3395.33 -3345.04 -582.23 0.23 6027505.29 659325.34 N 70.48172117 W 148.69802927 Continue 9335.92 53.87 188.81 7891.21 7947.58 3423.02 3436.74 3423.03 -3372.40 -586.54 3.45 6027477.84 659321.61 N 70.48164642 W 148.69806450 MWD+IFR+MS 9386.01 51.36 188.50 7921.62 7977.99 3462.80 3476.54 3462.81 -3411.74 -592.54 5.04 6027438.38 659316.47 N 70.48153894 W 148.69811342 9446.28 50.86 189.71 7959.46 8015.83 3509.71 3523.45 3509.72 -3458.06 -599.96 1.77 6027391.91 659310.05 N 70.48141240 W 148.69817403 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05\NS05 Generated 12/9/20056:25 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure lit) IdeQ) IdeQ) lit) lit) lit) lit) III) lit) (It) (deQ/100 It) IltUS) (IIUS) 9540.24 50.46 189.81 8019.02 8075.39 3582.37 3596.12 3582.39 -3529.68 -612.28 0.43 6027320.05 659299.27 N 70.48121675 W 148.69827463 9633.29 50.14 189.84 8078.46 8134.83 3653.97 3667.71 3653.98 -3600.22 -624.49 0.34 6027249.27 659288.57 N 70.48102403 W 148.69837439 9724.92 49.72 189.96 8137.45 8193.82 3724.09 3737.83 3724.10 -3669.30 -636.55 0.47 6027179.96 659278.01 N 70.48083532 W 148.69847283 9819.08 49.30 190.34 8198.59 8254.96 3795,70 3809.44 3795.71 -3739.79 -649.17 0.54 6027109.22 659266.91 N 70.48064275 W 148.69857588 9912.54 49.00 191.06 8259.72 8316.09 3866.38 3880.14 3866.40 -3809.25 -662.29 0.67 6027039.49 659255.28 N 70.48045298 W 148.69868305 10010.52 50.60 191.22 8322.96 8379.33 3941.20 3954.97 3941.21 -3882.68 -676.75 1.64 6026965.78 659242.40 N 70.48025239 W 148.69880113 10104.93 52.25 192.06 8381.82 8438.19 4014.98 4028.78 4014.98 -3954.96 -691.65 1.88 6026893.19 659229.06 N 70.48005491 W 148.69892278 10201.39 53.36 193.27 8440.14 8496.51 4091.73 4105.61 4091.73 -4029.93 -708.50 1.52 6026817.89 659213.83 N 70.47985011 W 148.69906040 10299.68 53.22 194.09 8498.89 8555.26 4170.37 4184.41 4170.37 -4106.49 -727.13 0.68 6026740.95 659196.84 N 70.47964096 W 148.69921258 10389.97 53.29 194.00 8552.91 8609.28 4242.54 4256.76 4242.54 -4176.67 -744.69 0.11 6026670.41 659180.80 N 70.47944921 W 148.69935596 . 10483.25 53.26 193.68 8608.69 8665.06 4317.13 4331.53 4317.15 -4249.27 -762.58 0.28 6026597.45 659164.48 N 70.47925089 W 148.69950201 10578.83 53.23 193.49 8665.88 8722.25 4393.56 4408.10 4393.60 -4323.70 -780.56 0.16 6026522.65 659148.10 N 70.47904753 W 148.69964889 10674.21 52.94 193.53 8723.17 8779.54 4469.68 4484.36 4469.73 -4397.85 -798.38 0.31 6026448.14 659131.88 N 70.47884496 W 148.69979436 10768.93 52.90 193.50 8780.28 8836.65 4545.11 4559.93 4545.18 -4471.33 -816.04 0.05 6026374.31 659115.81 N 70.47864423 W 148.69993856 10864.70 52.71 193.47 8838.17 8894.54 4621.25 4636.22 4621.36 -4545.51 -833.83 0.20 6026299.77 659099.62 N 70.47844156 W 148.70008382 10961.25 52.53 193.33 8896.79 8953.16 4697.84 4712.94 4697.98 -4620.14 -851.61 0.22 6026224.77 659083.45 N 70.47823767 W 148.70022900 11054.17 52.69 192.59 8953.21 9009.58 4771.57 4786.77 4771.73 -4692.09 -868.17 0.66 6026152.50 659068.44 N 70.47804112 W 148.70036418 11149.54 52.80 191.91 9010.95 9067.32 4847.42 4862.68 4847.61 -4766.27 -884.27 0.58 6026077.99 659053.94 N 70.47783846 W 148.70049567 11243.97 52.65 190.56 9068.14 9124.51 4922.54 4937.82 4922.74 -4839.97 -898.91 1.15 6026004.00 659040.88 N 70.47763712 W 148.70061519 11339.28 52.97 188.23 9125.76 9182.13 4998.46 5013.74 4998.64 -4914.87 -911.30 1.98 6025928.86 659030.11 N 70.47743250 W 148.70071633 11432.79 52.98 189.32 9182.07 9238.44 5073.09 5088.39 5073.26 -4988.65 -922.69 0.93 6025854.85 659020.31 N 70.47723094 W 148.70080928 11527.76 52.91 189.02 9239.29 9295.66 5148.88 5164.19 5149.03 -5063.4 7 -934.77 0.26 6025779.79 659009.84 N 70.47702653 W 148.70090787 11618.44 52.72 189.16 9294.10 9350.47 5221.11 5236.43 5221.26 -5134.81 -946.18 0.24 6025708.23 658999.97 N 70.47683164 W 148.70100102 11802.64 51.66 188.57 9407.02 9463.39 5366.60 5381.95 5366.73 -5278.59 -968.61 0.63 6025564.01 658980.63 N 70.47643884 W 148.70118410 11899.64 50.04 189.18 9468.26 9524.63 5441.81 5457.17 5441.92 -5352.91 -980.21 1.74 6025489.46 658970.63 N 70.47623580 W 148.70127877 11999.61 48.98 189.00 9533.17 9589.54 5517.83 5533.20 5517.93 -5427.99 -992.23 1.07 6025414.16 658960.24 N 70.47603071 W 148.70137681 12091.71 47.85 188.04 9594.30 9650.67 5586.69 5602.09 5586.78 -5496.11 -1002.44 1.45 6025345.83 658951.49 N 70.47584459 W 148.70146013 12185.30 45.83 187.40 9658.32 9714.69 5654.90 5670.35 5654.98 -5563.76 -1011.61 2.22 6025278.01 658943.77 N 70.47565979 W 148.70153501 . 12279.40 43.95 187.62 9724.98 9781.35 5721.24 5736.76 5721.30 -5629.59 -1020.29 2.00 6025212.01 658936.51 N 70.47547993 W 148.70160581 12375.26 42.07 188.82 9795.08 9851.45 5786.60 5802.15 5786.65 -5694.31 -1029.63 2.14 6025147.11 658928.57 N 70.47530314 W 148.70168199 12470.89 40.62 188.35 9866.87 9923.24 5849.75 5865.32 5849.79 -5756.77 -1039.06 1.55 6025084.47 658920.48 N 70.47513249 W 148.70175897 12565.85 39.03 188.86 9939.80 9996.17 5910.54 5926.13 5910.58 -5816.90 -1048.16 1.71 6025024.16 658912.68 N 70.47496822 W 148.70183319 12662.27 37.45 187.90 10015.52 10071.89 5970.19 5985.81 5970.23 -5875.94 -1056.86 1.75 6024964.95 658905.25 N 70.47480693 W 148.70190422 12757.23 34.23 187.55 10092.49 10148.86 6025.74 6041.40 6025.77 -5931.03 -1064.34 3.40 6024909.72 658898.96 N 70.47465644 W 148.70196525 12851.01 30.98 188.47 10171.48 10227.85 6076.24 6091.93 6076.26 -5981.06 -1071.36 3.51 6024859.55 658893.01 N 70.47451975 W 148.70202254 12947.22 28.50 187.03 10255.02 10311.39 6123.92 6139.65 6123.94 -6028.34 -1077.82 2.68 6024812.14 658887.57 N 70.47439058 W 148.70207523 13042.62 26.30 187.28 10339.71 10396.08 6167.77 6183.55 6167.78 -6071.90 -1083.28 2.31 6024768.48 658883.05 N 70.47427158 W 148.70211981 13138.55 22.91 186.71 10426.92 10483.29 6207.65 6223.48 6207.65 -6111.54 -1088.16 3.54 6024728.75 658879.02 N 70.47416330 W 148.70215958 13232.45 19.66 186.01 10514.40 10570.77 6241.66 6257.57 6241.66 -6145.41 -1091.95 3.47 6024694.81 658875.96 N 70.47407077 W 148.70219050 13327.25 16.90 188.55 10604.41 10660.78 6271.35 6287.29 6271.35 -6174.90 -1095.67 3.03 6024665.25 658872.88 N 70.47399020 W 148.70222084 13421.66 16.52 186.66 10694.83 10751.20 6298.47 6314.44 6298.4 7 -6201.80 -1099.27 0.70 6024638.28 658869.86 N 70.47391670 W 148.70225018 SurveyEditor Ver Sld( doc40x_37 ) NS05\NS05\NS05\NS05 Generated 12/9/20056:25 PM Page 4 of 5 Comments Latitude Longitude 13465.35 16.34 188.44 10736.74 10793.11 6310.81 6326.79 6310.81 -6214.05 -1100.89 1.22 6024626.00 658868.50 N 70.47388324 W 148.70226342 13628.25 18.22 186.20 10892.28 10948.65 6359.13 6375.17 6359.13 -6262.04 -1107.00 1.22 6024577.89 658863.42 N 70.47375214 W 148.70231330 13724.61 17.34 185.02 10984.04 11040.41 6388.4 7 6404.60 6388.4 7 -6291.32 -1109.89 0.99 6024548.56 658861.17 N 70.47367214 W 148.70233681 13820.06 17.10 183.42 11075.21 11131.58 6416.58 6432.85 6416.58 -6319.50 -1111.97 0.56 6024520.34 658859.69 N 70.47359516 W 148.70235378 13915.31 16.72 186.99 11166.34 11222.71 6444.18 6460.55 6444.18 -6347.08 -1114.47 1.16 6024492.72 658857.78 N 70.47351982 W 148.70237419 Last MWD+IFR+MS 13959.90 16.39 183.56 11209.09 11265.46 6456.83 6473.25 6456.84 -6359.72 -1115.64 2.31 6024480.05 658856.88 N 70.47348527 W 148.70238374 TD ( Projected) 14033.00 16.39 183.56 11279.22 11335.59 6477.33 6493.88 6477.34 -6380.31 -1116.92 0.00 6024459.44 658856.05 N 70.47342903 W 148.70239417 . 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 + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) LeQal Description: Surface: 1089 FSL 641 FEL S11 T13N R13E UM BHL: 5269 FSL 1763 FEL S23 T13N R13E UM NorthinQ (YI musl 6030861.82 6024459.44 EastinQ (XI fftUSI 659835.49 658856.05 . SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05\NS05 Generated 12/9/20056:25 PM Page 5 of 5 Report Date: 2-Mar-05 Client: BP Exploration Alaska Field: Northstar Structure I Slot: Northstar PF I NS05 Well: NS05 Borehole: NS05PB 1 UWVAPI#: 500292324470 Survey Name I Date: NS05PB11 March 2, 2005 Tort I AHD I DDII ERD ratio: 101.796' 15600.08 It 15,8581 0.590 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.49085943, W 148.69327224 Location Grid NlE Y/X: N 6030861.820 ItUS, E 659835.490 ItUS Grid Convergence Angle: + 1.23173007' Grid Scale Factor: 0.99992902 NS05PB1 Survey Report Survey I DLS Computation Method: Minimum CUNature / Lubinski Vertical Section Azimuth: 190,010' Vertical Section Origin: N 0.000 It, E 0.000 It TVD Reference Datum: Rotary Table TVD Reference Elevation: 56.37 It relative to MSL Sea Bed I Ground Level Elevation: 15.67 It relative to MSL Magnetic Declination: 24.968' Total Field Strength: 57642.861 nT Magnetic Dip: 80.977' Declination Date: February 14, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.968' Local Coordinates Referenced To: Well Head Schlumberger . Comments Latitude Longitude RTE N 70.49085943 W 148.69327224 First GYD-GC-SS N 70.49085930 W 148.69327312 N 70.49085899 W 148.69327239 N 70.49085939 W 148.69326729 N 70.49086052 W 148.69326128 276.00 0.92 49.34 219.61 275.98 -1.49 3.00 2.53 1.11 2.28 0.18 6030862.98 659837.74 N 70.49086245 W 148.69325364 370.00 0.37 47.92 313.60 369.97 -2.31 4.06 3.56 1.80 3.07 0.59 6030863.69 659838.52 N 70.49086435 W 148.69324712 470.00 0.30 152.39 413.60 469.97 -2.36 4.50 3.87 1.79 3.43 0.53 6030863.68 659838.88 N 70.49086431 W 148.69324417 570.00 0.17 150.24 513.60 569.97 -2.03 4.91 3.90 1.43 3.63 0.13 6030863.32 659839.09 N 70.49086332 W 148.69324257 670.00 0.19 159.89 613.60 669.97 -1.78 5.22 3.93 1.14 3.76 0.04 6030863.04 