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205-207
VF Zo 5 .20�-7 ,, �i��i 4 a- ; ,er United States Department of the Interior �z i 32 BUREAU OF SAFETY AND ENVIRONMENTAL ENFORCEMENT �gRC3 Bag Alaska OCS Region 3801 Centerpoint Drive,Suite 500 Anchorage,Alaska 99503-5823 FEB 2 2018 RECEIVED John A. Barnes MAR 11 I ?OIR Senior Vice President and North Slope Asset Team Leader Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 `'` Anchorage, Alaska 99503 Dear Mr. Barnes: SCANNED a,, , 2 �,t;; During the inspection out-briefing at Northstar Production Island on July 20, 2017, Hilcorp Alaska, LLC (HAK), requested clarification concerning our approach to the inspections of federal wells at Northstar. This topic has come up in various meetings with HAK in recent years. Therefore,this letter provides updated guidance to HAK regarding how we will approach inspections related to the federal wells at Northstar. Our goal here is to provide better clarity for HAK by setting down in writing what we have been relating verbally to HAK since you took over as operator of Northstar in 2014, and by drawing clear distinctions around our inspection parameters where it is practical for us to do so. Please be advised that this letter explicitly supersedes the February 1, 2005 letter from this office to BP Exploration Alaska, Inc. (Jeffrey Walker to Gray Herring). BSEE will conduct inspections related to all North Star federal wells (currently including NS-6, NS-9,NS-12,NS-22,NS-30,NS-32, and NS-34A) according to the following. The federal wells are subject to applicable federal regulations from bottom hole through Safety and Pollution Prevention Equipment(SPPE) and any devices that protect the wellhead. SPPE and devices that protect the wellhead will be generally defined as, but may not be limited to: a. Subsurface Safety Valve (SSSV) and their control system/actuators to include any component in the process stream establishing set points. b. Surface Safety Valve (SSV) and related actuators (e.g. a Pressure Safety High/Low, or PSHL)to include components establishing set points such as: tubing and annular pressures (static and flowing), first flowline segment pressure ratings, and first stage separator vessel pressure ratings. c. Injection Valve. d. Tubing/annular subsurface and surface safety devices. e. Emergency Shut Down (ESD) system and related controls. f. Any Temperature Safety Elements (TSE), Temperature Safety High (TSH) or other heat/fire detector installed at the well related to the actuation of well safety devices. g. Wellhead Injection Lines and Gas Lift Wellhead Injection Lines and related safety devices to include: Pressure Safety Valves (PSV), Flow Safety Valve(FSV), and PSHL. • • This letter sets forth the current BSEE regional policy for conducting federal well inspections at Northstar; however it does not represent a binding statement on the extent of BSEE's jurisdiction over facilities in state waters with wells that reach the OCS. If you have any questions about this guidance please contact Michael Jordan at michael.jordan@bsee.gov or at(907) 334-5300. Sincer ly, 41141111190 Kevin J. Pendergast, PE'CPG Regional Supervisor, Field Operations cc: James Regg, Inspections Supervisor, AOGCC STATE OF ALASKA A KA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations U Fracture Stimulate A Pull Tubing Li Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ .rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 2 Exploratory ❑ 205-207 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23293-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: •_1 ADL0312808 NORTHSTAR UNIT NS-30 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MAR 2 9 2016 N/A NORTHSTAR/ NORTHSTAR OIL 11. Present Well Condition Summary: MOGGC Total Depth measured 16,398 feet Plugs measured 16,245 feet true vertical 11,244 feet Junk measured N/A feet 14,368, 15,694& Effective Depth measured 16,245 feet Packer measured 15,739 feet 9,406, 10,592& true vertical 11,098 feet true vertical 10,632 feet Casing Length Size MD TVD Burst Collapse Conductor 200' 20" 200' 200' N/A N/A Surface 4,443' 13-3/8" 4,443' 3,255' 5,020psi 2,260psi Production 14,549' 9-5/8" 14,549' 9,561' 7,930psi 6,620psi Intermediate 1,509' 7" 15,877' 10,757' 7,240psi 5,410psi Liner 674' 4-1/2" 16,396' 11,242' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic W APR 1 1 2016 icAlitI True Vertical depth See Attached Schematic 9 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13CR VAM TOP 15,743' 10,636' ZXP LTP 4-1/2"S-3 1,027'(MD) Packers and SSSV(type,measured and true vertical depth) ZXP LTP TRM-4E TRSV See Above 1,013'(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: 684 39,580 1,000 141 806 Subsequent to operation: 718 42,194 886 233 820 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ 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: 316-018 Contact Taylor Wellman ?'Yr✓ Email twellman(c�hilcorp.com Printed Name ike D n Title Operations Manager c Signature Phone 777-8382 Date 3/22/2016 Form 10-404 Revised 5/2015 Submit Original Only )" - %4,7RBDMS LL. MAR 31 2016 1111 • • Northstar Unit Well: NS-30 SCHEMATIC Last Completed: 4/8/2006 liileorp Alaska,LI t: PTD: 205-207 TREE&WELLHEAD Orig.KBE=56.27'/BFE=40.1'(CB 15.9')Nabors 33E Tree ABB-VGI 5-1/8"SKSI 2,, 41 Wellhead ABB-VGI 13-5/8"Multibowl SKSI OPEN HOLE/CEMENT DETAIL 20" Driven r:. 13-3/8" 607 sx AS Lite,465 sx Class"G"in 16"Hole m-' 2 9-5/8" 1,362 sx Ext.Slurry,450 sx Class"G"in 12-1/4"Hole 7" 365 sx Class"G"in 9-1/2"Hole 13-3/8" 4-1/2" 86 sx Class"G"in 6"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 200' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 4,443' 0.150 9-5/8" Production 53.3/L-80/Btc-Mod. 8.535 Surface 14,549' 0.0732 7" Intermediate 29/L-80/Hydril 511 6.184 14,368' 15,877' 0.0372 -' 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 15,722' 16,396' 0.0152 "i 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 15,743' 0.0152 5-1/2" VIT Tubing L-80 13Cr80 3.958 Surface 44' 0.0152 WELL INCLINATION DETAIL KOP@50' 3(€ Max Hole Angle=57 deg.@ 3,390' II Max Angle at Top Perf:21 Deg.@ 16,050' JEWELRY DETAIL No Depth Item 1 44' 5-1/2"x 4-1/2"VIT XO,ID=3.958" 2 1,027' 4-1/2"TRM-4E TRSV w/ "X"Profile- ID=3.812" 3 6,666' STA 1:GLM-MMG Dev=55/DMY w/RK Latch/ND @ 4,495'/Port=0/ Set 4/13/2006 `° 4 14,368' 9-5/8"x 7"Baker ZXP LTP ,I_ JI 5 14,382' 9-5/8"x 7"Baker Flex Lock Liner Hanger 4 6 15,649' 4-1/2"HES"X"Nipple,10=3.813 - j ' 5 7 15,670' 4-1/2"WFD Fiber Optic Transducer w/cable,ID=3.958 ''� i F 8 15,694' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 9 15,718' 4-1/2"HES "X"Nipple,ID=3.813 9-5/8 10 15,728' 11.77'Baker Tie Back 11 15,729' 4-1/2"HES XN Nipple,ID=3.725"(15,712'ELMD 4/15/2006) 12 15,739' Baker 7"x 5"Baker ZXP Top Packer 13 15,743' 4-1/2"Self-aligning Mule Shoe,ID=3.860" 1 i 6 14 15,750' Baker 7"x 5"Flex-Lock Liner Hanger 7 15 15,760' 5"x 4-1/2"Cross-over-ID=3.958" PERFORATION DETAIL C4 '" 8 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) SPF Shot Date Status Size MnID-3.725"@ 16,050' 16,220' 10,914' 11,074' 6 10/22/2010 Open 2-7/8" 15,729' _ 16,082' 16,112' 10,944' 10,972' 6 6/4/2009 Open 2-7/8" 16,090' 16,116' 10,952' 10,976' 6 1/25/20010 Open 2-7/8" 11 16,112' 16,132' 10,972' 10,991' 6 4/15/2006 Open 2-7/8" JI j12 16,112' 16,137' 10,972' 10,995' 6 6/28/2008 Open 2-7/8" ''' 13 14 16,116' 16,142' 10,976' 11,000' 6 1/24/2010 Open 2-7/8" 16,132' 16,152' 10,991' 11,010' 6 4/15/2006 Open 2-7/8" 15 16,137' 16,157' 10,995 11,014' 6 3/15/2016 Open 2-3/4" 7 Ivishak 16,137' 16,162' 10,995' 11,019' 6 4/30/2008 Open 2-7/8" 16,142' 16,168' 11,000' 11,025' 6 1/24/2010 Open 2-7/8" 16,152' 16,172' 11,010' 11,028' 6 4/15/2006 Open 2-7/8" Tag Depth of on 22/201616,215'ND 16,157' 16,177' 11,014' 11,033' 6 3/15/2016 Open 2-3/4" Ivishak 16,168' 16,194' 11,025' 11,049' 6 1/24/2010 Open 2-7/8" 16,169' 16,194' 11,026' 11,049' 6 9/16/2007 Open 2-7/8" 4-1/2 16,184' 16,194' 11,040' 11,049' 6 4/14/2006 Open 2-7/8" TD=16,398'(MD)/TD=11,244(ND) 16,204' 16,224' 11,059' 11,078' 6 1/24/2010 Open 2-7/8" PBTD=16,245'(MD)/PBTD=11,098(ND) 16,204' 16,224' 11,059' 11,078' 6 4/14/2006 Open 2-7/8" Reference Log:GR-CCL on 5/15/2006. Note:Refer to production DB for historical perf data. ADDITIONAL INFORMATION GENERAL WELL INFO SAFETY NOTE Location:SEC.11,T13N,R13E,1,339'FSL&649'FEL API:50-029-23293-00-00 Well requires a safety valve, Datum MD=15,655'/Datum ND=10,500'SS Completed by N33E-4/8/06 4-1/2"Chrome Tubing&Liner Revised By:TDF 3/15/2016 For Perf Dates See Table Above • • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-30 Slickline 50-029-23293-00-00 205-207 2/22/16 3/13/16 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 i,i,il;i:l 1 No activity to report. 2/21/2015 -Sunday No activity to report. 2/22/2015 - Monday "PT 366 PSI LOW 5 MINUTES (PASS) &4,140 PSI HIGH 15 MINUTES (PASS). RAN A 2.84" CENT, 2' 1-7/8" STEM, 18' 3" BAILER (MULE SHOE/FLAPPER) OAL=241",TAG BOTTOM @ 16,182' SLM, + 33' correction from 9/17/14= 16,215' elmd. P/U WEIGHT AT TAG DEPTH 1,025#. RIG DOWN. 2/23/2015-Tuesday No activity to report. S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-30 E-Line 50-029-23293-00-00 205-207 2/22/16 3/13/16 Daily Operations: 3/9/2015-Wednesday RU E-LINE AND PT SURFACE EQUIP 300 LP 4,200 HP (CHARTED). GOOD TEST. INSTALL NIGHT CAP ON QTS. LDFN. 3/10/2015 -Thursday No activity to report. 3/11/2015 - Friday RU E-LINE & PT QTS 300 LP 4200 HP. RIH W/201X 2.75" MILLENIUM HMX GUNS 6SPF 60°. CORRELATE TO SLB SCMT LOG 4/3/2006. PERFORATE INTERVAL 16,157' TO 16,177' ALL SHOTS FIRED. LDFN. 3/12/2015 -Saturday SWAP OUT E-LINE LOGGING UNITS DUE TO BAD 5/16 CABLE. REHEAD AND TEST TOOLS. RU E-LINE AND PT SURFACE EQUIP 300 LP/4,400 HP (CHARTED). GOOD TEST. LDFN 3/13/2015 -Sunday RU E-LINE AND PT QTS 300 LP/4,400 HP. RIH W/20'X 2.75" MILLENIUM HMX GUNS 6SPF 60° CORRELATE TO SLB SCMT LOG 4/3/2006. PERFORATE INTERVAL 16,137'-16,157' ALL SHOTS FIRED. RDMO. 3/14/2015- Monday No activity to report. 3/15/2015-Tuesday No activity to report. ®FT • • evi I%%i THE STATE Alaska Oil and Gas ofA T` ASKA Conservation Commiss1on iist - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager FEBHilcorp Alaska, LLC iCANIE EB 2 4 2016' 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,Northstar Unit NS-30 Permit to Drill Number: 205-207 Sundry Number: 316-018 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, Nett )-(-44/4"---• Cathy P. Foerster Chair DATED this /4 of January, 2016. RBDMS I.A. JAN 1 9 2016 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 8 2016 APPLICATION FOR SUNDRY APPROVALS ,//¢(tL 4_14 rV7%.or 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ (4_, 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: Hilcorp Alaska LLC Exploratory ❑ Development El• 205-207 3.Address: Stratigraphic ❑ Service ii 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23293-00-00 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-30 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): 16,398' - 11,244' • 16,245' 11,098' 3,915 16,245' N/A Casing Length Size MD TVD Burst Collapse Conductor 200' 20" 200' 200' N/A N/A Surface 4,443' 13-3/8" 4,443' 3,255' 5,020psi 2,260psi Intermediate 14,549' 9-5/8" 14,549' 9,561' 7,930psi 6,620psi Intermediate 1,509' 7" 15,877' 10,757' 7,240psi 5,410psi Liner 674' 4-1/2" 16,396' 11,242' 8,430psi 7500 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 VAM TOP 15,743 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"ZXP LTP,7"x 4-1/2"S-3&7"x 5"ZXP LTP 14,368MD/9,406TVD, 15,694MD/10,592TVD&15,739MD/10,632TVD and 4-1/2"TRM-4E TRSV and 1,027MD/1,013TVD 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 /^ I G 15.Well Status after proposed work: `2 Commencing Operations: Z, /3 © OIL ❑✓ 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 twelimanAhilcorp.com Printed Name e Dunn Title Operations Manager Signature ii. �_ Phone 777-8382 Date 1/7/2016 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \,�(— 0\`'6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑i Subsequent Form Required: ! 0 -- 0 j APPROVED BY .i(„4,7 Approved by: 7) —)9„.c.4„,.74,......____ COMMISSIONER THE COMMISSION Date: /_/y__/,‘, /"� ��/'y� tij a Submit Form and Form 10-403 Revised 11/2015 Jp �v8p 1 i n/A}lv`lid for 12 months from the date of approval. Attachments in Duplicate RBDMS 11- JAN 1 9 2016 alt_ /-(2. -/ c., 'de/4 r./74.. • Reperf NW • Well: NS-30 • PTD: 205-207 Hilcorp Alaska,LD API: 50-029-23293-00 Well Name: NS-30 API Number: 50-029-23293-00 Current Status: Online Rig: SL& EL Estimated Start Date: February 3, 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: 205-207 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): 5,015psi © 11,100' TVD (Based on SBHPS on NS-30 09/17/14) MPSP: 3,915psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 3,703psi Recorded on 06/14/15 Min ID: 3.725" XN Nipple @ 15,729' and Brief Well Summary: NS-30 was completed in 2006. The well has had multiple stimulations (reperf&acid stimulations) throughout the well's life. Each stimulation has shown production improvement from the well. The last stimulation work (145' or reperfs)was completed in October 2010. Objective: Re-perforate the existing Ivishak formation. NOTE—This is a BSEE well. Ensure that all ATP documents are completed prior to rigging up to the well. 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 @ 16,181' slm/16,214' elmd on 09/17/14 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 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 20'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 16,050' and prior to dropping past the top perfs in the well. a. Note: During previous reperforation jobs in 2010, toolstrings have been stuck 3 times. All guns ,,- were stuck within the permitted perforating zones. To get free, 2 were shot and 1 the well was flowed to become free. b. Tie-In Log to be used:SLB SCMT 04/03/2006 'f 9. Perforate the following interval: +/-16,157'—16,177' and 10. POOH and MU 20' x 2-3/4" carrier guns. • Reperf • Well: NS-30 • PTD: 205-207 IIiku,rp Alaska.LL API: 50-029-23293-00 11. RIH and perforate the following interval: +/-16,137'—16,157' md 12. POOH, rig down and slide over to the next well. ATTACHMENTS: Schematic Proposed Schematic • Northstar Unit . li • Well: NS-30 SCHEMATIC Last Completed: 4/8/2006 Hilcorp Alaska,LLC PTD: 205-207 TREE&WELLHEAD Orig.KBE=56.27'/BFE=40.1'(CB 15.9')Nabors 33E Tree _ ABB-VGI 5-1/8"5KSI 1 Wellhead ABB-VGI 13-5/8"Multibowl 5KSI,1 I [ I 20 OPEN HOLE/CEMENT DETAIL "All 20" Driven 13-3/8" 607 sx AS Lite,465 sx Class"G"in 16"Hole ' 2 9-5/8" 1,362 sx Ext.Slurry,450 sx Class"G"in 12-1/4"Hole 7" 365 sx Class"G"in 9-1/2"Hole 13-3/8" 4-1/2" 86 sx Class"G"in 6"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 200' N/A 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 4,443' 0.150 9-5/8" Intermediate 53.3/L-80/Btc-Mod. 8.535 Surface 14,549' 0.0732 7" ntermediate 29/L-80/Hydril 511 6.184 14,368' 15,877' 0.0372 ). 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 15,722' 16,396' 0.0152 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 15,743' 0.0152 5-1/2" VIT Tubing L-80 13Cr80 3.958 Surface 44' 0.0152 WELL INCLINATION DETAIL KOP @ 50' Max Hole Angle=57 deg.@ 3,390' Max Angle at Top Perf:21 Deg.@ 16,050' JEWELRY DETAIL No Depth Item 1 44' 5-1/2"x 4-1/2"VIT XO,ID=3.958" 2 1,027' 4-1/2"TRM-4E TRSV w/ "X"Profile- ID=3.812" 3 6,666' STA 1:GLM-M MG Dev=55/DMY w/RK Latch/ND @ 4,495'/Port=0/ Set 4/13/2006 4 14,368' _ 9-5/8"x 7"Baker ZXP LTP I` 4 5 14,382' 9-5/8"x 7"Baker Flex Lock Liner Hanger ai 5 6 15,649' 4-1/2"HES"X"Nipple,ID=3.813 .01 7 15,670' 4-1/2"WFD Fiber Optic Transducer w/cable,ID=3.958 8 15,694' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 9-5/8.• • 9 15,718' 4-1/2"HES "X"Nipple,ID=3.813 10 15,728' 11.77'Baker Tie Back 11 15,729' 4-1/2"HES XN Nipple,ID=3.725"(15,712'ELMD 4/15/2006) 12 15,739' Baker 7"x 5"Baker ZXP Top Packer 13 15,743' 4-1/2"Self-aligning Mule Shoe,ID=3.860" 6 14 15,750' Baker 7"x 5"Flex-Lock Liner Hanger Iv 7 15 15,760' 5"x 4-1/2"Cross-over-ID=3.958" PERFORATION DETAIL 9 Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) SPF Shot Date Status Size Mn IC 3.725"@ 16,050' 16,220' 10,914' 11,074' 6 10/22/2010 Open 2-7/8" 15,729' 16,082' 16,112' 10,944' 10,972' 6 6/4/2009 Open 2-7/8" 10 16,090' 16,116' 10,952' 10,976' 6 1/25/20010 Open 2-7/8" III 11 16,112' 16,132' 10,972' 10,991' 6 4/15/2006 Open 2-7/8" la12 16,112' 16,137' 10,972' 10,995' 6 6/28/2008 Open 2-7/8" 14 16,116' 16,142' 10,976' 11,000' 6 1/24/2010 Open 2-7/8" .15 16,132' 16,152' 10,991' 11,010' 6 4/15/2006 Open 2-7/8" 74 & Ivishak 16,137' 16,162' 10,995' 11,019' 6 4/30/2008 Open 2-7/8" 16,142' 16,168' 11,000' 11,025' 6 1/24/2010 Open 2-7/8" 16,152' 16,172' 11,010' 11,028' 6 4/15/2006 Open 2-7/8" = 16,168' 16,194' 11,025' 11,049' 6 1/24/2010 Open 2-7/8" r Ivishak 16,169' 16,194' 11,026' 11,049' 6 9/16/2007 Open 2-7/8" J 16,184' 16,194' 11,040' 11,049' 6 4/14/2006 Open 2-7/8" 16,204' 16,224' 11,059' 11,078' 6 1/24/2010 Open 2-7/8" 44/2" ill 16,204' 16,224' 11,059' 11,078' 6 4/14/2006 Open 2-7/8" TD=16,398'(MD)/TD=11,244(TVD) Reference Log:GR-CCL on 5/15/2006. Note: Refer to production DB for historical perf data. PBTD=16,245'(MD)/PBTD=11,098'(ND) ADDITIONAL INFORMATION GENERAL WELL INFO SAFETY NOTE Location:SEC.11,T13N,R13E,1,339'FSL&649'FEL API:50-029-23293-00-00 Well requires a safety valve, Datum MD=15,655'/Datum ND=10,500'SS Completed by N33E-4/8/06 4-1/2"Chrome Tubing&Liner Revised By:TDF 1/7/2016 For Perf Dates See Table Above • Northstar Unit Well: NS-30 PROPOSED Last Completed: 4/8/2006 IHilcorp Alaska,LLC PTD: 205-207 TREE&WELLHEAD Orig.KBE=56.27'/BFE=40.1'(CB 15.9')Nabors 33E Tree ABB-VGI 5-1/8"5KSI 10. 1 Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20OPEN HOLE/CEMENT DETAIL 20" Driven 1 1 13-3/8" 607 sx AS Lite,465 sx Class"G"in 16"Hole I 2 9-5/8" 1,362 sx Ext.Slurry,450 sx Class"G"in 12-1/4"Hole L 7" 365 sx Class"G"in 9-1/2"Hole 13-3/8" l 4-1/2" 86 sx Class"G"in 6"Hole I; CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 200' N/A 1 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 4,443' 0.150 9-5/8" Intermediate 53.3/L-80/Btc-Mod. 8.535 Surface 14,549' 0.0732 7" ntermediate 29/L-80/Hydril 511 6.184 14,368' 15,877' 0.0372 3 4-1/2" Liner 12.6/13Cr80/Vam Top 3.958 15,722' 16,396' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Top 3.958 Surface 15,743' 0.0152 5-1/2" VIT Tubing L-8013Cr80 3.958 Surface 44' 0.0152 WELL INCLINATION DETAIL - KOP@50' Max Hole Angle=57 deg.@ 3,390' Max Angle at Top Perf:21 Deg.@ 16,050' JEWELRY DETAIL No Depth Item 1 44' 5-1/2"x 4-1/2"VIT XO,ID=3.958" 2 1,027' 4-1/2"TRM-4E TRSV w/ "X"Profile- ID=3.812" 3 6,666' STA 1:GLM-MMG Dev=55/DMY w/RK Latch/TVD @ 4,495'/Port=0/ Set 4/13/2006 4 14,368' 9-5/8"x 7"Baker ZXP LTP 5 14,382' 9-5/8"x 7"Baker Flex Lock Liner Hanger 4 6 15,649' 4-1/2"HES"X"Nipple,ID=3.813 0 , ____ 5 7 15,670' 4-1/2"WFD Fiber Optic Transducer w/cable,ID=3.958 8 15,694' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 9 15,718' 4-1/2"HES "X"Nipple,ID=3.813 9-5/8"a & 10 15,728' 11.77 Baker Tie Back 11 15,729' 4-1/2"HES XN Nipple,ID=3.725"(15,712'ELMD4/15/2006) 12 15,739' Baker 7"x 5"Baker ZXP Top Packer 13 15,743' 4-1/2"Self-aligning Mule Shoe,ID=3.860" 1 6 14 15,750' Baker 7"x 5"Flex-Lock Liner Hanger 7 15 15,760' 5"x 4-1/2"Cross-over-ID=3.958" alk. PERFORATION DETAIL 8 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) SPF Shot Date Status Size 9 16,050' 16,220' 10,914' 11,074' 6 10/22/2010 Open 2-7/8" MnI 0=3.725"@ 15,729' 16,082' 16,112' 10,944' 10,972' 6 6/4/2009 Open 2-7/8" 16,090' 16,116' 10,952' 10,976' 6 1/25/20010 Open 2-7/8" 10 16,112' 16,132' 10,972' 10,991' 6 4/15/2006 Open 2-7/8" JI 11 I, 12 16,112' 16,137' 10,972' 10,995' 6 6/28/2008 Open 2-7/8" 13 14 16,116' 16,142' 10,976' 11,000' 6 1/24/2010 Open 2-7/8" 16,132' 16,152' 10,991' 11,010' 6 4/15/2006 Open 2-7/8" 15 ±16,137' ±16,157' ±10,995 ±11,014' 6 Future Future 2-3/4" - 7 Ivishak 16,137' 16,162' 10,995' 11,019' 6 4/30/2008 Open 2-7/8" 16,142' 16,168' 11,000' 11,025' 6 1/24/2010 Open 2-7/8" 16,152' 16,172' 11,010' 11,028' 6 4/15/2006 Open 2-7/8" ±16,157' ±16,177' ±11,014' :3' 6 FULL Future 2-3/4" • Ivishak 16,168' 16,194' 11,025' 11,049' 6 1/24/2010 Open 2-7/8" 16,169' 16,194' 11,026' 11,049' 6 9/16/2007 Open 2-7/8" 4-1/2'4 16,184' 16,194' 11,040' 11,049' 6 4/14/2006 Open 2-7/8" 16,204' 16,224' 11,059' 11,078' 6 1/24/2010 Open 2-7/8" TD=16,398'(MD)/TD=11,244(TVD) 16,204' 16,224' 11,059' 11,078' 6 4/14/2006 Open 2-7/8" PBTD=16,245'(MD)/PBTD=11,098'(TVD) Reference Log:GR-CCL on 5/15/2006. Note:Refer to production DB for historical perf data. ADDITIONAL INFORMATION GENERAL WELL INFO SAFETY NOTE Location:SEC.11,T13N,R13E,1,339'FSL&649'FEL API:50-029-23293-00-00 Well requires a safety valve, Datum MD=15,655'/Datum TVD=10,500'SS Completed by N33E-4/8/06 4-1/2"Chrome Tubing&Liner Revised By:TDF 1/7/2016 For Perf Dates See Table Above • . \ \I % %/� sA THE STATE Alaska Oil and Gas o f _:- A L AsKA Conservation Commission GOVERNOR SEAN PARNELL � w „ 333 West Seventh Avenue o ALAS' Anchorage, Alaska 99501 -3572 Main: 907.279.1 433 Fax: 907.276.7542 Mark Sauve ���BAR 2013' Petroleum Engineer p `�H BP Exploration (Alaska), Inc. P.O. Box 196612 7 Anchorage, AK 99519 -6612 ° a Re: Northstar Field, Northstar Oil Pool, NS 30 Sundry Number: 313 -101 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, athy P. roerst r Chair DATED this 14 day of March, 2013. End. . (Npx' ` 7 tk RECEIVED • e • STATE OF ALASKA FEB 2 6 201 ALASKA OIL AND GAS CONSERVATION COMMISSION p --, 3 /14 ( 3 APPLICATION FOR SUNDRY APPROVALS AC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ 311 �IZ ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown El Re-enter Susp. Wear] w{ &' ! 4C!C/1 Stimulate 0 ' Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development 0 Exploratory ❑ 205 -207-0 3. Address: . ❑ Service ❑ 6 API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23293 -00 -00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS30 Will planned perforations require a spacing exception? Yes ❑ No ❑ 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 (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16398 • 11244 . 16352 11200 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 169# X -56 40 - 200 40 - 199.98 Surface 4404 13 -3/8" 68# L -80 39 - 4443 39 - 3254.51 5020 2260 Intermediate None None None None None None Production 14511 9 -5/8" 53.5# L -80 38 - 14549 38 - 9560.39 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 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and ND (ft): See Attachment for Packer Depths 4 -1/2" SSV Nipple 102T, 1013.6' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development al ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark.Sauveabo.com Printed Name Mark Sauve Title PE Signature / Phone 564 -4660 Date 2/26/2013 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 31 3 ' (0 ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMB MAR 1 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / 0 —4 p 4 ��� / /7) APPROVED BY Approved by: / / - 1 COMMISSIONER THE COMMISSION Date: 2 — ; 4-- /.3 Form ofte i 1 App roved application is valid for 12 months from the date of approval. Submit in Duplic i �°�'�l 3/i'f1 V .- 66 • • To: ADW Wireline Team Lead Date: 19- Feb -13 ADW Well Service Team Lead AFE: ANSCAPSU Josh Allely - Wells Group PE Matt Brown - Wells Group PE From: Mark Sauve- North Star PE IOR: 250 Subject: NS30 CT Acid Stim Procedure Please perform the following: 1. C Mud Acid Stimulation Job Objectives The objective of this job is to stimulate all open perforations with HCL and mud acid to remove skin - damage caused by scale and fines migration. Well Detail Current Status: Operable Producer Integrity Status No annular communication. Last Test: 03/04/11: 2235 bfpd 37.3% WC. 47.3 mmscfpd. 818 psi ftp 141 deg F wht. Max Inclination: 57.5deg at 3390; Top Perf 22deg at 16,050' MD Max Dog Leg: 5.6 at 1,214' MD Minimum ID: 3.725" at the 4 -1/2" XN Nip at 15,729" MD Last TD tag: 10/06/10: Tagged 16,220' ELMD with 2 -7/8" dummy gun Last Downhole Op: 10/22/10: E -Line AddPerf 16050 -16220 BHP /BHT: 09/11/09: 5,097 psi / 241 °F at 11,100 ft sstvd H2S: None Well History NS30 is a 2006 development well at Northstar. It is a 4'/2" Chrome mono -bore completion. Initial production was -8100 BOPD. The well declined to -6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31/06. On 8/1/06 the acid treatment locked up after 231 bbls. Despite the complications, production rose to about -7000 bopd and within a year declined to around -4000 bopd. Subsequent to the 2006 acid treatment an add /reperf intervention performed on 9/19/07 resulted in -900 bopd increase. Two 2008 re -pert interventions resulted in -200 bopd increase each. 2009 add perfs to the upper sands at 16,082- 16,112' resulted in -600 bopd increase. Total formation gas has since increased from -40 to 50 MMSCFD. A Memory PPROF performed 11/19/09 indicates no production at all from 16184' - 16224' MD perfs, - half of total gas entering from top 6' of perforations, and almost all oil at moderate GOR entering from 16090'- 16134' MD. In January 2010 the well was perforated across a broad interval from 16,090' - 16,224' MD resulting in a nice -200 bopd IOR boost. However, an HCL bullhead acid stimulation pumped on April 24, 2010 apparently damaged the formation and it was not until October when re- perfs were able to reverse the situation. Please contact Josh Allely at 564- 5732(w), 350- 7362(c), or Mark Sauve at 748- 2865(c) or 564 - 4660(w) with any questions or comments. 1 • • BOP Stack: BSEE and Schlumberger CAT II. The SITP of NS30 is above 3500 psi putting it into the CAT II status as defined by Schlumberger. It is also a federally regulated BSEE well which carries it's own set of BOP requirements. Appendix A contains a detailed BOP schematic we will be using on NS30. This schematic requires modifying the arrangement of the quads as described in Appendix A. Please use this exact BOP schematic, changes are not allowed once approved by the BSEE. Job Considerations Obtain an oil sample from NS30 and have it delivered to the Schlumberger lab for pre -job emulsion /sludge testing one week before the acid stim. Verify the mud acid and hydrochloric design is acceptable for application. Test both live and spent acid with the crude oil to ensure there is no sludge or emulsions. Ensure a lab report is sent to the CT scheduler prior to loading out the acid. Ensure NS operations understands the scope of work to be performed including the acid flowback to - the facility and the wellhead neutralization of the mud acid using magnesium oxide. The flowback procedure will be added as an attachment to this procedure. If the CT string is new and has not had acid pumped through it at any time, make provisions to pickle the CT string prior to coming out to Northstar. This acid stimulation utilizes mud acid. Major loss of permeability is possible if the HF acid is not flowed back as soon as feasible. Keep this in mind while POOH and make preparations to get off of well and have it ready to turn over to operations for flowback after securing the well and popping off. Relevant PE Manual Sections Alaska Wells Group Recommended Practice: Acidizing with Coiled Tubing Alaska Drilling and Wells Recommended Practice: Acid Safety and General Rig Up Alaska Drilling and Wells Guidance Document: Risk Analysis — Acidizing 2 • • 1. MIRU CT Unit. Ensure RU / BOP stack arrangement matches the schematic in Appendix A. Perform a BOP test per BSEE requirements. 