659839.22 N 70.49086254 W 148.69324150 770.00 0.19 187.25 713.60 769.97 -1.47 5.55 3.88 0.82 3.80 0.09 6030862.72 659839.27 N 70.49086167 W 148.6.1 870.00 0.14 172.66 813.60 869.97 -1.19 5.84 3.83 0.54 3.79 0.06 6030862.44 659839.27 N 70.49086089 W 148.6 25 970.00 0.33 210.66 913.60 969.97 -0.80 6.23 3.66 0.17 3.66 0.24 6030862.06 659839.14 N 70.49085988 W 148.69324232 1070.00 0.12 164.59 1013.60 1069.97 -0.44 6.61 3.55 -0.18 3.54 0.26 6030861.71 659839.03 N 70.49085893 W 148.69324330 1170.00 0.11 201.19 1113.60 1169.97 -0.25 6.80 3.55 -0.37 3.53 0.07 6030861.52 659839.03 N 70.49085841 W 148.69324335 1270.00 0.17 153.68 1213.60 1269.97 -0.03 7.03 3.61 -0.60 3.56 0.13 6030861.30 659839.07 N 70.49085780 W 148.69324310 1370.00 0.15 102.85 1313.60 1369.97 0.09 7.30 3.83 -0.76 3.76 0.14 6030861.14 659839.26 N 70.49085736 W 148.69324152 1470.00 0.20 101.19 1413.60 1469.97 0.10 7.60 4.14 -0.82 4.06 0.05 6030861.09 659839.56 N 70.49085719 W 148.69323908 1570.00 0.32 96.37 1513.59 1569.96 0.09 8.05 4.59 -0.89 4.51 0.12 6030861.03 659840.01 N 70.49085701 W 148.69323541 1670.00 0.44 100.03 1613.59 1669.96 0.07 8.72 5.25 -0.98 5.16 0.12 6030860.95 659840.67 N 70.49085674 W 148.69323005 1770.00 0.62 77.03 1713.59 1769.96 -0.14 9.63 6.14 -0.93 6.07 0.28 6030861.02 659841.57 N 70.49085689 W 148.69322265 Last GYD-GC-SS 1850.00 0.55 126.36 1793.58 1849.95 -0.14 10.40 6.88 -1.06 6.80 0.62 6030860.91 659842.31 N 70.49085653 W 148.69321667 First MWD+IFR+MS 1968.52 1.16 192.23 1912.09 1968.46 1.31 12.00 7.46 -2.57 7.00 0.90 6030859.40 659842.54 N 70.49085241 W 148.69321501 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05PB1 \NS05PB 1 Generated 5/12/2005 5:24 PM Page 1 of 4 Comments Latitude Longitude N 70.49084733 W 148.69322026 N 70.49084254 W 148.69322731 2251.99 1.29 204.03 2195.50 2251.87 7.02 17.89 9.22 -7.95 4.66 0.20 6030853.97 659840.32 N 70.49083770 W 148.69323417 2344.68 1.21 209.37 2288.17 2344.54 8.96 19.91 10.46 -9.76 3.75 0.15 6030852.15 659839.45 N 70.49083277 W 148.69324156 2439.21 1.23 211.00 2382.68 2439.05 10.85 21.92 11.82 -11.50 2.74 0.04 6030850.38 659838.48 N 70.49082802 W 148.69324984 2535.92 1.33 208.35 2479.36 2535.73 12.88 24.08 13.48 -13.38 1.67 0.12 6030848.48 659837.45 N 70.49082289 W 148.69325856 2630.19 1.38 217.74 2573.61 2629.98 14.92 26.30 15.24 -15.24 0.46 0.24 6030846.60 659836.28 N 70.49081780 W 148.69326849 2725.51 1.45 216.66 2668.90 2725.27 17.02 28.66 17.14 -17.11 -0.96 0.08 6030844.69 659834.89 N 70.49081268 W 148.69328012 2818.85 2.62 199.38 2762.18 2818.55 20.18 31.95 20.21 -20.07 -2.38 1.40 6030841 .70 659833.55 N 70.49080460 W 148.69329167 2913.09 6.42 183.45 2856.11 2912.48 27.54 39.33 27.58 -27.37 -3.41 4.21 6030834.39 659832.67 N 70.49078467 W 148.69330011 3007.90 7.94 182.41 2950.18 3006.55 39.30 51.18 39.40 -39.20 -4.00 1.61 6030822.55 659832.33 N 70.49075234 W 148.69. 3101.16 9.30 187.10 3042.38 3098.75 53.21 65.15 53.37 -53.11 -5.21 1.64 6030808.61 659831 .43 N 70.49071433 W 148.69 3133.57 9.45 188.03 3074.36 3130.73 58.48 70.43 58.64 -58.35 -5.90 0.66 6030803.36 659830.84 N 70.49070003 W 148.69332048 3247.52 10.45 189.11 3186.59 3242.96 78.17 90.12 78.31 -77.81 -8.84 0.89 6030783.84 659828.32 N 70.49064685 W 148.69334453 3342.20 11.13 189.40 3279.60 3335.97 95.89 107.85 96.02 -95.31 -11.70 0.72 6030766.29 659825.85 N 70.49059906 W 148.69336784 3435.59 11.90 187.59 3371.11 3427.48 114.52 126.49 114.66 -113.75 -14.44 0.91 6030747.80 659823.50 N 70.49054869 W 148.69339027 3529.65 12.12 186.61 3463.11 3519.48 134.07 146.06 134.23 -133.17 -16.86 0.32 6030728.33 659821.50 N 70.49049563 W 148.69341003 3624.53 11.46 188.18 3555.99 3612.36 153.43 165.44 153.61 -152.39 -19.35 0.77 6030709.06 659819.43 N 70.49044312 W 148.69343037 3719.65 10.56 189.53 3649.36 3705.73 171.59 183.61 171.77 -170.34 -22.13 0.98 6030691.06 659817.02 N 70.49039408 W 148.69345315 3815.32 9.80 192.29 3743.52 3799.89 188.50 200.51 188.65 -186.94 -25.32 0.94 6030674.39 659814.20 N 70.49034873 W 148.69347918 3911.41 10.00 192.03 3838.18 3894.55 205.01 217.03 205.12 -203.09 -28.80 0.21 6030658.17 659811.07 N 70.49030461 W 148.69350762 4005.28 10.44 192.06 3930.56 3986.93 221.65 233.69 221.74 -219.38 -32.27 0.47 6030641.81 659807.94 N 70.49026011 W 148.69353603 4101.82 10.67 190.10 4025.47 4081.84 239.33 251.37 239.40 -236.73 -35.67 0.44 6030624.39 659804.92 N 70.49021270 W 148.69356378 4195.72 10.75 186.81 4117.73 4174.10 256.77 268.82 256.85 -253.99 -38.23 0.66 6030607.09 659802.73 N 70.49016557 W 148.69358473 4291 .48 10.69 184.29 4211.82 4268.19 274.52 286.63 274.63 -271.71 -39.95 0.49 6030589.33 659801.39 N 70.49011715 W 148.69359882 4385.69 9.36 186.29 4304.59 4360.96 290.86 303.03 291.01 -288.04 -41.45 1.46 6030572.98 659800.25 N 70.49007254 W 148.69361102 4481.71 8.80 189.07 4399.41 4455.78 306.00 318.18 306.15 -303.05 -43.46 0.74 6030557.92 659798.56 N 70.49003152 W 148.69362747 4575.19 9.01 188.81 4491.76 4548.13 320.46 332.65 320.62 -317.35 -45.71 0.23 6030543.58 659796.62 N 70.48999247 W 148.6.5 4669.99 9.34 189.26 4585.35 4641.72 335.58 347.76 335.74 -332.28 -48.08 0.36 6030528.61 659794.56 N 70.48995169 W 148.6 6 4763.91 9.57 188.62 4677.99 4734.36 351.00 363.19 351.17 -347.52 -50.48 0.27 6030513.32 659792.49 N 70.48991005 W 148.6 85 4867.69 11.56 191.69 4780.01 4836.38 370.02 382.21 370.17 -366.23 -53.88 1.99 6030494.54 659789.50 N 70.48985893 W 148.69371264 4953.25 15.46 194.88 4863.19 4919.56 389.96 402.19 390.08 -385.66 -58.55 4.64 6030475.02 659785.25 N 70.48980587 W 148.69375079 5047.25 18.21 195.68 4953.15 5009.52 417.07 429.41 417.12 -411.91 -65.74 2.94 6030448.62 659778.63 N 70.48973414 W 148.69380954 5142.27 20.72 196.81 5042.73 5099.10 448.54 461.07 448.55 -442.30 -74.61 2.67 6030418.05 659770.41 N 70.48965112 W 148.69388208 5238.45 22.43 197.43 5132.17 5188.54 483.63 496.44 483.63 -476.10 -85.03 1.79 6030384.04 659760.72 N 70.48955879 W 148.69396722 5329.78 23.33 196.28 5216.31 5272.68 518.88 531.95 518.91 -510.08 -95.32 1.10 6030349.84 659751.17 N 70.48946595 W 148.69405132 5425.44 24.66 195.21 5303.70 5360.07 557.59 570.85 557.66 -547.52 -105.86 1.46 6030312.19 659741.43 N 70.48936367 W 148.69413751 5519.93 26.30 192.57 5389.00 5445.37 598.14 611.49 598.25 -586.98 -115.59 2.11 6030272.53 659732.55 N 70.48925588 W 148.69421702 5614.17 27.79 190.84 5472.94 5529.31 640.96 654.33 641.10 -628.94 -124.27 1.79 6030230.40 659724.78 N 70.48914125 W 148.69428793 5707.62 30.50 190.90 5554.55 5610.92 686.47 699.84 686.60 -673.63 -132.85 2.90 6030185.54 659717.16 N 70.48901916 W 148.69435807 5802.98 32.75 190.09 5635.74 5692.11 736.46 749.84 736..60 -722.79 -141.95 2.40 6030136.20 659709.12 N 70.48888485 W 148.69443241 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05P!31 \NS05PB 1 Generated 5/12/2005 5:24 PM Page 2 of 4 Comments Latitude Longitude N 70.48874212 W 148.69450808 5992.22 36.90 189.61 5791.1 0 5847.47 844.45 857.83 844.57 -829.16 -160.56 2.25 6030029.46 659692.80 N 70.48859426 W 148.69458452 6086.39 39.18 189.92 5865.26 5921.63 902.47 915.85 902.58 -886.35 -170.40 2.43 6029972.08 659684.19 N 70.48843804 W 148.69466497 6179.30 40.53 189.17 5936.58 5992.95 962.01 975.39 962.10 -945.06 -180.27 1.54 6029913.17 659675.59 N 70.48827764 W 148.69474561 6273.93 41.31 189.39 6008.09 6064.46 1023.99 1037.37 1024.06 -1006.23 -190.27 0.84 6029851.80 659666.91 N 70.48811053 W 148.69482729 6368.65 41.69 188.75 6079.03 6135.40 1086.74 1100.14 1086.80 -1068.21 -200.16 0.60 6029789.63 659658.35 N 70.48794121 W 148.69490813 6462.24 42.01 188.62 6148.74 6205.11 1149.17 1162.58 1149.21 -1129.94 -209.59 0.35 6029727.72 659650.25 N 70.48777259 W 148.69498518 6556.11 42.63 189.02 6218.15 6274.52 1212.35 1225.78 1212.38 -1192.39 -219.28 0.72 6029665.08 659641.91 N 70.48760197 W 148.69506437 6649.90 43.25 188.65 6286.81 6343.18 1276.23 1289.67 1276.25 -1255.52 -229.09 0.71 6029601.76 659633.45 N 70.48742950 W 148.69514454 6743.95 43.98 188.02 6354.90 6411.27 1341.08 1354.55 1341.09 -1319.71 -238.50 0.90 6029537.38 659625.43 N 70.48725414 W 148.69522137 6839.45 44.90 187.63 6423.08 6479.45 1407.89 1421.41 1407.90 -1385.95 -247.60 1.00 6029470.96 659617.76 N 70.48707317 W 148.69.3 6934.32 45.45 187.37 6489.96 6546.33 1475.12 1488.70 1475.12 -1452.67 -256.38 0.61 6029404.08 659610.41 N 70.48689092 W 148.695 49 7028.37 46.49 187.42 6555.33 6611.70 1542.67 1556.32 1542.67 -1519.72 -265.08 1.11 6029336.86 659603.15 N 70.48670773 W 148.69543859 7123.62 49.90 189.08 6618.82 6675.19 1613.62 1627.31 1613.63 -1589.97 -275.30 3.81 6029266.42 659594.45 N 70.48651583 W 148.69552204 7217.65 52.91 189.88 6677.47 6733.84 1687.10 1700.79 1687.11 -1662.45 -287.41 3.27 6029193.70 659583.90 N 70.48631783 W 148.69562101 7313.05 54.71 189.54 6733.80 6790.17 1764.09 1777.78 1764.10 -1738.34 -300.39 1.91 6029117.56 659572.55 N 70.48611051 W 148.69572708 7408.99 54.93 189.55 6789.07 6845.44 1842.50 1856.20 1842.51 -1815.67 -313.39 0.23 6029039.97 659561.22 N 70.48589925 W 148.69583332 7503.39 55.33 189.66 6843.04 6899.41 1919.95 1933.65 1919.96 -1892.03 -326.32 0.43 6028963.35 659549.94 N 70.48569063 W 148.69593890 7597.57 55.67 189.78 6896.38 6952.75 1997.56 2011.26 1997.58 -1968.53 -339.42 0.38 6028886.59 659538.48 N 70.48548164 W 148.69604596 7692.63 55.89 190.16 6949.84 7006.21 2076.17 2089.87 2076.18 -2045.95 -353.03 0.40 6028808.91 659526.54 N 70.48527015 W 148.69615714 7784.74 55.79 190.09 7001.56 7057.93 2152.39 2166.08 2152.40 -2120.98 -366.43 0.13 6028733.61 659514.76 N 70.48506517 W 148.69626660 7878.92 55.67 189.85 7054.60 7110.97 2230.22 2243.91 2230.23 -2197.63 -379.91 0.25 6028656.69 659502.94 N 70.48485576 W 148.69637669 7974.09 55.53 190.10 7108.36 7164.73 2308.74 2322.44 2308.76 -2274.97 -393.51 0.26 6028579.08 659491.00 N 70.48464448 W 148.69648780 8068.77 55.43 190.15 7162.02 7218.39 2386.75 2400.45 2386.76 -2351.77 -407.22 0.11 6028502.01 659478.94 N 70.48443468 W 148.69659983 8164.47 55.33 190.22 7216.39 7272.76 2465.51 2479.20 2465.52 -2429.28 -421.15 0.12 6028424.22 659466.69 N 70.48422292 W 148.69671359 8260.20 55.24 190.34 7270.91 7327.28 2544.19 2557.89 2544.20 -2506.71 -435.19 0.14 6028346.52 659454.31 N 70.48401140 W 148.69682830 8355.69 55.21 190.Q7 7325.37 7381.74 2622.63 2636.33 2622.64 -2583.90 -449.09 0.23 6028269.05 659442.08 N 70.48380051 W 148.69694182 8450.18 54.95 190.39 7379.46 7435.83 2700.11 2713.81 2700.11 -2660.15 -462.85 0.39 6028192.53 659429.96 N 70.48359222 W 148.6.1 8545.03 54.81 190.08 7434.03 7490.40 2777.69 2791.39 2777.69 -2736.50 -476.63 0.31 6028115.91 659417.82 N 70.48338365 W 148.6 1 8640.04 54.69 190.33 7488.86 7545.23 2855.28 2868.98 2855.28 -2812.86 -490.38 0.25 6028039.28 659405.72 N 70.48317503 W 148.6 09 8733.74 54.51 190.10 7543.14 7599.51 2931.65 2945.36 2931.66 -2888.02 -503.92 0.28 6027963.84 659393.80 N 70.48296969 W 148.69738973 8827.86 54.52 190.29 7597.77 7654.14 3008.29 3021.99 3008.30 -2963.45 -517.49 0.16 6027888.15 659381.86 N 70.48276362 W 148.69750052 8923.49 54.64 190.03 7653.20 7709.57 3086.22 3099.93 3086.23 -3040.16 -531.23 0.25 6027811.16 659369.76 N 70.48255406 W 148.69761280 9017.25 54.65 190.01 7707.45 7763.82 3162.69 3176.39 3162.70 -3115.46 -544.54 0.02 6027735.60 659358.08 N 70.48234834 W 148.69772146 9110.99 54.77 189.50 7761.61 7817.98 3239.20 3252.91 32~9.21 -3190.87 -557.50 0.46 6027659.93 659346.74 N 70.48214233 W 148.69782734 9206.04 54.87 188.92 7816.37 7872.74 3316.88 3330.60 33.16.89 -3267.56 -569.94 0.51 6027583.00 659335.96 N 70.48193283 W 148.69792888 9301.87 55.02 189.11 7871.41 7927.78 3395.32 3409.04 3395.33 -3345.04 -582.23 0.23 6027505.29 659325.34 N 70.48172117 W 148.69802927 9395.84 55.17 188.51 7925.18 7981.55 3472.37 3486.11 3472.38 -3421.19 -594.03 0.55 6027428.90 659315.18 N 70.48151312 W 148.69812565 9490.86 55.25 188.52 7979.40 8035.77 3550.38 3564.14 3550.39 -3498.37 -605.59 0.08 6027351.50 659305.28 N 70.48130229 W 148.69822000 9584.60 55.28 188.58 8032.81 8089.18 3627.39 3641.18 3627.41 -3574.55 -617.04 0.06 6027275.10 659295.47 N 70.48109418 W 148.69831352 9678.51 55.39 188.66 8086.22 8142.59 3704.60 3718.42 3704.64 -3650.91 -628.62 0.14 6027198.51 659285.54 N 70.48088555 W 148.69840805 SurveyEditor Ver Bld( doc40x_37 ) NS051NS051NS05PB1 INS05PB 1 Generated 5/12/2005 5:24 PM Page 3 of 4 latitude longitude . Com ments 9772.81 55.47 188.60 8139.73 8196.10 3782.23 3796.07 3782.27 -3727.68 -640.27 0.10 6027121.51 659275.54 N 70.48067582 W 148.69850319 9866.24 55.31 188.92 8192.80 8249.17 3859.11 3872.96 3859.16 -3803.68 -651.98 0.33 6027045.28 659265.47 N 70.48046819 W 148.69859881 9961.67 55.26 188.73 8247.14 8303.51 3937.53 3951.41 3937.59 -3881.20 -664.01 0.17 6026967.53 659255.10 N 70.48025643 W 148.69869708 10055.24 55.09 188.84 8300.58 8356.95 4014.33 4028.22 4014.39 -3957.11 -675.74 0.21 6026891.39 659245.01 N 70.48004905 W 148.69879286 10150.61 54.91 188.94 8355.28 8411.65 4092.44 4106.34 4092.51 -4034.29 -687.82 0.21 6026813.97 659234.60 N 70.47983819 W 148.69889143 10245.23 54.78 189.70 8409.76 8466.13 4169.79 4183.70 4169.86 -4110.63 -700.35 0.67 6026737.39 659223.71 N 70.47962964 W 148.69899372 10340.85 53.80 190.32 8465.58 8521.95 4247.43 4261.34 4247.50 -4187.09 -713.84 1.15 6026660.66 659211.87 N 70.47942076 W 148.69910389 10434.73 53.68 190.63 8521.10 8577.47 4323.13 4337.04 4323.19 -4261.53 -727.60 0.30 6026585.95 659199.71 N 70.47921741 W 148.69921626 10530.82 54.64 190.88 8577.36 8633.73 4401.02 4414.94 4401.08 -4338.05 -742.14 1.02 6026509.13 659186.82 N 70.47900834 W 148.69933496 10625.39 55.65 190.83 8631.41 8687.78 4478.61 4492.54 4478.66 -4414.27 -756.75 1.07 6026432.63 659173.85 N 70.47880013 W 148.69945428 10721.91 56.03 190.96 8685.61 8741.98 4558.47 4572.41 4558.52 -4492.70 -771.85 0.41 6026353.90 659160.45 N 70.47858587 W 148.69_ 10815.05 55.50 190.52 8738.01 8794.38 4635.46 4649.41 4635.51 -4568.35 -786.20 0.69 6026277.96 659147.73 N 70.47837919 W 148.699 0 10910.48 55.09 190.68 8792.34 8848.71 4713.91 4727.86 4713.95 -4645.46 -800.63 0.45 6026200.56 659134.96 N 70.47816852 W 148.69981252 11004.89 54.64 190.68 8846.67 8903.04 4791.11 4805.07 4791.15 -4721.33 -814.94 0.48 6026124.41 659122.28 N 70.47796125 W 148.69992934 11099.94 54.85 191.06 8901.54 8957.91 4868.72 4882.69 4868.75 -4797.56 -829.58 0.39 6026047.89 659109.29 N 70.47775301 W 148.70004884 11195.05 55.75 191.22 8955.68 9012.05 4946.90 4960.88 4946.92 -4874.28 -844.68 0.96 6025970.87 659095.83 N 70.47754342 W 148.70017218 11289.35 56.45 191.35 9008.27 9064.64 5025.15 5039.15 5025.17 -4951.03 -860.00 0.75 6025893.81 659082.17 N 70.47733373 W 148.70029723 11384.86 56.95 190.75 9060.71 9117.08 5104.96 5118.98 5104.98 -5029.38 -875.30 0.74 6025815.15 651:1068.56 N 70.47711969 W 148.70042212 11480.91 57.46 190.86 9112.74 9169.11 5185.70 5199.72 5185.71 -5108.69 -890.44 0.54 6025735.54 659055.13 N 70.47690302 W 148.70054569 11576.84 56.16 190.13 9165.25 9221.62 5265.97 5280.00 5265.98 -5187.62 -905.06 1.50 6025656.32 659042.21 N 70.47668738 W 148.70066508 11669.24 53.58 189.30 9218.42 9274.79 5341.53 5355.56 5341.54 -5262.10 -917.82 2.89 6025581.59 659031.05 N 70.47648391 W 148.70076923 11765.31 50.81 188.26 9277.30 9333.67 5417.41 5431.46 5417.43 -5337.10 -929.42 3.01 6025506.36 659021.07 N 70.47627901 W 148.70086388 11861.52 48.13 187.39 9339.82 9396.19 5490.48 5504.57 5490.50 -5409.54 -939.38 2.87 6025433.73 659012.67 N 70.47608112 W 148.70094521 Last MWD+IFR+MS 11931.00 46.04 187.08 9387.12 9443.49 5541.30 5555.46 5541.33 -5460.02 -945.80 3.03 6025383.13 659007.34 N 70.47594322 W 148.70099752 TO ( Projected) 11993.00 46.04 187.08 9430.16 9486.53 5585.87 5600.08 5585.91 -5504.30 -951.30 0.00 6025338.74 659002.80 N 70.47582223 W 148.70104240 Survey Type: Definitive Survey NOTES: GVD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing. . Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leaal Description: Northina IV) [ftUSl EastihCl IX) [flUSl Surface: 1089 FSL 641 FEL S11 T13N R13E UM 6030861.82 659835.49 BHL: 865 FSL 1597 FEL S14 T13N R13E UM 6025338.74 659002.80 SurveyEditor Ver Bld( doc40x_37 ) NS05\NS05\NS05PB 1 \NS05PB 1 Generated 5/12/2005 5:24 PM Page 4 of 4 . '205 ~ ooq . Winton, As per our conversation, the lead cement for the 9 5/8" casing will be changed from a 12.5 ppg slurry (yield 2.08 cufUsack) to an 11.3 ppg slurry (yield 3.25 cufUsack). This is to insure that the Schrader Bluff formation does not break down while cementing. The 11.3 ppg slurry has been used in the past on Northstar wells. The cement will be designed to bring the top of cement to ± 8400'TVD (+1- 430 BBLS of lead) The cement volume in sacks will change from 1130 to 750 sxs due to the difference in yield for the cement slurries. Thank you Dave Johnson Content-Type: application/ms-tnef Content-Encoding: base64 . ~1T!Æ1rŒ fID~ !Æ~1Al~~ . A"~ASHA OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Pulchorage,AJe 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar NS-05 BP Exploration (Alaska), Inc. Permit No: 205-009 Surface Location: 1089' NSL, 641' WEL, See, 11. T13N, R13E, UM Bottomhole Location: 92' NSL, 1754' WEL, Sec. 14, T13N, R13E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. eas provide at least twenty-four (24) hours notice for a representative of the Commissi to wit ess any required test. Contact the Commission's petroleum field inspector at (907 -36 ager). DATED this I q day of January, 2005 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. . . STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 MC 25.005 / 1AJ4A- I ( I f I µ"~$ EIVED 1 ii 2005 {jtÞ¥e~GÛ6.dJßPliTÍðøíaf( 1a. Type of work BDrill o Redrill rb. Current Well Class 0 Exploratory B Development Oil !::::! ~ one ORe-Entry o Stratigraphic Test 0 Service 0 Development Gas 0 Sin¡jl~ Zone 2. Operator f'Jame: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 NS05 ./ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14055 TVD 11336 Northstar Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 312808 1089' NSL, 641'WEL, SEC. 11, T13N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 02/09/05 ./ 203' NSL, 1735' WEL, SEC. 14, T13N, R13E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 92' NSL, 1754' WEL, SEC. 14, T13N, R13E, UM 3433 2860' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 659835 y-6030861 Zone- ASP4 (Height above GL): 55.80' feet 4300' away from NS 19 16. Deviated Wells: Kickoff Depth: 2750' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 55.07 dearees Downhole: 5318 Surface: 3964 1 ¡S,casing program: Specifications Setting [)èpth , Size Top .> Bottom . (C.f. oFsacks) .i Hole Casina Weiaht Grade CouDlina Lenç¡th MD TVD MD TVD (includinç¡ staae data) 20" 20" 169# X-56 Welded 200' Surface Surface 200' 200' Driven 16" 13-3/8" 68# L-80 BTC 3209' Surface Surface 3209' 32060/ 1460 sx PF 'L', 322 sx Class 'G' /' 12-1/4" 9-518" 53.5# L-80 BTC-M 12016' Surface Surface 12016' 9486' 1188 sx Extended, 670 sx 'G' /c 8-12" 7" 29# L-80 Hydril511 1757' 11866' 9389' 13623' 10916' 326 sx Class 'G' /' 6" 4-1/2" 12.6# 13CR-80 Yam Ace 582' 13473' 10769' 14055' 11336' 65 sx Class 'G' ¡I' 19. PRESENT WELL CONDITION SUMMARY (To be completed fO!" Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): ..... iLérimh······ ·F. 5~Ø F .. ........ FNi....) ,-) M,ªF .iTVO···· CondlJr.tor ~llrf::O""A Int Production I inAr Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot 181 Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report o Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Johnson, 564-4171 Printed Name Pat Archey Title Senior Drilling Engineer Siç¡nature ¡:5. Cb-r ..1~.// I/tV05 Prepared By Name/Number: Phone 564-5803 Date Sondra Stewman, 564-4750 ~/ iN .... ... i, .)i.·.....)F.... ~. i.. F. .. . .i. i Permit To Drill J API Number: 9 Permit APpr~al. ~ .-- I ~ee cover letter for Number: 2D .ç - 00' 50- 02.. t:; _. 2.B ~ '71 Date: I If ps. other requirements Cond;tions ot Appm':.:J:] Requi'ed . [] Yes ÄNo Mud Log Required D Yes ~No rogE" Sulfide Measures ~Yes D No Directional Survey Required .;E'Yes D No Othe' T:e>i.}.Op. ~ HOD p,i, . . Y'<'J ì.4)-'-k ~ ~i t.1../ cu 1I" J. rcY»:S Odtz) J rt"·ýt,,, . t<,. Annmve . . h'/i APPROVED BY 1- /9" ðS' . ~ r ! THE COMMISSION Date Form 10-401 ~d~ , L Submit In Duplicate - . . bp ... ,\It.'II, --,~ ~..- ~..- ~..- .,~ -F'" ·'.'~i\· ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: January 12, 2005 From: David Johnson Northstar ODE Subject: NS05 Application for Drilling Permit Mr. Aubert, Well NS05 is currently scheduled for Nabors 33E on Februaury 5,2005. / A Diverter waiver is also requested on NS05. To date, BP has successfully drilled twenty-three development * wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Twenty-three surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (-150' TVD below the top of the SV6), with one well extending into the SV5 -3280' / TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Mud-gas monitoring equipment will be rigged up for the entire well and the well logged with LWD tools as per the drilling program enclosed. NS05 parallels the direction of the NS10 disposal well. The directional program is designed to avoid the Area ,/ of Review of NS 10 and NS05 will not penetrate that area. Please find attached the NS05 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-4171. avid A Johnson BP Northstar ODE 564-4171 work 632-5806 cell NS05 Permit to Dt . Pre-Ri2 Work: 1. The 20" conductor with an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead has been installed along with a 7' x 7' cellar. Ri2 Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested -k 3. MU 16" drilling assembly with MWD/GR and direction ally drill surface hole to +1-150' TVD below the top of the SV6 marker at approximately 3057' MD (-3056' tvd rkb). Surface casing point has been picked at 3209' MD (-3206' tvd rkb). POOH. /' 4. Run 13-3/8",68# surface casing. Cement the casing to surface ~ge. /C 5. NU casing I multi-bowl wellhead. NU BOPE and test to 250/~si (Hydril3500 psi). 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3400 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT /' to a minimum of 12.5 ppg EMW. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to the 9-5/8" casing point (approximately 12016' MD) at the top of the Miluveach. Minimum mud weight of 9.8 ppg at the top of HRZ and a minimum of 10.0 ppg at the top of Kuparuk. POOH. 9. 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 a down-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 WOe. 10. MJðW-. . 8 1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to fJJR! psi with 10.3 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 11. Drill out remaining cement and weight up to a minimum of 12.3 ppg MW. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a minimum of 14.5 ppg EMW, (FIT/LOT procedure on file with AOGCC). 12. 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 13581' MD (10876 TVD RKB). The Intermediate casing point has been picked at.J-l36:ì1" MD. POOH. ì3 ~ Z. 1. l~ 4J\-=- 13. Run and cement a 7" 29# Hydril 511 drilling liner. Displace cement with mud. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 14. POOH and lay down liner running tools. Test 95/8" x 7" casing to 3600 with 12.3 ppg fluid. ,/ This test pressure may change based on the actual mud weight in the hole. 15. Rill wi 6" directional assembly. Clean out the 7" 29# liner to the landing collar. Displace the wellbore to 9.1 ppg mud. 16. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1 ppg MW. Perform a FIT to 11.5 ppg. EMW (FIT/LOT procedure on file with AOGCC). 17. Drill 6" production interval to the proposed TD at 14055' MD. Condition mud weight to 9.3 ,,/ ppg prior to POOH. / 1/1212005 Page 1 of 10 NS05 Permit to D! . 18. Run and cement the 4-112" 12.6# 13 CR-80 liner with a 2 7/8" inner string. 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. 19. Once a successful cement job is obtained, pressure test liner lap to 1500 psi with 9.3 ppg mud .r- to confirm pressure integrity. 20. Change well over to clean seawater through the inner string (less than 80 NTD's) and by using spacers as per MI recommendation. 21. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 22. POOH and lay down liner running tool and inner string. / 23. Close blind rams and test 9 5/8" casing x 7" drilling liner x 4 'i2" liner to 4000 psi for 30 / minutes. This liner lap test assumes a 15.5 ppg LOT at 7" shoe 00916' TVDrkb) + 500 psi. 24. Run and land the 4-112" 12.6# 13-CR80 Yam Ace tubing string with fiber optics..¿ís per completion diagram. Pressure test the control lines and tubing hanger seals to 5000 psi. 25. Set 7" X 4 Yz" packer. Test tubing and annulus to 4200 psi. Open shear valve in gas lift mandrel. 26. Freeze protect the tubing and annulus to 3000' TMD/TVD 27. 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. 28. Test the tubing head adapter and tree to 5000 psi. Pull TWC valve and install BPV. 29. Ensure all tree and annulus valves are secured. RD and move off well. Post-Rie: Work: 1. Tie-in and FCO. 2. MIRV slickline. Pull the dummy SCSSSV, and ball and rod / RHC sub from 'RN' nipple below the new production packer. 3. Perforate -200' Ivishak formation. 4. Record initial BHP survey. 5. Install 4 Yz" SCSSSV. / 1/1212005 Page 2 of 10 NS05 Permit to D! . General Information 1 Type of Well (producer or injector): 1 Preproduced Injector Northstar Slot: NS05 Surface Location: 1089' FSL, 641' FEL, Sec. 11, T13N, R13E, UM (' X = 659,835.49 Y = 6,030,861.80 AOR Target 1 708 FSL, 709 FEL, See 11, T13N, R13E, UM 200' Radius X = 659,776.00 Y = 6,030,480.00 4,896.00 TVDrkb AOR Target 1 4928 FSL, 897 FEL, See 14, T13N, R13E, UM 200' Radius X = 659,612.00 Y = 6,029,416.00 6496.00 TVDrkb Target (Top of SAG): 203 FSL, 1735 FEL, Sec. 14, T13N, R13E, UM 400' Radius X= 658880.00 Y= 6,024,675.00 10876.00 TVDrkb Bottom Hole Location: 92 FSL, 1754 FEL, Sec. 14, T13N, R13E, UM /' X = 658,862.74 Y = 6,024,563.06 11336 TVDrkb 1 AFE Number: 1 1 Rig: 1 Nabors 33E / I Estimated Start Date: 12/9/2005 / . 1 I Operating days to complete: 130.2 fMD=l ]4055 I TVDrkb: 111336 1 I RKB/Surface Elevation: (a.m.s.l.) 155.80'1 15.67' I I Well Design (conventional, slimhole, et~ Modified Big Bore I I Objective: Ivishak Preproduced Injector Well Name: NS05 API Number: BHP: 5192psi @ 11,100' TVDss EMW: 8.95 ppg BHT: 254 of @ ]],100' TVDss / Land Use Permit: LO- N96-006 Distance to Nearest Property: 2860 ft Distance to Nearest Well within Pool: 4300' to NS 19. MECHANICAL CONDITION: Cellar box: Elevation above MSL = 15.67' RKB to Cellar box: 40.13' (Estimated) Rig Elevation: RKB + MSL = 55.8' Conductor: 200' MDrkb of 20", 169#, X-56 (pre-driven) 1/]212005 Page 3 of 10 NS05 Permit to D! . General Information Formation Estimated Depths Pore Press. Top (TVDss) TVDrkb MDrkb (Psi) (ppg EMW) Top Permafrost 1,149 1,205 1205 542 8.65 Base Permafrost 1,519 1,575 1575 708 8.65 SV6 - top confining zone 3,000 3,056 3057 1375 8.65 Surface casing point 3,150 3,206 3209 1442 8.65 SV5 - base confining zone 3,290 3,346 3352 SV4 3,580 3,636 3648 1635' 8.65 SV2 - top upper injection zone 3,995 4,051 4071 1822_ 8.65 SV1 - top major shale barrier 4,395 4,451 4480 2002· 8.65 TMBK - top lower injection zone - Top Ugnu 4,740 4,796 4832 21ST 8.65 AOR Target 1 4840 4896 4934 WS1 - top Schrader Bluff - Base Ugnu 6,280 6,336 6676 2850 8.65 AOR Target 2 6440 6496 6890 CM3 - Base lower injection zone (top Colville) 6,900 6,956 7622 3129· 8.65 THRZ - Top HRZ 8,600 8,656 10591 3893 8.65 BHRZ - Base HRZ 8,680 8,736 10731 3929 8.65 Top Kuparuk 8,830 8,886 10993 4265 9.29 Kuparuk C 9,080 9,136 11429 4428 9.38 Top Miluveach 9,380 9,436 11941 Intermediate casing point 9,430 9,486 12016 Intermediate logging point 9,430 9,486 12016 Top Kingak 9,960 10,016 12685 Fault #8 - throw = 150 feet 10,460 10,516 13216 Top Sag River 10,820 10,876 13581 Geol target #1 10,820 10,876 13581 Intermediate casing point 10,860 10,916 13622 5080 8.95 Top Shublik - 90 10,910 10,966 13673 5080 8.95 Top Ivishak 10,990 11,046 13755 Oil- Water contact 11,100 11,156 13869 5192 8.95 Total Depth 11,280 11,336 14055 5276 8.95 ~.~ t I (). -r, f 12. " ¿ 1·) ~ ./ Notes: 1. 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 NS17 through this interval - max gas = 70 units 2. Depth predictions based on NS13, NS14, NS27, Seal A-1, NS29, Seal A-3 wells and comparison to 3D seismic volume. 