2. MU 2.0" OD JSN. /Q1 3. Fluid pack well with 3% NH4CI per pump schedule [Appendix B]. It is acceptable to begin RIH before well is completely fluid packed. 4. RIH down to TD and tag bottom. While RIH, continue to pump minimum 0.5 bpm down the backside to ensure well stays fluid packed. 5. Dry tag TD and use last SL corrected tag of 16,220' ELMD to correct depth. All depths in this procedure reference ELMD. PUH 10' and flag pipe. Do not go deeper than this depth during the acid stimulation. 6. Keep nozzle at flag and prepare for acid stim. While preparing for acid stim, begin pumping NH4CI down the coil flushing 60/40 and, once NH4CL is at the nozzle, continue pumping a minimum of 100 bbls of NH4CI at max CT rate. This is intended to cool the perfs as much as possible before pumping the acid and diversion steps. 7. After all preparations to pump acid have been made (pressure testing, safety meetings, etc), begin pumping the attached pump schedule. Please remember the following: • Always attempt to pump max rate at the highest specified pressure (typically 4000 psi). Rate will be dictated by friction pressure and this will vary with different fluids. • After pumping the first acid and diversion stage, the CT will be parked above the perfs and further reciprocations across the perfs will not be made. • Filter all water that is placed in UR tanks using the Northstar filter pots. If fluid is pumped directly off of a truck, filtering is not necessary. Do not filter any fluid with the L066 scale inhibitor. • When making passes across perforations, ensure entire interval is covered by jetting 15' above and below perforations. With NS30, the bottom interval will be the flag due to lack of rathole. • Fracture gradient of Northstar is 0.7 psi /ft. With a backside column of 3% NH4CI (0.437 psi /ft), a maximum WHP of 2900 psi is possible without fracturing the formation. • If well locks up during acid stimulation, open choke and flush remaining acid from CT by taking returns up the backside. Once the all the acid is over the gooseneck (but not necessarily out of the CT), attempt to work acid into perfs by slowing increasing the treating pressure. It is acceptable to go over frac gradient. It this occurs, pump several bbls above frac gradient and then let fractures close and see if injectivity has improved. Continue this until either all the acid is away or injectivity below frac gradient returns. Downhole conditions will dictate whether or not the acid job is resumed after a lock up event. 8. POOH. Secure well and begin RD. Well will be turned over to Northstar operations for flowback. 3 1 • WEE . 4684/G1 6.1ff filtS1 W AFETY Y NOES: ELL A REQUIRES =V '441131).EAD. 4061-VG1 13-4Ir NULTROWL 61,2310 N S S30 ""411-1112* 001011BT USG & Lmr --mommetvm_L ACTUATOR . &AMER 1•.153/ ; ' ----- -- girl' • Iii 4g• H5-1/2" x4 0. asfor I KOP . Sr 1027. FIS V? 1F044ETIVIV WWII Lip. 1 5655' s i X PROFLE ID. astr 111■4 -- . ---- 11 34.6" CSG, LEA Loa sic 13 . 12_41 e I - 1 4443' GAS LET 111171 ' Minimum ID -3.725" fA 15729' gr i lc I 171 C r 6 I lYPE 1 VIM I LAI171 1 7 1: 4-112" HES XN NIPPLE ITCP OF r LNR 7 11L. T a d . a - • • 14368 I- 91 X r ERR Z4CP L111 Et . 7 1 I in 143ar H x r ma FUN WO( Lig D .r I Is CM, 61511, 140 (MC, D. 0.535' H 1450 15648 H41 17 KB X PIP, D • EA tr I II lea" H41 /7 RINR CAM IRMO:SEER 0 . 3.956' lase FIT X 41 fr SCR S-3 RR, 13. 1675 1 III FA.1 M 15718 H4-1rr FES X NP, 13 . allir I 1572, 41 rr FEB XIN 41 ID - 372 I1CP OF 4-1 rr UR 114717 RAI 014401111416) 4- V7 TOG, 12 OP, 13011 VAIII-TOP, 15783 Ot 1 * - 11 Jr 01CFITIEMOC, D. ? 52 IV, ID. 3.950' Ma.. j . 1' X 0 FM 110 LW, D - r 1.116. 2914 460 14/13ML 621, 158TT la II! 1574y 41,2 MY MIMIC RUM, 13 •21_0111* 0313 41, u.athe k REEFORKBONSUAIRRf -• ' r 7 X S' BKFt FLBC LOO( PGR El - 7 I REF WO GRCO_ MSC 51013 157 wy HS' z4-1.7 xo, a. agfir 4143LE AT TOP FEW: 2 m 16050 1 RearloProlar km 136 kr halortill FAA data SIZE SPF B11E46/14/1113) Oprekiz DATE 2.70" 6 16050 -1622D o 10O2/10 2.716 6 46062 - 1St t2 0 0&01.09 2-7Er 6 46060 -10166 0 0105/10 2-78 8 6 tat t2 -16132 0 04/15/06 I 2-78 6 1012 - 10137 0 06426438 2-74r 13 101 22 -, 16152 0 01/16416 I 2-74r 6 161 37 -, 10102 0 MOMS 2-716 6 16162 -16472 0 04115.0€ 2.? 6 1011611 - 10194 0 01124110 2-70r 18 1 MN - 16194 0 01/1406 2-Z8 - 8 196 -16224 0 01 /24/1 0 I 2-78 6 196 - 16224 0 04/1400 4J4 12, CR VA 16201 RIT LR 10 'OII-TOP, ireff rffel-- n 1.4" ata 0152 &pi, Cl. 1661r DA1E RN BY COAENTS 041E RS/ BY COMENTS tCRTFISTAR 4411141111 PON ACTUAL car PLETIDN 10d/10 WFIVFOC FERFS (1 01221101 NELL: NSW 0511146 &JILIN PEEPS (0492146) 02/17 /11 AMMO ALEECISSW SAFETY N01E FENN' ND: %621370 07/W %WRAC ALPERFS (06121101) AR lex 50-029-23293-02 0131146 3 FiCTITLN AEFERFS (06/04105) SEC 11. T136t ROE 13:51? FEL 6.649 FEL 02109/10 RIIMPUO REFS (21/24 25/10) 1026/10 BEEP.0 SM NOW (IMMO) IP arplurallast (Mask 4 4 • • Minilog for Well Techlog Project : NORTNSTAR NS30 Author LAURAJ. LARSON Scale: 1:700 Date 6/25/2012 Producer Well: N530 UWI: 500292329300 Elevation: 56.27 X: SPUD date: 2006-02-05 00:00:00 Country : USA Short name: NS30 Elevation datum: RF Y: Completion date: 2006 -04 -14 00:00:00 Field: NORTNSTAR Long name: NORTHSTAR NO 30 Total depth: 16398 Longitude: - 148.6933346 Status: State: Alaska Coordinate system: NAD27 AFT Latitude: 70.4913416 Operator: BPXA Company: BPXA Or t7' _. Ns an i]fUtaTI(1N F mMV »� ul∎b Neutron Porosity 5l N 4 (FE s TVOSS MD Notes ^ NC. 151 n ET) (k� PE Notes RES MED DEN PE Q I n NCin 1 NC n OFF nn 1:700 1:700 n, RES geSMal nn .r. 561n RFCT RN(1R .— SWT a R DR C RES OEP NOSS P06 O • 1. ' ''i ',ArS2:. • X v.aa. .,m a1 rv� Cw ca y Fv our III 10150 - 0/W/G '1 I I I I 15GR ... _Y^ 10700 - I \ I I I I -� _- _ ii • ' . I I 10750 1 l'-'A . . Za M. !W I • Illt -10800 t I I . i. :l- 16000 - I 1 -ill F - 10850 I p TZE t I - PERF 4PF PERF RPF I PELF RP _ Al - 10900- &.-4. 16100: PERF RPF _ AN I PF I ERF RPF 100/0/100 PERF RPF t / 10950, P I �= 1 1 PERF REF PFRF RPF .. 0 /0 /0 PERF RPF < mill - 11000x16200 + — PERF RPF _ r` � er 'az IN PERF RPF l►" J = __ t i I. 0 I I I I • 11050 - I- I I I I I . 16300 - I I i t I 1 TZB � 11100 - C I TZA2 -11150, - I I -- —r '-16400 I I I I I 5 • • Appendix A: BOP and Valve Manifold Detail Northstar CAT II /BSEE BOP Rig up Triplex Pump For NS -30 L vs ill -:- :zxzeuu vw. 3 MEW 9i 4.060" 10K ps P Pe' Bowen Conne.& on 4C6C CKpP Quad BOP �.._ �� Blind/Shear Ram I # • - _� Blind/Shear Ram !Kh; , blank blank i Y4 ' 40 • im..yl, H Slip /P RarR CC777 Bimd/Shear Ram 24 - ;; 4060' YOK Da, Aw , 10: 4 56 PO Range 1► J ij 10 n ..�. 5.Y25'4K 016 1440 ICI Po- ..n o, I ! —1p !d CM00 Blind /Shear Ram { ' ,- p --) 4.06" 10K EH Series QUAD BOP; Blind /Shear Ram fi i6 -. , 1° 4.06 10K Flange (Top) x 4.06" 10K Flange (Bottom) BLANK .._� 1.3' BLANK 4 L.r Slip /Pipe Ram ,1 i t, f B. 4.06" 10K EH Series COMBI BOP; Blind /Shear Ram . a 4.06" 10K Flange (Top) x 4.06" 10K Flange (Bottom) 4.06" 10K Flange (Top) x R39 5K Flange (Bottom) 6 • • Appendix B: Pump Schedule - Load Well 3% NH4CI + 0 2% F103 295 Initial fluid pack, bullhead at max rate. - RIH 3% NH4CL + 0.2% F103 100 Pump down the backside at 0.5 bpm while RIH to keep well fluid packed. 1 Perf Cooling 3% NH4CI + 0.2% F103 90 Position nozzle at flag for perf cooling. 2 Spacer 3% NH4CI + 0.2% F103 10 Nozzle should be at the top of the perfs when acid first exits nozzle 3 HCI 12% HCI 70 Make at least 3 up /down passess across perforations. 4 Mud Acid 9:1 Mud Acid 50 Make at least 2 up /down passess across perforations. 5 Spacer 3% NH4CI + 0.2% F103 20 Make at least 1 up /down passess across perforations. 6 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 Make at least 2 up /down passess across perforations. 7 Overflush 3% NH4CI + 0.2% F103 70 Make at least 2 up /down passess across perforations. 8 Diversion Wax Beads + 20ga1 /1000 Oilseeker 9 Position nozzle at 16000 and continue with stim at this depth 9 Spacer 3% NH4CI + 0.2% F103 10 10 HCI 12% HCI 50 11 Mud Acid 9:1 Mud Acid 50 12 Overflush 3% NH4CI + 0.2% F103 20 13 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 14 Overflush 3% NH4CI + 0.2% F103 70 15 Diversion Wax Beads + 20ga1 /1000 Oilseeker 9 16 Spacer 3% NH4CI + 0.2% F103 10 17 HCI 12% HCI 50 18 Mud Acid 9:1 Mud Acid 50 19 Overflush 3% NH4CI + 0.2% F103 20 20 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 21 Overflush 3% NH4CI + 0.2% F103 70 22 Diversion Wax Beads + 20ga1 /1000 Oilseeker 9 23 Spacer 3% NH4CI + 0.2% F103 10 24 HCI 12% HCI 50 25 Mud Acid 9:1 Mud Acid 50 26 Overflush 3% NH4CI + 0.2% F103 20 27 Scale Inhibitor 3% NH4CI + 0 2% F103 + 5% L066 50 28 Overflush 3% NH4CI + 0.2% F103 70 Total Volume (starting from stage 1) 1137 At an average of 1.2 bpm, this job will take 947 minutes (15 hours) 1 Working Fluid 3% NH4CI + 0.2% F103 X 885 Extra fluid should be available in case of operational difficulties 2 HCI 12% HCI 220 See HCI recipie. 3 Mud Acid 9:1 Mud Acid 200 See mud acid recipe. 4 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 200 Do not filter this fluid. 5 Diversion Wax Beads + 20ga1 /1000 Oilseeker 27 Oilseeker is being used instead of HEC gel to carry the wax beads. 1 NH4CI Amount in LBS 11393 Ibs or 228 501b sacks 2 F103 Surfactant 91 gal 3 L066 Scale Inhibitor 420 gal 4 Wax Beads Diverter 1136 Ibs 5 Oilseeker Viscous Diverter 11 gal A264 8 10 gal /Mgal Corrosion Inhibitor A201 60 60 gal /Mgal Inhibitor Aid A153 10 20 Ib /Mgal Intensifer F103 2 2 gal /Mgal Flowback Aid L058 20 20 lb /Mgal Iron Control W054 5 5 gal /Mgal Antiemulsifier U067 0 50 gal /Mgal Mutual Solvent 7 • • Perforation Attachment ADL0312808 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS30 10/22/10 APF 16050 16070 10914 10933 NS30 10/21/10 RPF 16070 16082 10933 10944 NS30 10/21/10 RPF 16082 16090 10944 10951 NS30 10/20/10 RPF 16090 16110 10951 10970 NS30 10/20/10 RPF 16110 16112 10970 10972 NS30 10/20/10 RPF 16112 16116 10972 10976 NS30 10/20/10 RPF 16116 16130 10976 10989 NS30 10/19/10 RPF 16130 16132 10989 10991 NS30 10/19/10 RPF 16132 16137 10991 10995 NS30 10/19/10 RPF 16137 16142 10995 11000 NS30 10/19/10 RPF 16142 16150 11000 11008 NS30 10/15/10 RPF 16150 16152 11008 11010 NS30 10/16/10 RPF 16152 16155 11010 11012 NS30 10/16/10 RPF 16155 16162 11012 11019 NS30 10/16/10 RPF _ 16162 16168 _ 11019 11025 NS30 10/16/10 RPF 16168 16169 11025 11026 NS30 10/16/10 RPF 16169 16170 11026 11027 NS30 10/16/10 RPF 16170 16172 11027 11028 NS30 10/16/10 RPF 16172 16175 11028 11031 NS30 10/16/10 RPF 16175 16184 11031 11040 NS30 10/15/10 RPF 16184 16194 11040 11049 NS30 10/15/10 RPF 16194 16195 11049 11050 NS30 10/15/10 RPF 16195 16204 11050 11059 NS30 10/15/10 RPF _ 16204 16220 11059 11074 NS30 10/15/10 APF 16220 16224 11074 11078 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 Casing Summary ADL0312808 Casing Length Size MD Top MD Base TVD Top ND Base Burst Collapse Grade CONDUCTOR 160 20" 169# X -56 40 200 40 200 4260 2590 X -56 LINER 674 4 -1/2" 12.6# 13Cr8( 15722 16396 10617 11242 8430 7500 13Cr80 LINER 1509 7" 29# L -80 14368 15877 9404 10757 8160 7020 L -80 PRODUCTION 14511 9 -5/8" 53.5# L -80 38 14549 38 9560 7930 6620 L -80 SURFACE 4404 13 -3/8" 68# L -80 39 4443 39 3255 5020 2260 L -80 TUBING 15608 4 -1/2" 12.6# 13Cr8( 135 15743 135 10636 8430 7500 13Cr80 • TUBING 98 5 -1/2" X 4 -1/2" VIT 37 135 37 135 • . • • Packers and SSV's Attachment ADL0312808 Well Facility Type MD Top Description TVD Top NS30 SSSV 1027 4 -1/2" SSV Nipple 1014 NS30 PACKER 14368 7" Baker ZXP Top Packer 9404 NS30 PACKER 15694 4 -1/2" Baker S -3 Packer 10592 NS30 PACKER 15739 4 -1/2" Baker ZXP Packer 10632 TREE= ` ABB -VGI 5 -1/8" 5 51 ' NOTES: WELL REQUIRES A SSSV. WELLHEAD = ABB -VGI 13-5/8" MULTIBOWL 5 '''BOEMRE WELL *** '"` *** NS30 4 -1/2" CHROMETBG & LNR" ACTUATOR = BAKER KB. ELEV = 56.27' ∎ - BF. ELEV = 40.1' (CB 15.9') 44' H5 -1/2" X 4 -1/2" VIT, ID = 3.958" I KOP = 50' Max Angle = 57° @ 3390' 410 I 1027' I- 4 -1/2" TRM-4E TRSV Datum MD = 15655' w / X PROFILE, ID = 3.812" Datum TVD = 10500' SS 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 4443' L. GAS LIFT MANDRELS ST MD TVD DEV TYPE I VLV LATCH PORT DATE Minimum ID = 3.725" @ 15729' 1 6666 4495 55 MMG DMY RK 0 04/13/06 4 -1/2" HES XN NIPPLE 'TOP OF 7" LNR H 14368' I ( 14368' H9-5/8" X 7" BKR ZXP LTP, ID = ?" 1--H 14382' H9-5/8" X 7" BKR FLEX LOCK LTP, ID = ?" I 9 -5/8" CSG, 53.5 #, L -80 BTM-C, ID = 8.535" I—I 14549' I.--A L. I 15649' 114 -1/2" HES X NIP, ID = 3.813" I ' 15670' H4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" I 15694' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.875" 1 I 15718' H4 -1/2" HES X NIP, ID = 3.813" I I 15729' - 4-1/2" HES XN NIP, ID = 3.725" TOP OF 4-1/2" LNR I-1 15728' (15712' ELM O (04/15/06) 4 -1/2" TBG, 12.6 #, 13CRVAM -TOP, —I 15743' 0152 bpf, ID = 3.958" —1 15728' -I 11.77' BKR TIEBACK, ID = ?" I 7" LNR, 29 #, L -80 HYDRIL 521, -1 15877' :,71 , 4 I 15739' -1 7" X 5" BKR ZXP LTP, ID = ?" I .0383 bpf, ID = 6.184" 15743' —14-1/2" SELF ALIGNING WLEG, ID = 3.860" 1 PERFORATION SUMMARY 15750' -1 7" X 5" BKR FLEX LOCK HGR, ID = ?" I REF LOG: GR -CCL ON 04/15/06 15760' -I5" x 4 -1/2" XO, ID = 3.958" I ANGLE AT TOP PERF: 21° @ 16050' lk Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 16050 - 16220 0 10/22/10 I 2 -7/8" 6 16082 - 16112 0 06/04/09 2 -7/8" 6 16090 - 16168 0 01/25/10 I 2 -7/8" 6 16112 - 16132 0 04/15/06 2 -7/8" 6 16112 - 16137 0 06/28/08 2 -7/8" 6 16132 - 16152 0 04/15/06 I 2 -7/8" 6 16137 - 16162 0 04/30/08 2 -7/8" 6 16152 - 16172 0 04/15/06 I 2 -7/8" 6 16168 - 16194 0 01/24/10 2 -7/8" 6 16184 - 16194 0 04/14/06 I 2 -7/8" 6 16204 - 16224 0 01/24/10 2 -7/8" 6 16204 - 16224 0 04/14/06 4 -1/2" LNR, 12.6 #, 13CRVAM -TOP, -{ 16396' v�� e,,,,, I 16245' H PBTD I 6 44.444A. .0152 bpf, ID = 3.958" DATE REV BY COMMENTS I DATE REV BY COMMENTS NORTHSTAR 1 04/08/06 N33E ACTUAL COMPLETION 10/26/10 WRR/PJC PERFS (10/22/10) WELL: NS30 05/11/08 JLJ/TLH PERFS (04/30/08) 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 2052070 07/07/08 WRR/JMD ADPERFS (06/28/08) API No: 50- 029 - 23293 -00 06/14/09 RCT/TLH ADPERFS (06/04/09) SEC 11, T13N, R13E, 1339' FSL & 649' FEL 02/03/10 RRD /PJC PERFS (01/24- 25/10) 10/26/10 BSE/PJC SFTY NOTE (10 /08/10) BP Exploration (Alaska) • • sulf[E AlturKA /SEANPARNELL.GOVERNOR �T�+ t� �S OIL AND GAS 333 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mark Sauve Petroleum Engineer ats-Y) BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 311 -088 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, 4 Daniel T. - -mount, Jr. Chair r DATED this 2 'day of March, 2011. Encl. STATE OF ALASKA c kI " ECE_ ' `'" j - ALASKAQAND GAS CONSERVATION COMMISSIO + C IA 2 2011 - APPLICATION FOR SUNDRY APPROVALS p 3. 7 ,7 2 1.7,7 20 AAC 25.280 Alaska Oil * Cite 1. C m . . 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ C ange A pro ed g Suspend ❑ Plug Perforations ❑ Perforate U Pull Tubing ❑ Anchom Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate F•I 9 4ter Casing ❑ Other: MUD ACID STIMULATION . El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development is _ Exploratory ❑ 205-2070 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23293 -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 ❑ NS30 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 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): 16398 - 11243.78 - 16245 11097.6. NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 13 -3/8" 68# L -80 40 4438 40 3252 4930 2270 Production 9 -5/8" 53.5# L -80 39 14420 39 9449 7930 6620 Production 9-5/8" 47# L -80 14420 14544 9449 9556 6870 4760 Liner 7" 29# L -80 14368 15789 9404 10678 8160 7020 Liner 7 "26# L -80 15789 15877 10678 10757 7240 5410 Liner 4 -1/2" 12.6# 13CR80 15722 16396 10617 11242 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5 -1/2" 17# L -80 41 135 - - 4 -1/2" 12.6# 13CR80 135 15740 Packers and SSSV Tvoe: 9 -5/8" X 7" BKR ZXP LTP Packers and SSSV MD and TVD (ft): 14368 9404 7" X 4 -1/2" BKR S -3 PKR 15694 10592 7" X 5" BKR ZXP LTP 15739 10632 12. Attachments: Description Summary of Proposal Ei 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for , I 15. Well Status after proposed work: Commencing Operations: 3/2 11 11•• I t . , Oil IS 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 - L - -�. 564 -4660 3/22/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '1 1'1)83 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Re uired: /D _ L/D 4 7/ APPROVED BY Approved by: CO -'• COMMISSION Date: 3/211i 1 - ,, MAR 2 9201 sz3.: Form 10-403 'evised 1/21 0 -..r4' Submit in Duplicate 'rr NS30 205 -207 - PERF ATTACHMENT Sw Name /Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132: 6,132 10,971.92 10,990.69 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11 077.66 1 NS30 f 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15106 L PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,132. 16,137 10 990.69 10,995.39 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 1 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 i 6/28/08 I RPF � _ 16,112. 16,137 . 10,971.92 � 10,995.39 NS30 6/4/09 APF 16,082 16,112 j 10,943 92' 10 971.92 II NS30 1/24/10 APF 16,204. 16,224. 11,058.7 11,077.66 NS30 1/24/10 ; APF 16,168. 16,194. 11,024.64 11,049.23 NS30 1/25/10 APF 16,090. 16,116._ 10,951.37 10,975.67 NS30 1/25/10 APF 16,116 , 16,142. 10,975.67 11 000.1 - - - - - -- - - -- NS30 1/25/10 APF 16,142. 16,168. 11,000.1 11,024.64 NS30 10/15/10 RPF 16,170. 16,195 11,026.53 11 05018 NS30 10/15/10: RPF 16,195. 16,220 11,050.18 11,073.87 NS30 + 10/15/10)21 16,150. 16,170 11,007.65 11,026.53 26 NS30 I 10 /16 /10iRPF � 16,155. 16 175 ' 11,012.37 11,031 26 NS30 10/19/10 RPF 16,130. 16,150. 10 988.81 11,007 65 NS30 10/20/10 RPF 16,090. t 16,110. 10,951.37 10,970.05 NS30 10/20/10 RPF 16,110. 16 130.1 10,970.05 10 988.81 NS30 10/21/10 RPF 16,070. 16,090.1 10,932.76 10 951.37 NS30 10/22/10 I APF 16,050. 16,070 10,914.24 10 932.76 AB ABANDONED — PER PERF APF } ADD PERF RPF REPERF + • - - - - - -- - — - -- - - -- BPP BRIDGE PLUG PULLED SL SLOTTED LINER i BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED TSQZ SQUEEZE _ - - - - - -- - - -- -- MIS MECHANICAL ISOLATE D STC STRADDLE PACK CLOSED MLK MECHANICAL LEAK STO ISTRADDLE PACK, OPEN OH ;OPEN HOLE 1 T bp • • To: ADW Wireline Team Lead Date: 03/19/2010 ADW Well Service Team Lead AFE: AMSFLDWL30 From: Josh Allely - Wells Group PE IOR: 250 Subject: NS30 CT Acid Stim Procedure Est. Cost: Please perform the following: 1. C Mud Acid Stimulation Job Objectives The objective of this job is to stimulate all open perforations with HCL and mud acid to remove skin damage caused by scale and fines migration. Well Detail Current Status: Operable Producer Integrity Status No annular communication. Last Test: 03/04/11: 2235 bfpd 37.3% WC. 47.3 mmscfpd. 818 psi ftp 141 deg F wht. Max Inclination: 57.5deg at 3390; Top Perf 22deg at 16,050' MD Max Dog Leg: 5.6 at 1,214' MD Minimum ID: 3.725" at the 4 -1/2" XN Nip at 15,729" MD Last TD tag: 10/06/10: Tagged 16,220' ELMD with 2 -7/8" dummy gun Last Downhole Op: 10/22/10: E -Line AddPerf 16050 -16220 BHP /BHT: 09/11/09: 5,097 psi / 241°F at 11,100 ft sstvd H2S: None Well History NS30 is a 2006 development well at Northstar. It is a 4W Chrome mono -bore completion. Initial production was -8100 BOPD. The well declined to -6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31/06. On 8/1/06 the acid treatment locked up after 231 bbls. Despite the complications, production rose to about -7000 bopd and within a year declined to around -4000 bopd. Subsequent to the 2006 acid treatment an add /reperf intervention performed on 9/19/07 resulted in -900 bopd increase. Two 2008 re -perf interventions resulted in -200 bopd increase each. 2009 add perfs to the upper sands at 16,082- 16,112' resulted in -600 bopd increase. Total formation gas has since increased from -40 to 50 MMSCFD. A Memory PPROF performed 11/19/09 indicates no production at all from 16184' - 16224' MD perfs, half of total gas entering from top 6' of perforations, and almost all oil at moderate GOR entering from 16090'- 16134' MD. In January 2010 the well was perforated across a broad interval from 16,090' - 16,224' MD resulting in a nice -200 bopd IOR boost. However, an HCL bullhead acid stimulation pumped on April 24, 2010 apparently damaged the formation and it was not until October when re -perfs were able to reverse the situation. Please contact Josh Allely at 564- 5732(w), 350- 7362(c), or Mark Sauve at 748- 2865(c) or 564 - 4660(w) with any questions or comments. 1 • • • BOP Stack: BOEMRE and Schlumberger CAT II. The SITP of NS30 is above 3500 psi putting it into the CAT II status as defined by Schlumberger. It is also a federally regulated BOEMRE well which carries it's own set of BOP requirements. Appendix A contains a detailed BOP schematic we will be using on NS30. This schematic requires modifying the arrangement of the quads as described in Appendix A. Please use this exact BOP schematic, changes are not allowed once approved by the BOEMRE. Job Considerations Obtain an oil sample from NS30 and have it delivered to the Schlumberger lab for pre job emulsion /sludge testing one week before the acid stim. Verify the mud acid and hydrochloric design is acceptable for application. Test both live and spent acid with the crude oil to ensure there is no sludge or emulsions. Ensure a lab report is sent to the CT scheduler prior to loading out the acid. Ensure NS operations understands the scope of work to be performed including the acid flowback to the facility and the wellhead neutralization of the mud acid using magnesium oxide. The flowback procedure will be added as an attachment to this procedure. If the CT string is new and has not had acid pumped through it at any time, make provisions to pickle the CT string prior to coming out to Northstar. 1/ This acid stimulation utilizes mud acid. Major loss of permeability is possible if the HF acid is not flowed back as soon as feasible. Keep this in mind while POOH and make preparations to get off of well and have it ready to turn over to operations for flowback after securing the well and popping off. Relevant PE Manual Sections Alaska Wells Group Recommended Practice: Acidizing with Coiled Tubing Alaska Drilling and Wells Recommended Practice: Acid Safety and General Rig Up Alaska Drilling and Wells Guidance Document: Risk Analysis — Acidizing 2 i 1. MIRU CT Unit. Ensure RU / BOP stack arrangement matches the schematic in Appendix A. Perform a BOP test per BOEMRE requirements. 2. MU 2.0" OD JSN. 3. Fluid pack well with 3% NH4CI per pump schedule [Appendix B]. It is acceptable to begin RIH before well is completely fluid packed. 4. RIH down to TD and tag bottom. While RIH, continue to pump minimum 0.5 bpm down the backside to ensure well stays fluid packed. 5. Dry tag TD and use last SL corrected tag of 16,220' ELMD to correct depth. All depths in this procedure reference ELMD. PUH 10' and flag pipe. Do not go deeper than this depth during the acid stimulation. 6. Keep nozzle at flag and prepare for acid stim. While preparing for acid stim, begin pumping NH4CI down the coil flushing 60/40 and, once NH4CL is at the nozzle, continue pumping a minimum of 100 bbls of NH4CI at max CT rate. This is intended to cool the perfs as much as possible before pumping the acid and diversion steps. 7. After all preparations to pump acid have been made (pressure testing, safety meetings, etc), begin pumping the attached pump schedule. Please remember the following: • Always attempt to pump max rate at the highest specified pressure (typically 4000 psi). Rate will be dictated by friction pressure and this will vary with different fluids. • After pumping the first acid and diversion stage, the CT will be parked above the perfs and further reciprocations across the perfs will not be made. • Filter all water that is placed in UR tanks using the Northstar filter pots. If fluid is pumped directly off of a truck, filtering is not necessary. Do not filter any fluid with the L066 scale inhibitor. • When making passes across perforations, ensure entire interval is covered by jetting 15' above and below perforations. With NS30, the bottom interval will be the flag due to lack of rathole. • Fracture gradient of Northstar is 0.7 psi /ft. With a backside column of 3% NH4CI (0.437 psi /ft), a maximum WHP of 2900 psi is possible without fracturing the formation. • If well locks up during acid stimulation, open choke and flush remaining acid from CT by taking returns up the backside. Once the all the acid is over the gooseneck (but not necessarily out of the CT), attempt to work acid into perfs by slowing increasing the treating pressure. It is acceptable to go over frac gradient. It this occurs, pump several bbls above frac gradient and then let fractures close and see if injectivity has improved. Continue this until either all the acid is away or injectivity below frac gradient returns. Downhole conditions will dictate whether or not the acid job is resumed after a lock up event. 8. POOH. Secure well and begin RD. Well will be turned over to Northstar operations for flowback. 3 D . Triplex Rump C _ Northstar CAT II / BOEMRE BOP Rig up — – -; CD ila For NS-30 and NS -06 I lei (7xzeoa yaw a k Bee 2x2ea,vak.. D 03 0 ID / -0 zu a 16141 c' Lao! 0»n, 3 0 10 0. a I 4.080' 10K pea I If V ' Ben r+ Stipp" 11) f 1 4. 080' ¶OK pm R;ser Bowen oomec0m i 4. i�P s] 16I e riiig -w"x .a"x- _13 Blind/ Stoat Rae K ' Pad I tN.— . _IIII. , 1 ,., .. 7 tfi. 8endd Shea Ram g 111 410 20 ii* .: - U 40 tri __44. �^ Bond! Shear Ram t_., 4• 41 4.060' 10K - 4. 060'SKPM Range L? 41 1 • •i fie] 41 ! • 5.125» 5K eel f�ege 1 e �1• =a•+ ®e i1 Ccm +m Kt Pon Esal '. Va!ve� Compmc, C4 Nava ♦ ■ try .. yQ. w I. 1 III iI T • • Appendix B: Pump Schedule - Load Well 3% NH4CI + 0.2% F103 295 Initial fluid pack, bullhead at max rate. - RIH 3% NH4CL + 0.2% F103 100 Pump down the backside at 0.5 bpm while RIH to keep well fluid packed. 1 Perf Cooling 3% NH4CI + 02% F103 90 Position nozzle at flag for perf cooling. 2 Spacer 3% NH4CI + 0.2% F103 10 Nozzle should be at the top of the perfs when acid first exits nozzle 3 HCI 12% HCI 70 Make at least 3 up /down passess across perforations. 4 Mud Acid 9:1 Mud Acid 50 Make at least 2 up /down passess across perforations. 5 Spacer 3% NH4CI + 0.2% F103 20 Make at least 1 up /down passess across perforations. 6 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 Make at least 2 up /down passess across perforations. 7 Overflush 3% NH4C1 + 0.2% F103 70 Make at least 2 up /down passess across perforations. 8 Diversion Wax Beads + 10ga1/1000 Oilseeker 9 Position nozzle at 16000 and continue with stim at this depth 9 Spacer 3% NH4CI + 0.2% F103 10 10 HCI 12% HCI 50 11 Mud Acid 9:1 Mud Acid 50 12 Overflush 3% NH4CI + 0.2% F103 20 13 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 14 Overflush 3% NH4CI + 0.2% F103 70 15 Diversion Wax Beads + l Oga1 /1000 Oilseeker 9 16 Spacer 3% NH4CI + 0.2% F103 10 17 HCI 12% HCI 50 18 Mud Acid 9:1 Mud Acid 50 19 Overflush 3% NH4C1 + 0.2% F103 20 20 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 21 Overflush 3% NH4CI + 0.2% F103 70 22 Diversion Wax Beads + 10ga1 /1000 Oilseeker 9 23 Spacer 3% NH4CI + 0.2% F103 10 24 HCI 12% HCI 50 25 Mud Acid 9:1 Mud Acid 50 26 Overflush 3% NH4CI + 0.2% F103 20 27 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 50 28 Overflush 3% NH4CI + 0.2% F103 70 Total Volume (starting from stage 1) 1137 At an average of 1.2 bpm, this job will take 947 minutes (15 hours) 1 Working Fluid 3% NH4C1 + 0.2% F103 885 Extra fluid should be available in case of operational difficulties 2 HCI 12% HCI 220 See HCI recipie. 3 Mud Acid 9:1 Mud Acid 200 See mud acid recipe. 4 Scale Inhibitor 3% NH4CI + 0.2% F103 + 5% L066 200 Do not filter this fluid. 5 Diversion Wax Beads + 10gat /1000 Oilseeker 27 Oilseeker is being used instead of HEC gel to carry the wax beads. 1 NH4CI Amount in LBS 11393 Ibs or 228 501b sacks 2 F103 Surfactant 91 gal 3 L066 Scale Inhibitor 420 gal 4 Wax Beads Diverter 1136 Ibs 5 Oilseeker Viscous Diverter 11 gal ,_ 'roc,„ _. +.'7,1145:41;1. ". A264 8 10 ' gal/Mgal Corrosion Inhibitor A201 60 60 gal/Mgal Inhibitor Aid A153 10 20 lb /Mgal Intensifer F103 2 2 gal /Mgal Flowback Aid L058 20 20 Ib /Mgai Iron Control W054 5 5 gal /Mgal Antiemulsifier U067 0 50 gal /Mgal Mutual Solvent 5 -W • WELLHEAD = ABB -VGi 13 -5 8 MULTIBOWL 5KSI N S 3 0 ""`"4 F1I2" Y C RROMETBG & LNR'" ""w'BOBI1 RE WELL*** ACTUATOR = BAKER KB. ELEV = 56.27' BF. ELEV = 40.1' (CB 15.9') 44' H5-1/2" X 4-1/2" VII, ID = 3.958" I KOP= 50' Max Angle = 57° @ 3390' 1111 I 1027' J- 4 -1/2" TRM- 4ETRSV Datum MD = 15655' w / X PROFILE, ID = 3.812" Datum TV D = 10500' SS 113 -3/8" CSG, 68#, L -80 BTC, ID = 12.415" H 4443' GAS LFT MANDRELS ND D LA Minimum ID = 3.725" @ 15729' S 1T1 MD 66661 4495 1 55 EV I MMG TYPE I VLV DMY 1 RK TCH 1 FORT DATE 0 104/13/06 4 -1/2" HES XN NIPPLE 'TOP OF 7" LNR I 14368' 14368' H 9 -5/8" X 7" BKR ZXP LW, ID = ?" I 14382' 1-19-5/8" X 7" BKR FLEX LOCK LTP, ID = ?" I 19 -5/8" CSG, 53.5#, L -80 BTM-C, ID = 8.535" (--{ 14549' I 15649' 1-14-1/2" HES X NIP, ID = 3.813" I 15670' I--I4 -1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 15694' 1--17" X 4 -1/2" BKR S-3 PKR, ID = 3.875" I ►1 r I 15718' H 4 -1 /2" HES X NIP, ID = 3.813" I 15729' I- 4 -1/2" HES XN NP, ID = 3.725" TOP OF 4 -1/2" LNR H 15728' (15712' ELMD (04/15/06) 4 -1/2" TBG, 12.6 #, 13CR VAM -TOP, —I 15743' 0152 bpf, ID = 3.958" 15728' H11.77' BKR TIEBACK, ID = ?" I 7" LNR, 29#, L -80 HYDRIL 521, 15877' 15739' -17" X 5" BKR ZXP LTP, ID = ?" .0383 bpf, ID = 6.184" , 15743' 1- I4 -1/2" SELF ALIGNING WLEG, ID = 3.860" PERFORATION SUMMARY 15750' I--17" X 5" BKR FLEX LOCK HGR, ID = ?" I REF LOG: GR -CCL ON 04/15/06 15760' I-I5" x 4 -1/2" XO, ID = 3.958" I ANGLE AT TOP PERF: 21° @ 16050' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 16050 - 16220 0 10/22/10 I 2 -7/8" 6 16082 - 16112 0 06/04/09 2 -7/8" 6 16090 - 16168 0 01/25/10 I 2 -7/8" 6 16112 - 16132 0 04/15/06 2 -7/8" 6 16112 - 16137 0 06/28/08 2 -7/8" 6 16132 - 16152 0 04/15/06 I 2 -7/8" 6 16137 - 16162 0 04/30/08 2 -7/8" 6 16152 - 16172 0 04/15/06 I 2 -7/8" 6 16168 - 16194 0 01/24/10 2 -7/8" 6 16184 - 16194 0 04/14/06 I 2 -7/8" 6 16204 - 16224 0 01/24/10 2 -7/8" 6 16204 - 16224 0 04/14/06 4 -1/2" LNR, 12.6 #, 13CRVAM -TOP, ± 16396' WOWS' O I 16245' H PBTD I .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 04/08/06 N33E ACTUAL COMPLETION 10/26/10 WRR/PJC PERFS (10/22/10) WELL: NS30 05/11/08 JLJ/TLH PERFS (04/30/08) 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: x 2052070 07/07/08 WRR/JMD ADPERFS (06/28/08) API No: 50- 029 - 23293 -00 06/14/09 RCT/TLH ADPERFS (06/04/09) SEC 11, T13N, R13E, 1339' FSL & 649' FEL 02/03/10 RRD/PJC PERFS (01/24- 25/10) 10/26/10 BSE/PJC SFTY NOTE (10/08/10) BP Exploration (Alaska) • • • U.S. Department of the Interior Submit original plus THREE copies,with ONE copy OMB Control No. 1010 -0141 Minerals Management Service (MMS) marked "Public Information." OMB Approval Expires 11/30/2011 Application for Permit to Modify (APM) 1. WELL NAME (CURRENT) 2. SIDETRACK NO. 3. BYPASS NO. (CURRENT) 4. OPERATOR NAME and ADDRESS NS30 ( BPOO (Submitting office) BP 5. API WELL NO. (12 digits) 6. START DATE (Proposed) 7. ESTIMATED DURATION (DAYS) 90 EXPLORATION ASKA, INC. 900 E. BENSON BLVDVD. 50- 029 - 23293 -00 APRIL 2011 2 ANCHORAGE, AK 99508 8. 9. If revision, please ❑ Revision list changes: WELL AT TOTAL DEPTH WELL AT SURFACE 10 O L A E-\ 0181 13 A 1 151512799 1 BEE 1 POINT BEEA�HY POINT 12. BL NO. 1tSLOCK NO. Proposed l orr Completed Work 16. PROPOSED OR COMPLETED WORK (Describe in Section 17) PLEASE SELECT ONLY ONE PRIMARY TYPE IN BOLD AND AS MANY SECONDARY TYPES AS NECESSARY. ❑ Enhance Production ❑ Workover: ❑ Completion: ❑ Acidize ❑ Change Tubing ❑ Initial Completion ❑ Artifice! Lift ❑ Casing Pressure Repair ❑ Reperforation ❑ Wash /Desand Well ❑ Change Zone ❑ Jet Well ❑ Abandonment of Well Bore: ❑ Modify Perforations ❑ Utility ❑ Permanent Abandonment ❑ Initial Injection Well ❑ Temporary Abandonment ❑ Information: ❑ Additional Fluids for Injection ❑ Plugback to Sidetrack/Bypass ❑ Surface Location Plat ❑ Other Operations ❑ Site Clearance ❑ Change Well Name ❑ Describe Operation(s) 17. BRIEFLY DESCRIBE PROPOSED OPERATIONS (Attach prognosis): 18. LIST ALL ATTACHMENTS (Attach complete well prognosis and attachments required by 30 CFR 250.513(a) through (d); 250.613(a) through (d); 250.1712(a) through (f); 250.1721(a) through (g); 250.1722(a) through (d); or 250.1743(a). 19. Rig Name or Primary Unit (e.g., Wireline Unit, Coil Tubing, Snubbing Unit, etc.) 20. The greater of SITP or MASP (psi): 121. Type of Safety Valve (SV): _ SCSSV SCCSV _ N/A I 22. SV Depth BML (ft): 23. Rig BOP (Rams) 24. Rig BOP (Annular) Size: Working Pressure Test Pressure Working Pressure Test Pressure (inches) (psi) (psi) (psi) (psi) Low /High: Low /High: 25. Coiled Tubing BOP: 126. Snubbing Unit BOP: 127. Wireline Lubricator: Working Pressure BOP Test Pressure Working Pressure Test Pressure Working Pressure Test Pressure (psi) (psi) (psi) (psi) (psi) (psi) Low /High: Low /High: Low /High: 28. CONTACT NAME: 29. CONTACT TELEPHONE NO.: 30. CONTACT E -MAIL ADDRESS: MARK SAUVE 1 907 - 564 -4660 mark.sauve @bp.com 31. AUTHORIZING OFFICIAL (Type or print name) 32. TITLE MARK SAUVE NORTHSTAR PRODUCTION ENGINEER 33. AUTHORIZING SIGNATURE 34. DATE 03/22/2011 THIS SPACE FOR MMS USE ONLY APPROVED BY: TITLE DATE M Form MMS (November 2008 - Supersedes all previous versions of form MMS -124 which may not be used.) Page 1 of 2 • • Application for Permit to Modify (APM) Information Sheet 35) Question Information Questions Response Remarks a) Is H present in the well? If yes, ❑ YES then comment on the inclusion of a ❑ NO Contingency Plan for this operation. El N/A _ _......... ___ ..._:... _..___ b) Is this proposed operation the only ❑ YES lease holding activity for the subject El NO lease? If yes, then comment. ❑ N/A c) Will all wells in the well bay and ❑ YES related production equipment be shut -in when moving on to or off of an offshore ED NO platform, or from well to well on the ❑ N/A �..._..�.....w_ .�.�...........v ..... _...... _. ...� ....�...._�_.... platform? If not, please explain. ❑ YES d) If sands are to be commingled for this completion, has aproval been obtained? ❑ NO ❑ N/A e) Will the completed interval be within ❑ YES 500 feet of a block line? If yes, then ❑ NO comment. ❑ f) For permanent abandonment, will El YES casings be cut 15 feet below the ❑ NO mudline? If no, then comment. Ej N/A PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT The PRA (44 U.S.C. 3501 et. seq.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and /or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.197. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form, MMS -124, is estimated to average between 1 -3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 5438, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS Form MMS -124 (November 2008 - Supersedes all previous versions of form MMS -124 which may not be used.) Page 2 of 2 r • • ~~~~5~~ OLD a~Q~~S~ /,~.mA~,.~a.~. Mark Sauve Production Engineer BP Exploration (Alaska), Inc. ~,~~;°4.~ ~, ,, ~r,~° ;„ ~;j „;~; P.O. Box 196612 c~ /-] Anchorage, AK 99519-6612 `~ d ~ ~-- o~~ _/ ~~C, Re: Northstar Field, Northstar Oil Pool, NS30 " Sundry Number: 310-164 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~j ~ Chair DATED this ! day of June, 2010. Encl. ~Q ilb V1' i~~~D STATE OF ALASKA ~E~EIVED -~~~ ID/"` ALASKA AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVALS 6'~/d ~n nnr. ~~ ~Rn ~I.AY ~ ~ 2010 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^-~~'Ra ~~t ~s nde Well Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ O~er ~6ti~~' ~s$~On Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ Anchorage 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development a Exploratory ^ 205-2070 " 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 _ 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 ~ NS30 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-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): 16398 11243.78 ~ 16245 11097 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4397 13-3/8" 68# L-80 45 4442 45 3254 5020 2270 Intermediate 14506 9-5/8" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7"29# L-80 14367 15877 94044 10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 16396 10624 11242 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13CR80 41 - 15739 Packers and SSSV Tvoe: 7"x4-1/2" bkr s-3 okr Packers and SSSV MD and TVD (ft): 15694' 10592' 12. Attachments: Description Summary of Proposal Q 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: 6/7/2010 Oil Q ~ Gas ^ WDSPL ^ Plugged ^ 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 5/26/2010 Prepared by Gary Preble 564-4944 ~ COMMISSION USE ONLY Number: J I O -~ witness Sund o that a re resentative ma diti f l N tif C i i C ry y on ons o approva : o y omm ss on s p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: / D . ~O / ` / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~j~ / ~i RBDMS JUN 10 ~°~ Form 10-403 Revised 07/2009 ORIGINAL ~~~'l~ Submit in Duplicate NS30 205-207 PERF ATTArI-IMFNT Sw Name Operation Date Perf Operation Code - ---- - -- Meas Depth Top -- ----------- Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4115/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 6/4/09 APF 16,082. 16,112. 10,943.92 10,971.92 NS30 1/24/10 APF 16,168. 16,194. 11,024.64 11,049.23 NS30 1/24/10 APF 16,204. 16,224. 11,058.7 11,077.66 NS30 1/25/10 APF 16,090. 16,116. 10,951.37 10,975.67 NS30 1/25/10 APF 16,116. 16,142. 10,975.67 11,000.1 NS30 1/25/10 APF 16,142. 16,168. 11,000.1 11,024.64 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 4 y • • by To: Jerry Bixby/Clark Olsen Well Operations Supervisors Date: May 26, 2010 From: Mark Sauve, Northstar PE (w: 564-4660 c: 748-2865 h: 336-6128) Subject: NS30 a-line P-Prof & Re-Perf AFE: NSFLDWL30-C Cost: $ IOR: 300 Please perform the requested well work on NS30 per the below procedure. 1 S D&T w/ 2-7/8" DMY Gun Obtain Sam le, Need 16,224' 2 E P-Prof w/DEFT & GHOST 3 E Re-Perf 174' Btm shot at 16,224' Well Detail Current Status: Producer Last Test: 5/21/10: 1642 BOPD, 419 BWPD, 19,350 GOR Max Inclination: 57° at 3,390' MD; 20° at Perfs Max Dog Leg: 5.6 deg/100' at 1,214 MD Minimum ID: 3.725" @ 15,729' MD, 4.5" XN Nipple Last TD tag: 11/18/09: Tag TD w/2.875" dummy guns @ 16,230' ELMD Last Downhole Op: 4/24/10: Bullhead acid stimulation Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 6/11/07 BHP: 5,065 psi @ 11,100 ft ss, 5/4/08 Objective The objective of this well intervention is to increase oil production by re-perforating a large part of the existing producing interval. Well History NS30 is a 2006 development well at Northstar. It is a 4'/Z" Chrome mono-bore completion. Initial production was 8100 BOPD. The well declined to 6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31/06. On 8/1/06 a matrix acid treatment locked up after 231 bbls away. Despite the complications, production rose to about 7000 bopd and within a year declined to around 4000 bopd. Subsequent to the 2006 acid treatment an add/reperf intervention performed on 9/19/07 resulted in 900 bopd increase. Two 2008 re-pert interventions resulted in 200 bopd increase each. A June-09 Add-pert program yielded some 400 bopd increase and aJan-10 re-perf program yielded 100 bopd IOR. However, an April 2010 bullhead HCL acid stimulation appears to have negatively affected oil rate from NS30 and it is hoped that this can be reversed with another re-perf. • • Slickline 1. SI Well. MIRU SL. 2. Drift and Tag TD w/ XN locator and 2-7/8" Dummy Gun; include S.Bailer in BHA. Locate XN profile, correct depth and tag TD. Bottom proposed Re-perf is 16,224'MD. Obtain sample if obstruction/fill encountered (scale possible). If unable to reach target depth with 2-7/8"dummy gun attempt smaller ID drift (2.50"). • Last TD Tag -11/18/09: Tagged 16,230' MD w/ 2-7/8" Perf gun • Last Downhole Op - 4/24/10 Bullhead acid stimulation • Note corrected Tag depths in WSR • 4'/" Chrome Tubing and Liner 3. RDMO SL. E-Line P-Prof w/DEFT & GHOST 1. MIRU EL. NOTE: Prior to starting logging job ensure the following; ^ NS30 has been producing for at least 24 hours. ^ Place NS30 in test and produce for a minimum of 4 hrs (or until stable) prior to logging. Choke back to maintain gas production under 10 MMSCFD to enable safe wireline logging operations. ^ Well is lined up through the test separator during logging. ^ Please take all proper precautions regarding possible gas jetting. 2. MU tools with GR/CCUPressure/Temperature/Gradio/GHOST/DEFT/Spinners. Park tool in lubricator. 3. Ensure well is lined-up through the test separator. RIH slowly while monitoring tension to ensure tool is falling. Monitor well and wait for stabilized flow before proceeding with logging passes. Ensure well rates are acceptable for the tool components (<10 mmscfd). Tie into Schlum Jewelry GR/CCL dated 4/3/06. ** If necessary RIH with well SI or severely choked back but be sure to open choke back up and allow well to stabilize for logging passes.*'` 2 of 4 • ' 4. Run 40, 80, 120 FPM up & down passes from 16,275' MD (or TD, whichever is shallower) to 15,975' MD. All logging passes should be made below the max gas rate of 10 MMSCFD (please note NS30 currently makes ~40 MMSCFD). 5. Make 10 minute stop counts at 15500', 16000', 16110', 16160', 16180', 16200' & 16230' ELMD. When finished POOH. 6. Send logging data to Anchorage Engineering staff for immediate analysis. The plan will be to have Anchorage Engineering analyze the logging data while preparations are made to start the perforation part of this program without rigging down from NS30. E-Line P-Prof R~-PERF 174' 7. MU tools for perforating operations. 8. Shoot 174' of Perfs per the attached perforating procedure with 2-7/8" HSD Power Jet 2906 HMX (6 spf). Proposed Add Perfs • 16,050-16,224' MD Reference Log: GR/CCL dated 15-April-2006 9. RDMO E-Line and return NS30 to production. Obtain well test. Please contact Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. 3 of 4 BATE Fwd BY OOkAEK15 QATE ~/ BY Oi~ITS A41~l08 N1~ ACTUAL Ctiii ~'LEi10N (ISIttK19 ,~.JRH t~S{©if9dd08) ©~CtA!(19 liGTtTt1f AL~tf3 {08IQ4lfl9j 02f[13~10 li~ii@G PE~3 0'41-~i/t NORf}iSTAR YVk1J.: FLSiO ~Elffi47U AFi ~, fi0di29.23299~ SEA 4t, T13K Ri3$ 1939"FSL d 8d®' FFl SP 6~a~ion {AJttka) 4 of 4 ' TREE• AB~Y{~5-td~' 9G9 ~ ~ SAFETYN47ifS; +rr4-td~"iiETSK3R LF~2"" SYEIIF~AD+ AB&Yt~ tS 3~8" ktH.T~O~WI 9C~ art~q, ~~+~ar I. ,, PERFORATING PROCEDURE ADW rYW~MI~iManets Well: NS30 API #: 50-029-23122-00 Date: 05/19/09 Prod Engr Jack Lau Office Ph: 564.5102 ...... Home Ph: ............................................. Cell: 227.2760 ............................................. CC or AFC: NSFLDWL30-C Detail Code: Description: .Drift to TD with,Dummx.Gun: AdPerfs ............................................................................................................ WBL Entries 1 S DB,T w/ 2-7/8" DMY Gun (Obtain Sam le, Need 16,112') 2 E ADPERF 30' Btm shot at 18,112') Ver 4.0 08/04/01 .................. H2S. Level:.................. 0 ppm Well Objectives and Logging Notes: For the a detailed NS well history, please see NS30 ADPERF program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale and ensure the guns and patch can make it to target depth. The proposed perforations are an attempt to increase production by adding perts to the shallower high perm rock. Questions or Concerns alease contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4680 (w); 748-2865 (c); 338-6128 (h) Attachment: Reference Log with annotated perforations. Reference Log Tie in Log Log: GR-CCL ........................ GR-CCL ...... Date: 4/15/2006 ....................... . . .............................. 4/15/2006 . . ... Company: Schlumber. ............................. .............................. Schlumber. .............................. Depths (from-to) Depths from-to Feet SPF ( 1 16,082' - 16,112' 16,082'. 16,112' 30' 6 ................... feet #REF! tie-in log to be on depth with the reference log. Orient. Phasing Zone Random 60° 0 Ivishak Gas Jetting Expected? . No At what Depth? N/A ................. Requested Gun Size: 2.875" HSD Charge: Power Jet 2906 ............................... Desired Penetration: 25.3" Entry Hole Diam: 0.34" - -_ Ad/Re/lperf Add Is Drawdown Necessary/Desired/Unnecessary During Perforating Unnecessar)r-.Do.not.flowwelt.durin~.perforatin~ Describe below how to achieve tlrawdown (check w/ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lif! 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: 4-1/2" XN.Nipple @ 15,729 MD ............ Tail Depth: 15 743 tt MD Casing Size: .4.5 in 12.6# 13-CR Liner Est Res. Pres. ~ MD -11100' SS -5,065 psi Last Tag: 16,227 ft ELMD on 6!28/2008 Well: NS30 Perforation Summary Date: API #: 50-029-23122-00 General Comments: Feet SPF Orient. On-Site Prod Engr: .............................................................. PBTD .............................................................................................................. Phasing Zone Aperf/Reperf • 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 Dear Mr. Maunder, by REC'~IVE MAY C~ ; 70~n .( Ofi & f~ Cotr~. Comm-~sic~ Andtorage a~'~°~ ~s 30 Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar ai~ni~nt n Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 'Not measured due to rig proximity. STATE OF ALASKA ALASKA~AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS RECEIVE APR 2 ~ 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 tti~ ~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ A~>~QQ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ente Suspended Well ^ 2.Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^~ Exploratory ^ 205-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-312808 ~ NS30 10. Field/Pool(s): \ TAR IL POOL NORTHSTAR FIELD / NORTHS O 11. Present Well Condition Summary: Total Depth measured 16398 feet Plugs (measured) None feet true vertical 11243.78 feet Junk (measured) None feet Effective Depth measured 16245 feet Packer (measured) 15694 true vertical 11097 feet (true vertical) 10592 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4397 13-3/8" 68# L-80 45 - 4442 45 - 3254 5020 2270 Intermediate 14506 9-5/8" 53.5# L-80 43 - 14549 43 - 9560 7930 6620 Production Liner 1510 7"29# L-80 14367 - 15877 9404 - 10757 8160 7020 Liner 656 4-1/2" 12.6# 13CR80 15730 - 16396 10624 - 11242 8440 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ - - True Vertical depth: _ - - - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 41 - 15739 41 - 10632 Packers and SSSV (type, measured and true vertical depth) 7'X4-1 /2" BKR S-3 PKR 15694 10592 12. Stimulation or cement squeeze summary: Intervals treated (measured): , ~ ~~i , ,-, 'J W~; s~ n ~~ ~ t • W ~.s 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: 2608 51231 431 811 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ G1NJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-067 Contact Jack Lau Printed Name Jack Lau Title Production Engineer Signature ~ Phone 564-5102 Date 4/27/2010 ' ~"" ~ ' ~ ~ ' "~~J RBDMS APR 2 8 ~ ~ y/moo NS30 205-207 OCS-Y-0181 PFRF OTTOCHMENT u n U Sw Name Operation Date Perf Operation Code - ---- --- Meas Depth Top ------------- Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 6/4/09 APF 16,082. 16,112. 10,943.92 10,971.92 NS30 1/25/10 RPF 16,090. 16,116. 10,951.37 10,975.67 NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 1/25/10 RPF 16,116. 16,142. 10,975.67 11,000.1 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 1/25/10 RPF 16,142. 16,168. 11,000.1 11,024.64 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 1/24/10 RPF 16,168. 16,194. 11,024.64 11,049.23 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 1/24/10 RPF 16,204. 16,224. 11,058.7 11,077.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ • NS30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 'ACTIVITYDATE SUMMARY 4/22/2010,Travel to Northstar. Prep unit. FWHP=250/0/150. Pump 50 bbls diesel @ 110* I down tbg for first stage of tbg pickle. Turn well over to DSO to flowback. *** Job in progress. Continue on 4-23-10 AWGRS.*** 4/23/2010 4/23/2010 wax bead diversion. ~ Pump 12% HCL + L66 scale inhibitor treatment as per program. 4 wax bead diversion stages pumped- observed --500 psi increase as beads hit perfs. ~ 5 bpm @ 2500 psi -increase to 3000 psi @ 5 bpm when beads hit perfs j Observed -500 psi decrease as HCL hit perfs behind wax beads. Displace fluids to perfs with 170 bbls 1 %KCL and 70 bbls diesel. ;Observed increases and decreases in pump pressure while displacing treating ;fluids through formation. Shut in - 4 hr soak at 1910 hrs 4/23 -POP well at 2310 hrs 4/23 ;Flow back tubing volume of 245 bbls and begin pumping MagOx at 0.5 bpm to neutralize acid at well head at 0623 hrs 4/24 ~ *****Acid pumping complete - LRS to submit MagOx AWGRS***** _ 'J b progress. Continued from 4-22-10 AWGRS. (Acid treatment). Pump 70 E bbls diesel @ 85* down tbg for tbg pickle acid treatment. Standby for well to flowback. Start third stage of acid treatment. Pump 70 bbls diesel heated to 90* 'down tbg for final stage of acid treatment. Turn well over to DSO. Leave well shut in for 4 hrs. FWHP=930/0/50. 4/24/2010 ~ T/I/0=1100/0/65. (Acid treatment). Spear into FL w/ 2 bbls neat meth followed by 148 bbls Mag-Ox to neutralize acid during flowback to plant. Freeze protect surface lines w/ 3 bbls neat meth. FWHP=2150/0/75. FLUIDS PUMPED BBLS 190 DIESEL 420 2% KCL + 0.2% F103 389 1%KCL 95 2% KCL + 0.2% F103 + 5% U67 220 12% HCL + 2% L66 SCALE INHIBITOR 58 12% HCL 40 1.5 PPA WAX BEADS + 30# HEC 5 NEAT METH 148 MAG-OX 1565 Total TREE= ~ ABB-VGI5-1/8" 5KSI WELLHEAD= RBB-VGI 13-5/8" MULTIBOWL SKSI ACTUATOR = BAKER KB. ELEV = 56.27' BF. ELEV = 40.1' {CB 15.9') KOP = 50' Max Angle = 57° @ 3390' Datum MD = 15655' Datum TV D = 10500' SS 13-3/8" CSG, 68#, L-80 BTG ID = 12.415" 4443' Minimum ID = 3.725" @ 15729' 4.1/2" HES XN NIPPLE TOP OF 7" LNR 1 14368 19-5/8" CSG, 53.5#, L-80 BTM-C, ID = 8.535" N V ~ ~ s *MMS ~~****4-1 /2" CHROME TBG &LNR*** 44' 5-1/2" X 4-112" VIT, ID = 3.958" 1027' 4-1 /2" TRM-4 E TRSV w / X PROFILE, ID = 3.812" GAS LIFT MANDRELS TV D DEV TYPE V LV LATCH PORT DATE 4495 55 MMG DMY RK 0 04/13/06 14368' -{9-5/8" X 7" BKR ZXP LTP, ID = ?" 143$2' 9-5(8" X 7" BKR FLEX LOCK LTP, ID = ?" 15649' 1-14-1/2" HES X NIP, ID = 3.813" 156-{4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 15694' 7" X 4-112" BKR S-3 PKR, ID = 3.875" 15718' 4-1/2" HES X NIP, ID = 3.813" (TOP OF 4-1 /2" LNR ~--~ 15728' 4-1/2" TBG, 12.6#, 13CR VAM-TOP, 15743' .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80 HYDRIL 521, 15$77' .0383 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: GR-CCL ON 04/15/06 ANGLE AT TOP PERF: 21 ° @ 16082' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) OpnlSgz DATE 2-7/8" 6 16082 - 16112 O 06104/09 2-718" 6 16090 - 16168 O 01/25/10 2-7/8" 6 16112 - 16132 O 04/15/06 2-7/8" 6 16112 - 16137 O 06/28/08 2-7/8" 6 16132 - 16152 O 04/15/06 2-7(8" 6 16137 - 16162 O 04/30/08 2-7/8" 6 16152 - 16172 O 04/15/06 2-7/8" 6 16168 - 16194 O 01/24/10 2-718" 6 16184 - 16194 O 04/14/06 2-7/8" 6 16204 - 16224 O 01/24/10 2-7/8" 6 16204 - 16224 O 04/14/06 4-1/2" LNR, 12.6#, 13CR VAM-TOP, I 16396' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04!08146 N33E ACTUAL COMPLETION 05/11108 JLJlTLH PERFS {04/30/08) 07!07!08 WRR/JMD ADPERFS (06/28/08} 06/14/09 RCTiTLH ADPERFS {06/04109) 02/03/10 RRD/PJC PERFS (01/24- 25!10) 15729' I 4-1/2" HES XN NIP, ID = 3.725" (15712' ELMD{04!15106} 15728' 11.77' BKR TIEBACK, ID = ?" 15739' 7" X 5" BKR ZXP LTP, ID = ?" 15743' 4-112" SELF ALIGNING WLEG, ID = 3.860" 15750' 7" X 5" BKR FLEX LOCK HGR, ID = ?" 15760' 5" x 4-1/2" XO, ID = 3.958" 16245' 1-I ~~ NORTHSTA R WELL: NS30 PERMff No: '2052070 API No: 50-029-23293-00 SEC 11, T13N, R13E, 1339' FSL & 649' FEL BP Exploration {Alaska) r e Jack Lau Production Engineer Bp Exploration (Alaska), Inc. P.O. Box 196612 - t ,, , ~ ~~~; 2~sl~t~ :k ._ f-~ `~ ^ ~~ c~ Anchorage, AK 99519 661 ~~~~?~` ~ pZ. o(, Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 310-067 Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this< U day of March, 2010. Encl. STATE OF ALASKA ~~D' (~ ALASK~ AND GAS CONSERVATION C MMISSION APPLICATION FOR SUNDRY APPROVALS ~n nnr. ~s ~Rn ~1* E~EIVEDf=~r~ MAR 0 8 2010 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ R~ ~~~~ (pj$$jp~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate 0- Other S~1CdQP Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Time Extension ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ . Exploratory ^ 205-2070 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00. 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: ^~ ^ NS30 - No Spacing Exception Required? Yes 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-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 (meas ured): Junk (measured): 16398 ~ 11243.78 16245 11097 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4397 13-3/8" 68# L-80 45 4442 45 3254 5020 2270 Intermediate 14506 9-5/8" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7" 29# L-80 14367 15877 94044 10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 16396 10624 11242 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13CR80 41 - 15739 Packers and SSSV Tvoe: 7"x4-1/2" bkr s-3 okr Packers and SSSV MD and ND (ftl: 15694' 10592' 12. Attachments: Description Summary of Proposal Q 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: 12/19/2009 Oil ^~ -" Gas ^ WDSPL ^ Plugged ^ 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 Jack Lau Printed Name J k Lau Title Production Engineer Signat a Phone Date 564-5102 3/8/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY witness Sundry Number: ~' ~ ~ O "' ti t t e ma i i th l N tif C a represen a v y omm on so a : o y ss Condition pprova Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: /~~ / ® l APPROVED BY Approved by' COMMISSIONER THE COMMISSION Date: ~~(.~ Q RBDMS MAR`S ~. Form 10-403 Revised 07/2009 diEiPJAL ~~ ~?~ lam ~, ~- ~/r ~frv Submit in Duplicate NS30 205-207 PERF ATTA(_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15106 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15106 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 6/4/09 APF 16,082. 16,112. 10,943.92 10,971.92 NS30 1/24/10 APF 16,168. 16,194. 11,024.64 11,049.23 NS30 1/24/10 APF 16,204. 16,224. 11,058.7 11,077.66 NS30 1/25/10 APF 16,090. 16,116. 10,951.37 10,975.67 NS30 1/25/10 APF 16,116. 16,142. 10,975.67 11,000.1 NS30 1/25/10 APF 16,142. 16,168. 11,000.1 11,024.64 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE Subject: NS30 FCO, HCI & SIT Date: March 05, 2010 (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Please perform the requested well work on NS30 per the below procedure. 