3. Pore pressures estimated using data from offset wells. Details found in Section (8) of this SOR. 1/1212005 Page 4 of 10 NS05 Permit to D! . General Information CASINGITUBING PROGRAM: Casing String Hole Casing Description Measured Depth Vertical Depth Length Size Top Bottom Top Bottom Feet 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 3209 Surface 3206 3209 Intermediate Csg 121/4 9-5/8" 53.5# L-80 BTC-M Surface 12016 Surface 9486 12016 Intermediate Liner 81/2 7" 29.0# L-80 Hydril 511 11866 13623 9389 10916 1757 Production Liner 6 4-1/2" 12.6# 13-CR80 Vam Ace 13473 14055 10769 11 336 582 Tubing - 4-1/2" 12.6# 13-CR80 Vam Ace Su rface 13473 Surface 10769' 13473 /' Formation Inteeritv Testine: Test Point Depth Shoe Test T FIT FIT FIT N/A EMW / 13 3/8" Surface Casin 9 5/8" Intermediate Casin 7" Intermediate Liner 4 Y2" Production Liner 20' min below shoe 20' min below shoe 20' min from 7" shoe N/A MUD PROGRAM SUMMARY: S f HIM dP S S dM d 16" HIS ur ace oe u ropertIes: eawater ¡PU u oe ectlOn From Surface to -3209' MD I 3206' TVD -150' TVD below top SV6). Interval Density Viscosity YP Gel API FL pH (ppq) (seconds) 10 sec Initial to base PF *8.8 - 9.3 100 - 200 50 - 70 25 - 40 15 - 20 8.5 - 9.5 Base PF to the top of SV *9.0 - 9.3 1 00 - 1 50 30 - 45 15 - 25 6 -10 8.5 - 9.5 sands SV6 @ Interval TD *9.3 max 75 - 125 20 - 35 10 - 25 6 -10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. I t d' HIM d P S P 1 Md 12 114" HIS t n erme late oe u ropertIes: eawater o ymer u - oe ec Ion From Surface Casing Shoe into the Top of the Miluveach (-12016' MD I 9486' TVD). Interval Density (ppg) PV YP APII HTTP FL pH Initial 8.7 - 9.3 10 - 16 20 - 30 6 -10 8.5 - 9.5 Top HRZ 10.1 -10.3 10 -16 20 - 25 4-6 I <12 8.5 - 9.5 Top Kuparuk to Miluveach 10.1 -10.3 10 -18 20 - 28 4-61<12 8.5 - 9.5 1/1212005 Page 5 of 10 . NS05 Permit to Drill . General Information Drillin Liner Hole Mud Pro erties: Inhibited KCL Mud From Intermediate Casing Shoe to 13623' MD / 10916' TVD (top of Sag) Interval Density (p PV YP Miluveach & Kingak to top of Sag 12.3 - 2. 25 - 30 20 - 30 8-112" Hole Section APIFL 4-6/<12 pH 8.5 - 9.5 P d f HIM dP f S t IC C03 D 11 I FI . d 6" HIS f ro uc IOn oe u roper les: eawa er a rI - n Ul oe ec Ion From Intermediate Casing Shoe to 14055' MD /11,336' TVD Interval Density (ppg) PV YP API/ HTTP FL pH Initial/Final 9.1 -9.3 8-12 20-25 3-5 8.5 - 9.5 DIRECTIONAL: KOP: 2750 TMDrrVD Build Rates 1 °/100' to 3°/100' Maximum Hole Angle: +55.07° Close Approach Wells: Surface- 10' well spacing to well NS06. All wells passed the major risk rule, however NS06 passed within 0.01' of the allowable tolerance. NS06 has been classified under the minor risk rule of 1 :200 which allows a clearance of 9.23'. / Gyro will be used for the initial survevs and kickoff. NSIO Area of Review NS05 is directionally designed to avoid the Area of Review for NS 10 disposal well. /' Survey Program: Gyros as required from surface to +1-1500'. MWD surveys will be run from 1500' to 2500' . IFR+MS corrected MWD surveys from +/- 2500' to TD. SURFACE AND ANTI-COLLISION ISSUES: Note: All wells passed the major risk well. NS06 has been re-classified under the minor risk rule to allow more clearance from tolerance lines. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 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 4800 psi. Maximum Surface Pressure - Full Column of Gas from TD - 0.12 psi/ft gradient Gradients - psi/ft Pressures 121,4" Intermediate Hole Section: TVD - ss Formation Gas BHP Surface 1.2 * Surface Kuparuk C 9,080 9.38 0.12 4429 3339 4007 8 W' Intermediate Hole Section: Sag River 10820 8.95 0.12 5036 3738 4486 6" Production Hole Section: Total Depth 11280 Jt3.9Š 0.12 5318 3964 / 4757 Planned BOP test pressure:4j BOO psi (annular to 3500 psi) Planned completion fluid: 8.5í )PQ Seawater / 6.8 ppg Diesel 1/12/2005 Page 6 of 10 NS05 Pennit to D! . General Information LOGGING PROGRAM: Well Evaluation 16" Surface Hole 121/4" Intermediate 9" Intermediate 6" Production Hole Program Hole Hole Interval - MDrkb depths From I TO From TO From I TO From I TO MWD/LWD Directional Surface 3,209 3,209 12,016 12,016 I 13,622 13,622 I 14055 Gamma Ray Surface 3,209 3,209 I 12,016 12,016 I 13,622 13,622 I 14055 Gyro Surface 3,209 None None None PWD None 3,209 I 12,016 12,016 I 13,622 None Resistivity - recorded mode None None None 13,622 I 14055 Resistivity - real time mode None 6,800 12,016 None None Density None 6,800 12,016 None 13,622 I 14055 Neutron None 6,800 12,016 None 13,622 I 14055 Form. pressure while drillino None None None Sonic ( ISONIC) None 6,800 I 12,016 None None Wireline Open Hole logs GR None Continoent None Continqent Resistivity ( HALS) None Continç¡ent None Continoent Neutron (HGNS) None Continqent None Contingent Density (HRMS) ** None Continqent None Continç¡ent Sonic None None None None FMI (4 arm caliper) ** None None None None CMR None None None None RFT None None None None MDT None None None None Cased Hole logging SCMT I CBL I USIT None None None 12,016 I 14055 SONIC - DSI ( P wave only None None None None needed) None None Mudloooino Gas Detection None None None None None None None None None None None None None None None None None None None None Comments Importance Wireline logs MWD I LWD logs Intermediate Hole 1: PWD Resistivity and LWD in real Low Do not re-run if unsuccessfull If tool fails - drill ahead time mode in the Intermediate hole #1 ; Intermediate Hole 1: MDT Re-run if unsuccessfull except if TBD contingency. Wireline Med conditioning trip required to run PEX log run contingent on casing failure of LWD loas Re-run if unsuccessfull, even if If unsuccessfull - POOH and Intermediate Hole II: High conditioning trip required. repair if possible. Willing to run Drillpipe conveyed logging not back in hole without tool required repaired Re-run if unsuccessfull, even if Production Hole: Cement V. High drill pipe conveyed logging bond log is required for this needed interval.Open hole wireline Re-run if unsuccessfull even if If unsuccessfull - POOH and logs run if MWD logs fail. Critical (Cr) sidetrack hole or DPC logging wait to fix before proceeding needed even if the rig remains idle 1/12/2005 Page 7 of 10 . NS05 Permit to Drill Reauired Materials: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: L-80 Liner: 13Cr Completion: 1/12/2005 3209' 1 - 13 3/8" 1 - 13 3/8" 1 - set 17 -13 3/8" xIS 3/4" 17 -13 3/8" xIS 3/4" 1 - 20" x 133/8" 1 - 13 5/8" 12016' 1 - 9 5/8" 1 - 9 5/8" 1 - set 1 - 13 5/8" x 9 5/8" 183 - 9 5/8" x 12" 183 - 95/8" x12" 1807' 1 - 8 Y2" 1-7" 7 - 7" x 8 114" 7 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1-7" 632' 1-4-1/2" 1 - 4-1/2" 30 - 4-1/2" x 5-3/4" 30 - 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1- 4-1/2" 13423' 1 1 1 1 1 1 1 1 1 2 1 . 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) HES Cement Plug Set SV Rigid Centralizers Stop Bands ABB- VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB- VGI Casing Headffbg head 95/8",53.5# L-80 BTC-MOD 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 7",29# L-80 Hydril511 BBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Stop Bands Baker Double-Grip Flex Lock Hydraulic Set Liner Hanger - Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2", 12.6# L-80 Yam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop Bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Yam Ace 4 Y2" ABB-VGI tubing hanger 4 Y2" ABB-VGI adapter flange 4 Y2" ABB-VGI 5-1/8" 5K Swab Valve wI tree cap CIDRA mandrel and 0.25" fiber optic cable (wI 4 Y2" cable clamps). 4 Y2" SVLN and 1 - 0.25" control lines 4 Y2" x 1 Y2" GLM with dummy valve installed 4 Y2" x 1 Y2" GLM with RP Shear valve installed 7" x 4 Y2" Baker 13 Cr packer S-3. 4 Y2" WLEG (Self-Aligning Mule Shoe) 4 Y2" 13 Cr X nipples 4 Y2" 13 Cr XN nipple Page 8 of 10 . NS05 Permit to Drill . PERMAFROST: The 13-3/8" surface casing will be run approximately 1631' TVD below the permafrost to -3209' MD / 3204' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and "Permafrost" 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. CEMENT CALCULATIONS: The followin cement calculations are based upon a single stage job with gauge hole. Casin 13-3/8" 68# BTC Surface Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 2506' of gauge open hole + 125% excess. Lead TOG: Surface / Tail: Based on 500' tvd (503' md) of 16" gauge open hole + 50% excess + 80' shoe joint. Tail TOG: -2706' MD . Total Cement I S acer Tail Hi' Casin Basis: -112" 12.6# L-80 Prod Liner tage 1: Slurry: Based on 433' of 6" open hole x 4 Y2 liner + 100% excess + 150' of 7" csg x 41/2" csg liner lap + 00' of 7" csg x 4" drillpipe aboye TaL + 5' shoe joint. Slurr TOG: At -13272' MD / tage 1: Total Spacer 5 bbl MudPush II Spacer Cement I S acer ) Slurry I §.~"'sk of 15.8 ppg Premium 'G'. cf7sk; 1/12/2005 Page 9 of 10 . . NS05 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 (1000 Ibs) Strength (1000 Ibs) Strength (psi) Strength (psi) 13-3/8" 68 L-80 BTC 12.415 12.295 Position 14.375 1556 1545 5024 2264 Intermediate Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID (in) Drift (in) Min/Max Coupling OD Strength (1000 Ibs) Strength (1000 Ibs) Strength (psi) Strength (psi) 9-5/8" 53.5 L-80 BTC-M 8.535 8.5 Position 10.625 1244 1268 7927 6617 Production Liner Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID (in) Drift (in) Min/Max Coupling OD Strength (1000 Ibs) S tren gth Strength S tren gth 7" 29 13CR-80 NSCC 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 Strength (1000 Ibs) Strength (1000 Ibs) Strength (psi) Strength (psi) 4.5" 12.6 13CR-80 V AM ACE 3.958 3.833 3600 4.964 288 288 8430 7500 1/1212005 Page 10 of 10 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 133/8", 68#/ft, L-80, BTC @ 320 4 1/2", 12.6#/ft, 13-Cr, Va TUBING ID: 3.958" CAPACITY: 0.01522 BB 9-5/8" 53.5# L-80 BTM-C @ 1 4.5" X NIPPLE, @ 134 3 4.5" X NIPPLE, @ 134 3 4.5" XN NIPPLE, @ 134 3 4.5" WLEG, @ 13 3 7", 29#/ft L-80, Hyd @ 13623' MD PBTD @ TD @ 14055 MD DATE 1/10/05 REV. BY DAJ NS05 - Proposed A 1/ - 6.8 .... AT ..4 ~ 9'MD m-Ace .. LIFT - ~- 2016' MD ... ~~ 4 3 23' MD I .813" 10 43' MD ~ ~ _7" .813" ID .:;..; 53' MD ~ . .725" ID 463' MD _I--i l- I~ .958" ID I'--' ril521 -... ... 