1 C FCO, HCL Stim & SIT w/ wax bead diversion. Well Detail Current Status: Operable Online Producer Last Test: 05/07/09: 2,341BOPD, 262 BWPD, & 50 MMSCFD Max Inclination: 57° at 3390'; ~20° at Top Perf 16,112' Max Dog Leg: 5.6 at 1,214'MD Minimum ID: 3.725" at the 4'/s" XN Nip @ 15,729'MD Last TD tag: 11/18/09: Tagged 16,230' ELM w/ 2-7/8" DMY Gun & S-Bailer (no Sample recovered, ~6' of rat hole) Last Downhole Op: 11/19/09: Memory PPROF w/GHOST & DEFT Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP/BHT: 09/11 /09: 5097 psia / 241 °F C~ 11,000 ft ss Objective The objectives of this well intervention design are to: 1) Cleanout liner to 16,300' to allow adding future perfs to the shallower higher perm sands 2) Perform a diverted HCI and SIT treatment across perforated interval to remove calcium carbonate scale from the near wellbore area Well History NS30 is a 2006 development well at Northstar. It is a 4~h" Chrome mono-bore completion. Initial production was 8100 BOPD. The well declined to 6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31/06. On 8/1/06 the acid treatment locked up after 231 bbls. Despite the complications, production rose to about 7000 bopd and within a year declined to around 4000 bopd. Subsequent to the 2006 acid treatment an add/reperf intervention performed on 9/19/07 resulted in 900 bopd increase. Two 2008 re-pert interventions resulted in 200 bopd increase each. 2009 add perfs to the upper sands at 16,082-16,112' resulted in 600 bopd increase. Total formation gas has since increased from ~40 to 50 MMSCFD. A Memory PPROF performed 11/19/09 indicates no production at all from 16184'- 16224' MD perfs, half of total gas entering from top 6' of perforations, and almost all oil at moderate GOR entering from 16090'-16134' MD. The plan forward is increase oil production performing a FCO and performing a diverted HCI acid stimulation. Acid compatible scale inhibitor L066 will be included in the acid ~" treatment to provide ~6 months of protection from scale build up. Operational Phases Coil tubing • FCO to ~16,300'MD • Reciprocate across perforated interval with wax bead diverted HCI treatment • Flowback & Sampling Program Contingency: If coil is unable to rig up on NS30 due to footprint of Nabors 33E rig then the HCI Acid and Scale Inhibition portions of this work will be completed as a bullhead treatment using a fullbore pump truck. The FCU using coil tubing will then be attempted once the rig is demobilized off of North Star. ;~`~Coil Tubing. FCO to 16,300' 1. MIRU CTU. 2. PU 2-7/8" X-treme Motor and 3.700" Baker ParaTurbo Mill 3. PT as per standard procedures. . • RIH with motor and mill making weight checks as necessary. Dry tag bottom. Correct depths. 4. Come on line with pumps. FCO to 13,300' ELMD. 5. POOH while chasing final sweep to surface. HCL Acid & SIT Stimulation -Reciprocate Across Perforated Interval 2 of 4 ~., 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. RU Acidizing equipment. PT lines. Line up to pump fluids down the coil per the following schedule. 8. RIH w/ jetting nozzle to bottom perfs at 16,224'MD. 9. Lay 10 bbls of 12% HCI w/ Scale Inhibitor L066 across entire perforated interval. PUH to safety and .let soak for 30 minutes. 10. After soak period jet 200 bbls of 12% HCI while jetting reciprocating across the perfs. 11. Flowback acid. Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. 3 of 4 ., ,. I V Tt~~ A1~-V 13i 5-178' ~~ wra-~. At3~-vc~ 13-s5a3" 11~9LT113tl1fl1. ACTtLATOTt ~ BJI 1(~ 13A~' _ ._ 58.27" .13A~~ 40.1`{OB is.fr} t~ Ang1s ~ s7° t~.r, tletus- T4D ~ tOSDir ~ 13-3t$"'t~~ ~-sasTC,n.i~si~ Minimum ID 3.725" ~ 15729' 41l2" HES XN NIPPLE TO~t7F 7' t.tlfi 14368 ~ 9.518" C9Q 53.5#,1_-8l113TlAG, ~: ~ ~ ~TOf>t)F'41f!' 11+IR I 4112"T'~412~6#, 13CRYA1!-TCP. .Q152 hof, [5 ~ 3.958" I .b3~i 6pf. Dv 8.184• I 14TfOMl StlliMAARY t~ 1.4f?c 4~-CCt_ ON 04715A6 ANC~EAT TtXit~: 20° ~ 18112' ttote: Ref er b #4od~cian 013 for Nsioriisl per! sfe~a S~2£ SEd= 11Yt'S2dAi. (!~} t]pN'5tg t71ATE 2-7~' 8 16112 - 18132 O WJiSI~b6 2-T~° 8 i8i 12 - 18137 O i9dJ281'~ 2-7dB' 6 1813'2 - 16152 O blliSdn6 2-T~"' 6 16137 - 16182 O 2-T~° 6 16152 - 16172 O Q1W115Jt36 2-T~"' 6 16184 - 16194 O iOWliA14)8 2-7,8' 6 16L04 - 182't4 O Od1141ti6 QASt_Ff xrtz~T~:m$r I X 7' 13y0i ft.19C L(}OC LT1? D ^ = xu, v • iD~ 3.958' t7ATE tiEY SY HATE fiEV 13Y 047U8106 t13~ ACTtMI CCMPt.ET1d~1 12/13107 YN~tlP.IC SKt~T1' N(}TE(t~i11B~Wt3.1} 04!13106 .AJRLH C3iV C70 05111/08 JL.YiLH P'E#~S (Q413Q08} 0411511)6 ,lL.I16iH tF(ML f'+6iES 07707/08 1W (fl6,Q1fR}B} 135710106 JL.lii'lH 1J~ti17f7APf 11 R71ft7 ~C~CJ-TDFI 12715107 RL"f71'+JC TREY COi10#1 1VOftTH3TAR 1V53tD floe 2062b70 AA No: 5402~2328t~011 11,T1~4,12131; 1°1=~8609'ffi 8P6cp1aratlora {Ataaka) 4of4 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS R~C~IVED FEB 1 Z 201 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ 8t 68$ CANS COf1Yi118$ ~~ RB Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ ~ . S Time Ex ension Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-ent r Suspended Well ^ AnChara~8 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 205-2070 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ~ ADLO-312808 \ NS30 10: Field/Pool(s): NORTHSTAR FIELD / NORTHSTAR OIL POOL 11. Present Well Condition Summary: Total Depth measured 16398 feet Plugs (measured) None feet true vertical 11243.78 feet Junk (measured) None ,feet Effective Depth measured 16245 feet Packer (measured) 15694 true vertical 11097 feet (true vertical) 10592 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4397 13-3/8" 68# L-80 45 - 4442 45 - 3254 5020 2270 Intermediate 14506 9-5/8" 53.5# L-80 43 - 14549 43 - 9560 7930 6620 Production Liner 1510 7" 29# L-80 14367 - 15877 9404 - 10757 8160 7020 Liner 656 4-1/2" 12.6# 13CR80 15730 - 16396 10624 - 11242 8440 7500 r Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 41 - 15739 41 - 10632 Packers and SSSV (type, measured and true vertical depth) 7'X4-1/2" BKR S-3 PKR 15694 10592 12. Stimulation or cement squeeze summary: Intervals treated (measured): • ~ .`fib.:. IAL~p0. ~'4~~a-~. 4.. ~~~~, [` fi„ dw~~~ 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: 2537 44229 232 824 Subsequent to operation: 3082 54056 288 852 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 6. 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: 309-412 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 2/10/2010 Oh r~nn iv-wu~r r~cviseu ncwy ~ 1L.76JM~ rttf 1 ~ LUG ~Q~•L ou~nm vnyuiai .~~~~y NS30 205-207 DFDF ATTA!_I-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 6/4/09 APF 16,082. 16,112. 10,943.92 10,971.92 NS30 1/24/10 APF 16,168. 16,194. 11,024.64 11,049.23 NS30 1/24/10 APF d 16,204. 16,224. 11,058.7 11,077.66 NS30 1/25/10 APF 16,090. 16,116. 10,951.37 10,975.67 NS30 1/25110 APF 16,116. 16,142. 10,975.67 11,000.1 NS30 1/25/10 APF 16,142. 16,168. 11,000.1 11,024.64 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • NS30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/22/20101'"*"ARRIVE ON LOCATION*""(E-LINE PERFORATION) ARRIVE TO LOCATION, PJSM, PREPPING EQUIPMENT FOR JOB t ,"""JOB IN PROGRESS AND CONTINUED ON 23-JAN-10 WSR*** ` ~~.. ...w.._......_,.w...~._ __..._.~ - ~ ~_ ~~. 1/23/2010;""*JOB IN PROGRESS CONTINUED FROM 22-JAN-10"""(E-LINE j ;PERFORATION) CONTINUE JOB PREP, START RIG UP TO PT AND THEN ARM 1ST GUN ="**JOB IN PROGRESS AND CONTINUED ON 24-JAN-10 WSR'"*'` 1/24/2010'***JOB IN PROGRESS AND CONTINUED FROM 23-JAN-10**"(E-LINE PERFORATION) CONTINUE RIG UP, WELL FLOWING UNTIL READY TO RIH INITIAL SHUT IN T/I/0=3500/0/300 1ST GUN RUN PERFORATE FROM 16204'-16224' WITH 2-7/8" PJ HSD @ 6SPF AND 60 DEGREES PHASING 2ND GUN RUN PERFORATE FROM 16168'-16194' WITH 2-7/8" PJ HSD @ 6SPF AND 60 DEGREES PHASING :RIH WITH 3RD GUN RUN AND MAKING CORRELATION PASSES ***JOB IN PROGRESS AND CONTINUED ON 25-JAN-10 WSR*"* 1/25/2010 "**JOB IN PROGRESS CONTINUED FROM 24-JAN-10***(E-LINE PERFORATION) GUN RUN #3 PERFORATE 16142'-16168' WITH 2-7/8" PJ HSD, GOOD INDICATION, POOH ;GUN RUN #4 PERFORATE 16116'-16142' WITH 2-7/8" PJ HSD, GOOD INDICATION, POOH ;GUN RUN #5 PERFORATE 16090'-16116' WITH 2-7/8" PJ HSD, GOOD INDICATION, POOH SON FINAL GUN RUN LOG CORRELATION PASSES, DROP DOWN TO =PULL INTO POSITION. ;HAD TO PULL 3200 LBS TO MOVE TOOL AND LOG INTO POSITION. GETTING STICKY. LOG OFF FINAL GUN RUN, POOH, FINAL UP WEIGHT FROM PERFORATIONS 2600 LBS. AT SURFACE, CONFIRMED ALL SHOTS FIRED, START RIG DOWN ***JOB IN PROGRESS AND CONTINUED ON 26-JAN-10 WSR"** • 1 /26/2010 CJ _ __~ ***JOB IN PROGRESS CONTINUED FROM 24-JAN 10***(E-LINE PERFORATION) RIG DOWN. TURNED WELL OVER TO NORTH STAR WELL TENDER. WELL WAS IMMEDIATELY POP. WELL LEFT FLOWING SSV/M/SSSV/W=O, S=0 IA/OA=OTG ***JOB COMPLETE MOVE TO NS19*** TREE _ ABB-VGI5-1/8" 5KSI WELLHEAD= ABB-VGI 13-5/8" MULTIBOWL 5KSI ACTUATpR = BAKER KB. ELEV = 56.27' BF. ELEV = 40.1' (CB 15.9'} -- ,.,. KOP = 5p' Max Angle = 57° @ 3390' Datum MD = 15655' ___ ---- Datum TVD = 10500' SS 13-318" CSG, 68#, L-80 BTC, ID = 12.415" 4443 Minimum ID = 3.725" @ 15729' 4-1 /2" HES XN NIPPLE TOP OF 7" LNR 14368 (9-5/8" CSG, 53.5#, L-80 BTfv1-C, ID = 8.535" ~ 9-518" X 7" BKR ZXP LTP, ID = ?" 9-5/8" X 7" BKR FLEX LOCK LTP, 1D = ?" 4-1/2" HES X NIP,ID = 3.813" 15670' -14-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 15694' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 15718 -r4-112" HES X NIP, ID = 3.813" 15729 4-112" HES XN NIP, ID = 3.725" TOP OF 4-112" LNR ~--~ 15728' ~ 4-112" TBG, 12.6#, 13CR VAM-TOP 15743 .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80 HYDRIL 521, 15877 .0383 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: GR-CCL ON 04/15/06 ANGLE AT TOP PERF: 21 ° @ 16082' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 16082 - 16112 0 06/04/09 2-718" 6 16090 - 16168 O 01/25/10 2-718" 6 16112 - 16132 O 04/15/06 2-718" 6 16112 - 16137 O 06/28108 2-7(8" 6 16132 - 16152 O 04/15(06 2-7/8" 6 16137 - 16162 O 04/30/08 2-7/8" 6 16152 - 16172 O 04/15/06 2-7/8" 6 16168 - 16194 O 01124/10' 2-718" 6 16184 - 16194 O 04!14106 2-718" 6 16204 - 16224 O 01/24/10- 2-718" 6 16204 - 16224 O 04(14(06 4-112" LNR, 12.6#, 13CR VAM-TOP, I~ 16396, .0152 bpf, ID = 3.958" N S 3 0 S *MMS ~~****4-112" CHROME TBG ~ LNR*** 44~ 5-112" X 4-112" VIT, ID = 3.958" 1027' 4-1/2" TRM-4ETRSV w 1 X PROFILE, ID - 3.812" GAS LIFT MANDRELS ! TYPE VLV LATCH PORT DATE MMG DMY RK 0 04/13/0 ((15712' ELMD(04/15106) ( 15728 11.77' BKR TIEBACK, ID = 15739 7" X 5" BKR ZXP LTP, ID = ?" 15743 4-112" SELF ALIGNING WLEG, ID = 3.860" 15750' 7" X 5" BKR FLEX LOCK HGR, ID = ?" 15760 5" x 4-1 /2" XO, ID = 3.958" 16245' I-I PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 04/08/06 N33E ACTUAL- COMP<_ETION 05111/08 JLJ/TLH PERFS (04/30/08) 07/07!08 WRR/JMD ADPERFS {06128/08} 06!14/09 RCT/TLH ADPERFS (06/04109) 02/03/10 RRD/PJC PERFS {01/24- 25/10) NORTHSTA R WELL: NS30 PERMIT No: 2052070 API No: 50-029-23293-00 SEC 11, T13N, R13E, 1339' FSL & 649' FEL BP Exploration (Alaska) SEAN PARNELL, GOVERNOR ALASKA OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CONDUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mark Sauve Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 309-412 "ANNEL D 2 ZOOS 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. 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, 04. Orman Commissioner DATED this I' day of December, 2009 Encl. r STATE OF ALASKA "' �.t�l E1E � ALASKA�OIL AND GAS CONSERVATION COMMISSIA r2 _Wo APPLICATION FOR SUNDRY APPROVALS DEC 0 9 2009 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑� '4DOt1If11iS51 CI Alter casing E] Repair well E] Plug Perforations ❑ Stimulate ❑ Other Sp6tclh Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension F-1 H �� c 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑, Exploratory ❑ 205 -2070 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23293 -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 Q NS30 — 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 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): 16398 _ 11243.78 16245 11097 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 4397 13 -3/8" 68# L -80 45 4442 45 3254 5020 2270 Intermediate 14506 9 -5/8" 53.5# L -80 43 14549 43 9560 7930 6620 Liner 1510 7" 29# L -80 14367 15877 94044 10757 8160 7020 Liner 666 4 -1/2" 12.6# 13CR80 15730 16396 10624 11242 8440 7500 Perforation Depth MD (ft): 770ration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13CR80 41-15739 Packers and SSSV TVDe: 7 "x4 -1/2" bkr s -3 Dkr Packers and SSSV MD and TVD (ft): 15694' 10592' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/19/2009 Oil Gas ❑ WDSPL ❑ Plugged ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Mark Sauve Title Production Engineer Signature Phone Date 564 -4660 12/9/2009 Prepared by Gary Preble 564 -4944 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: 0 . APPROVED BY Approved by: ISSIONER THE COMMISSION Date: 4:51� "0 IGINAL Form 10-403 Revised 07/2009 ` Submit in Duplicate NS30 205 -2070 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 • NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 6/4/09 APF 16,082. 16,112. 10,943.92 10,971.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i by 0 To: Jerry Bixby /Clark Olsen Date: December 8, 2009 Well Operations Supervisors From: Mark Sauve, Northstar PE (w: 564 -4660 c: 748 -2865 h: 336 -6128) Subject: NS30 RE -PERF AFE: NSFLDWL30 -C Cost: $100M IOR: 300 Please perform the requested well work on NS30 per the below procedure. 1 S D &T w/ 2 -7/8" DMY Gun Obtain Sample, Need 16,224' 2 1 E I RE -PERF 124' Btm shot at 16,224' Well Detail Current Status: Producer Last Test: 10/15/09: 2605 BOPD, 394 BWPD, 19,868 GOR Max Inclination: 57 at 3,390' MD; 20 at Perfs Max Dog Leg: 5.6 deg /100' at 1,214 MD Minimum ID: 3.725" @ 15,729' MD, 4.5" XN Nipple Last TD tag: 11/18/09: Tag TD w/2.875" perf guns @ 16,230' ELMD (corrected) Last Downhole Op: 11/19/09: Memory P -Prof logging Latest H2S value: Field Produced Gas 4 ppm - Taken from HP Separator 6/11/07 BHP: 5,065 psi @ 11,100 ft ss, 5/4/08 Objective The objective of this well intervention is to increase oil production by re- perforating a large part of the existing producing interval. Well History NS30 is a 2006 development well at Northstar. It is a 4 1 /2" Chrome mono -bore completion. Initial production was 8100 BOPD. The well declined to 6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31/06. On 8/1/06 the acid treatment locked up after 231 bbls. Despite the complications, production rose to about 7000 bopd and within a year declined to around 4000 bopd. Subsequent to the 2006 acid treatment an add /reperf intervention performed on 9/19/07 resulted in -900 bopd increase. Two 2008 re -perf interventions resulted in -200 bopd increase each. A 2009 Add -perf program yielded some -400 bopd increase. However, a recent P -Prof has indicted that approximately one third of the perforated interval is producing poorly and one third is not producing at all. II Slickline 1. SI Well. MIRU SL. 2. Drift and Tag TD w/ XN locator and 2 -7/8" Dummy Gun; include S.Bailer in BHA. Locate XN profile, correct depth and tag TD. Bottom proposed Re -perf is 16,224'MD. Obtain sample if obstruction /fill encountered (scale possible). If unable to reach target depth with 2 -7/8" dummy gun attempt smaller ID drift (- 2.50 "). • Last TD Tag - 11/18/09: Tagged 16,230' MD w/ 2 -7/8" Perf gun • Last Downhole Op - 11 /19/09: Memory P -Prof • Note corrected Tag depths in WSR • 4 1 /2 " Chrome Tubing and Liner 3. RDMO SL. E -Line RE -PERF 124' 1. MIRU EL. 2. Shoot 124' of Perfs per the attached perforating procedure with 2 -7/8" HSD Power Jet 2906 HMX (6 spf). Proposed Add Perfs • 16,090- 16,194' MD • 16,204- 16,224' MD Reference Log GR /CCL dated 15 -April -2006 3. RDMO E -Line and return NS30 to production. Obtain well test. Please contact Mark Sauve 564 -4660 (w); 748 -2865 (c); 336 -6128 (h) with any questions, comments, or concerns. 2 of 3 TREE= ABB-VQ5-l1&*&K(SJ NOTES: —4-1/2" CHROME TBG LNR WELD HEAD = ABB �TBOWLL SKS1 NS30 F ll s,A lm m m " s w EILIL ACTUATOR aAKER BF. ELE14 56- 40:v (CB 15.9) sa Mqx Angle lir TRM-4E TF S� w I X FRDFLE, ID a 3 81 113 CSa 68#, L-80 BTC, ID - �12.415' 4443" GAS LFr MANDRELS I ST I MD I TV I 71 VLV ILATCH I PORT DATE Minimum ID = 3.725" @ 15729' 11 16%61 56 1 MMG I DW I RK 1 0 3MI 41/2" HES XN NIPPLE I ITOPOF 7- Lm H IUW- 143W "W X 7 aKR 4518' Csc, 53.54. L-W ST", ID =a-sw H 14549' —I—A' 1 5$49' 4112' HESX NP, D - 1813*1 15694 Px 4912" 3KR S-3 W-R. D =3.875' r 15TM _ 1[15712' FLMD (044I5406) ITOP OF 410 LNR 15728' 1 41t2'TM 12J6#, 13CRVAM-TOP, -0152 W. ID - 3.958° 1 7* LMR, 29#, L-W HYDFIL 521, 157501 7'X9*BKRR.EX LOCK W-R.D-r .0383 bpd. ID - 6.I84" S x X0, D - r PERFORATION SUMMARY REF LOG: CPOCL ON 04115 6 A NGLEAT TOPPERF. 20' @ 161 92' Nwe: Refer Io Ptodwim OB for fulortal perf daft SIZE SPF INTERVAL (MD) OpWSqz DATE 2-7#r 6 16112-16132 0 04/154'476 2 -7.45" 6 16112-16137 0 06128108 2 -79r 6 16132 -16152 0 041151Ci6 2-7V 6 16137-16162 0 0030108 2-7V 1 6 16152 - 161 0 04115106 2-71W 6 16184 - 16194 0 04114106 12-7V 6 1 16204 - 16224 1 0 04194406 PBTD 16045' FF-Lw- 926#, 13CR YAM -TOP, 16396' 1.0152 bpd. D 3,958" DATE I REV BY COMMENTS DATE REV BY OOMMENTS NORTHSTAR ")MOB NSM ACTU%L COMPLETION 1211 &07 WRPJPJC SA FETY NOTE (MMS WELL) VVEL : NSW 04113406 JUITLH GLV 00 09411108 JLnLH F0f`S(04030408) FERWT Nm 'AM2070 04115106 JLJfTLH INTAL PERFS 07107/08 NRR(JLID ADWMS(06428=) APIMx 50-029-23293-00 0510*6 JLJ/TLH D DRAFT OORRECTIONS SEC 11, 713K RM 1339' FSL & 641r FEL 11127107 WRRfPJC IWELLFU LOCATION C04VEMIDNS 12115107 RCTIPUIC TRSV OORRECTION 13P &p1wation (Alaska) 3 of 3 I . 0 0 PERFORATING PROCEDURE ver4006 /04/01 Rom rrfwtwutn��s Well: NS30 API #: 50-029 - 23122 -00 ................................ ............................... .................. ............................... Date: 12/ 8/ 09 .............. ............................... Prod En g r Mark Sauve................... Office Ph: 564.4660 - H2S Level: ......,............ ....... ....... ............................... Home Ph: 336.6128 0 ppm ......................... ............................... Cell: 748.2865 ..............I.- ...................................... CC or AFC: NSFLDWL30 -C Detail Code: .. ............................... ............ . .................................... ................................................................. ....... Description: Drift to TD with Dummy Gun, Re -Pert ..................................................................... ............................... WBL Entries 1 S D &T w/ 2 -7/8" DMY Gun Obtain Sample, Need 16,224' 2 E RE -PERF 124' (Btm shot at 16,224') Well Objectives and Logging Notes: For the a detailed NS well history, please see NS30 RE -PERF program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale and ensure the guns and patch can make it to target depth. The proposed perforations are an attempt to increase production by stimulating pats of the reservoir that we believe to be under performing. Questions or Concerns please contact Mark Sauve 564 -4660 (w); 748 -2865 (c); 336 -6128 (h) Attachment: Reference Log Tie in Log Log: GR -CCL GR -CCL Date: 4/15/2006 4/15/2006 ............................. .............................. Company: . Schlumber : Schiumber. .............................. Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 16,090' - 16,194' 16,090' 16,194' 104' 6 Random 60 0 Ivishak Re ............................. ......... .....I................ .................. ..................... ......................... ................... ......................................... erf P ................ ....................... 16,204' - 16,224' 16,204' 16,224' 20' 6 Random 60 0 Ivishak Re erf ................... . ........................... ............................... ........ ............................... ..................... .......................... P. ........... . ............................... ......................... ........................ I - ................... .......... ............ ................... ................................................... ............................... . ............................... ............................ ............................... .................. ............................... ............ .......................... ................... ........................................................ ............................... Gas Jetting Expected? No At what Depth? N /A Requested Gun Size: 2 HSD . Charge: Power Jet 2906 ................... Desired Penetration: 25.3" Entry Hole Diam: . 0.34" Is Drawdown Necessary /Desired/Unnecessary During Perforating UnnecessarX - Do not flow well during perforating ............. Describe 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 -1/2" XN .. Nipple @ 15,729 MD ................... ..................... Tail Depth: 15,743 ft MD Casing Size: ,4 . .5 in 12.6# 13 CR Liner ........... Est Res. Pres. @ MD - 11100. S S -5 psi Last Tag: 16,227 ft ELMD on 6/28/2008 Well: NS30 Perforation Summary Date: API #: 50-029.23122 -00 On -Site Prod Engr: ............................. ....................... ............................... .............................. ............................... PBTD .............................. ............................... General Comments: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ....................................................... . . . .................... . . . . . . . . . . ...................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depths Balance Referenced to BHCS Feet SPF Orient. Phasing Zone Aperf/Reperf 0 /13/U ' .............................. 0 ............................. O /B /U - O 0 /B /U _..... ... " ........................... ............................ .................. ..................... ....................... O _................................................ ............................... O /B /U - .............................. 0 ..................... ............................... O /e /U - O _ --; ~" ~~ ~~ ~~` ~~~ -~ n ~.I ate: 12-17-2009 Transmittal Number: 931 14 BPXA i~VELL DATA TRANSlV~~TTAL Enclosed are the materials listed below. if you have anv questions. olease contact Joe Lastulka at (907)554-4091 Delivery Contents Bottom SW Name Date Contractor Run To De th De th Descri tion MEMORY PRESSURE/ NS33A 11-11-2009 SCH 1 25380 25970 EMPERATURE SURVEY CD-ROM -MEMORY PRESSURE/TEMPERATURE NS33A 11-11-2009 SCH SURVEY MEMORY PPROF WITH DEFT NS05 11-16-2009 SCH 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 SCH 1 200 25873 AND WATER FLOW LOG GD-ROM -RESERVOIR SATURATION AND WATER NS33A 11-10-2009 SGH FLOW LOG i"sAe~~9 ~~wr ~ ~ L~ k ~ L lJ ;: ~ r r j ~'~ ~~troi~chnisa] ?~at~ ~~:e~lt~; ~ ~2-] f\j~~r~Os ~~~~ aid %~~ 1')-Ob 12 ALASI~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS - - ~"GSi~ 6-/.s-o9. 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 0 - Re-enter Suspended Well 2.Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r ~ Exploratory ~ 205-2070 3. Address: P.O. Box 196612 Stratigraphic r ServiC@ ~- 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 56.27 RT - NS30 , 8. Property Designation: 10. Field/Pool(s): , ADLO-312808 - NORTHSTAR--Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 16398 ~ feet Plugs (measured) None true vertical 11243.78 _ feet Junk (measured) None Effective Depth measured 16245 - feet ~` ~"~ ~ ' ~~ ~ ~' ~ yx ~~ +r~~:r true vertical 11097 feet Casing Length Size MD TVD Burst Collapse Surface 4397 13-3/8"68# L-80 45 -4442 45 - 3254 5020 2270 Production 14506 9-5/8" 53.5# L-80 43 - 14549 43 - 9560 7930 6620 Liner 1510 7" 29# L-80 14367 - 15877 9404 -10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 - 16396 10624 -11242 8440 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: - _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 41' -15739' o b - Packers and SSSV (type and measured depth) 4-1/2" baker S-3 PKR 15694' 4-1/2" TRSSV 1026' 0 ~~~~ 0 12. Stimulation or cement squeeze. summary: Intervals treated (measured): QfA5k8 Oil & G8S Gdns. Cammissian Treatment descriptions including volumes used and final pressure: QfiCIlOrBgE 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2711 37776 129 783 Subsequent to operation: 3639 44309 143 833 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development ~ ~ Service r Daily Report of Well Operations X 16. Well Status after proposed work: OII r " Gas r WAG r GINJ r WINJ ~ WDSPL r 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: 309-120 Contact Jadc Lau Printed Name Jack Lau Title PE Signature Phone 5645392 Date 6/12/2009 Form 10-404 Revised 04/20v06 ,~( ~ ~'s ~ ~ ~ ~ ~ ~" Oq STATE OF ALASKA Submit Original Only ~~~~~ NS30 205-207 PERF OTTOCHMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4115/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 NS30 6/4/09 APF y 16,082. 16,112. 10,943.92 10,971.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE r1 U . NS30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/3/2009 ****WELL FLOWING ON ARRIVAL*** (adperfs) INITIAL T/I/O = 750/0/300. RIG UP E-LINE. ***CONT. WSR ON 6/4/2009*** 6/4/2009 ***CONT. FROM 6/3/09*** INITIAL T/I/0=775/0/300 PSI, T/I/O WHEN SHUT IN = 3500/0/300 PERFORATE30' FROM 16082'-16112' MD WITH 2-7/8" HSD POWERJET GUNS 6 SPF. ALL SHOTS FIRED. ***JOB CONTINUED ON 5-JUNE-2009*** 6/5/2009 ***CONTINUED FROM 6/4/09*** FINAL T/I/0=3400/0/300 PSI. RIG DOWN ELINE. NOTIFY WELL ROW OPERATOR, WELL FLOWING, SWAB SHUT, IA/OA OPEN TO GAUGES. *** JOB COMPLETE*** FLUIDS PUMPED BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 26, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, -~~~7 ~~ ~~ ---' 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, I "(,~-~ Andrea Hughes BPXA, Well Integrity Coordinator • ~i~~~ ail ~ ~~rq~A (;~~;n'li~sion ~sl~~r~ ~~~~~~~ .1P~ r `~ 2~ • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30!2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 * na na 2.6 5!2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 * na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. ~ JUN 0 1 1009 p ,.. ALASSA OIL A1~TD GAS COI~SERQATIOI~T COl-'II-IIS5IOIIT ,' Jack Lau .~_ _._.' _. Well Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 `~; , ~,,.a,... ~. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~Q~ Re: Northstar Field, Northstar Oil Pool, NS30 ~r ,_5 Sundry Number: 309-120 Dear Mr. Lau: 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 Conurussion to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2009 Encl. O ~~,~A STATE OF ALASKA 'I ~ Dc` ALA~IL AND GAS CONSERVATION COMMIS /~r~ ~P~ ~~ 1~ APPLICATION FOR SUNDRY APPROVAL'" ` ~ 2009 ~n nnr ~~ ~Qn ~1acb~ n:- n ,. 