14050' MD ..4 ~ COMMENTS ORIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.9' 2" SSSV @ 1000' TMD/TVD PPG DIESEL FREEZE PROTECTION +/- 3000' TVD (3000'MD) 41/2" GLM @ 4500' TVD (4539' MD) w/4.62" ID 7" LINER TOP @ 11866' MD .5" Fiber Optic Transducer .958" ID PACKER, 13 Cr @ 13433' MD 4.5" LINER TOP @ 13473' MD 4.5", 12.6#, 13Cr Vam Ace Northstar WELL: NS05 API NO: BP Exploration (Alaska) NS05 (P10) lumberuer Report Date: January 6, 2005 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 190.010° Field: Northstar 12/01 lOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF / NS05 APproved TVD Reference Datum: KB Well: NS05 TVD Reference Elevation: 56.00 ft relative to MSL Borehole: Plan NS05 Sea Bed / Ground Level Elevation: 15.67 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 24.968° Survey Name I Date: NS05 (P1 0) I January 6, 2005 Total Field Strength: 57643.122 nT Tort I AHD I DDII ERD ratio: 105.168° /6373.90 ft /5.920 I 0.562 Magnetic Dip: 80.977" Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 15, 2005 Location LaULong: N 70.49085943, W 148.69327224 Magnetic Declination Model: BGGM 2004 Location Grid NIE YIX: N 6030861.820 ftUS, E 659835.490 ftUS North Reference: True North Grid Convergence Angle: + 1.2317300r Total Corr Mag North -> True North: +24.968° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head . Comments RTE Top Perm Base Perm KOP Bid 111 00 Bid 3/100 2850.00 1.00 190.09 2793.99 2849.99 0.87 0.87 -0.86 -0.15 1.00 -169.91M 1.00 0.00 6030860.96 659835.36 N 70.49085708 W 148.69327349 2900.00 2.50 190.09 2843.97 2899.97 2.40 2.40 -2.36 -0.42 3.00 -169.91M 3.00 0.00 6030859.45 659835.12 N 70.49085297 W 148.69327567 3000.00 5.50 190.09 2943.72 2999.72 9.37 9.37 -9.23 -1.64 3.00 O.OOG 3.00 0.00 6030852.56 659834.05 N 70.49083421 W 148.69328566 SV6 3056.63 7.20 190.09 3000.00 3056.00 15.64 15.64 -15.40 -2.74 3.00 O.OOG 3.00 0.00 6030846.37 659833.08 N 70.49081737 W 148.69329463 3100.00 8.50 190.09 3042.96 3098.96 21.56 21.56 -21.23 -3.78 3.00 O.OOG 3.00 0.00 6030840.52 659832.17 N 70.49080144 W 148.69330311 3200.00 11.50 190.09 3141.43 3197.43 38.92 38.92 -38.32 -6.82 /3.00 O.OOG 3.00 0.00 6030823.36 659829.50 N 70.49075474 W 148.69332797 End Bid 3202.11 11.56 190.09 3143.50 3199.50 39.34 39.34 -38.74 -6.89 3.00 O.OOG 3.00 0.00 6030822.95 659829.43 N 70.49075360 W 148.693. 13-3/8" Csg PI 3208.75 11.56 190.09 3150.00 3206.00 40.68 40.68 -40.05 -7.12 0.00 O.OOG 0.00 0.00 6030821.63 659829.23 N 70.49075003 W 148.693 SV5 3351.65 11.56 190.09 3290.00 3346.00 69.32 69.32 -68.25 -12.14 0.00 O.OOG 0.00 0.00 6030793.33 659824.82 N 70.49067298 W 148.693 SV4 3647.66 11.56 190.09 3580.00 3636.00 128.65 128.65 -126.67 -22.53 0.00 O.OOG 0.00 0.00 6030734.71 659815.68 N 70.49051339 W 148.69345644 SV2 4071.25 11.56 190.09 3995.00 4051.00 213.56 213.56 -210.26 -37.41 0.00 O.OOG 0.00 0.00 6030650.82 659802.61 N 70.49028502 W 148.69357800 SV1 4479.54 11.56 190.09 4395.00 4451.00 295.41 295.41 -290.84 -51.74 0.00 O.OOG 0.00 0.00 6030569.96 659790.01 N 70.49006489 W 148.69369517 TMBK 4831.69 11.56 190.09 4740.00 4740.00 365.99 365.99 -360.34 -64.11 0.00 O.OOG 0.00 0.00 6030500.22 659779.15 N 70.48987504 W 148.69379622 Cry 3/100 4933.16 11.56 190.09 4839.42 4895.42 386.33 386.33 -380.36 -67.67 0.00 -100.64G 0.00 0.00 6030480.12 659776.02 N 70.48982033 W 148.69382534 NS10 AOR Tgt 1 4933.76 11.56 190.00 4840.00 4896.00 386.45 386.45 -380.48 -67.69 3.00 O.OOG -0.55 -14.71 6030480.00 659776.00 N 70.48982001 W 148.69382551 5000.00 13.55 190.00 4904.65 4960.65 400.85 400.85 -394.66 -70.19 3.00 O.OOG 3.00 0.00 6030465.77 659773.80 N 70.48978127 W 148.69384594 5100.00 16.55 190.00 5001.21 5057.21 426.81 426.81 -420.22 -74.70 3.00 O.OOG 3.00 0.00 6030440.12 659769.85 N 70.48971144 W 148.69388278 5200.00 19.55 190.00 5096.28 5152.28 457.79 457.79 -450.73 -80.07 3.00 O.OOG 3.00 0.00 6030409.51 659765.13 N 70.48962810 W 148.69392673 5300.00 22.55 190.00 5189.60 5245.60 493.70 493.70 -486.09 -86.31 3.00 O.OOG 3.00 0.00 6030374.02 659759.66 N 70.48953149 W 148.69397767 5400.00 25.55 190.00 5280.91 5336.91 534.44 534.44 -526.22 -93.38 3.00 O.OOG 3.00 0.00 6030333.75 659753.45 N 70.48942187 W 148.69403547 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) NS05\NS05\Plan NS05\NS05 (P10) Generated 1/6/20059:30 AM Page 1 of 3 Comments End Cry 5933.84 41.56 189.99 5724.34 5780.34 828.55 828.55 -815.87 -144.42 3.00 O.OOG 3.00 0.00 6030043.10 659708.65 N 70.48863058 W 148.69445262 WS1 6676.46 41.56 189.99 6280.00 6336.00 1321.23 1321.24 -1301.08 -229.92 0.00 O.OOG 0.00 0.00 6029556.20 659633.61 N 70.48730505 W 148.69515129 Cry 3/100 6890.14 41.56 189.99 6439.88 6495.88 1462.99 1462.99 -1440.68 -254.52 0.00 119.36G 0.00 0.00 6029416.10 659612.01 N 70.48692366 W 148.69535231 NS10 AOR Tgt 2 6890.30 41.56 190.00 6440.00 6496.00 1463.10 1463.10 -1440.79 -254.54 3.00 O.OOG -1.47 3.94 6029416.00 659612.00 N 70.48692337 W 148.69535246 6900.00 41.85 190.00 6447.24 6503.24 1469.55 1469.55 -1447.14 -255.66 3.00 O.OOG 3.00 0.00 6029409.62 659611.01 N 70.48690601 W 148.69536161 7000.00 44.85 190.00 6519.95 6575.95 1538.19 1538.19 -1514.74 -267.58 3.00 O.OOG 3.00 0.00 6029341 .79 659600.55 N 70.48672135 W 148.6954. 7100.00 47.85 190.00 6588.96 6644.96 1610.54 1610.54 -1585.99 -280.15 3.00 O.OOG 3.00 0.00 6029270.29 659589.52 N 70.48652670 W 148.69556 7200.00 50.85 190.01 6654.10 6710.10 1686.41 1686.41 -1660.70 -293.33 3.00 O.OOG 3.00 0.00 6029195.32 659577.94 N 70.48632261 W 148.69566940 7300.00 53.85 190.01 6715.17 6771.17 1765.57 1765.57 -1738.66 -307.09 3.00 O.OOG 3.00 0.00 6029117.09 659565.87 N 70.48610962 W 148.69578181 End Cry 7340.62 55.07 190.01 6738.78 6794.78 1798.62 1798.62 -1771.21 -312.83 3.00 O.OOG 3.00 0.00 6029084.42 659560.82 N 70.48602070 W 148.69582874 CM3 7622.18 55.07 190.01 6900.00 6956.00 2029.46 2029.46 -1998.53 -352.95 0.00 O.OOG 0.00 0.00 6028856.31 659525.60 N 70.48539968 W 148.69615653 Top HRZ 10591.18 55.07 190.01 8600.00 8656.00 4463.59 4463.59 -4395.61 -776.03 0.00 O.OOG 0.00 0.00 6026450.86 659154.18 N 70.47885108 W 148.69961178 Base HRZ 10730.90 55.07 190.01 8680.00 8736.00 4578.14 4578. 14 -4508.42 -795.94 0.00 O.OOG 0.00 0.00 6026337.66 659136.70 N 70.47854291 W 148.69977433 Top Kuparuk 10992.87 55.07 190.01 8830.00 8886.00 4792.92 4792.92 -4719.93 -833.27 0.00 O.OOG 0.00 0.00 6026125.42 659103.93 N 70.47796509 W 148.70007909 Kup C 11429.49 55.07 190.01 9080.00 9136.00 5150.88 5150.88 -5072.44 -895.49 0.00 O.OOG 0.00 0.00 6025771.68 659049.31 N 70.47700205 W 148.70058698 Drp 3/100 11753.96 55.07 190.01 9265.79 9321.79 5416.89 5416.90 -5334.41 -941.72 0.00 -180.00G 0.00 0.00 6025508.79 659008.71 N 70.47628637 W 148.70096439 11800.00 53.69 190.01 9292.60 9348.60 5454.32 5454.32 -5371.26 -948.23 3.00 -180.00G -3.00 0.00 6025471.81 659003.00 N 70.47618569 W 148.70101748 11900.00 50.69 190.01 9353.90 9409.90 5533.31 5533.31 -5449.05 -961.96 3.00 -180.00G -3.00 0.00 6025393.75 658990.95 N 70.47597317 W 148.70112954 TMLV 11940.67 49.47 190.01 9380.00 9436.00 5564.50 5564.50 -5479.77 -967.38 3.00 -180.00G -3.00 0.00 6025362.92 658986.19 N 70.47588925 W 148.70117379 12000.00 47.69 190.01 9419.25 9475.25 5608.99 5608.99 -5523.58 -975.11 3.00 -180.00G -3.00 0.00 6025318.96 658979.40 N 70.47576957 W 148.70123690 9-5/8" Csg PI 12015.90 47.21 190.01 9430.00 9486.00 5620.70 5620.70 -5535. 11 -977.15 3.00 -180.00G -3.00 0.00 6025307.39 658977.62 N 70.47573806 W 148.70125351 12100.00 44.69 190.01 9488.47 9544.47 5681.14 5681.14 -5594.63 -987.65 3.00 -180.00G -3.00 0.00 6025247.66 658968.39 N 70.47557545 W 148.70133925 12200.00 41.69 190.01 9561.37 9617.37 5749.57 5749.57 -5662.02 -999.54 3.00 -180.00G -3.00 0.00 6025180.03 658957.95 N 70.47539134 W 148.70143632 12300.00 38.69 190.01 9637.76 9693.76 5814.10 5814.10 -5725.56 -1010.76 3.00 -180.00G -3.00 0.00 6025116.27 658948.11 N 70.47521775 W 148.70152784 12400.00 35.69 190.01 9717.41 9773.41 5874.53 5874.53 -5785.08 -1021.26 3.00 -180.00G -3.00 0.00 6025056.55 658938.89 N 70.47505516 W 148.70161356 .' 12500.00 32.69 190.01 9800.12 9856.12 5930.72 5930.72 -5840.41 -1031.02 3.00 -180.00G -3.00 0.00 6025001.02 658930.32 N 70.47490400 W 148.70 12600.00 29.69 190.01 9885.66 9941.66 5982.50 5982.50 -5891.40 -1040.02 3.00 -180.00G -3.00 0.00 6024949.85 658922.42 N 70.47476469 W 148.70176 68 Top Kingak 12684.54 27.15 190.01 9960.00 10016.00 6022.73 6022.73 -5931.02 -1047.01 3.00 -180.00G -3.00 0.00 6024910.10 658916.28 N 70.47465646 W 148.70182373 12700.00 26.69 190.01 9973.79 10029.79 6029.73 6029.73 -5937.92 -1048.23 3.00 -180.00G -3.00 0.00 6024903.18 658915.21 N 70.47463762 W 148.70183366 12800.00 23.69 190.01 10064.27 10120.27 6072.28 6072.29 -5979.82 -1055.63 3.00 -180.00G -3.00 0.00 6024861.12 658908.72 N 70.47452313 W 148.70189401 12900.00 20.69 190.01 10156.85 10212.85 6110.05 6110.05 -6017.01 -1062.19 3.00 -180.00G -3.00 0.00 6024823.81 658902.96 N 70.47442154 W 148.70194755 13000.00 17.69 190.00 10251.29 10307.29 6142.91 6142.91 -6049.38 -1067.90 3.00 -180.00G -3.00 0.00 6024791.33 658897.95 N 70.47433312 W 148.70199415 13100.00 14.69 190.00 10347.31 10403.31 6170.79 6170.79 -6076.83 -1072.74 3.00 -180.00G -3.00 0.00 6024763.78 658893.70 N 70.47425812 W 148.70203367 13200.00 11.69 190.00 10444.66 10500.66 6193.60 6193.60 -6099.29 -1076.70 3.00 -180.00G -3.00 0.00 6024741.24 658890.22 N 70.47419675 W 148.70206600 Faull Crossing 13215.65 11.22 190.00 10460.00 10516.00 6196.71 6196.71 -6102.35 -1077.24 3.00 -180.00G -3.00 0.00 6024738.17 658889.74 N 70.47418839 W 148.70207041 End Drp 13256.28 10.00 190.00 10499.94 10555.94 6204.19 6204.19 -6109.72 -1078.54 3.00 O.OOG -3.00 0.00 6024730.77 658888.60 N 70.47416826 W 148.70208101 Kingak 0 13256.35 10.00 190.00 10500.00 10556.00 6204.20 6204.20 -6109.73 -1078.54 0.00 O.OOG 0.00 0.00 6024730.76 658888.60 N 70.47416823 W 148.70208102 NS Target 1 13581.28 10.00 190.00 10820.00 10876.00 6260.62 6260.62 -6165.30 -1088.34 0.00 O.OOG 0.00 0.00 6024675.00 658880.00 N 70.47401642 W 148.70216098 Top Sag River 13581.29 10.00 190.00 10820.01 10876.01 6260.63 6260.63 -6165.30 -1088.34 0.00 O.OOG 0.00 0.00 6024675.00 658880.00 N 70.47401642 W 148.70216098 Well Design Ver 3.1RT-SP3.03-HF5.00 Bld( do31 rt-546 ) NS05\NS05\Plan NS05\NS05 (P10) Generated 1/6/2005 8:44 AM Page 2 of 3 Comments Latitude 13621.91 10.00 190.00 10860.01 10916.01 6267.68 6267.68 -6172.25 -1089.57 0.00 O.OOG 0.00 0.00 6024668.03 658878.93 N 70.47399744 W 148.70217098 Bid 5/100 13641.90 10.00 190.00 10879.70 10935.70 6271.15 6271.15 -6175.67 -1090.17 0.00 O.OOG 0.00 0.00 6024664.60 658878.40 N 70.47398810 W 148.70217590 Shublik 13672.75 11.54 190.00 10910.00 10966.00 6276.91 6276.92 -6181.34 -1091.17 5.00 O.OOG 5.00 0.00 6024658.90 658877.52 N 70.47397259 W 148.70218407 13700.00 12.91 190.00 10936.63 10992.63 6282.68 6282.69 -6187.03 -1092.17 5.00 O.OOG 5.00 0.00 6024653.20 658876.64 N 70.47395707 W 148.70219224 End Bid 13741.90 15.00 190.00 10977.29 11033.29 6292.79 6292.79 -6196.97 -1093.93 5.00 O.OOG 5.00 0.00 6024643.22 658875.10 N 70.47392989 W 148.70220656 Top Ivishak 13755.05 15.00 190.00 10990.00 11046.00 6296.19 6296.19 -6200.33 -1094.52 0.00 O.OOG 0.00 0.00 6024639.85 658874.58 N 70.47392073 W 148.70221138 owe 13868.93 15.00 190.00 11100.00 11156.00 6325.67 6325.67 -6229.35 -1099.63 0.00 O.OOG 0.00 0.00 6024610.72 658870.09 N 70.47384143 W148.70225315 TD 14-1/2" Lnr 14055.28 /' 15.00 190.00 11280.00 11336.00 6373.90 6373.90 -6276.85 -1108.01 0.00 O.OOG 0.00 0.00 6024563.06 658862.74 N 70.47371167 W 148.70232149 . Survev TVDe: Raw Proposal LeQal DescriDtion: Surface: 1089 FSL 641 FEL S11 T13N R13E UM NS10 AOR Tgt 1: 708 FSL 709 FEL S11 T13N R13E UM NS10 AOR Tgt 2: 4928 FSL 897 FEL 514 T13N R13E UM NS Target 1: 203 FSL 1735 FEL S14 T13N R13E UM BHL: 92 FSL 1754 FEL S14 T13N R13E UM NorthinQ (VI [ftUS] 6030861.82 6030480.00 6029416.00 6024675.00 6024563.06 WellDesign Ver 3.1RT-SP3.03-HF5.00 Bld( d031rt-546) EastinQ (XI [ftUS] 659835.49 659776.00 659612.00 658880.00 658862.74 NS05\NS05\Plan NS05\NS05 (P10) . Generated 1/6/2005 8:44 AM Page 3 of 3 WELL NS05 (P10) Magnetic Parameters Model: BGGM 2004 4500 ~ 0 0 It) ~ ~ II Q) 6000 ro u CI) 0 > I- 10500 . . Schlumberger Northstar STRUCTURE Northstar PF Dip 80.977" MagDe<: .24,968° Surface Locatior't February 15, 2005 La! N702927.094 57643.1nT Lon" W1484135.780 TVO Ref: KB (56.00 ft above MSl) SrvyDate: January 06, 2005 NADV Alaska State PIMes. Zone 04. US Feel NOftt1ing 6030861.82ftUS GridConv: +1.23173007" Easting 659835.49ftUS Scale Fact: 0.9999290206 Slot NS05 Plan NS05(P10} o 7500 1500 3000 4500 6000 o D= ..-..-..-. rop Perm ..-..-...... 3ase Perm ~OPBld1l100 ~Bld 3/100 ;~ - End Bid 'ìjf; 13·3/8" Csg PI r r CN 3/100 -vF···~:··· r,/ y: N~lU ~ase AU" 1 -£ Cry "- /<0':;;:';,'9<£ Cry 3/100 '"'S ÿ-- XEnd Cry 2 ~ " ~ "ase Nt«: "'- "...........-.....,,-.. .Drl ,3/100 "- -' ~u, .~ "Z'---' i-5I8" Csg PI 'Mev }\ '0" ~'''".. \ /...ault Crossing _End Drp Kingak D , \ L--NS Target 1 .. if1tä~ v,,~ \ .-". ~S05 (P10) 1500 3000 7500 9000 o 1500 3000 4500 6000 Vertical Section (ft) Azim = 190.01°, Scale = 1(in):1500(ft) Origin = 0 N/-S, 0 E/-W 7500 o 1500 3000 4500 6000 7500 9000 10500 / e . Schlumberger NS05 (P10) Northstar STRUCTURE Northstar PF MaQl1etk:ParametefS Model BGGM 2004 Date: February 15,2005 FS: 57643.1nT Surface location Lat: N702927.094 Lon W1484135.780 Dip: 80.977' Mag Doc: +24.968· NAD27 Alaska State Planas, Zema 04, US Feet Northing: 6030861.82ftUS GridCoJW: +1.23173007' Easting 659835.49ftUS Scale Fact: 0.9999290206 Miscellaneous Slot NSOS Plan" NS05(P10) -800 800 TVDRef: KB(56.00ftaboveMSl) SrvyDate: J8f1uary06,2005 o KOP Bid 1/100 RTE -2400 -1600 ^ -2400 -2400 ^ ^ z £" 0 0 <X> .;...:. <:: = ~ -3200 -3200 II Q) -¡¡¡ <> (/) (/) V V V -4000 -4000 o -800 -1600 -4800 -5600 -6400 -2400 -1600 -800 0 <<< W Scale = 1 (in):800(ft) E >>> 800 o -800 -1600 -4800 -5600 -6400 o \500 3000 4-500 5000 l500 C1000 \0500 12000 13500 . NSOS/Plan NSOS . _ '3 (::::§:::~ 0 _ " S00 I - Plan NS05 c::::::> v " --- ~ e:::::::> "svD " ~ o " -G ~ ,?:>DDD "- ¿ "- ~ ~ ~-;?- . . Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell Street, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Thursday, January 06, 2005 Pat Archey Northstar NS05 (P10) BP Exploration Alaska 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. Survey Proqram: Instrument Type GYD-GC-SS MWD MWD + IFR + MS Start Depth 40.43' md 1,500.00' md 1,500.00' md End Depth 1,500.00' md 2,500.00' md 14,055.28' md Close Approach Analysis results: Under method (2), all wells pass major risk rules: Note: NS06 passes the major risk ruleset. However, it is suggested the risk based 1 :200 ruleset be used for more room from tolerance lines during surface drilling. The closest point of tolerance is at 780'md, with a 0.01' of / clearance. With a risk based assessment at 1 :200, it becomes 9.23' of clearance. A tolerable collision risk worksheet will need to be filled out. All data documenting these procedures is available for inspection at the Drilling and Measurements Directional Planning Center. Close Approach Drillinq Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott Delapp 01/06/04 Field: Northstar Site: Northstar PF Well: NS05 Wellpath: Plan NS05 100 27 294 200 ]00 NS09 (NS09) . 200 294 ]80 Travelling Cylinder Azimuth (TFO+AZI) (dcg] vs Centre to Centre Separation [100ft/in] - BP Alaska Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.43 to 14055.28 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/22/2004 Validated: No Planned From To Survey ft ft 40.43 1500.00 1500.00 2500.00 1500.00 14055.28 Version: 2 Toolcode Tool Name Planned Plan #10 V1 Planned Plan #10 V1 Planned Plan #10 V1 GYD-GC-SS MWD MWD+IFR+MS Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station Casing Points 3208.75 3206.00 13.375 16.000 13 3/8" 12015.90 9486.00 9.625 12.250 95/8" 13621.90 1 0916.00 7.000 8.500 7" 14055.28 11336.00 4.500 6.125 4 1/2" Summary Northstar PF NS06 NS06 V34 799.83 800.00 14.28 14.27 0.01 Pass: Major Risk Northstar PF NS07 NS07 V33 549.54 550.00 17.86 9.96 7.90 Pass: Major Risk Northstar PF NS08 NS08 V18 1699.64 1700.00 35.42 28.04 7.38 Pass: Major Risk Northstar PF NS09 NS09 V14 999.60 1000.00 41.33 16.69 24.65 Pass: Major Risk Northstar PF NS10 NS10 V17 1345.88 1350.00 34.76 22.59 12.17 Pass: Major Risk Northstar PF NS12 NS12 V28 649.26 650.00 70.54 12.17 58.37 Pass: Major Risk Northstar PF NS13 NS13 V13 2449.66 2450.00 87.60 33.76 53.85 Pass: Major Risk Northstar PF NS14 NS14 V11 1999.48 2000.00 114.60 31.68 82.93 Pass: Major Risk Northstar PF NS15 NS15 V19 1249.32 1250.00 104.71 22.61 82.11 Pass: Major Risk Northstar PF NS16 NS16 V39 499.15 500.00 114.36 9.44 104.92 Pass: Major Risk Northstar PF NS17 NS17 V12 1299.53 1300.00 115.04 20.62 94.43 Pass: Major Risk Northstar PF NS18 NS18 V14 600.03 600.00 133.86 10.97 122.90 Pass: Major Risk Northstar PF NS19 NS19 V17 898.29 900.00 144.88 16.58 128.30 Pass: Major Risk Northstar PF NS20 NS20 V8 500.68 500.00 151.45 8.53 142.93 Pass: Major Risk Northstar PF NS20 NS20PB1 V10 550.68 550.00 151.67 9.24 142.43 Pass: Major Risk Northstar PF NS21 NS21 V57 299.71 300.00 161.09 5.64 155.46 Pass: Major Risk Northstar PF NS22 NS22 V13 399.24 400.00 160.26 7.07 153.19 Pass: Major Risk Northstar PF NS23 NS23 V33 499.42 500.00 183.21 9.14 174.07 Pass: Major Risk Northstar PF NS24 NS24 V15 1249.37 1250.00 188.62 21.64 166.98 Pass: Major Risk Northstar PF NS25 NS25 V3 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS25 NS25PB1 V9 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS25 NS25PB2 V3 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS26 NS26 V23 1450.54 1450.00 215.11 22.79 192.31 Pass: Major Risk Northstar PF NS27 NS27 V29 3169.23 3200.00 86.46 49.15 37.31 Pass: Major Risk Northstar PF NS28 Plan NS28 V5 Plan: Pia 449.97 450.00 230.94 8.62 222.31 Pass: Major Risk Northstar PF NS29 NS29 V23 399.82 400.00 240.62 7.24 233.38 Pass: Major Risk Northstar PF NS31 NS31 V14 2842.24 2850.00 277.62 45.25 232.37 Pass: Major Risk Northstar PF NS32 NS32 V11 350.05 350.00 274.00 7.19 266.81 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 2796.30 2800.00 458.54 43.24 415.30 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 2796.75 2800.00 454.85 43.01 411.84 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 2796.72 2800.00 454.12 40.70 413.42 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 2936.00 3000.00 317.66 