1. Type of Request: Abandon Suspend Operational shutdown Pertorate ~ - Waiver Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension hOYa~ 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 ^ 205-2070 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6 . API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Wetl Name and Number: property line where ownership or landownership changes: NS30 Spacing Exception Required? Yes ^ No ^~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312808 ' 56.27 RT - NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESEN T WELL CONDITION SUMMARY Total Depth MO (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 16398 - 11243 - 16245 11097 None None Casing Length Size MD ND Burst Collapse Surtace 4397 13-3/8" 68# L-80 45 4442 45 3254 5020 2270 Production 14506 9-5/8" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7" 29# L-80 14367 15877 9404 10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 16396 10624 11242 8440 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached 4-1/2" 12.6# 13CR80 41' - 15739' Packers and SSSV Type: 4-1/2" TRSSSV Packers and SSSV MD (ft): 1026' 4-1/2" BAKER S-3 PACKER 15694' 0 0 0 0 12. Attachments: Descriptive Summaryof Proposal 0 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: 4/15/2009 Oil ~- Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by ~aiy r~~ule 564-4944 t7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Lau Printed Na _ Jack Lau Title Well Engineer Signature Phone 564-5102 Date 4/1/2009 COMMISSION USE ONLY Conditions o pproval: Notify Commission so that a representative may witness Sundry Number: -. ' ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ other: ~E~L Cq~-~~-crt3\C~~~,Fv~-~e~~~~i~~.CC®~ ~ ~~~~~~. ~-~ ~ a~~ Subsequent Form Required: `~~ ~1 APPROVED BY /] ~ ~ Approved b COMMISSIONER THE COMMISSION Date: 7 Form 10-403 Revised 06/2006 '` t' ~ - -- ~ ~ ~`~_~ 4E e? l.~~~ Submit in Duplicate NS30 205-207 PFRF OTTO[`HMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 18,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,152. 16,162. 11,009.54 11,018.98 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~J by ~ To: Jerry Bixby/Clark Olsen Well Operations Supervisors From: Jack Lau, Wells Engineer Mark Sauve, Northstar PE u Date: March 31, 2009 (w: 564-5102 c: 227-2760) (w: 564-4660 c: 748-2865) Subject: NS30 PPROF w/ DEFT & GHOST, Add/Re-Perf Pending PPROF AFE: NSFLDWL30-C Cost: $120M IOR: 200 Please perform the requested well work on NS30 per the below procedure. 1 S D&T w/ 2-7/8" DMY Gun Obtain Sam le, Need 16,224' 2 E PPROF w/ DEFT & GHOST. Add/RePerf Btm shot at 16,224' Well Detail Current Status: Operable Online Producer Last Test: 12/08/08: 2,621 BOPD, 138 BWPD, & 40 MMSCFD Max Inclination: 57° at 3390'; ~20° at Top Pert 16,112' Max Dog Leg: 5.6 at 1,214'MD Minimum ID: 3.725" at the 4'/i" XN Nip @ 15,729'MD Last TD tag: 06/28/08: Tagged 16,227 MD w/ 2-7/8" Perf gun Last Downhole Op: 06/28/08: RePerf 16,112-16,137'MD w/ 2-7/8" Perf guns Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 06/11/07 BHP: 05/04/08: 5,065 psia @ 11,000 ft ss Objective The objective of this well intervention is to: 1) Increase oil production by adding perforations to the upper sands above the existing perforated interval 2) Perform a production profile to better understand production characteristics and contributions. The production profile will be utilized to determine fluid entry contributions across the perforated interval and influence a future re-pert design. Well History NS30 is a 2006 development well at Northstar. It is a 4~h" Chrome mono-bore completion. Initial production was 8100 BOPD. The well declined to 6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 bbls away during the acid pickle treatment on 7/31 /06. On 8/1 /06 the acid treatment locked up after 231 bbls. Des ite the com lications, roduction rose to about 700• o d and within a ear p p p p Y declined to around 4000 bopd. Subsequent to the 2006 acid treatment an add/reperf intervention performed on 9/19/07 resulted in 900 bopd increase. Two 2008 re-perf interventions resulted in 200 bopd increase each. The plan forward for NS30 is to add perfs to the shallower higher perm rock and perform agas/fluid view log to evaluate additional add/reperf opportunities. Slickline 1. SI Well. MIRU SL. 2. RIH with 3.75" gauge ring and tag XN-profile at 15,729'MD. Use this depth to make subsequent depth correction. POOH. 3. Drift and Tag TD w/ 2-7/8" Dummy Gun; include S.Bailer & TEL in BHA. Target depth is 16,224'MD. Obtain sample if obstruction/fill encountered (scale possible). If unable to reach target depth with 2-7/8" dummy gun attempt smaller ID drift (2.50"). • Last TD Tag - 06/28/08: Tagged 16,227 MD w/ 2-7/8" Perf gun • Last Downhole Op - 06/28/08: RePerf 16,112-16,137'MD w/ 2-7/8" PJ • Note corrected Tag depths in WSR 4. Drift 4~/z" Baker 45 KB DMY Patch to 16,112'MD. OD of the Baker 45KB is 3.70". The goal is of this drift is to ensure a patch can be set over the proposed add pert interval above 16,112' if high gas rates are observed. • Current top perf is located at 16,112'MD. 5. RDMO SL. E-Line PPROF 2of7 1. Prior to starting a-line job, ensure the following: • NS30 has been producing for at least 24 hours. • Place NS30 in test and produce for a minimum of 4 hrs (or until stable)prior to logging with well choked. back to a max gas rate of 10 MMSCFD to enable safe a-line logging operations. • Well is lined up through the NS test separator during logging • Due to NS30's current gas rates of ~40 mmscfd, gas jetting is a risk; please take all proper precautions. • Be prepared to upload live data into Interact to allow live viewing. This will allow the production team to decide actual interval to perforate based on real-time PPROF data,- Once rigged up and prepared to upload to Interact contact Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) or Jack Lau 564-5102 (w); 227-2760 (c). Well Bore un Date Total Fluid Rate b Oil Rate b d Water Rate b d Fonm (,'~ Rttt~ IOR bo d NS30 3/20/2009 2,759: 2,621 138 40,OB5' 1,545 NS30 2/7/2009 2,777 2,695 82 40,025 . 1;636 NS30 2/7/2009 2,774 2,690 84 39,902 1,634 NS30 1/30/2009 2,793 ' 2,724 69 39,845 1,626 NS30 1 /30/2009 2,806 ' 2,743 63 39,840 1;645 NS30 1/10/2009 2,999 ' 2,904 95 40,602 1,831 NS30 1/9/2009 2,968 2,864 104 40,4~i 1.,794 NS30 12/24!2008 2,905 ' 2,797 109 40,160 1,766 2. M1RU EL. 3. MU BHA w/ Wtbars/ GR/ CCU Pressure/ Temperature/ Gradio/ GHOST! DEFT/ Spinners. Utilize heat sock. SI with wing valve and RIH ~ 4. RIH to below the SSSV. Open the wing valve slowly and continue to RIH. ~ 5. Slowly bring well on production to acceptable logging rates (<10 mmscfd). Ensure well is lined-up through the test separator. Monitor well and wait for stabilized flow before proceeding with logging passes. Ensure well rates are acceptable for the tool components. Tie into SWS GR/CCL dated 15-Aprif- 2006. RIH slowly while monitoring spins and tension to ensure tool is falling. • If unable to RIH against requested flow rate, the well can be choked back to an acceptable RIH rate, but be sure to open choke back up for logging passes. • Please note choke settings and flow rates for dynamic passes in WSR and field logs. 3of7 6. Run 40, 80, and 120 FPM up & down passes from TD to 150' above the top perf located at 16,112'MD. Record a stop count at the top of the logging interval prior to making. each dynamic pass. All logging passes should be made below the max gas rate of 10 MMSCFD. • NS30 currently makes ~40 MMSCFD, rates above 10MMSCFD are anticipated. • Document changes in choke setting and flow rates in WSR and field: logs. 7. Perform stop counts a) At the following depths above and below perforated intervals • 16,100'MD • 16,180'MD • 16,200'MD b) Above and below any anomalies Note: Ensure that sufficient time is spent at each designated stop to achieve a reasonably constant rotation count PPROF L in Summa Pass Direction m De th' ft, and Notes PPROF w/ GHOST & DEFT Flowin Pass DowNU 40 15,960' - TD' Well Flowin Flowin Pass DowNU 80 15,960' - TD' Well Flowin Flowin Pass Down/U 120 15,960' - TD' Well Flowin 8. Ensure good data. SI well after logging to POOH. • Note: Minimize freeze-up due to Hydrate Formation by `trickling' McOH into lubricator stack while POOH, utilize Triplex pump per established SOP. Hydrate formation is a potential at Northstaryear-round. At a FWHP of 2,500 psi, the hydrate formation temperature is approximately 75 deg F. POOH. 9. While rigged up evaluate PPROF data to determine contributing intervals. Contact Mark Sauve or Jack Lau to discuss intervals to add/re-perf. • Contact Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) or Jack Lau 564-5102 (w); 227-2760 (c) 4of7 10. Add/Re-Perf per the attached perforating procedure with 2-7/8" HSD Power Jet 2906 HMX. Contact Mark Sauve or Jack Lain. prior to perforating to discuss actual adtl/re-serf interval based on RPROF results.. Proposed-Adtl Perfs • 16,022-16,112'MQ Proposed Re-Perfs • 16,112-16,172'MD • 1..6,184-16,194'MD • 16,204-16,224'MD Reference Log: GR/CCL dated,l5-April-2006 11. RDMO E-Line and return NS30 to production. Obtain. well. test. PPROF Log .Presentation 1. Job Comments • Operating steps in sequence • Changes in choke setting and production. noted at test separator. • Volumes pumped • Logging passes executed • Field data interpretation 2. In the header for. each pass, include a summary of the production conditions such as choke setting, pressure, and phase specific rates. 3. Flowing STP up pass overlay -spinner and temperature data from 40, 80, and 120 fpm. dynamic up passes with constant choke. 4. Flowing STP , up/down pass. overlay - spir~er and temperature data from best up/down pass. 5. StaticLFlowing pass overlay -temperature from best .static and flowing passes 6. Stop Counts. Please contact Jack Lau 564-5102 (w); 227-2760 (c) or Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. 5 of 7 • 6of7 Gan~a~a Aar i6Rl o ~~A) goo TIit:Fm AAR.V(S141NM Q[d W~L}~d • Aea-vc~ l~-s~ >ru..Tr~avx s~ ACTUATOR a BA K8. <iEV a 56.37' ___ - 8F~ aEN a 4Q1'(C$ 13.9 KOP ^ 50' Mme Ante ^ S7' ~ 3396' tum ^ Dstun TVd ^ 10500' SS a Minimum ID = 3.25" ~ 95729' 4-112" HES XN NIPPLE ToPaF r LNR 143!78 i 9-Srs° csct , ~-eo aTlv4c, In . 6.5~ ~ iTOP OF4 f2° LNR i 4112°TBK~, 1265, 13CRVAM-TOP. .©152 6pf, D •3.958" 11383 Gef _ ~ a 818d• PERFGWITION SUMAIIIRY R~ L00: (3i-OCL ON 04113iQB A NC3Y.FAT TOP Pt3~: 20` ~ 16112' Note: Refer la Ptad~ OBfar Wstu~alperf dale SEE SiaF g4TEft11AL (~ OprJSgz DATE 3 7.15' B 16112 - 16132 O 44/15/06 2 7.8" B 16112- 16137 O 1}6~2810B 2-7Ax' 6 161 - 16152 O 041151iD6 2-AB° B 16737 - 76162 O 04130Y08 2-7.8" 6 16152 - td172 O 04118!06 2 7~8' B 76184 - 16194 O 04/14106 2-T,®"' 6 162A4- 16224 O 44!14106 4-112' LAIR. 12841, l3 .4152bpf, D~ 3.958' N S 3 ~ r~oTFS: -"4.172°' ,tea °'-~1MSweu.~- S-1/2° X 4112' Vff ID ~ 3958° 10Y17' 4112^ TRfii~4E TR.SV w ! X PROfi~ D^ 3812' QA8 LFT iJANQREL3 WD TVO DEiI TYf+E VLV LATt71 P!?Rf GG 6668 4495 Sb Mi~1fi DMd RK 0 0411 143' ~"xrZXP'LTP,iD=z° 14383' 916" x r BKR a.~c L0IX LTR D • r 15849' 4112° Hl~ X tJIP, d ~ .3813° 158'70 41tr ~OPfICTRANSDIJ(332,1fl x3.956' 1589 r X 411Y eKR 5 3 AU2. ~ i 3.675' 15718' 4112° HB X NP, d a 3813' 15729' 4112' MBXN !~! D ~ 3:725' (iS112' ELMD (04116108) 15728' 11.77 81CRTE~ACK D a 7 15739' rxsZlWLTP,D^~° 1574:t' 4112° SaF ALCiT~40 WLBD, D a 3860' 1575Dr r x s 8KR ~ LOCK tiGR, a. r 15760' S X x0. D • r DATE R'EV 8Y ODA4t~4T3 DATE REV SY OOMrB4T3 04A8106 N33E ACTUALCOMPLETION 12!15107 VYRRIPJC SAFETYAIOTE(1WbIBYV81) 04/13106 JWRLH OLV 710 04'7111106 JL.YTLH P8iF3(04/3d08) 04!15146 JL11RH NML F73if3 07/47108 1-D ADPERFS(4628438) 4SM0106 JLJliLH DRLO DRAFT OORR~T1L7~4S 11127/07 WRRIPJC 1AIEt.LH01 LOCATCN4 Odf~OTDfr3 12n51o7 RcT/PJC TRSV ODRRBCf1DN AIDRTH9TAR VS~L• A1330 P~+/T No: x10142470 AANoe 50429-2328300 513; t 1, T13N. R13E 1339' FSL a 649" 713 BP Exploratkt~t (Alaska) 7of7 i~J~~ ~~~ s"~-,~,~ • Date 07-23-2008 Transmittal Number:92988 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf vrn~ have anv auesti~ns_ nlease contact Joe Lastufka at (9071564-4091 Delivery Contents SW Name Date Contractor Run To De th Bottom De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS10 07-10-2008 PDS 8 0 8022 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS10 07-10-2008 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS32 07-09-2008 PDS 5 0 8116 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS32 07-09-2008 PDS RESULTS SUMMARY NS16A 07-04-2008 SCH 1 14100 14376 PERFORATING RECORD CD-ROM -PERFORATING NS16A 07-04-2008 SCH RECORD NS19 06-30-2008 SCH 1 13550 13940 PERFORATING RECORD CD-ROM -PERFORATING NS19 06-30-2008 SCH RECORD NS30 06-28-2008 SCH 1 15890 16197 PERFORATING RECORD CD-ROM -PERFORATING NS30 06-28-2008 SCH RECORD Please Sign and Return one copy of this transmittal. Thank You, Joe Lastufka ~c~~ryt ~ll0~05 ~r Petrotechnical Data Cente a6~ =ap'l I(o~o~' ~9 c~2 ~ o~ ~ ~(~~ BPXA c~-r caOCv-ik2 / lola~r r AOGCC ~~ ~a~ _ ash ~~~~°~ Murphy Exploration DNR MMS ~--~~~~~~~ AUG ~ ~; 2008 David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ~~~ Ud ALAS OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS ~~ .~® ~~ ~~ ~?~ ~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Q e~., ..~ O ~ 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 ~~~~ 205-2070 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: .~~ Anchorage, AK 99519-6612 50-029-23293-00-00~ ~ 7. KB Elevation (ft): 9. Well Name and Number: 56.27 RT " NS30 8. Property Designation: 10. Field/Pool(s): ADLO-312808 - NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 16398 ~ feet Plugs (measured) None true vertical 11243.78 ~ feet Junk (measured) None Effective Depth measured 16245 feet true vertical 11098 feet Casing Length Size MD TVD Burst Collapse Surface 4397' 13-3/8" 68# L-80 45' - 4442' 45' - 3254' 5020 2270 Production 14506' 9-5/8" 53.5# L-80 43' - 14549' 43' - 9560' 7930 6620 Liner 1510' 7" 29# L-80 14367' - 15877' 9404' - 10757' 8160 7020 Liner 666' 4-1/2" 12.6# 13CR80 15730' - 16396' 10624' - 11242' 8440 7500 S~ANN~®JUL 2 5 2008 Perforation depth: Measured depth: See Attached True Vertical depth: Tubing: (size, grade, and measured depth) 4-12/2" 12.6# 13CR VAM 41' - 15739' 0 0 - Packers and SSSV (type and measured depth) 4-1/2" baker s-3 packer 15694' 4-1/2" trssv 1026' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3821 39094 47 800 Subsequent to operation: 4158 42459 36 807 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~~ Development +~ Service ""A Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG Paz' GINJ WINJ "W' 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: ~a~z -z~ Contact Robert Younger Printed Name Robert Yo nger Title Production Engineer Signature Phone 564-5392 Date 7/9/2008 ®9ilR9 L~Y9 Q^? UVL k /~ 6uuu Form 10-404 Revised 04/20f~ ~ ~ ^ ~ ~~ p ~ Submit Original Only 'R f~~ NS30 205-2070 aaRa errerunnan~T __ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base ~ Tvd Depth Top Tvd Depth Base NS30 4/15/06 PER 16,112. 16,132. 10,971.92 10,990.69 NS30 4/15/06 PER 16,132. 16,137. 10,990.69 10,995.39 NS30 4/15/06 PER 16,137. 16,152. 10,995.39 11,009.54 NS30 4/15/06 PER 16,152.1 16,162. 11,009.54 11,018.98 NS30 4/15/06 PER 16,162. 16,169. 11,018.98 11,025.59 NS30 4/15/06 PER , 16,169. 16,172. 11,025.59 11,028.42 NS30 4/15/06 PER 16,184. 16,194. 11,039.77 11,049.23 NS30 4/15/06 PER 16,204. 16,224. 11,058.7 11,077.66 NS30 9/16/07 RPF 16,169. 16,194. 11,025.59 11,049.23 NS30 4/30/08 RPF 16,137. 16,162. 10,995.39 11,018.98 NS30 6/28/08 RPF 16,112. 16,137. 10,971.92 10,995.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH j OPEN HOLE ~ NS30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY - _ -- _ _ - - 6/27/2008;. Well flowing on arrival. Job scope - Reperf. :Travel to Northstar island. Begin clearing well row and spotting e-line ;equipment. 6/28/2008 **`*In ro ress*"* '. _. ~_. ~,P. 9_~ .... _..___. ~... _.__ _ __.~. , Continued from WSR dated 6/27/08 **"Well shut in at 0600 hrs for TAPS proration**** Tie into SLB GR/CCL dated 4/15/06. Tag TD at 16227'mdbkb. Re-perforate Ivishak 16112' - 16137' mdbkb + 2.875" x 25' 6 SPF 2906 PJ EHD=0.38" TTP=25.3" All shots fired Turn well over to production Begin move to NS-19 *****JOB COMPLETE***'`" FLUIDS PUMPED BBLS 1 diesel 1 Total U.S. Department of the Interior Submit original plus THREE copies, OPlB`Confrol No. 1010-0141 Minerals Management Service (MMS) with ONE copy marked "Publiclnrormarion." OMB Approval Expires 8/31/2408 END OF OPERATIONS REPORT (EOR)~c~~`sV ~~7 1. ^X COMPLETION ~ CORRECTION ABANDONMENT 2. MMS OPERATOR NO. 00113 3. OPERATOR NAME and ADDRESS (Submitting office) 4. WELL NAME (CURRENT) NS30 ,'" 5. SIDETRACK NO. (CURRENT) ST00 6. BYPASS NO. (CURRENT) BP00 BP Exploration Alaska PO Box 196612 Anchorage Alaska 7. API WELL NO. (CURRENT SIDETRACK /BYPASS) (12 DIGITS; 50-029-23293-00-00 8. PRODUCING INTERVAL CODE S01 , 99519-6613 WELL AT TOTAL DEPTH 9. LEASE NO. OCS-Y0181 10. AREA NAME BEECHY POINT 11. BLOCK NO. 516 12. LATITUDE 70.4,5757751 NAD 27 (GOM & Pacific) X NAD 83 (Alaska) 13. LONGITUDE _14.S.6O595022 NAD 27 (GOM & Pacific) X NAD 83 (Alaska) WELL STATUS INFORMATION 14. Well Status COM 15. Type Code POW 16. Well Status Date 7/9/08 17 MD 16398' TVD 11244' Total Deptr, 16398' WELL AT PRODUCING ZONE 18. LEASE NO. OCS-Y-0181 19. AREA NAME BEECHY POINT 20. BLOCK NO. 516 21. LATITUDE 70.48761486 22 LONGITUDE _148.GO6CO213 NAD 27 (GOM & Pacific) NAD 27 (GOM & Pacific) X NAD 83 (Alaska) X NAD 83 (Alaska) 23.COMPLETION DATE: 4/14/OC 24.DATE OF FIRST PRODUCTION: 4/15/O6 25. ISOLATED DATE: PERFORATED INTERVAL(S) THIS COM PLETION 26.TOP (MD): 27. BOTTOM (MD) 28. TOP (TVD) 29. BOTTOM (TVD): 16112' 16172' 10972' 11028' 16184' 16194' 11040' 11049' 16204' 16224' 11059' 11078' 30. RESERVOIR NAME(S): IVISHAK 31. NAME(S) OF PRODUCING FORMATION(S) THIS COMPLETION TOP OF IVISHAK HYDROCARBON BEARING INTERVALS 32. INTERVAL NAME: 33. TOP (MD) 34. BOTTOM (MD) 35. TYPE OF HYDROCARBON TOP SAG RIVER 15846' 10729' OIL TOP KUPARUK 15948' 10821' OIL TOP IVISHAK 16052' 10916' OIL SIGNIFICANT MARKER S Penetrated (account for all markers identified on APD) 36. INTERVAL NAME: 37. TOP (MD) 38. REASON IF MARKER NOT PENETRATED TOP KUPARUK 13909' TOP SAG RIVER 15846' TOP IVISHAK 16052' SUBSEA COMPLETION 39. SUBSEA COMPLETION? Yes/No NO 40. IF YES: PROTECTION PROVIDED? Yes/No 41. BUOY INSTALLED? Yes1No 42. TREE HEIGHT ABOVE ML(ft): MMS FOrm MMS-1 Z5 (October 2005 -Supersedes all previous versions of form MMS-125 which may not be used.) Page 1 of 2 END OF OPERATIONS REPORT (EOR) ABANDONMENT HISTORY OF WELL 43. CASING SIZE: 44. CASING CUT DATE: 45. CASING CUT METHOD: 46. CASING CUT DEPTH: 47. Type of Obstruction: 48. Protection Provided: Yes/No 49. Obstruction Height Above ML (ft): 50. Buoy Installed? Yes/No CONTACT NAM CONTACT TELEPHONE NO.: 907-564-5392 CONTACT E-MAIL ADDRESS: Robert.Younger@BP.com PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 et sue.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form is estimated to average between 1-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing Instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS FOrm MMS-'i 25 (October 2005 - Supercedes all previous versions of form MMS-125 which may not be used.) Page 2 of 2 l K M °~- DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2052070 Well Name/No. NORTHSTAR UNIT NS-30 MD 16398 TVD 11244 Completion Date 4/14/2006 REQUIRED INFORMATION Mud Log No Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23293-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional DATA INFORMATION Types Electric or Other Logs Run: MWD/LWD, GR, RES, DEN, NEU Well Log Information: Log/ Electr Da Digital Dataset Tye Med/Frmt Number Name D D Asc Directional Survey Rpt Directional Survey ~ g Induction/Resistivity ' ~o Induction/Resistivit ,, g ~ y 1 -L.og Induction/Resistivity /dog Induction/Resistivity 13860 I~tSiduction/Resistivity ED C I 13974,,kfduction/Resistivity ;';~ E~ C Pds 13974 Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 0 16398 Open 5/10/2006 0 16398 Open 5/10/2006 ~ 2 Blu 1-10 200 16398 515!2006 Measure Depth Log Compostie Recorded FINAL PRINT Scale 1:600 I 25 Blu 1-10 200 16398 5/5/2006 Measure Depth Log Compostie Recorded FINAL PRINT Scale 1:600 & 1:240 25 Blu 1-10 200 16398 5/5/2006 True Veritical Depth Log Compostie Recorded FINAL PRINT Scale 1:600 & 1:240 2 Blu 1-10 200 16398 5/5!2006 True Veritical Depth log Compostie Recorded ~ FINAL PRINT Scale 1:600 ~ 25 Blu 1-10 200 16398 5/5/2006 True Veritical & MeasuredDepth Log Compostie Recorded FINAL PRINT Scale 1:600 & 1:240 200 16398 7/5/2006 Measure Depth Log ' Compostie Recorded FINAL PRINT Scale 1:600 200 16398 7/5/2006 Measure Depth Log ~ Compostie Recorded ~ FINAL PRINT Scale 1:600 & 1:240 I DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2052070 Well Name/No. NORTHSTAR UNIT NS-30 MD 16398 TVD 11244 Completion Date 4/14/2006 og 13974 Induction/Resistivity C Pds 13974 rl'fiduction/Resistivity I ~~ 13974 Cement Evaluation Cif' C Lis 13974~uction/Resistivity wog See Notes .l,6g Perforation See Notes ~ ~I L~ Perforation Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23293-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N 5 Blu 200 16398 Open 7/5!2006 Measured Depth Log Composite Mode FINAL PRINT Scale 1:600 ****DATA REVISED 5-Jun- 2006**** 200 16398 Open 7/5/2006 Measured Depth Log Composite Mode FINAL PRINT Scale 1:600 ****DATA REVISED 5-Jun- 2006**** 25 Col 1 50 16228 Case 7/5/2006 Slim Cement Mapping Tool, Gauge Ring, Dummy Gun, SCMT-GR 3-Apr-2006 200 16398 Open 7/5/2006 Measured Depth Log Composite Mode FINAL PRINT Scale 1:600 ****DATA REVISED 5-Jun- 2006**** 5 Blu 14200 16228 Case 8!23/2006 Jewelry Log GR/CCL 3- April-2006 5 Blu 15950 16205 Case 8/23/2006 Perforation Record with Gamma Ray 2.88" HSD 6SPF 60 Deg Phased PJ2906 14-April-2006 5 Blu 15550 16205 Case 8/23!2006 Jewelry Log Gamma Ray / CCL 15-April-2006 5 Blu 15900 16170 Case 10/24/2007 Perf Record, 2 7/8 PJ GR, CCL 16-Sep-2007 Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~71Q- Analysis Received? Sample Set Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2052070 Well Name/No. NORTHSTAR UNIT NS-30 Operator BP EXPLORATION (ALASKA) INC MD 16398 TVD 11244 Completion Date 4/14/2006 Completion Status 1-OIL Current Status 1-OIL Comments: Compliance Reviewed By: _ ___._ _ __ - API No. 50-029-23293-00-00 UIC N --- Date. MN.- ~w ~1 g s by BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv auestions_ please contact .Tc,e T.acr„fka at (A(1715~,4_4(191 Date OS-23-2008 Transmittal Number:92975 Deliver Contents SW Name Date Contractor Run To De th Bottom De th Descri tion STATIC BOTTOM HOLE NS15 04-21-2008 SCH 1 14800 15000 PRESSURE SURVEY CD-ROM -STATIC BOTTOM NS15 04-21-2008 SCH HOLE PRESSURE SURVEY NS30 04-30-2008 SCH 1 15950 16190 PERFORATING RECORD CD-ROM -PERFORATING NS30 04-30-208 SCH RECORD ~_- " MEMORY MULTI-FINGER CALIPER LOG RESULTS NS15 05-18-2008 PDS 2 0 14812 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS15 05-18-2008 PDS RESULTS SUMMARY NS15 04-20-200 SCH 1 14900 15144 PERFORATING RECORD NS15 %? 0 CD-ROM -PERFORATING 04-20-2Q 8 SCH RECORD Please Sign and~eturn~one'`opy of this transmittal Thank You, Joe Lastufka Petrotechnical Data Center BPXA AOGCC Murphy Exploration DNR MMS ,rti =.~~ - ~~ _. .~ . ~- David Fair Christine Mahnken Ignacio Herrera Kristin Dirks Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 19661.2 Anchorage, AK 99519-6612 I~l~`r6~1 V ~U STATE OF ALASKA ~ ~~Y ~ ~ ALAS~OIL AND GAS CONSERVATION COMM~ ION ~ 1 ZOOi3 REPORT OF SUNDRY WELL OPERATIONS~laska flil $~ Gas Cons. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ nc Cage Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q . Re-enter Suspended Well 2. Operator BP Exploration (Alaska), inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ''~ Exploratory 205-2070 ' 3. Address: P.O. Box 196612 StratlgraphlC ~ SerVICe 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 56.27 RT - NS30 8. Property Designation: 10. Field/Pool(s): ADLO-312808 - NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 16398 ~ feet Plugs (measured) None true vertical 11243.78 - feet Junk (measured) None Effective Depth measured 16245 feet true vertical 11098 feet Casing Length Size MD TVD Burst Coilapse Surface 4397' 13-3/8" 68# L-80 45' - 4442' 45' - 3254' 5020 2270 Production 14506' 9-5/8" 53.5# L-80 43' - 14549' 43' - 9560' 7930 6620 Liner 1510' 7" 29# L-80 14367' - 15877' 9404' - 10757' 8160 7020 Liner 666' 4-1/2" 12.6# 13CR80 15730' - 16396' 10624' - 11242' 8440 7500 Perforation depth: Measured depth: 16112 - 16172 16184 - 16194 16204 - 16224 True Vertical depth: 10972 - 11028 11040 - 11049 11059 - 11078 Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# 13CR VAM 41' - 15739' 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" BKR S-3 15964' 4-1/2" SELF ALIGNING WLEG 15743' 0 0 0 0 12. Stimulation or cement squeeze summary: ~ ~ ~ ~~~ ~ ~ ~~.~ Intervals treated (measured): C P~ ` - ~ \ 5 ~~~. MAY 2 ~ 200E ~"~c~- ~rc S ~ O q~ ~E3 v`1 ~vc~,~v cy.~ o ~ o ~ ~ Treatment descriptions including volumes used and final pressure: -}~~ vJCZr~ . ~~~ Q W ~-`~ ~ ~ Q ~ ~~S ~' y( ~ ~ /~t ~ ~~ `i5 Q ~~\~S~ V L^ b`~~\ a S/c~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3934 25953 57 791 Subsequent to operation: 4868 35722 58 767 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: 307-284 Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature - - Phone 564-5392 Date 5/15/2008 Form 10-404 Revised 04/2006 ~ ~ ~ ~ /~ ~ ~ ~~y Submit Original Only .~ t ~ • NS30 C~ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY _ _~ 4/28/2008'""'WELL S/I ON ARRIVAL"'~ (pre re-perf) R/U S/L UNIT '"**CONTINUED ON WSR 04/29/08 ,,,, _ __ 4/29/2008:**CONTINUED FROM WSR 04/28/08**" (pre re-perf) DRIFTED TBG W/ 4 1/2" XN LOC, 10' x 2 7/8" DMY GUN, SAMPLE BAILER. LOC XN NIPPLE @ 15,704' SLM (+8' CORRECTION), TAGGED TD @ 16,218' SLM (16,226' ELMD). TARGET DEPTH = 16,162' MD. NO SAMPLE. ***WELL LEFT S/I, TURNED OVER TO CONTROL ROOM*'`* 4/29/2008:"`*WELL SHUT IN ON ARRIVAL"** (re-perf) !'INITIAL T/I/O = 3400/10/35. RIG UP E-LINE. ''`*'`'CONTINUED ON 4/30/08 AWGRS*"" 4/30/2008 INITIAL WHP 3500/1100/3450 ;PERFORATED 25 ' OF 2 7/8" 2906 PJ HMX GUNS FROM 16137'-16162'.. EH: '0.36", PENE; 27.7". DID NOT TAG TD, WELL LEFT SHUT IN. FINAL WHP 3500/1100/3450 FLUIDS PUMPED BBLS 1 diesel 1 Total NS30 Perforation Strategy Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 23, 2008 3:44 PM To: 'Younger, Robert O' Cc: Preble, Gary B (SAIC) Subject: RE: NS30 (205-207) Perforation Strategy Bob, That will be fine. Tom From: Younger, Robert O [mailto:Robert.Younger@bp.com] Sent: Wednesday, April 23, 2008 3:39 PM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAIC} Subject: RE: NS30 (205-207) Perforation Strategy Tom, Page 1 of 4 For the approved 10-,403, we will plan to submit individual 10-404's far each perforation job (we submitted one already for the Sept 2007 Perfs). That way we will ensure that everything is reported in the event we do not shoot the final perforation interval. Please let me know if that is acceptable or if additional information is needed. Thanks! Bob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Wednesday, April 23, 2008 10:31 AM To: Younger, Robert O; Monkelien, Kyle (MMS) Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 (205-207) Perforation Strategy Bob, Do you mean a Sundry (Form 10-403) or a Report of Sundry Well Operations {Form 10-404)? If I understand correctly, you are planning to submit individual 10-404s. Tom Maunder, PE AOGCC From: Younger, Robert 0 [mailto:Robert.Younger@bp.com] Sent: Wednesday, April 23, 2008 10:25 AM To: Maunder, Thomas E (DOA); Monkelien, Kyle (MMS) Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 (205-207) Perforation Strategy Tom /Kyle, In order to ensure that nothing slips through the cracks, we would prefer to submit sundries after each perforation job if that is acceptable. For the first perforation interval that was shot in September, we did submit a 404 & MMS- 125. We can plan to submit a summary of ail the operations when the final perforation interval is shot. Thanks for the help! Bob 4/23/2008 NS30 Perforation Strategy ~ ~ Page 1 of 3 Maunder, Thomas E (DOA) From: Monkelien, Kyle [Kyle.Monkelien@mms.govj Sent: Wednesday, April 23, 2008 9:04 AM To: Younger, Robert O; Maunder, Thomas E (DOA) rr~~ Cc: Preble, Gary B (SAIC); Walker, Jeffrey ~~ ~ ~ c~-V Subject: RE: NS30 Perforation Strategy We agree with Tom that a consolidated report will best suit our needs. Otherwise we have no problems with your process. Thanks Kyle Monkelien petroleum Engineer Alaska OCS Region 907-334-5307 Phone 907-334-5302 Fax From: nger, Robert 0 [mailto:Robert.Younger@bp.wm] Sent: Tue April 22, 2008 2:57 PM To: Maunder, Th as E (DOA); Monkelien, Kyle Cc: Preble, Gary B (S • Walker, Jeffrey Subject: RE: NS30 Perfor n Strategy All, Continuing with the perforation strategy outline my below e- d da#ed 09105107, we plan to re-perforate another 25' of perforations in NS30. This work is co ed un r approved AOGCC and MMS sundries, but just wanted to touch base because of the staged perforation ach. The first 25' of the proposed 75' of perforation was shot 09/16/07. The fina125' will be sho a r date depending on the results of the currently planned re-perforations. Please see attachment for ditional in anon. This work will be sheltered under a Northstar tdown planned for April 2 May 5th. Please let me know if additional information is required. Thanks! Bob From: Maunder, Thomas A) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, Sep ber 05, 2007 11:00 AM To: Monkelien, Kyle S); Younger, Robert O Cc: Preble, Gary C); Walker, Jeffrey Subject: RE: 0 Perforation Strategy don't s, here being a need for any additional paperwork. The approved sundry should be on its way back to you. 1 ' ill place a copy of this message in the file. You have valid reasons for doing the proposed work in se ate operations. 