54.59 263.06 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1605.89 1600.00 494.19 28.11 466.07 Pass: Major Risk -- BP Alaska Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.43 to 14055.28 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/22/2004 Validated: No Planned From To Survey ft ft 40.43 1500.00 1500.00 2500.00 1500.00 14055.28 Version: 2 Toolcode Tool Name Planned: Plan #10 V1 Planned: Plan #10 V1 Planned: Plan #10 V1 GYD-GC-SS MWD MWD+IFR+MS Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station Casing Points 3208.75 3206.00 13.375 16.000 133/8" 12015.90 9486.00 9.625 12.250 9 5/8" 13621.90 1 0916.00 7.000 8.500 7" 14055.28 11336.00 4.500 6.125 4 1/2" Summary Northstar PF NS06 NS06 V34 349.94 350.00 10.32 2.98 7.33 Pass: Minor 1/200 Northstar PF NS07 NS07 V33 549.54 550.00 17.86 9.96 7.90 Pass: Major Risk Northstar PF NS08 NS08 V18 1699.64 1700.00 35.42 28.04 7.38 Pass: Major Risk Northstar PF NS09 NS09 V14 999.60 1000.00 41.33 16.69 24.65 Pass: Major Risk Northstar PF NS10 NS10 V17 1345.88 1350.00 34.76 22.59 12.17 Pass: Major Risk Northstar PF NS12 NS12 V28 649.26 650.00 70.54 12.17 58.37 Pass: Major Risk Northstar PF NS13 NS13 V13 2449.66 2450.00 87.60 33.76 53.85 Pass: Major Risk Northstar PF NS14 NS14 V11 1999.48 2000.00 114.60 31.68 82.93 Pass: Major Risk Northstar PF NS15 NS15 V19 1249.32 1250.00 104.71 22.61 82.11 Pass: Major Risk Northstar PF NS16 NS16 V39 499.15 500.00 114.36 9.44 104.92 Pass: Major Risk Northstar PF NS17 NS17 V12 1299.53 1300.00 115.04 20.62 94.43 Pass: Major Risk Northstar PF NS18 NS18 V14 600.03 600.00 133.86 10.97 122.90 Pass: Major Risk Northstar PF NS19 NS19 V17 898.29 900.00 144.88 16.58 128.30 Pass: Major Risk Northstar PF NS20 NS20 V8 500.68 500.00 151.45 8.53 142.93 Pass: Major Risk Northstar PF NS20 NS20PB1 V10 550.68 550.00 151.67 9.24 142.43 Pass: Major Risk Northstar PF NS21 NS21 V57 299.71 300.00 161.09 5.64 155.46 Pass: Major Risk Northstar PF NS22 NS22 V13 399.24 400.00 160.26 7.07 153.19 Pass: Major Risk Northstar PF NS23 NS23 V33 499.42 500.00 183.21 9.14 174.07 Pass: Major Risk Northstar PF NS24 NS24 V15 1249.37 1250.00 188.62 21.64 166.98 Pass: Major Risk Northstar PF NS25 NS25 V3 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS25 NS25PB1 V9 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS25 NS25PB2 V3 1241.99 1250.00 193.85 22.74 171.11 Pass: Major Risk Northstar PF NS26 NS26 V23 1450.54 1450.00 215.11 22.79 192.31 Pass: Major Risk Northstar PF NS27 NS27 V29 3169.23 3200.00 86.46 49.15 37.31 Pass: Major Risk Northstar PF NS28 Plan NS28 V5 Plan: Pia 449.97 450.00 230.94 8.62 222.31 Pass: Major Risk Northstar PF NS29 NS29 V23 399.82 400.00 240.62 7.24 233.38 Pass: Major Risk Northstar PF NS31 NS31 V14 2842.24 2850.00 277.62 45.25 232.37 Pass: Major Risk Northstar PF NS32 NS32 V11 350.05 350.00 274.00 7.19 266.81 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 2796.30 2800.00 458.54 43.24 415.30 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 2796.75 2800.00 454.85 43.01 411.84 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 2796.72 2800.00 454.12 40.70 413.42 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 2936.00 3000.00 317.66 54.59 263.06 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 1605.89 1600.00 494.19 28.11 466.07 Pass: Major Risk Site: Northstar PF -- Drilling Target Conf.: 95% Description: Map Northing: 6029416.00 ft Map Easting : 659612.00 ft Latitude: 70029'12.924N Shape: Circle Target: NS 1 0 Target 2 evell: NS05 Based on: Planned Program Vertical Depth: 6440.00 ft below Mean Sea Level Local +N/-S: -1440.78 ft Local +E/-W: -254.54 ft Longitude: 148°41'43.269W Radius: 200 ft -1000 -1100 -1200 -1300 -14-00 -IS 00 -1500 -llOO -/800 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 LJ) -.:t- (I) N N ~ 0 I I I I ~ ~ j ~ Site: Northstar PF . Drilling Target Conf.: 95% Description: Map Northing: 6030480.00 ft Map Easting : 659776.00 ft Latitude: 70029'23.352N Shape: Circle Target: NSlO Target 1 .ell: NS05 Based on: Planned Program Vertical Depth: 4896.00 ft below Mean Sea Level Local +N/-S: -380.48 ft Local +E/-W: -67.69 ft Longitude: 148°41 '37.772W Radius: 200 ft o -100 -200 -300 -4-00 -SOD -500 -lOO 0 D D D D D CJ D CJ o 0 D CJ CJ D CJ D CJ o ~ ~ (I) N N (I) ----=I- I I 0 ~ ~ ~ J J. Site: Northstar PF . Drilling Target Conf.: 95% Description: Map Northing: 6024675.00 ft Map Easting : 658880.00 ft Latitude: 70028'26.459N Shape: Circle aell: NS35,NS33,NS05 Based on: Planned Program Vertical Depth: 11000.00 ft below Mean Sea Level Local +N/-S: -6165.29 ft Local +E/-W: -1088.34 ft Longitude: 148°42'07.780W Radius: 400 ft Target: NS Target 1 ~ o o 0 o ~ ; o / o / / / CJ CJ LO CJ CJ -3- CJ CJ N CJ CJ C) CJ CJ OJ I CJ CJ LO I CJ CJ -3- I / -54-00 -5500 -5800 -5000 -5200 -54-00 -5500 -5800 CJ CJ N I Pennit for Northstar NS05 . . Bob, Per our conversation, the NS05 well will be drilled and completed as a development production well. The casing tubulars have been upgraded to allow BP to convert the well to a gas injector if it becomes desirable to at a later date. If BP ever desires to convert this well to an injector the proper paper work requesting approval. Dave 1 of! 1/14/20054:21 PM SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 . ANCHORAGE, AK 99519-6612 89-6/1252 119 "Mastercard Check" DATEDt-1L-l")S PAY TO THE ~('1. (ì' ORDER OF L '- ~ ... j. '.,~ ()-n~ ... ~eo-~~ First Nation ank Alaska ~"'''''..g.. ~K 9~501 ~ . MEM;(\'8:>S . '. . . . ~ I $ lD:).(X) DOLLARS -: ~ 25 2000bO-:99 ~~lIq; 2 2 711' ~ 5¡;~1I· 0~~9 . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 4/5 (] _Ç" PTD# ?os----- ~7 X Development Service Exploration Stratigraphic CHECKWBAT ADD-ONS ~'CLUE ". APPLIES (OPTIONS) MULTI Tbe permit is for a Dew wenbore 'segmeDt of LATERAL existiDg weD . Permit No, API No. . (If API Dumber Production. sbould continue to be reported as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT BOLE In accordance witb 20 AAC 25.00S(f), an (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb Dame (name 011 permit plus PH) .' and API number (50 - 70/80) from records, data and logs acquired for wen (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25..05S~ Approval to perforate and produce is contingent upon issuance of ~ cODservation order approving a spa cing n cep1ion. (Company Name) assumes tbe liability of any prot est to the spacing .e~ception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 30' sample inten'als from below tbe permafrost or from wbere samples are first caught aDd ] 0' sample inter-vals tbrough target zones. o __ Well bore seg Annular Disposal Qn Program DEV On/Off Shore Unit Well Name: NORTHSTAR.UNIT 05 11-QIL GeoArea DEV . The wejsrviCß _as ç¡n inieçtor~ Ina phone_ Gonver~atiQn. 1J14 OavidJohnson 56.4-475Q iridiça_tedc c_ooversjontoinieçtion wjll_not Qcurr for several y-e¡¡rs._ RI:IC WO. is: e_quipped Jor Yes Yes .Yes .Yes Yes .Yes .Yes Yes Yes .Yes .Yes Yes Yes NA NA No NA Initial ClasslType NORTHSTAR. NORTH STAR OIL - 590100 NG _Permit fee attached .Lease _number _appropri¡¡te _U_nique welt n_arne _aod oumb_er JQcç¡t~ Field & Pool ina defined pool We_ We I Well distance_ from driJling unitb.ound_ary_ distance from other wel!s JQc¡¡ted proper indrilJiog unjt included IQc¡¡ted proper S_utficientacreélge _aYélil¡¡ble Ifdeviated. js weJlbQre plç¡t O-perator only- affected party _O-per_ator has_appropriate_ bond __n '-0 i_ssued without 2 3 4 5 6 7 8 9 Administration (For 10 11 Date 12 t issued without admioistrativea-pproval 1/14/2005 13 Can permit be approved before 15-day wait 14 Well IQc¡¡t~ within area and_str¡¡t¡¡authorized by_lnjectioo Order # (put 10# 15 _All wel!s_ within J l4JIJile _area_of reyiew id_eolified (For !¡ervjc_e well onlY-) 16 Pre-produced injector; _duratiQnof pre--produçtion tes!¡ théln 3. months_ (for_service well only) 17 _AÇMP Fïndjngof Consistency_ h_as been j!¡sued for this proiect --~- - incomrnents) in Jorçe co_nserva1ion Qrder Permit v_~" "'" Permi Appr RPC @2QO' 20' Adequate exCl3!¡S_ f\.Iabors33E._ f\.Iewwel W¡¡iyerrequested_. Max MW 12._6_ppg . Test to .4600_ psi .Yes .Yes Yes No_ Yes Yes .Yes NA .Yes NA Yes Yes Yes Yes Yes No NA Coodu_ctor stringprQvided S_urfacec¡¡singprotec.t~ al 8 19 20 Engineering known USOWs _CMT v_oj adeq u_ate_ to circ_ulate _ o_n _cond_uctor_ & surf csg IQngstring to surf C&9_ tie-iJ1 koown _pro_ductiye hQrizon_s CMT vol adequ_ate_ to C.T. B&perJ'lJafr_ost re_serve pit _ lOAO;3 fOJ ¡¡bandonment _CMT Wil! coyeraJ C_asing designs éld_eQuate for _Adequate télnkage_ or be_eo ¡¡PPJoved Ifdivecter required. does ]! meet reguJatíons_ DrilJiog fluid program sGhematic_& equip list BDPEs._do adequ¡¡te they meet regulation testto(pu_t PSig in _comments) C.hoke_J'lJanjfold cQmpJies w/API Rp-53 (May 64) WQrk will occur without Is presence_ of 21 22 23 24 25 26 27 28 29 30 31 32 33 Ifa re-drilt has a _Adequate well bore !¡epar¡:¡tjo_n _pro-po!¡ed Date 1/18/2005 Appr WGA ra1iog élp-propriate; BDPE_press Oper¡¡tjonshutdown_ H2S gas_ prob_able -~ -~ wells within AQR yerified (Forservjce wel! only) 34 Mecha_nic¡¡Lcoodjliooof No _NA NA NA NA issued w/o hydrogen_ s_ulfide measures Permit cao Þe _D_ata_preseoted on_ pote_ntial oveJPres_sure _ZOnes 35 36 37 38 39 Geology Appr RPC SeislJlicanalysjs Qf shaJlow gas_zones off-sh_ore) weekly progress_reports [exploratory _only] f _Seabedconditioo survey CQnta_ctnamelphoneJor Date 1/14/2005 Date I-/f-~ Date Engineering Commissioner: Date: I/~ l} Geologic Commissioner: b/s