4/23/200$ NS30 Perforation Strategy ~ • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 22, 2008 3:08 PM To: 'Younger, Robert O'; Monkelien, Kyle (MMS) Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 (205-207) Perforation Strategy Bob, i don'# really see an issue staging the perforations. This eases the paperwork burden on all of us. When reporting, I would suggest that all stages be covered in one report with any production information between stages provided as well. Call or message with any questions. Tom Maunder, PE AOGCC From: Younger, Robert 0 [mailto:Robert.Younger@bp.com] Sent: Tuesday, April 22, 2008 2:57 PM To: Maunder, Thomas E (DOA); Monkelien, Kyle (MMS) Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 Perforation Strategy All, Continuing with the perforation strategy outlined in my below a-mail dated 09/05/07, we plan to re-perforate another 25' of perforations in NS30. This work is covered under approved AOGCC and MMS sundries, but just wanted to touch base because of the staged perforation approach. The first 25' of the proposed 75' of perforation was shot 09/16/07. The final 25' will be shot at a later date depending on the results of the currently planned re-perforations. Please see attachment for additional information. This work will be sheltered under a Northstar shutdown planned for April 28th to May 5th. Please let me know if additional information is required. Thanks! Bob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 05, 2007 11:00 AM To: Monkelien, Kyle (MMS); Younger, Robert O Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 Pertoration Strategy 1 don't see there being a need for any additional paperwork. The approved sundry should be on its way back to you. I will place a copy of this message in the file. You have valid reasons far doing the proposed work in separate operations. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC From: Monkelien, Kyle [mailto:Kyle.Monkelien@mms.gov] Sent: Wednesday, September 05, 2007 10:49 AM To: Younger, Robert 0; Maunder, Thomas E (DOA) 4/23/2008 NS30 Perforation Strategy ~ • Page 2 of 3 Cc: Preble, Gary B (SAIC); Walker, Jeffrey Subject: RE: NS30 Perforation Strategy This should not require a resubmittal of the permit for MMS. We will take it into account during our review and add the information you attached to the submitted form. Thanks Kyle Monkelien Petroleum Engineer Alaska OCS Region 907-334-5307 Phone 907-334-5302 Fax From: Younger, Robert O [mailto:Robert.Younger@bp.com] Sent: Wednesday, September 05, 2007 10:19 AM To: Monkelien, Kyle; Thomas Maunder Cc: Preble, Gary B (SAIC) Subject: NS30 Perforation Strategy Kyle /Tom, I just wanted to touch base on the current perforation strategy for the sundry request for NS30. After further discussion with the Northstar Subsurface Team regarding the perforation strategy for NS30, a stepped approach is proposed for the perforation strategy. We requested approval for perforating: RePerfs: 16112' to 16162' MD Ad/Re Perfs: 16169' to 16194' MD The current strategy would be to proceed with perforating 16169' to 16194' MD and evaluate perforating 16112' to 16162' MD at a later date based on the perforation results. We would like to proceed with obtaining sundry approval to shoot both intervals outlined above and in the submitted sundries; however, the upper RePerf interval 16112'-16162' MD would be shot at a later date dependent on evaluation of the lower Ad/Re Perfs and the well's overall performance. Please see below attachments. «NS30 09-05-07 Perf Reference Log.ZIP» Please let me know if we need to make any adjustments to the sundries that have already been submitted. Thanks! Bob ~ ert Yflunger 4/23/2008 • tr ~ ~&~•, P -, } , ~~ . Date 10-23-2007 Transmittal Number:92913 :~ ~. _,: i~~ =~:, BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ -+2'3 ~ l55(0`~ ao$_ab~- ~- col ___- ~' aoa - ~~rr ~o f a.l°l Log Top SW Name Date Contractor Run De th Bottom De th Lo T e MEMORY MULTI-FINGER CALIPER LOG RESULTS NS16 09-11-2007 PDS 1 0 12110 SUMMARY MULTI-FINGER CALIPER 3D NS16 09-11-2007 PDS 1 0 12110 DATA AND VIEWER NS30 09-16-2007 SCH 1 15900 16170 PERFORATING RECORD MEMORY STATIC PRESSURE NS06 07-29-2007 SCH 1 13096 13694 AND TEMERATURE SURVEY MEMORY STATIC PRESSURE NS18 07-30-2007 SCH 1 16290 16845 AND TEMERATURE SURVEY MEMORY STATIC PRESSURE NS09 07-31-2007 SCH 1 12666 13341 AND TEMERATURE SURVEY Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA /D~G~ F,'.~ ~~~„_ ALA OIL AND GAS CONSERVATION COM~SION ~~ E '~.:" ~r. REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~~ ~,;, n ` ~t~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ ~~ .5 Performed: Alter Casin Pull Tubin Perforate New Pool Waiver Time Extension g ^ g^ ^ ^ ~ 'e ~'f~ rr-,. '~! 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 ~ 205-2070 - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.27 ~ RT NS30 8. Property Designation: 10. Field/Pool(s): ADLO-312808 NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 16398 feet Plugs (measured) None true vertical 11242 ~ feet Junk (measured) None Effective Depth measured 16245 feet true vertical 11098 feet Casing Length Size MD TVD Burst Collapse Surface 4397' 13-3/8" 68# L-80 45' - 4442' 45' - 3254' 5020 2270 Production 14506' 9-5/8" 53.5# L-80 43' - 14549' 43' - 9560' 7930 6620 Liner 1510' 7" 29# L-80 14367' - 15877' 9404' - 10757' 8160 7020 Liner 666' 4-1 /2" 12.6# 13CR80 15730' - 16396' 10624' - 11242' 8440 7500 Perforation depth: Measured depth: 16112' - 16169' 16169' - 16194' 16204' - 16224' True Vertical depth: 10972' - 11026' 11026' - 11049' 11059' - 11078' Tubing: (size, grade, and measured depth) 4-1/2" 12..6# 13CR80 41' - 15739' Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Packer 15694' 4-1/2" TRSSV 1026' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~, ~,~, ~~~ ~ ~ 200 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: 4781 27306 35 0 777 Subsequent to operation: 6172 34674 54 0 797 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: 307-284 Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date 10/1/2007 S(p~ ~- Form 10-404 Revised 04/20060 ~ ~ G ~ N A ~ ,~ \~~~ mi~OOr~al70nly i • NS30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/15/2007 Well flowing***** Upcoming Add Re-perforate***** Move in slickline and a-line equipment in preparation for dummy gun drift and add ', ', re-perf during plant shut down. ******continue on WSR 9-16-06***** 9/16/2007`***WELL S/I ON ARRIVAL*** ADD PERF DRIFT *** DRIFTED WELL WITH 2 7/8" DG AND XN LOCATOR. TAG TD AT 16226' MD ' CORRECTED. *** JOB COMPLETE, LEFT WELL SHUT IN, TURNED OVER TO E-LINE FOR !PERF JOB **"` __ _ _ _ __ 9/16/2007' *****WELL SHUT IN ON ARRIVAL-PLANT SHUT DOWN*''**ADD PERF**** INITIAL WHP 3100/0/0 PERFORATED 16169'-16194' WITH 2 7/8" 2906 POWERJET 6 SPF, CHARGE ', DATA: 27.7" PENE, 0.36" EH, 15 GMS. CORRELATED TO SWS GR/CCL LOG ': .DATED 15-APR-2005. ALL SHOTS FIRED. FINISH RIG DOWN IN AM OF THE 17TH. 'LEFT WELL SHUT IN DUE TO PLANT SHUT DOWN. *****JOB COMPLETE***"* FLUIDS PUMPED BBLS 1 Diesel 1 Total • ~ ~~~ ~~`~~ ~ zoo? "~~r,~~ a1 t y~~, r .' ~~ V..S. Department of the Interior Submit original plus THREE copies, . OMB Contr~ll<fd~~~f~f141 Minerals Management Service (MMS) with ONE copy marked "Publiclnformation." OMB A)SpCt~vafi Expires 8/31/2008 END OF OPERATIONS REPORT FOR 1. ~ COMPLETION ~ CORRECTION ABANDONMENT 2. MMS OPERATOR NO. 00113 3. OPERATOR NAME and ADDRESS (Submitting office) 4. WELL NAME (CURRENT) NS30 5. SIDETRACK NO. (CURRENT) ST00 6. BYPASS NO. (CURRENT) BP00 BP Exploration Alaska PO Box 196612 Anchorage AK 7. API WELL NO. (CURRENT SIDETRACK /BYPASS) (12 DIGITS; 50-029-23293-00-00 8. PRODUCING fNTERVAL CODE S01 . , 99519-6613 WELL AT TOTAL DEPTH 9. LEASE NO. OCS-Y0181 10. AREA NAME BEECHY POINT 11. BLOCK NO. 516 12. LATITUDE 70.48757751 13. LONGITUDE _148.60595022 NAD 27 (GOM & Pacific) NAD 27 (GOM b Pacific) x NAD 83 (Alaska) x NAD 83 (Alaska) WELL STATUS INFORMATION 14. Well Status COM 15. Type Code POW 16. Well Status Date 10-1-07 17 MD 16398' Np 11244' Total Depth 16398' WELL AT PRODUCING ZONE 18. LEASE NO. OCS-Y0181 19. AREA NAME BEECHY POINT 20. BLOCK NO. 516 21. LATITUDE 70.48761486 NAD 27 (GOM & Pacific) X NAD 83 (Alaska) 22 LONGITUDE _148.60660213 NAD 27 (GOM & Pacific) x NAD 83 (Alaska) 23.COMPLETION DATE: 4/16/O6 24.DATE OF FIRST PRODUCTION: 4/15IO6 25. ISOLATED DATE: PERFORATED INTERVAL(S) THIS COM PLETION 26.TOP (MD): 27. BOTTOM (MD) 28. TOP (TVD) 29. BOTTOM (TVD): 16112' 16172' 10972' 11028' 16184' 16194' 11040' 11049' 16024' 16224' 11059' 11078' 30. RESERVOIR NAME(S): IVISHAK 31. NAME(S) OF PRODUCING FORMATION(S) THIS COMPLETION TOP OF IVISHAK HYDROCARBON BEARING INTERVALS 32. INTERVAL NAME: 33. TOP (MD) 34. BOTTOM (MD) 35. TYPE OF HYDROCARBON Top Sag River 15846' 10729' OIL Top Shublik 15948' 10821' OIL Top lvishak 16052' 10916' OIL SIGNIFICANT MARKER S Penetrated (account for all markers identified on APD) 36. INTERVAL NAME: 37. TOP (MD) 38. REASON IF MARKER NOT PENETRATED Top Kuparuk 13909' Top Sag River 15846' Top Ivishak 16052' SUBSEA COMPLETION 39. SUBSEA COMPLETION? Yes/No NO 40. IF YES; PROTECTION PROVIDED? Yes/No 41. BUOY INSTALLED? Yes/No 42. TREE HEIGHT ABOVE ML(ft): MMS FOrm MMS-125 (October 2005 -Supersedes all previous versions of form MMS-125 which may not be used.) Page 1 of 2 ~ ~ END OF OPERATIONS REPORT (EOR) ABANDONMENT HISTORY OF WELL 43. CASING SIZE: 44. CASING CUT DATE: 45. CASING CUT METHOD: 46. CASING CUT DEPTH: 47. Type of Obstruction: 48. Protection Provided: Yes/No 49. Obstruction Height Above ML (ft): 50. Buoy Installed? Yes/No CONTACT NAME: CONTACT TELEPHONE NO.: 907-564-5392 CONTACT E-MAIL ADDRESS: younger2@bp.com Y / +/ PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 et sec .) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form is estimated to average between 1-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS FO~m MMS-125 (October 2005 - Supercedes all previous versions of form MMS-125 which may not be used.) Page 2 of 2 NS30 Perforation Strategy ~ Page 1 of 2 ~ 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 05, 2007 11:00 AM To: 'Monketien, Kyle ;Younger, Robert O Cc: Preble, Gary B (SAIL); Walker, Jeffrey Subject: RE: NS30 Perforation Strategy ~~~-3-~~ I don't see there being a need for any additional paperwork. The approved sundry should be on its way back to you. 1 will place a copy of this message in the file. You have valid reasons for doing the proposed work in separate operations. Good luck. Call or message with any questions. Tom Maunder, PE AOGCC From: Monketien, Kyle [mailto:Kyle.Monkelien@mms.gov] Sent: Wednesday, September 05, 2007 10:49 AM To: Younger, Robert 0; Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAIC); Walker, 7effrey Subject: RE: NS30 Perforation Strategy This should not require a resubmittal of the permit for MMS. We will take it into account during our review and add the information you attached to the submitted form. Thanks Kyle Monketien Petroleum Engineer Alaska OCS Region 907-334-5307 Phone 907-334-5302 Fax From: Younger, Robert 0 {mailto:Rot~rt.Younger@bp.mm] Sen#: Wednesday, September 05, 2007 10:19 AM To: Monketien, Kyle; Thomas Maunder Cc: Preble, Gary B (SAIC) Subject: NS30 Perforation Strategy Kyle /Tom, I just wanted to touch base on the current perforation strategy for the sundry request for NS30. After further discussion with the Northstar Subsurface Team regarding the perforation strategy for NS30, a stepped approach is proposed for the perforation strategy. We requested approval for perforating: 915!2007 NS30 Perforation Strategy ~ Page 2 of 2 RePerfs: 16112' to 16162' MD Ad/Re Perfs: 16169' to 16194' MD The current strategy would be to proceed with perforating 16169' to 16194' MD and evaluate perforating 16112' to 16162' MD at a Later date based on the perforation results, We would like to proceed with obtaining sundry approval to shoot both intervals outlined above and in the submitted sundries; however, the upper RePerf interval 16112'-16162' MD would be shot at a later date dependent on evaluation of the tower Ad/Re Perfs and the well's overall performance. Please see below attachments. «NS30 09-05-07 Perf Reference Log.ZIP» Please let me know if we need to make any adjustments to the sundries that have already been submitted. Thanks! Bob Robert Younger BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Name) 907-830-4920 (Cell) younger2~bp.com 9/5/2007 ~ ~ ~,. -_,~, ~ - / SARAH PALIN, GOVERNOR AI.ASSA OII~ A1~TD G.~.S C~KS~RQ~~1'I~I~ COMI•IISSIOI4 ~fr 333 W. 7th AVENUE, SUITE 100 -7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 307-284 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided 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 da Encl. ao5 -~ `_ ~~ ~~E~OF~LASKA l/1'"~~~/ ~J a'"'""~ ALA~A OIL AND GAS CONSERVATION COMMI iON ~g9 APPLICATION FOR SU NDRY APPROVAL ~-~~ ~s~ao~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ i Waiver Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ 9~1C ~ or~ ~f C 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 Q Exploratory ^ 205-2070 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 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: NS30 .` Spacing Exception Required? Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312808 ' 56.27 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): 16398 ~ 11243 _ 16245 11097 None None Casing Length Size MD TVD Burst Collapse Surface 4397 13-3/8"68# L-80 45 4442 45 3254 5020 2270 Production 14506 9-5/8" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7"29# L-80 14367 15877 9404 10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 16396 10624 11242 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16112 - 16172 10972 - 11028 4-1/2" 12.6# 13CR80 41' - 15739' 16184-16194 11040-11049 16204 - 16224 11059 - 11078 Packers and SSSV Type: 4-1/2" TRSSSV Packers and SSSV MD (ft): 1026' 4-1/2" BAKER S-3 PACKER 15694' 0 0 0 0 12. Attachments: Descriptive Summaryof Proposal 0 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: 9/10/2007 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by nary rreule 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name Robert Youn Title Production Engineer Signature Phone 564-5392 Date 8/27/2007 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: Vv~~~CUtI\T~Q~~~v~Q ~~`~ ~~ ~ ~-'TC.._~~~~ Subsequent Form Required: ~jOL-` APPROVED BY may' ~//O~ `` ~~// f ~" Approved by: ISSIONER THE COMMISSION Date: ,, / // `~G~ ~'~~ ~~ d Other O NCO ~J ~~J' . ~~O 7 V `,--~ Form 10-403 Revised 06/2006 O R ~ ~ I ~ S ~~~ 5~~ ~ ~ 7a~~ Submit in Duplicate '' . • ~e,Q a ~~~~o, ~`~` PERFORATING PROCEDURE .~ :> . ADW .,~e.~, Well: NS30 _ _ _ _ _ _ _ _ _ API #: 50-029-23293-0( ___________ _ __ ___ Date: 8/22/07 Prod Engr Robert Younger Office Ph: 564-5392 H2S Level: _____________________. ___________-_-- Home Ph:V-V---677.2599----- ~~-V---------4-ppm_------------:_,l Cell Ph: 830-4920 CC or AFC: NSFLDWL30 Detail Code: Description: Drift to TD with Dummy Gun, Re_Perf & Ad Perf ..... .........___.- __ __. - .. ... WBLEntries IOR Type Work Description 500 S Drill to TD with Dumm Gun 500 E Re- erforate 1 b, l 12' - 1 b, l 62' & 16,184' - 7 b, 209' M D Well Objectives and Loaaina Notes: NS30 is a 2006 development well at Northstar. Initial production was -8100 BOPD. The well declined to -6100 BOPD and was treated for scale in August 2006. NS30 locked up at 227 6615 away during the acid pickle treatment on 7/31 /Ob. On 8/1 /06 the acid treatment locked up offer 231 6615. Despffe the complications, production rose to about -7000 bopd and has since declined to around -5000 bopd. The objective of the slickline portion of this procedure Is to evaluate the extent of any restriction that might exist. The proposed RePerfs are an attempt to increase production by perforating past any damage and the AdPerfs are an attempt to increase production by perforating additional reservoir. Please note that the re-perforations will be dependent on the drill. The last tag, 8/18/Ob tagged high in the lower section of perfs. Please try to get as deep as possible when shooting the lower section of perforations. 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. Reference Log Tie in Log Add/Subtract _ feet Log: GR/CCL _ to the tie-in log to be on Date: 4/15/2006 _ _ _ _ _ depth with the reference log. Company: Schlumber~er _ _ __ __ Depths (from-to) Depths (from-to) Feet SPF Orient. 16,112' - 16,162' - 50' 6 ....16,1.69'.._ ..16,194.. .....__._ •---------- ..25._. ...s.. .-___.-_- ..Gas letting Expected?.... ..... _ - - . - .. - - No .... ...... At what Depth? . - ... . Requested Gun Size: 2.875 Charge: 2906 PJ Phasing Zone Ad/Re/Iperf 60° _ 0 Ivishak _ _ _ _ RePerf 60° 0 Ivishak RePerf/AdPerf 0 0 -____-. 0 ______________________________ ....-. N/A ' ......................... Desired Penetration: _ 25.3_ _ _ _ _ Entry Hole Diam: _ _ _ 0.38 - Is Drawdown Necessary/Desired/Unnecessary During Perforating NA Describe below how toaehieve drawdown (check w/Pad Operator to see ifnscessarypipin9is installed) ------------------------------------------~---~-. . . •. . •~. ~. . -• (e.g. N2 Litt, Hardline Lik Oas, Oas Lilt, Flow Well, Backflow Through Drein or Hardin Tie in to JewelryC~ .. MD Tie in using: ...... .... ..... .............------ .................. ..................... ............................ Minimum ID: 3.725 in Min ID Type: 4.5" XN Nipple @ 15,729 'MD WLEG Depth: 15,743 _ ft MD Casing Size: 4.5 in 12.6# 13-CR Liner Est Res. Pres. ~ 16,_307 MD 1110.0' SS _-_5.1.20_ _ _ _ _ psi Last Tag: 16,210 ff SLMD on 8/18/2006 3.5" Bailer Well: NS30 Perforation Summary Date: API #: 50-029-23293-00 On-Site Prod Engr: • J W m CJ 2 Y c F ~. Q -- ~ ~ ~ 1338.83' FSL & 649.49' FEL ~. .. _....... Elev.: K.B. 56 ft i Q ~ o F Z G.L. ~ LL o o ~ SURFACE LOCATION D.F. ~ ~ ~ M M ~ ~ Permanent Datum: MSL Elev.: 0 ft z z ~ z ~ O Log Measured From: RKB 56.0 ft above Perm. Datum o ~ Drilling Measured From: RKB s~. ~ .. o ~ .~ - F API Seriat No. Saction ~'o+ranshi~ Range m° ii J ~ C~ 54-029-23293-00 11 13N t 3E Lo~glnc~.l]dfe _m_____ ~ 16-ABC-2006 --w~__ W ---__ Run Number 1 - __ A .~~ . _ m.......:~m...,.... __ _ __._, _~ Depth Driller 16245 ft - -- Schlurflberger Depth - - 16225 ft __- - - --- Bottom Log l ntervai 16205 ff _: Top Log Interval 15550 ft Casing Fluid Type SEA WATER /FREEZE PROTECT _.. Sat~nrty -~ _ - __ _ - Density _-- - ._ - -_ ___ - _._~___.. ®..w.......~.-~ Fluid bevel 0 ft _____ _ ~ - ~BITiCASING/1"UBIt~1G STRING ---,----- Bit Size .. .__.. ___.~ .~.--..,~~.._.._....,-.. ~- _._ From ._~,.,~.,....~..:__- .. To _. __ _ _._. ~... ~..._...~.. _... ~.....~. _ _ ___- Casin (Tubing Size . 4.500 rn e_. . WeE~ 12.6 it~n~(ft _ _ .._ Grade 13CR ;~,_~..~-...~.- From 0 ft _.- - - _ To 1639& ft ~ ~.. Maximum Recorded Tenn eratures _ ~ .Logger On Bottom ~ Tune 15-A~r-2006 12 10 _.. Unit Number ~ocation r 21513 ~ P8U~ __,,, ~ -:.._:.~:._.._.. _m...~. Recorded By _____ , „_ JEFF JC3NES , - ~nlitnPCCeri Rv BRIAN DICKINSON ~, TFj~E ABB-VGI 5-118" WELLHEAD = ABB-VGI 13-5/8" MULTIBOWL SKSI ACTUATOR KB. ELEV _ 56 BF. ELEV = 40.1' (CB 15.9') KOP= Max Angle...- 57 @ 3390' Datum MD = Datum TV D = ~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" Minimum ID = 3.725" @ 15728' 4-1 /2" XN NIPPLE TOP OF 7" LNR ~ 14367' 9-5/8" CSG, 53.5#, L-80 BTM-C, ID = 8.681" 14549' N S 3 0 S NOTES: ***4-1 /2" CHROME TBG &LNR*** 5-1/2"X4-1/2"VtT,ID=??? 1026' 4-1/2" TRSSSV, ID = 3.812" ?? GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT DATE -4492 55 MMG DMY RK 0 04/13/06 15648' I- j 4-1 /2" X NIP, ID = 3.813" 15669' 4-112" FIBER OPTIC TRANSDUCER, ID = 3.958" TOP OF 4-1/2" LNR ~ 15730' 4-1/2" TBG, 12.6#, 13CRVAM-TOP, 15739' .0152 bpf, ID = 3.958" 7" LNR, 29#, L-80 Hydril 521, ID = 6.184" 15877' PERFORATION SUMMARY REF LOG: GR-CCL ON 04/15/06 ANGLE AT TOP PERF: 20 @ 16112' INfrIAL PERF -CHARGE 2906 POWERJET, HMX, ?? PENETRATION: 27", HOLE 0.36" Note: Refer to Production DB for historical perf data S1ZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 16112 - 16132 O 04/15/06 2-7/8" 6 16132 - 16152 O 04/15/06 2-7/8" 6 16152 - 16172 O 04/15/06 2-7/8" 6 16184 - 16194 O 04/14/06 2-7/8" 6 16204 - 16224 O 04/14/06 PBTD 16245' 4-1/2" LNR, 12.6#, 13CRVAM-TOP, 16396' .0152 bpf, ID = 3.958" 15694' ~ 7" X 4-1 /2" BKR S-3 PKR, ID = ??? 15717' 4-1/2" X NIP, ID = 3.813" 15729' 4-1/2" XN NIP, ID = 3.725" 15712' ELM 4-1/2" XN NIP (04/15/06) 15743' 4-1/2" SELF ALIGNING WLEG, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/08/06 N33E ACTUAL COMPLETION 04/13/06 JLJ/TLH GLV GO 04/15/06 JLJlTLH INTIAL PERFS 05/10/06 JLJ/TLH DRLG DRAFT CORRECTIONS NORTHSTAR WELL: NS30 PERMfI- No: API No: 50-029-23293-00 BP Exploration (Alaska) ~~ y ~ • U.S. Department of the Interior Submit original plus THREE copies, with ONE copy Minerals Management Service (MMS) marked "Public Information." OMB Control No. 1010-0141 OMB Approval Expires 8131/2008 Appucatlon for Permit to Modify (l~ 1. WELL NAME (CURRENT) 2. SIDETRACK NO. 3. BYPASS NO. (CURRENT) NS30 (~5~~00 T) BP00 5. API WELL NO. (12 digits) 6. START DATE (Proposed) 7. ESTIMATED I 50-029-23293-00 September 2007 3 8. 9. If revision, please ^ Revision list changes: WELL AT TOTAL DEPTH . OPERATOR NAME and ADDRESS Submitting office) BP Exploration Alaska PO Box 196612 Anchorage, AK 99519-6613 WELL AT SURFACE 10. LEASE NO. 13. LEASE NO. OCS-Y-0181 ADL312799 11. AREA NAME 14. AREA NAME BEECHY POINT BEECHY POINT 12 . t CK NO. 15 1 CK NO. rJ 1 6 ~~ ~ Proposed or Completed Work 16. PROPOSED OR COMPLETED WORK Describe in Section 17 PLEASE SELECT ONLY ONE PRIMARY TYPE IN BOLD AND AS MANY SECONDARY TYPES AS NECESSARY. ^ Enhance Production ^ Workover: ®Com pletion: ^ Acidize ^ Change Tubing ^ Initial Completion ^ Artifical Lift ^ Casing Pressure Repair ^ Reperforation ^ WashlOesand Well ^ Change Zone ^ Jet Well ^ Abandonment of Well Bore: ® Modify Perforations ^ Utility ^ Permanent Abandonment ^ Initial Injection Well ^ Temporary Abandonment ^ Information: ^ Additional Fluids for Injection ^ Plugback to SidetracklBypass ^ Surface Location Plat ^ Other Operations ^ Site Clearance ^ Change Well Name ^ Describe Operation(s) E-LINE AD-REPERFORATE 16112'-16162' AND 16169'-16194' 18. LIST ALL ATTACHMENTS (Attach complete well prognosis and attachments required by 30 CFR 250.513(a) through (d); 250.613(a) through (d); 250.1712(a) through (~; 250.1721(a) through (g); 250.1722(a) through (d); or 250.1743(a). DESCRIPTIVE SUMMARY OF PROPOSAL; GR LOG; WELL BORE SCHEMATIC 19. Rig Name or Primary Unit (e.g., Wireline Unit, Coil Tubing, Snubbing Unit, etc.) E-LINE UNIT 20. The greater of $ITP or MASP (psi): 4500 21. Type of Safety Valve (SV): X SCSSV _SSCSV _ N/A 22. SV Depth BML (ft): 23. Rig BOP (Rams) 2a. Rig BOP (Annular) Size: Working Pressure Test Pressure Working Pressure Test Pressure (inches) (psi) (psi) (psi) (psi) Low/High: Low/High: 25. Coiled Tubing BOP: 26. Snubbing Unit BOP: 27. Wireline Lubricator: Working Pressure BOP Test Pressure (psi) (psi) Low/High: Working Pressure Test Pressure (psi) (psi) Low/High: Working Pressure Test Pressure (psi) (psi) Low/High: 300/4500 WP=5000 28. CONTACT NAME: Robert Younger 29. CONTACT TELEPHONE NO.: 907-564-5392 30. CONTACT E-MAIL ADDRESS: Robert.Younger@bp.com 31. AUTHORIZING OFFICIAL (Type or print name) ROBERT YOUNGER 32. TITLE PRODUCTION ENGINEER 33. AUTHORIZI(uGSIGNAT RE 34. DATE PROVED BY: ' :71TLE THIS SPACE FOR MMS USE ONLY ,DATE IVlllll$ Form MMS-124 (October 2005 -Supersedes all previous versions of form MMS-124 which may not be used.) Page 1 of 2 .. , r Application for Permit to Modify (APM) Information Sheet Questions a) Is H2S present in the well? If yes, then comment on the inclusion of a Contingency Plan for this operation. b) Is this proposed operation the only lease holding activity for the subject lease? If yes, then comment. 35) Question Information Response Remarks ^ YES Q NO ^ N/A ^ YES ~ NO ^ N/A c) Will all wells in the well bay and ^ YES related production equipment be shut-in when moving on to or off of an offshore ^ NO platform, or from well to well on the ~ N/A platform? If not, please explain. If sands are to be commingled for this ompletion, has aproval been obtained? e) Will the completed interval be within 500 feet of a block line? If yes, then comment. f) For permanent abandonment, will casings be cut 15 feet below the mudline? If no, then comment. ^ YES ^ NO D N/A YES ^ NO ^ N/A ^ YES ^ NO [] N/A PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT. The PRA (44 U.S.C. 3501 et. seq.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form, MMS-124, is estimated to average between 1-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS FOrrTI MMS-124 (October 2005 -Supersedes all previous versions of form MMS-124 which may not be used.) Page 2 of 2 • Roby, David S (DOA) From: Roby, David S (DOA) Sent: Thursday, May 10, 2007 8:14 AM To: Colombie, Jody J (DOA) Subject: Northstar Oil Spill Response Rate emails Attachments: Northstar Production rates; RE: Northstar Production rates; Northstar SRPS; FW: Northstar SRPS; RE: FW: Northstar SRPS; dave_roby.vcf Northstar RE: Northstar Northstar SRPS Production rates Production rates... ~,~~. 0 FlN: Northstar RE: FW: Northstar dave_raby.vcf (350 SRPS SRPS B) Jody, Attached are a series of emails for the files related to establishing the oil spill response rate for the Northstar field. The emails state that NS-30 will be used to determine the response rate but according to a phone call I received from Mr. Bob Tisserand with the DEC on May 9th they have decided to use well NS-7 to establish the response planning standard rate (the rate for both NS-7 and NS-30 are contained within the email trail). Mr. Tisserand stated that the emails were sufficient and at this time no letter is required. Thanks, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 1 Page 1 of 4 Roby, David S (DOA) From: Tisserand, Robert L (DEC) Sent: Wednesday, April 25, 2007 11:50 AM To: Roby, David S (DOA) Subject: RE: FW: Northstar SRPS Thank you Dave for your response. Bob From: Dave Roby [mailto:dave_roby@admin.state.ak.us] Sent: Wednesday, April 25, 2007 11:46 AM To: Tisserand, Robert Subject: Re: FW: Northstar SRPS Hi Bob: NS-30 produced for 251 days during 2006 and produced a total of 1,772,620 bbls of oil, which yields an average daily production rate of 7,062 bbls of oil per day. Also, if I remember correctly the DEC regulations for response planning standard volumes also take into consideration whether or not the wells at the facility are artificially lifted. NS-30, and all wells at Northstar, are naturally flowing and not on any form of artificial lift. Hope this helps. Do you need a formal letter to follow up on this, or is this email sufficient? Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 Tisserand, Robert wrote: Hi Dave. Here are the emails that I talked about. Bob From: Tisserand, Robert Sent: Monday, April 23, 2007 12:44 PM To: 'roby a~7admin.state,ak,us' Subject: FW: Northstar SRPS Good afternoon Dave. 6/16/2008 • ~ Page 2 of 4 Please take a read of these emails and email to me the total barrels produced by NS-30 and the number of days produced. Thank you, Bob From: Miner, Lydia Sent: Monday, Apri123, 2007 12:13 PM To: Tisserand, Robert Subject: FW: Northstar SRPS could you please find out from AOGCC the total barrels produced by NS-30 and the number of days produced? (in other words, how did they come up with their average?) Thanks. From: Breck Tostevin [mailto:Breck_Tostevn a~law_state.ak.us] Sent: Friday, April 20, 2007 3:25 PM To: Wilson, Craig; Miner, Lydia Subject: RE: Northstar SRPS How many barrels did NS-30 produce in total? »> "Wilson, Craig" <Craig_Wilson crd_ec.state_ak.us_> 4/20/2007 3:19 PM »> I'll give Breck the last word, but here's my take: The key here is "the maximum producing well". This term was derived from the statutory requirement for RMOD as defined at AS 46.04.030(x)(3), that is, "the maximum and most damaging oil discharge". The RMOD has been determined to be the maximum producing well. The RPS is based upon RMOD, which is the maximum producing well. The requirement of "annual average daily oil production volume" was introduced as a method to normalize flow rates and account for wells going on and off line. During discussions around the Phase 1 revisions to the RPS the producers expressed concern that the highest production day of a given well was not indicative of it's long-term threat. They argued that a well could flow extremely high during testing or some other condition, and then produce at a lower rate during normal operation. Therefore the concept of averaging daily production flows over a longer time period was introduced, to handle offline and non-routine operational flows. But the "annual" period of time was introduced strictly to smooth out the production data and to handle days of no production, not to set an age requirement on a well. I would posit that if, in the department's discretion, there is sufficient past data to determine the "annual average daily oil production volume" for NS-30, and NS-30 is the "maximum producing well" in absolute terms for the previous calendar year, then it doesn't matter 6/16/2008 Page 3 of 4 that there is not a full year's worth of data. Eight months is enough data to ascertain with reasonable confidence what the average daily flow rate is. Craig -----Original Message----- From: Miner, Lydia Sent: Thursday, April 19, 2007 1:49 PM To: Wilson, Craig; AG Office: Breck Tostevin Subject: RE: Northstar SRPS Hi Craig and Breck - I was going to send this back to AOGCC but thought I'd run it by you first, in case you can make the argument that a different well should be used. Our regulation states that the response planning standard (RPS) for a production facility is based upon the annual average daily oil production volume for the highest producing well at the facility (18 AAC 75.434(e). "Annual average daily oil production volume" is defined at 18 AAC 75.900(162) as the highest annual volume produced by a well at the facility during the previous calendar year divided by the number of days in the year, epxressed as barrels per day. So while the more conservative (and preferable) approach would be to use NS-30 and its 8 months of production and a higher RPS, I believe we must do our best to comply with the regulation as written, so we should use NS-7. I know BP will shove back on anything to get the RPS lower so I'm loath to get into a fight with them if you think I can't win. The difference is nearly 800 bbls/day so I'd like to get it right! Thanks. Lydia -----Original Message----- From: Tisserand, Robert Sent: Thursday, April 19, 2007 11:52 AM To: Miner, Lydia Subject: FW: Northstar SRPS Hi Lydia. What are your thoughts? Bob -----Original Message----- From: Dave Roby [mailto;daye ruby@adminatate.ak.us] Sent: Thursday, April 19, 2007 11:08 AM 6/16/2008 • • Page 4 of 4 To: Tisserand, Robert Subject: Northstar SRPS Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 BOPD, however this well was not completed until Apri12006 (the rate would only be 4,856 BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 BOPD (if based on an entire 365 day year). My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this well. But, I will defer to your guidance since it is your program that will be affected by how the average daily rate is determined. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 6/16/2008 • • Page 1 of 4 Roby, David S (DOA) From: Tisserand, Robert L (DEC) Sent: Wednesday, April 25, 2007 11:34 AM To: Roby, David S (DOA) Subject: FW: Northstar SRPS Hi Dave. Here are the emails that I talked about. Bob From: Tisserand, Robert Sent: Monday, April 23, 2007 12:44 PM To: 'roby@admin.state.ak.us' Subject: FW: Northstar 5RPS Good afternoon Dave. Please take a read of these emails and email to me the total barrels produced by NS-30 and the number of days produced. Thank you, Bob From: Miner, Lydia Sent: Monday, April 23, 2007 12:13 PM To: Tisserand, Robert Subject: FW: Northstar SRPS could you please find out from AOGCC the total barrels produced by NS-30 and the number of days produced? (in other words, how did they come up with their average?) Thanks. From: Breck Tostevin [mailto:Breck_Tostevin@law.state.ak.us] Sent: Friday, April 20, 2007 3:25 PM To: Wilson, Craig; Miner, Lydia Subject: RE: Northstar SRPS How many barrels did NS-30 produce in total? »> "Wilson, Craig" <Craig_Wilson@dec.state.ak.us> 4/20/2007 3:19 PM »> I'll give Breck the last word, but here's my take: The key here is "the maximum producing well". This term was derived from the statutory requirement for RMOD as defined at AS 46.04.030(r)(3), that is, "the maximum and most damaging oil discharge". The RMOD has been determined to be the maximum producing well. The RPS 6/16/2008 • • Page 2 of 4 is based upon RMOD, which is the maximum producing well. The requirement of "annual average daily oil production volume" was introduced as a method to normalize flow rates and account for wells going on and off line. During discussions around the Phase 1 revisions to the RPS the producers expressed concern that the highest production day of a given well was not indicative of it's long-term threat. They argued that a well could flow extremely high during testing or some other condition, and then produce at a lower rate during normal operation. Therefore the concept of averaging daily production flows over a longer time period was introduced, to handle offline and non-routine operational flows. But the "annual" period of time was introduced strictly to smooth out the production data and to handle days of no production, not to set an age requirement on a well. I would posit that if, in the department's discretion, there is sufficient past data to determine the "annual average daily oil production volume" for NS-30, and NS-30 is the "maximum producing well" in absolute terms for the previous calendar year, then it doesn't matter that there is not a full year's worth of data. Eight months is enough data to ascertain with reasonable confidence what the average daily flow rate is. Craig -----Original Message----- From: Miner, Lydia Sent: Thursday, April 19, 2007 1:49 PM To: Wilson, Craig; AG Office: Breck Tostevin Subject: RE: Northstar SRPS Hi Craig and Breck - I was going to send this back to AOGCC but thought I'd run it by you first, in case you can make the argument that a different well should be used. Our regulation states that the response planning standard (RPS) for a production facility is based upon the annual average daily oil production volume for the highest producing wel{ at the facility (18 AAC 75.434(e). "Annual average daily oil production volume" is defined at 18 AAC 75.900(162) as the highest annual volume produced by a well at the facility during the previous calendar year divided by the number of days in the year, epxressed as barrels per day. So while the more conservative (and preferable) approach would be to use NS-30 and its 8 months of production and a higher RPS, I believe we must do our best to comply with the regulation as written, so we should use NS-7. I know BP will shove back on anything to get the RPS lower so I'm loath to get into a fight with them if you think I can't win. The difference is nearly 800 bbls/day so I'd like to get it right! Thanks. Lydia -----Original Message----- From: Tisserand, Robert 6/16/2008 • Page 3 of 4 Sent: Thursday, April 19, 2007 11:52 AM To: Miner, Lydia Subject: FW: Northstar SRPS Hi Lydia. What are your thoughts? Bob -----Original Message----- From: Dave Roby [mailto:dave rob_y@admin.sta_t_e.ak.us) Sent: Thursday, April 19, 2007 11:08 AM To: Tisserand, Robert Subject: Northstar SRPS Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 BOPD, however this well was not completed until April 2006 (the rate would only be 4,856 BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 BOPD (if based on an entire 365 day year). My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this weH. But, I will defer to your guidance since it is your program that will be affected by how the average daily rate is determined. Regards, Dave Roby 6/16/2008 • Page 4 of 4 Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 6/16/2008 Roby, David S (DOA) From: Roby, David S (DOA) Sent: Thursday, April 19, 2007 11:08 AM To: Tisserand, Robert L (DEC) Subject: Northstar SRPS Attachments: dave_roby.vcf dave_roby.vcf(350 B) Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 BOPD, however this well was not completed until April 2006 (the rate would only be 4,856 BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 BOPD (if based on an entire 365 day year). My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this well. But, I will defer to your guidance since it is your program that will be affected by how the average daily rate is determined. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 1 • • Page 1 of 1 Roby, David S (DOA) From: Tisserand, Robert L (DEC) Sent: Thursday, February 22, 2007 2:38 PM To: Roby, David S (DOA) Subject: RE: Northstar Production rates Hi Dave. Thanks for the information. t appreciate the discussion you and your co-workers had on this topic. Regards, Bob From: Dave Roby [mailto:dave roby@admin.state.ak.us] Sent: Thursday, February 22, 2007 2:27 PM To: Tisserand, Robert Cc: Jane Williamson, PE Subject: Northstar Production rates Bob, I believe you said that BP was question the rate to use for the Northstar response planning standard. Jane Williamson, the other reservoir engineer in the office and the one who actually handles Northstar, put together the following information on individual well production rates at Northstar during the past year. Annual average dai Year End oil, STBD water, STBD NS-07 2006 6270 NS-30 2006 6437 ly production Total Liquid, STBD 820 7090 7 6440 Not a whole lot of difference between the just oil rate of 6,437 BPD for NS-30 and the total liquid rate of 7,090 BPD for NS-07, unless 6,500 or 7,000 BPD is a threshold that automatically requires an increase in response preparedness. Thought you might be interested. Let me and/or Jane now if you have any further questions. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 6/16/2008 i Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 306-415 Dear Mr. Younger: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely 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. ~v5 -20~ Sincerely. O i~~~ STATE OF ALASKA ~'+ ~~1~ 1 (/~J' ~I~~~ ALAS~IL AND GAS CONSERVATION C'OMMISS~ ~, S ~~ D ~ ~ ~ $ ZOO6 APPLICATION FOR SUNDRY APPROVAL ~ 20 AAC 25.280 ~1aslt~ ~lii & issoD. 1. Type of Reques : Abandon Suspend Operational shutdown Perforate Waiver QI1Ch0~ O~tEer 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 Q Exploratory ^ 205-2070 3. Address: P.O. Box 196612 6 Stratigraphic ^ Service ^ . API Number: Anchorage, AK 99519-6612 50-029-23293-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 56.27 RT NS30 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): 16398 11243.78 16245 11097.6 .None None Casing Length Size MD TVD Burst Collapse Surface 4397 13-318" 68# L-80 45 4442 45 3254 5020 2270 Production 14506 9-5/8" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7" 29# L-80 14367 15877 9403.6 10757 8160 7020 Liner 666 4-1/2" 12.6# 13CR80 15730 16396 10624.31 11242 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16112 - 16172 10971.92 - 11028.42 4-1/2" 12.6# 13CR80 41 - 15739 16184 - 16194 11039.77 - 11049.23 16204 - 16224 11058.7 - 11077.66 Packers and SSSV Type: 4-1/2" TRSSSV Packers and SSSV MD (ft): 1026 4-1/2" Baker S-3 Packer 15694 12. Attachments: Descriptive 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: 1/5/2007 Oil Q Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared b 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 Robert Younger Title production En leer Signature Phone 564-5392 Date 12/22/2006 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~O /~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: W APPROVED BY : COMMISSIONER THE COMMISSION Date: /~- ~+~ Q A roved b pp y ``----- I Form 10-403 Revised 7/2005 Submit in Duplicate No portion of the below ork should be performed w/out firs king time to ensure No Accidents,~harm to People, and No damage +e Environment To: Jerry Bixby/Clark Olsen -Well Operations Supervisor December 15, 2006 From: Robert Younger/Carolyn Kirchner - Northstar Production Engineer subject: NS30 Bullhead Acid Treatment AFE NSFLDWL30 Est. Cost: $100 M Est. IOR: 1000 BOPD Please perform an acid stimulation on NS30 per the below procedure including a pickle and fullbore acid/scale inhibition treatment: Type IOR PR N DSWL AFE Job Description S 1000 NS30 NSFLDWL30 Drift to evaluate scale buildup F 1000 NS30 NSFLDWL30 Pump Acid Treatment & Scale Inhibition Treatment (SIT) Contingent on Drift Results Current Status: Producer Last Test: 12/05/06: BOPD: 5,884, BWPD: 0; MMCFPD: 25.85 Max Inclination: 57° at 3,390' md; 19° at Perfs Max Dog Leg: 5.6 deg/100' at 1,214 and Minimum ID: 3.725" @ 15,729` md, 4.5" XN Nipple Last TD tag: 08/18/06: 16,223' corr. Drift with 3.7" cent. Last Downhole Op: 08/18/06: Drift w/ 3.7" cent , xn locator, sample bailer. locate xn @ 15699' slm +13' = 15712'elm tag btm @-16210 + 13 = 16223' corr,depth. (hard bottom ), (perfs @ 16112-.16224') 1' of fill. no sample recovered. SBHPS was canceled by APE. Latest H2S value: None anticipated NS30 is a new development well at Northstar. Initial April production was 8100 BOPD. The well has since declined to 6100 BOPD. Please note that during the 7/31/06 acid treatment, the well locked up after pumping 227 bbls. The next day, 8/1/06, the well locked up again after pumping 231 bbls. Pumping was aborted due to reaching maximum injection pressure of 3500 psi. See attached pumping report and take extreme care when proceeding with this job. Due to Northstar's track record of scaling problems, a combination acid treatment/scale inhibitor treatment will help to clear any scale. 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. 1. Mobilize pumps, tanks and acid transport to Northstar. No portion of the below ork should be performed w/out firs king time to ensure No Accidents, harm to People, and No damage a Environment 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. RU pumping equipment. 4. Hold PJSM. Possible hazards on this job include bringing .partially spent acid back to surface when the pickle is produced back. 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 Pickle 7. Pump the following fluids to pickle the production tubing at 3 - 4 bpm, 3500 psi max pressure. After about 230 bbls have been .pumped into tubing; slow pumping rate to minimum pump rate around 0.25 bpm. Allow pickle to soak for 1 hour. a) 15 Bbls DAD acid b) 167 Bbls seawater c) 63 Bbls diesel 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 8. After soaking, produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 245 Bbls. Acid Treatment 9. Pump the following treatment at maximum rate or 3500 psi max pressure. When the acid first hits perfs, slow pump rate to 1 BPM for 'h of acid volume then resume pumping at maximum rate. a) 43 bbls Acid b) 101 bbls 2% filtered KCI (Overflush for 5' radial displacement) c) 183 bbls Seawater (for displacement) d) 63 bbls Diesel (for displacement and under-balance) Acid Description: 12% Acid to contain: 0.5% A261 Corrosion Inhibitor ' w No portion of the below rk should be performed w/out firs king time to ensure No Accidents, harm to People, and No damage i~e Environment 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. 10. RD Schlumberger. FLOWBACK PROCEDURE: 11. Following the treatment, line-up the well to flow into the test separator and well cleanup tank for flowback. Produce clean-up volume of 390 bbls. After clean- up, divert back to the plant and get 2 6-hour tests. Nate: Please have Schlumberger send a digital copy of the past aob report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures to Robert.Younger~ bp.om. Procedure Contacts: Robert Younger W K: 564-5392 H M: 677-2599 Cel I: 830-4920 ' _ No portion of the below~k should be performed w/out first king time to ensure No Accidents, arm to People, and No damage t e Environment .~~~~~„ NS 20 Pumping Report 7/31/06 cmmcaTw. 1~ pelf N::~u flient BPX F70fd Naath :"tar SER Ato. _~~10+>7957 Ent~iGteer Tyson 4tiae~e JobType .4r.sd Treztment Co4lntry U[?itetl Gtates. ]ob[?ate uz-3'.-2v~~ Tfr~1e ------Pre55ure Rafe ---QerlSfty HP M855aC)25 t" i3i)4 [ - ir ] ^,F a. _6~,.e x:' _. -- ' ~ ~ , ..__ se se a.. Val=9.6fl ab3 , -- F 3fl;41:6D i ', R s...rt a--~. ,acid ', ',, '. sa„ G ~c Ls&7 aeiG I I .".ese; c ., , V'al = '! 3..44 bh"s: '. ', 0 Star: F~~. , ag 8rme i Y1~L7:40 / + -`. / Rasac~ = 144,75 Gil I. :. '. '',. na: al dare ?umpng de~E ', ' : : ': I i:,attr =aa& e3 ' 2 36 ': ''. ~ '. a : : 655':CJ '., I ', Bi;ZF;6q I-....__._, _...._._ L.-® '\ Szart p3,.nning die : ', Rasa.'c•a:. Vcl = 3:x,33 hbg ',. '., start ~ no ~ ~ .:.. _. '. ', p 7 ~ a F-' :. ': ': 'east c..,!, s°cl =6?.L4'- 1z6i. OB:a7sQ-0. I '.. 5,~.~,..,„, eq~,. r`'° ', Y~^-~"' sou ~c;r.^. w rsezh us~e'su:+e II6:S7:Ca ',, 1 cs:z7:co I, . i ' i 1 ',, _c~me n z+~~IRns an~9 4xzx€h ~i~ ~ _~ ' - 44.4:. _o '' ' - - :.a taM~n s~ginaer ' n~: ~~ '. . : . tie3e[ Tou, Val = 12t4.G^a V1.F:r.::as t: --.v +xtl 40 U.92 5d ~ ... a.. x 3e lrvk 1)S daA ax- FAV Wu Y:Mw~_ «~,«~» ~..,.:,„ ....................._ 7a[ 61i.: ....................... f&`G X53 G'$J9112D06 i3:2Q: ~~ Date: 08-22-2006 Transmittal Number:92819 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC ar SFd_d(1Q1 ~pS,~,o7 SW Name Date Contractor Lo Run To De th Bottom De th Lo T e NS08 03-28-2006 SCH PERF RECORD NS08 06-01-2006 SCH PERF RECORD NS14A 01-20-2006 SCH DEPTH CONTROL NS16 05-05-2006 SCH PRODUCTION PROFILE NS31 06-05-2005 SCH PERF RECORD W ITH GAMMA RAY NS30 04-15-2006 SCH JEWELRY LOG NS30 04-02-2006 SCH JEWELRY LOG NS30 04-14-2006 SCH PERF RECORD W ITH GAMMA RAY NS19 05-15-2006 SCH PERF RECORD O Plea e ign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Ignacio Herrera Doug Chromanski ~. .; Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • • y~q ~~a°~ ~ ~ ~ ~ ~ ~ ~ ~ ;+ 3~ ~ ~'~~ ~ ~~ ~ { ~, ;~ FRANK H. MURKOWSKI, GOVERNOR ~~ OIL ~ ~ ~ l ANC ORAGE, ALASKAf9 50103539 COI~SERQATIOIIT COMDIISSIOI~T PHONE (907) 279-1433 J Robert Younger FAx (so7) 27s-7sa2 Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS30 Sundry Number: 306-241 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. l1' DATED this fl day of July, 2006 Encl. 805 =ao~- . ~, by ~ x/6/6 ~ ~(~y J U L Q (~ ~ iJ Alaska I)il ~ ~~s ` ~:~" .;~niss~r Al~~ila~ a~~ June 21, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS30 to Acidize (Ivishak) ~~~ ~, ~. BP Exploration (Alaska) Inc. I ~/ 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-8812 (907)581-5111 BP Exploration Alaska, Inc. proposes to acidize the new NS30 well. This well has exhibited a steady decline and the formation of CaCOs scale is suspected. The procedure includes the following major steps: • Pickle tubing • Bullhead HCL based acid treatment including scale inhibitor • Flowback Sincerely, Robert Younger Production Engineer BPXA, ACT, Northstar STATE OF ALASKA ~ ?~ ~ J r AKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEIVED JUL 0 6 200E 1. Type of Request: Abandon Suspend Operational shutdown Perforate 8 8 8S ORlf1 After casing ^ Repair well ^ Plug Perforations ^ Stimulate ~ Time Extension ^ Anchorage Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Weil Class: 5. Permit to Drtll Number: BP Exploration (Alaska), fnc. Development ® Exploratory ^ 205-2070 /'"~ 3. Address: P.O. Box 196612 ./ Service ^ Stratigraphic ^ 6. API Number: / Anchorage, AK 99519-6612 ~ 50-029-23293-00-00 / 7. KB Elevation (ft): 9. Well Name and Number: 56.27 RT NS30 8. Property Designation: 10. Feld/Pools(s): ADL-312808 NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ff): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16398 11243.78 16245 11097.6 None None Casing Length Size MD TVD Burst Collapse Surface 4397 13-3/8" 68# L-80 45 4442 45 3254 5020 2270 Production 14506 9-518" 53.5# L-80 43 14549 43 9560 7930 6620 Liner 1510 7" 29# L-80 14367 15877 9403.6 10757 8160 7020 Liner 666 4-1/2' 12.6# 13CR80 15730 16396 10624.31 11242 8440 7500 Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16112 - 16172 10971.92 - 11028.42 4-1/2" 12.6# 13CR80 41 - 15739 16184 - 16194 11039.77 -11049.23 16204 - 16224 11058.7 - 11077.66 Packers and SSSV Type: 4-1/2" TRSSSV Packers and SSSV MD (ft): 1026 4-1/2" Baker S-3 Packer 15694 12. Attachments: Descriptive Summaryof Proposal 13. Well Class after proposed work: J. Detailed Operations Program ^ BOP Sketch ^ Service ^ Exploratory ^ Development ® ~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/ 6 Oil ® Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Pre red b Sharmaine Vestal 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Youn er Printed Name Rob Youn er rule Production En leer Signature Phone 564-5392 Date 6/28/2006 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: 1~,674~ ®F~r ~~L ~ `~ 2~~6 Subsequent Form Required: ~ (~ - q- f~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~~ Form 10-403 Revised 712005 -~v ORIGINAL Submit in Duplicate mission _~ ~t r.. • Date: 07-OS-2006 Transmittal Number:92794 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 Lo Run To De th Bottom De th Lo T e NS32 ~ 07-27-2004 SCH 1 3836 8051 RST WATERFLOW PRESSURE ', NS32 05-26-2005 SCH 1 3750 8040 RST WATERFLOW -FLOW MODE NS20 06-27-2004 SCH 1 0 i 8495 PDC JEWELRY LOG NS32 05-14-2004 SCH 1 0 8131 JEWELRY LOG ~ NS30 04-03-2006 SCH 1 50 16228 SLIM CEMENT MAPPING OOL _.. NS14A 01-29-2006 SCH 1 10181 14230 VISION SERVICE -MEASURE DEPTH NS14A~ 01-29-2006 SCH i 10181 14230 VISION SERVICE -TRUE VERTICAL DEPTH ~ NS30 03-17-2006 SCH 1 200 16398 VISION SERVICE -MEASURE DEPTH NS30 - 03-17-2006 SCH 1 16000 16318 VISION RESISTIVITY - MEASURE DEPTH WASH DOWN ~- NS30 03-17-2006 SCH 1 200 16398 VISION SERVICE -TRUE VERTICAL DEPTH NS11 05-29-2006 SCH 1 0 14669 PRIMARY DEPTH CONTROL NS14A ~ 01-29-2006 SCH 1 305 1425 LDWG EDIT - CD ROM ti NS30 03-17-2006 SCH 1 320 16379 LDWG EDIT - CD ROM NS11 05-29-2006 SCH 1 7770 10470 LDWG EDIT - CD ROM Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date: 07-OS-2006 Transmittal Number:92794 BPXA WELL DATA TRANSMITTAL Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Doug Chromanski MMS Tim Ryherd DNR Howard Okland AOGCC Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date: OS-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 Lo Run To De th Bottom De th Lo T e 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 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 LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ".;~~ STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COSION ` WELL COMPLETION OR RECOMPLETION REPORT AND LOG - 6r~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZa.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/14/2006 12. Permit to Drill Number 205-207 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/5/2006 13. API Number 50-029-23293-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/17/2006 14. Well Name and Number: NS30 FEL, SEC. 11, T13N, R13E, UM 1339 FSL, 649 Top of Productive Horizon: 5279' FSL, 153' FEL, SEC. 18, T13N, R14E, UM g. KB Elevation (ft): 56 15. Field /Pool(s): Northstar Unit Total Depth: 5265' FSL, 44' FEL, SEC. 18, T13N, R14E, UM 9. Plug Back Depth (MD+TVD) 16352 + 11200 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 659822 y- 6031111 Zone- ASP4 10. Total Depth (MD+TVD) 16398 + 11244 Ft 16. Property Designation: ADL 312808, Y0181 TPI: x- 670815 y- 6030016 Zone- ASP4 Total Depth: x- 670924 Y- 6030004 Zone- ASP4 11. Depth where SSSV set 1026 MD 17. Land Use Permit: LO-N96-006 th if ff h 19 W t d Thickness of Permafrost 20 18. Directional Survey ®Yes ^ No er , ore a ep o s . 39' MSL . 1545' (Approx.) 21. Logs Run: MWD/LWD , GR , RES ,DEN , NEU ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HDLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 169# X-56 Surface 200' Surface 200' 20" Driven 13-3/8" 68# L-80 Surface 4443' Surface 3255' 16" 607 sx AS Lite, 465 sx Class 'G' 9-5/8" 53.5# L-80 Surface 14549 Surface 9560' 12-1/4" 1362 sx Ext. Slu , 450 sx'G' 7" 29# L-80 14368' 15877' 9404' 10757' 8-1/2" 365 sx Class 'G' 4-1/2" 12.6# 13CR80 15722' 16396' 10617' 11242' 6" 86 sx Class'G' 23. Perforations open to Production (MD +TVD of Top and " " 24. TUBING RECORD none Bottom Interval, Size and Number; if none, state ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6SPF 4-1/2", 12.6# 13-Cr80 15702' 15653' MD TVD MD TVD 16112' - 16172' 10972' - 11028' 16184' - 16194' 11040' - 11049' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 16204' - 16224' 11059' - 11078' DEPTH INTERVAL MD AMOUNT $i KIND OF MATERIAL USED Freeze Protected with 266 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 15, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 4/15/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD ,.,' OIL-BBL 368 GAS-McF 707 WATER-BBL 6 CHOKE $IZE 0 GAS-OIL RATIO 1920 Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL 2209 GAS-McF 4242 WATER-BBL 35 OIL GRAVITY-API (CORK) 0 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 ' _~~ ~~~~~ ~F~ Mr~Y j ~ ~~~~ ~~~ . ~ - Form 10-407 Revised 12/2003(} ~ ~ ~ ~ ~O TINUED ON REVERSE $IDE T GEOLOGIC MARKE 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Ugnu 7340' 4897' Top of Schrader Bluff 10145' 6514' None Top of Colville 11156' 7107' Top of Kuparuk 13909' 9024' Kuparuk C 14160' 9231' Top of Miluveach 14645' 9645' Top of Kingak 15143' 10096' Top of Sag River 15846' 10729' Top of Shublik 15948' 10821' Top of Ivishak 16052' 10916' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post-Rig Summary and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman Title Technical Assistant Date NS30 205-207 Prepared ey Name/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Paul Hanson, 564-4195 Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. h-eM 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). Irene 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 t • BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase. Description of'Operations 2/3/2006 19:00 - 00:00 5.00 RIGU PRE Prep rig for move to NS-30, Lay mats &herculite PJSM & ATP with all personnel involved with rig move Move rig from NS-14 to NS-30 2/4/2006 00:00 - 17:30 17.50 RIGU P PRE Move rig to NS 30 Monitoring flowline, well house & pipe rack clearances Laying Herculite & spotting mats Finish rig move & spot over NS 30 17:30 - 20:00 2.50 RIGU P PRE Connect water lines, connect to island electrical power Build berm around G & I and rig Set stairs & landings 20:00 - 00:00 4.00 RIGU P PRE Accept rig @ 20:00 hrs on 2/4/2006 Nipple up riser Load pipe shed w/MWD tools &HWDP 2/5/2006 00:00 - 02:00 2.00 RIGU P PRE Load pipe shed w/ BHA #1 NU surface riser, install valves on conductor Mix red spud mud 02:00 - 02:30 0.50 RIGU PRE Clean up mud spill, 4.5 bbls contained in rig, .5 bbls on herculite 02:30 - 04:00 1.50 RIGU P PRE Move gyro tools, bit, subs & stabilizers to rig floor NU surface riser 04:00 - 05:30 1.50 RIGU P PRE PU 21 jts of 5" HWDP & stand in derrick 05:30 - 06:00 0.50 RIGU PRE Fill riser w/sea water & check for leaks 06:00 - 08:00 2.00 RIGU P PRE RU wireline & gyro equipment 08:00 - 09:00 1.00 RIGU P PRE HSE standdown -Focus areas: Spills -valve alignment, need to double check Safety -PPE needs for every job, hand safety, watch out for inexperienced employees Pre spud mtg -review surface hole plans & potential problems Review D 7 conditions, responsibilities, evacuation plans & remote well monitoring 09:00 - 11:00 2.00 DRILL P -SURF PU BHA #1 11:00 - 11:30 0.50 DRILL P SURF RIH w/ 2 stands of HWDP 11:30 - 12:30 1.00 DRILL P SURF Displace sea water w/spud mud Circulate to 200' 12:30 - 13:30 1.00 DRILL P SURF Circulate & Condition 13:30 - 14:00 0.50 DRILL P SURF Drill from 200' to 237' 14:00 - 15:00 1.00 DRILL P SURF Run gyro on wireline 15:00 - 16:00 1.00 DRILL P SURF Directional drill, slide from 237' to 327' 16:00 - 16:30 0.50 DRILL P SURF Run gyro on wireline 16:30 - 17:30 1.00 DRILL P SURF POH, LD stabliizers 17:30 - 19:00 1.50 DRILL P SURF PU BHA #2 19:00 - 19:30 0.50 DRILL P SURF RIH 19:30 - 20:30 1.00 DRILL P SURF HSE standdown -Focus areas: Spills -valve alignment, need to double check Safety -PPE needs for every job, hand safety, watch out for inexperienced employees Pre spud mtg -review surface hole plans & potential problems Review D 7 conditions, responsibilities, evacuation plans & remote well monitoring 20:30 - 21:00 0.50 DRILL P SURF Directional drill, rotate & slide from 327' to 383' 21:00 - 21:30 0.50 DRILL P SURF Run gyro on wireline 21:30 - 23:00 1.50 DRILL P SURF Directional drill, rotate & slide from 383' to 542" 23:00 - 23:30 0.50 DRILL P SURF Run gyro on wireline Printed: 4/14/2006 11:11:52 AM ~~ • BP EXPLORATION Page 2 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase: Description of Operations 2/5/2006 23:30 - 00:00 0.50 DRILL P SURF Directional drill, slide from 542' to 566' 2/6/2006 00:00 - 11:00 11.00 DRILL P SURF Directional drill from 566' to 1285' Run gyro surveys every stand DP pressure 1175 psi @ 728 GPM WOB 20-30K, Torque 8K PU wt 131 K, SO wt 124K, Rot wt 131 K 11:00 - 11:30 0.50 DRILL P SURF Pump sweep RD wireline & gyro equipment 11:30 - 12:30 1.00 DRILL P SURF Circulate & condition hole for trip to shoe Pulsation problems w/mud pumps 12:30 - 14:00 1.50 DRILL N RREP SURF POH to conductor shoe 14:00 - 21:30 7.50 DRILL N RREP SURF Replace pulsation dampener bladders on both mud pumps Charge pulsation bladders to 1150 psi w/nitrogen Service top drive 21:30 - 22:30 1.00 DRILL N RREP SURF RIH from 200' to 1195' 22:30 - 23:00 0.50 DRILL N RREP SURF Wash to btm from 1195' to 1282' 23:00 - 00:00 1.00 DRILL P SURF Directional drill from 1282' to 1380' 100% slide 2/7/2006 00:00 - 01:00 1.00 DRILL P SURF Directional drill from 1380' to 1460' (sliding). PU 140K, SO 124K, RW 131 K, 740 GPM,1320 psi, Torq on 8K, Torq off 6K 01:00 - 02:00 1.00 DRILL P SURF Unable to build angle. Pmp sweep and circ. BU at 500 gpm @690 psi. 02:00 - 03:30 1.50 DRILL P SURF POH check BHA, run check w/ MWD at known gyro survey depth MWD OK. Continue POH. 03:30 - 05:30 2.00 DRILL P SURF POH w/ BHA. Inspect motor and bit, OK. 05:30 - 06:00 0.50 DRILL P SURF Clear and clean floor. 06:00 - 08:00 2.00 DRILL P SURF Adjust motor angle from 1.83 to 2.38. Move stab. to just above motor. RIH w/ BHA 08:00 - 09:00 1.00 DRILL P SURF RIH to 1377'. Stage up pumps. Precautionary wash to btm, OK, no fill. 09:00 - 09:30 0.50 DRILL P SURF Dir. drill from 1460' to 1519'. 09:30 - 10:00 0.50 DRILL N SFAL SURF Lost electrical power from Prod. Facility. PU off btm and circ at 100 gpm. 10:00 - 11:00 1.00 DRILL P SURF Dir. drill from 1519' to 1662' (sliding) at 700 gpm @ 1153 psi. PU 137K, SO 125K. Hole angle increasing. 11:00 - 12:00 1.00 DRILL P SURF Pmp sweep and recip. high side at 500 gpm and 623 psi. 12:00 - 15:00 3.00 DRILL P SURF POH to adjust BHA. 15:00 - 16:00 1.00 DRILL P SURF Adjust PDM angle to 1.83 deg. and reposition stabilizer (moved up 20') 16:00 - 17:00 1.00 DRILL P SURF RIH. Precautionary wash from 1570' to 1662'. 17:00 - 00:00 7.00 DRILL P SURF Dir. drill at 2323' @ 00:00 hrs. PU 140K, SO 120K, RW 130K, WOB 20-30K, Rot 0-30 rpm, 775 gpm, 1540 psi, Total Rot time 1.3 hrs & slide time 4.7 hrs in past 24 hrs. Hole conditions good on connections. Back ream through slide sections on connections, 12K to 14K torq while back reaming. 2/8/2006 00:00 - 00:00 24.00 DRILL P SURF Dir. drilling from 2323' to 4375'. 850 gpm at 1850 psi; WOB 10/40K; Rot. 40 rpm; torq on 11 K, torq off 9K; PU 145K, SO 124K, RW 134K. Total slide time = 5.8 hrs & rot. time = 7.83 hrs in last 24 hrs. Sliding 20-30'/stand to maintain hole angle. Back ream slide intervals. Hole conditions appear good. 2/9/2006 00:00 - 01:00 1.00 DRILL P SURF Dir drl from 4375' to 4460' MD(3258' TVD) to surface casing Printed: 4/14/2006 11:11:52 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Event Name: DRILL+COMPLETE Start: 2/3/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code -NPT Phase 2/9/2006 00:00 - 01:00 1.00 DRILL P SURF 01:00 - 04:00 3.00 DRILL P SURF 04:00 - 07:00 3.00 DRILL P SURF 07:00 - 08:30 1.50 DRILL P SURF 08:30 - 10:00 1.50 DRILL P SURF 10:00 - 13:30 3.50 DRILL P SURF 13:30 - 20:30 7.00 DRILL P SURF 20:30 - 21:30 1.00 DRILL P SURF 21:30 - 23:00 1.50 DRILL N SFAL SURF 23:00 - 00:00 1.00 DRILL P SURF 2/10/2006 00:00 - 02:00 2.00 CASE P SURF 02:00 - 03:00 1.00 CASE P SURF 03:00 - 15:00 12.00 CASE P SURF 15:00 - 15:30 0.50 CASE P SURF 15:30 - 19:30 4.00 CASE P SURF 19:30 - 22:30 3.00 CEMT P SURF 22:30 - 00:00 1.50 CEMT N SURF 2/11/2006 00:00 - 02:00 2.00 CEMT N CEMT SURF 02:00 - 13:00 11.00 CEMT N CEMT SURF 13:00 - 13:30 0.50 CEMT N CEMT SURF 13:30 - 16:00 2.50 CEMT N CEMT SURF 16:00 - 19:30 3.50 CEMT P SURF Page 3 of 22" Spud Date: 2/5/2006 End: Description of Operations point. 840 gpm @ 1980 psi, 40 RPM, WOB 30K, PU 185K, SO 125K, RW 130K, Torq on 13.8K, torq off 10.5K, Act. rot time = 0.5 hrs, Act. slide time = 0.0 hrs. Circ BU X 3 at 900 gpm. Recip. & rotate while circ. Pump 50 bbl weighted sweep on first BU. Hole cleaning OK. Sweep back at 10% over calculated hole volume. B/D top drive & lines. POH. Wipe tight spots at 2558' & 2332', OK. Started swabbing @ 2130. MU top drive to pump. Stage up pumps to 7 bpm. Establish circ and POH w/pmp to 1280'. POH from 1280' to 1180' w/o pmp, OK. B/D surf lines. RIH to 4410'. Wash to 4460', no fill. No tight hole on trip in. Circ & cond mud and hole. Pmp weighted sweep. Recip & rot @ 40 rpm, 875 gpm, and 2200 psi. POH to BHA. Hole conditions good. LD parts of the BHA. Stand back collars and HWDP. Level derrick before running casing. Clear & clean rig floor. RU to run 13 3/8" surface casing. Clean both mud pmp suction screens. PJSM. Chg bales and RU Franks Fillup tool. Rig up 350 ton elevators, casing tongs, pickup choker. PJSM. PU 13 3/8" shoe joint, shoe track and float collar jt. Circ. shoe track vol. Check floats, OK. Run total of 106 jts 13 3/8", 68# L-80 BTC surface casing as per plan. Make up to triangle, avg torque was 8200 ft-Ibs. Used B-O-L 2000 thrd comp. Fill each jt. Casing collars frequently hanging up on inside edge of landing ring thru jt #33. Hole tight at 2240'. Wash through tight spots from 2240' to 2252' & from 2300' to 2310' at 5 bpm 250 psi. No further washing required below 2340'. PU landing jt and hanger, land w/ shoe at 4442' MD (3248' TVD). Land w/ 185K on fluted mandrel hanger. LD Franks Fillup tool. MU cementing head loaded w/ top and bottom plugs. Circ and cond. mud and hole. Circ BU X 2. Slowly stage up to 10 BPM with final circulating pressure @ 450 psi. Held PJSM while circulating. Cementing. Pr tst lines to 3500 psi OK. Pmp. 25 bbl CW-101, 75 bbl 10.5 ppg Mud Push II, drop bottom plug, pump 516 bbls (610 sx) of 10.7 ppg lead slurry. During the switch to tail slurry, slurry mixing jet plugged forcing water back into the cement silo piping, plugging those lines. Shut down cementing. Displace spacers and lead slurry out of the hole. Stage up rig pump to 7 bpm at 500 psi and circ. Clear and blow dn. cmt & wtr lines. Circulate out and clear hole of spacers and lead slurry. Circ and cond. hole and mud waiting on cement resupply. Haul in and RU second cmt silo unit. Install bottom plug in cementing head. Reinstall top plug. PJSM. Pr tst lines to 3500 psi. Mix and pmp 25 bbl CW-101 spacer, 75 bbl Mud Push II (1 ppg over mud wt.), bottom plug, 607 sx (515 bbl) 10.7 ppg ASL lead slurry, 466 sx (94 bbl) 15.8 ppg CI G tail slurry, top plug, and 25 bbl salt water. Switch to rig pump and displace with mud at 90 spm (9 bpm) Printed: 4/14/2006 11:11:52 AM • • BP EXPLORATION Page 4 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code. NPT Phase Description of Operations 2/11/2006 16:00 - 19:30 3.50 CEMT P SURF and 700 psi. Contaminated cement to surface 280 bbl into displ. Slow pump to 70 spm (730 psi). Good lead slurry returns at 450 bbls into displ. Incr. pmp to 90 spm. Slow pmp to 5 bpm 10 bbl before plug to bump. Pr. incr to 1250 psi. Bumped plug with 1761 psi at 629 bbls. CIP at 19:15 hrs. Held pr for 3 min. Bled back. Floats held OK. Full returns throughout job. Est. 251 bbls of lead slurry to surface. 19:30 - 22:00 2.50 CEMT P SURF Rig down cementing head, tongs, and 350-ton elevators. Release and pull landing joint and lay down same. 22:00 - 00:00 2.00 CEMT P SURF Wash out and begin rigging down riser. 2/12/2006 00:00 - 01:00 1.00 BOPSU P SURF Rig do riser. 01:00 - 03:30 2.50 BOPSU P SURF Remove cement from lower riser, ND and secure same. Clean cement from 13 3/8" mandrel hanger neck. Clean L pit. Work on mixing hopper. 03:30 - 04:00 0.50 BOPSU N WAIT SURF Wait on Prod. to allow moving NS30 tree and stand for more room. 04:00 - 04:30 0.50 BOPSU P SURF Reposition tree to make room in cellar area for NU. 04:30 - 06:00 1.50 BOPSU P SURF NU casing spool. Pr. tst 13 3/8" landing neck and spool seal to 1000 psi for 10 min. OK. NU drilling spool. 06:00 - 09:00 3.00 BOPSU N WAIT SURF Wait on Prod to shut in adjacent wells to pick up and set BOP stack. Cont. to clean pits and adjust mud pump suction valves in pits. 09:00 - 17:00 8.00 BOPSU P SURF NU BOPE. Hook up Koomey lines and kill line. Function tst BOP, OK. 17:00 - 00:00 7.00 BOPSU P SURF Test BOPs. Mr. Jeff Jones, AOGCC inspector, is onsite to witness testing. Test annular to 250/3500 psi for 5 min. OK. Upper pipe rams leaked. Replaced 2 7/8X5 w/ 3 1/2X6. Ram door leaking-tighten. One TIW faliure. Packing glands on wellhead leaking-tighten. Test H2S and Methane gas detectors and alarms, OK. 2/13/2006 00:00 - 09:00 9.00 BOPSU P SURF Testing BOPE. Numerous component leaks (manifold, TIW, csg head packing glands, rams, test piping). Minimized components tested to more easily identify leaking components. Regrease drilling spool valves and choke manifold valves. Tested upper and lower pipe rams, blind shear rams, dart valve, floor TIW, manual and HCR kill and choke valves, choke manifold, upper and lower IBOPs to 250/5000 psi for 5 min. OK. Performed Koomey test, OK. All testing witnessed by Mr. Jeff Jones, AOGCC inspector, with Mike Dinger and Bret Allard. 09:00 - 10:00 1.00 BOPSU P SURF Pull test plug. Install wear bushing (ID = 12 5/16", OD = 13 5/8", Length = 35.5") 10:00 - 10:30 0.50 BOPSU P SURF Blow down lines and top drive. 10:30 - 14:00 3.50 CASE P SURF Cut and slip drilling line; 93'. Torque tie down and adjust brakes. 14:00 - 15:00 1.00 CASE P SURF Run HWDP and POH laying down same. 15:00 - 16:30 1.50 CASE P SURF PU BHA #5. Perform shallow test of rotary steerable tool and MWD. 16:30 - 20:30 4.00 CASE P SURF RIH picking up additional 5" DP. Singling in. 20:30 - 21:30 1.00 CASE P SURF Circ. and test MWD. Pmp 715 gpm @ 670 psi. Blow do mud lines and top drive. 21:30 - 22:30 1.00 CASE N RREP SURF Repair leak on Iron Roughneck. 22:30 - 23:30 1.00 CASE P SURF Continue singling in 5" DP. RIH to 2349' and fill drill pipe. Circ Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 5 of 22' Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From -To Hours Task .Code NPT Phase Description of Operations 2/13/2006 22:30 - 23:30 1.00 CASE P SURF at 700 gpm @ 760 psi. 23:30 - 00:00 0.50 CASE P SURF Continue RIH picking up 5" DP. At 2535' at 00:00 hrs. 2/14/2006 00:00 - 01:30 1.50 BOPSU P SURF RIH to 3581'. 01:30 - 02:00 0.50 BOPSU P SURF Circ. one pipe vol. Check MWD tools. 02:00 - 03:00 1.00 CASE P SURF RIH to 4320'. Wash do last stand. Rot. 50 rpm; 200 spm @ 1300 psi; torq 11 K. 03:00 - 03:30 0.50 CASE P SURF Circ. surf. to surf. to clear air from borehole and pipe in prep for csg. tst. Circ 9.4 ppg in and out. 03:30 - 04:30 1.00 CASE P SURF Close pipe rams and pr. tst. 13 3/8" surf casing to 3500 psi for 30 min., OK. 04:30 - 08:00 3.50 CASE P SURF Tag cmt plugs at 4356'. Drl plugs, float collar, shoe track, float shoe, rat hole, and 21' of new hole (4481'MD). Began pumping new 8.6 ppg LSND mud when drilling float shoe. 08:00 - 09:00 1.00 CASE P SURF Finish displacing to new 8.6 ppg mud, in and out. 09:00 - 10:00 1.00 DRILL P SURF Conduct Formation Integrity Test to 12.5 ppg pressuring up to 670 psi with 8.6 ppg mud. Held for 10 min. OK. Pmp in 1.9 bbls, bled back 1.9 bbls. 10:00 - 12:00 2.00 DRILL P INT1 Dir. Drl. from 4481' to 4706'. Rot 120 rpm, WOB 10K, Torq 12K, 212 spm/900 gpm @ 1200 psi. PU 175K, SO 135K, RW 150K. SPR: 1&2, 30 spm & 60 psi; 40 spm & 100 psi (4481' Md/3271' TVD) 12:00 - 15:00 3.00 DRILL N RREP INT1 POH to shoe and adjust top drive pipe handling torque valves. Change saver sub. RIH. 15:00 - 00:00 9.00 DRILL P INT1 Dir. Drl. from 4706' to 6221' MD/4260' TVD. Pmp weighted sweeps at 5621' & 6217'. Rot 120 rpm, WOB 10K, Torq 15K, 212 spm/900 gpm @ 1750 psi. PU 180K, SO 145K, RW 160K. SPR @5500' MD/3853' TVD: 182, 35 spm & 140 psi; 45 spm & 180 psi, w/ 9.1 ppg. Total rotating hours in last 24 hours = 6.24 hrs. 2/15/2006 00:00 - 04:00 4.00 DRILL P INT1 Dir. drill from 6221' to 6792'. 04:00 - 05:30 1.50 DRILL N RREP INT1 Work on saver sub problems (breaking out at lower IBOP). DP grabber dies dragging on saver sub bevel. Unable to make up with TD pipe handler. Move pipe OK while working on Top Drive. 05:30 - 08:30 3.00 DRILL N RREP INT1 POH to 4423' (above shoe) to repair Top Drive. 08:30 - 13:00 4.50 DRILL N RREP INT1 Remove pipe handler. Torque saver sub to Top Drive with rig tongs. Adjust spacing of saver sub/pipe handler dies. Trouble shoot torque wrench solenoid valve and adjust to Varco specs. 13:00 - 13:30 0.50 DRILL P INT1 Service rig and Top Drive. 13:30 - 15:00 1.50 DRILL N RREP INT1 RIH. Wash last stand down, precautionary. 15:00 - 00:00 9.00 DRILL P INT1 Dir. drill from 6792' to 7933' MD/5243' TVD. Pump hi-vis sweeps at 7000' & 7500' MD. Rot 120-140 rpm;212 spm/900 gpm @ 2150 psi; torq 14K; WOB 10K; PU 205K, SO 155K, RW 180K. SPR at 7743' MD/5099' TVD: Pmps 1 & 2, 35 spm @ 190 psi, 45 spm @ 210 psi. 2/16/2006 00:00 - 00:00 24.00 DRILL P INT1 Directional drilling from 7933' MD/5243' TVD to 9728' MD/6273' TVD. Rot 140 rpm, WOB 10K, Torq 17K-23K, 212 spm/900 gpm @ 2350 psi, PU 250K, SO 165K, RW 200K. SPR @ 8966' MD/5837' TVD & 9.1 ppg: Pmps 1 & 2 - 35 spm @ 200 psi, 45 spm @ 210 psi. Total rotating time in past 24 hrs 18.32 hrs. Drilling occasional hard streaks (1-5 fUhr). Pump sweeps every 500'. Hole condition good. Torque increasing. Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 6 of 22 .Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2006 00:00 - 00:00 24.00 DRILL P INT1 Raised tube additives (Lubetex and EMI 920) from 2% to 3%. 2/17/2006 00:00 - 07:00 7.00 DRILL P INT1 Directional drilling from 9728' MD to 10,107' MD. Pumping hi-vis sweep every 500'. WOB 15K, 140 rpm, Torque 23K, 215 spm/911 gpm @ 2500 psi; PU 250K, SO 170K, RW 205K. SPR @ 10,107' MD/ 6542' TVD: Pmps 1 & 2; 35 spm @ 180 psi, 45 spm @ 230 psi w/ 9.1 ppg. 07:00 - 07:30 0.50 DRILL P INT1 Service top drive. 07:30 - 15:30 8.00 DRILL P INT1 Directional drilling from 10,107' MD to 10,730' MD. 15:30 - 16:30 1.00 DRILL N RREP INT1 Replace liner, swab, and wear plate in Pump #1, #1 cylinder. 16:30 - 00:00 7.50 DRILL P INT1 Directional drill from 10,730' MD to 10,960' MD/ 6992' TVD. Pumping sweeps every 500'. WOB 15K, 140 rpm, Torque 22K, 213 spm/902 gpm @ 2500 psi; PU 260K, SO 175K, RW 210K. SPR @ 10960' MD/6992' TVD: Pmps 1 & 2; 35 spm @220 psi, 45 spm @ 280 ppg w/ 9.1 ppg. Total rotating time in past 24 hours = 17.41 hrs. Hole conditions good on connections. 2/18/2006 00:00 - 05:30 5.50 DRILL P INT1 Directional drill from 10,960' to 11,530' MD/7331' TVD. Pump hi-vis sweeps every 500'. WOB 20K, 140 rpm, torq 18-25K, 213 spm/902 gpm @ 2550 psi, PU 275K, SO 192K, RW 222K. SPR @ 11,528' Md 17330' TVD: 9.1 ppg, Pmp 1 & 2 35 spm @ 250 psi, 45 spm @ 310 psi. 05:30 - 07:00 1.50 DRILL N SFAL INT1 Lost electrical power on the island. Started 2 rig generator sets and established circulation while restoring Island power back to the rig. 07:00 - 00:00 17.00 DRILL P INT1 Directional drill from 11,530' to 13,137' MD/8427' TVD. Pump hi-vis sweeps every 500'. WOB 20K, 140 rpm, torq 18-25K, 213 spm/902 gpm @ 3050 psi, PU 300K, SO 195K, RW 240K. SPR @ 12,474' MD / 7933' TVD: 9.4 ppg, Pmp 1 & 2, 35 spm @ 260 psi, 45 spm @ 310 psi. Actual rotating time past 24 hours = 14.6 hrs. 2/19/2006 00:00 - 05:00 5.00 DRILL P INT1 Dir drill from 13,137' MD to 13421' MD/8638' TVD. Prep for short trip to shoe. Pmp hi-vis wt. sweep while drilling at 13,288'. WOB 29K, 140 rpm, torque 24K, 212 gpm/902 gpm @ 3100 psi, PU 300K, SO 195K, RW 245K. SPR @ 13,421' MD/8638' TVD: Pmps 1 & 2; 35 spm @ 180 psi, 45 spm @ 230 psi, 9.5 ppg. Actual rotating time past 24 hours = 3.27 hrs. 05:00 - 07:00 2.00 DRILL P INT1 Circ. Pmp second hi-vis wt. sweep at TD and prep to POH on short trip. Monitor well -static. 07:00 - 15:30 8.50 DRILL P INT1 POH from 13,421' to 8780'. Began pulling tight (30-40K over) between 8780' and 8027'. Worked through, no swabbing until 8027'. Hole swabbed both up and down. 15:30 - 22:00 6.50 DRILL P INT1 POH with pumps on hole from 8027' to 6983' (140 spm/600 gpm @ 1100 psi). Pipe freeing up. Attempt to pull w/o pump from 6983' to 6697'. Swabbing. Continue POH w/ pump and backream at 40 rpm. POH to 4233', 22:00 - 22:30 0.50 DRILL P INT1 RIH to 4455' to circulate sweeps for cleaning hole. Bit and rotary-steerable pads below shoe. 22:30 - 00:00 1.50 DRILL P INT1 Circ. 25 bbl 11.8 ppg, hi-vis sweeps at 212 spm/902 gpm @ 1600 psi, 120 rpm. Large quantities of clay balls, coal, and drilled sollids over shaker with sweeps. 2/20/2006 00:00 - 04:00 4.00 DRILL P INT1 Circ. 2-30 bbl 11.8 ppg hi-vis sweeps from 4455'. Considerable amount of clay and clay balls over shakers on first sweep. Printed: 4/14/2006 11:11:52 AM t BP EXPLORATION. Page 7 0# 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To .Hours Taslc Code NPT Phase Description of Operations 2/20/2006 00:00 - 04:00 4.00 DRILL P INT1 Hole cleaning OK. 04:00 - 05:00 1.00 DRILL P INT1 Service Top Drive, drawworks, and crown. Check and sync rig generators to island power. Using 2 generators to supplement power due to high torque and pump pressure. 05:00 - 06:00 1.00 DRILL P INT1 Circ BU at 4450'. Blow down mud lines and top drive. 06:00 - 10:30 4.50 DRILL P INT1 RIH to 13,421'. Fill DP every 30 stds. Washed last 2 stands to btm, precautionary. Hole conditions good. 10:30 - 14:30 4.00 DRILL P INT1 Circ. &cond. mud, displacing to 10.5 ppg mud. Adding glycol. 14:30 - 00:00 9.50 DRILL P INT1 Dir. drill from 13,421' to 13,802' MD / 8938' TVD. Torque increasing to +/-27K. Adding drilling beads to system, currently 1#/bbl and incr. tube products to 4%/vol. Torque decreased +/-4K. 2/21/2006 00:00 - 05:00 5.00 DRILL P INT1 Directional drill from 13,802' to 14,085' MD. WOB 20K, 140 rpm, TQ 26K, 180 spm/800 gpm @ 3750 psi, PU 355K, SO 205K, RW 255K. SPR at 13,991' MD / 9084' TVD: Pmp 1, 35 spm @ 350 psi, 45 spm @ 410 psi; Pmp 2, 35 spm@ 340 psi, 45 spm @ 430 psi, 10.5 ppg. 05:00 - 05:30 0.50 DRILL P INT1 Rig service. Service Top Drive. 05:30 - 12:30 7.00 DRILL P INT1 Dir. drl. from 14,085' MD to 14,395' / 9427' TVD. 12:30 - 15:00 2.50 DRILL N RREP INT1 Repair cap gasket on pmp #1/ #1 cylinder. Bring 2 generators back on line, had kicked off earlier. 15:00 - 20:30 5.50 DRILL P INT1 Dir. drl from 14,395' to intermediate casing point at 14,549' MD / 9556' TVD. WOB 18K, 140 rpm, TO 26K, 165 spm/ 700 gpm @ 2900 psi, PU 325K, SO 210K, RW 260K. SPR at 14,549' MD / 9556' MD: Pmp 1, 35 spm @ 320 psi, 45 spm@ 410 psi; Pmp 2, 35 spm @ 330 psi, 45 spm @ 410 psi, 10.5 ppg. Actual rotating time past 24 hrs. = 11.85 hrs. MWD logging tool quit at 14,408' MD/ 9437' TVD. 20:30 - 00:00 3.50 DRILL P INT1 Circ. &cond hole. Pmp 40 bbl weighted hi-vis sweep at 190 spm/900 gpm @ 3600 psi, 120 rpm. No notable quantities of cuttings across shakers. Prep for second sweep. 2/22/2006 00:00 - 03:30 3.50 DRILL P INT1 Circ &cond hole. Pmp hi-vis sweep. Hole clean. Prep for short trip. 03:30 - 11:30 8.00 DRILL N WAIT INT1 Circulate and move pipe waiting on wind abatement. 11:30 - 15:30 4.00 DRILL P INT1 POH from 14,549' to 13,043' short trip. Pump out each stand. 30-40K overpull first 2 stds. Work pipe through tight spots. 20-30K on remainder of trip. Blow do top drive. 15:30 - 16:30 1.00 DRILL P INT1 RIH. Circ last stand down, precautionary. 16:30 - 19:00 2.50 DRILL P INT1 Circ 60 bbl 13 ppg hi-vis sweep at 180 spm @ 3500 psi and 140 rpm. BU gas after short trip peaked at 320 units, averaging 260 units. 19:00 - 21:00 2.00 DRILL P INT1 Pull one std and circ 2nd 60-bbl weighted hi-vis sweep from 14,462' MD. Hole appears clean. Background gas at +/- 80 units. Monitor well-static. 21:00 - 00:00 3.00 DRILL P INT1 POH to run csg. Pmp out from 14,462' to 12,949' at 60 spm/265 gpm and 650 psi. Pulled 40K over at 13850'. Worked pipe through tight spot, OK. 2/23/2006 00:00 - 01:30 1.50 DRILL P INT1 Circulate btm up & condition mud @ 12,949' 01:30 - 04:00 2.50 DRILL P INT1 Monitor well- static. POH from 12,949' to 11,150' without pump 20-30K overpull typical, Occasional 40K overpull 04:00 - 04:30 0.50 DRILL P INT1 Spot 160 bbl G Seal pill from 11,150' to 10,000' MD. Printed: 4114!2006 11:11:52 AM BP EXPLORATION Page 8 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/23/2006 04:30 - 05:30 1.00 DRILL INT1 POH from 11,150' to 9916' 05:30 - 13:00 7.50 DRILL P INT1 Pump dry job, POH from 9916' to 4442' Monitor well 10 mins, well static POH from 4442' to 3100' 13:00 - 14:30 1.50 DRILL P INT1 Well began to swab while POH @ 3100' Pump 40 bbl high vis sweep Circulate to clean hole DP pressure 1600 psi @ 800 GPM Pump dry job, monitor well -static 14:30 - 17:00 2.50 DRILL P INT1 POH from 3100' to 271', No problems Monitor well 17:00 - 20:30 3.50 DRILL P INT1 LD BHA #5 Clear & clean rig floor 20:30 - 00:00 3.50 CASE P INT1 Pull wear bushing RU test joint, set test plug PJSM, Change upper pipe rams to 9 5/8" 2/24/2006 00:00 - 01:00 1.00 CASE P INT1 Test door seals on BOPs to 3000 psi 01:00 - 01:30 0.50 CASE P INT1 RD test joint & test plug 01:30 - 04:30 3.00 CASE P INT1 RD DP handling equipment RU tools & equipment to run 9 5/8" casing 04:30 - 05:00 0.50 CASE P INT1 PJSM, Running 9 5/8" casing Discuss safety hazards w/ focus on body placement and hand safety 05:00 - 07:00 2.00 CASE N HMAN INT1 Thaw mud line valves 07:00 - 08:30 1.50 CASE INT1 Level rig 08:30 - 09:30 1.00 CASE P INT1 Run 2 joints 9 5/8" casing 09:30 - 10:30 1.00 CASE N INT1 Level rig 10:30 - 11:30 1.00 CASE P INT1 Run 2 joints 9 5/8" casing 11:30 - 14:00 2.50 CASE N HMAN INT1 Thaw mud lines, test mud lines to 2800 psi 14:00 - 14:30 0.50 CASE P INT1 Circulate though float equipment and check floats 14:30 - 22:00 7.50 CASE P INT1 Run 71 joints of 9 5/8" casing Filling every joint w/ Franks fill up tool 22:00 - 00:00 2.00 CASE P INT1 Move rig 3" to the South Rig aligned over wellbore 2/25/2006 00:00 - 01:00 1.00 CASE P INT1 Air boot on riser, check for leaks Tighen turnbuckles on BOP stack 01:00 - 03:00 2.00 CASE P INT1 Run 9 5/8" casing 03:00 - 04:00 1.00 CASE P INT1 Circulate casing volume @ shoe- 4442' Pump pressure 663 @ 9 bpm Total volume pumped 315 bbls 04:00 - 16:30 12.50 CASE P INT1 Run 9 5/8" casing 16:30 - 18:00 1.50 CASE P INT1 Change out elevators Control valve failure 18:00 - 22:30 4.50 CASE P INT1 Run 9 5/8", 53.5 #, L-80, BTM casing Total Jts. ran 338, casing landed @ 14547' 22:30 - 23:00 0.50 CASE P INT1 RD tongs and casing handling equipment 23:00 - 23:30 0.50 CASE P INT1 RU cementing head and circulating line 23:30 - 00:00 0.50 CASE P INT1 Break circulation @ 14547' Pump pressure 800 psi @ 2 BPM 2/26/2006 00:00 - 04:30 4.50 CASE P INT1 Circulate and condition mud for cementjob Pump pressure 670 @ 7 BPM, Reduce mud to 10.5 ppg 04:30 - 05:00 0.50 INT1 PJSM, discuss cementing operations Printed: 4/14/2006 11:11:52 AM C] BP EXPLORATION Page 9 of 22 Operation Summary. Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2!3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT .Phase Description of Operations 2/26/2006 05:00 - 06:00 1.00 CEMT P INT1 Pump 5 bbl sea water ,pressure test lines to 3000 psi Pump 35 bbl CW 101, 75 bbl 11.0 ppg mud push 06:00 - 10:30 4.50 CEMT P INT1 Drop bottom plug, pump cmt per design 10:30 - 11:00 I 0.501 CEMT I P I I INT1 11:00 - 12:00 1.00 CEMT P INT1 12:00 - 13:00 1.00 CEMT P INT1 13:00 - 16:00 3.00 CEMT P INT1 16:00 - 17:30 1.50 CEMT P INT1 17:30 - 20:00 2.50 CEMT P INT1 20:00 - 21:00 1.00 CEMT P INT1 21:00 - 21:30 0.50 CEMT P INT1 21:30 - 00:00 2.50 CEMT P INT1 2/27/2006 100:00 - 03:00 I 3.001 CEMT I P I I INT1 03:00 - 04:30 I 1.501 CEMT I P I I INT1 04:30 - 05:30 1.00 CEMT P INT1 05:30 - 06:00 0.50 CEMT P INT1 06:00 - 08:00 2.00 CEMT P INT1 08:00 - 10:00 2.00 CEMT P INT1 10:00 - 12:00 2.00 CEMT P INT1 12:00 - 13:00 1.00 CEMT P INT1 13:00 - 13:30 0.50 CEMT P INT1 13:30 - 15:00 1.50 CEMT P INT1 15:00 - 19:00 4.00 CEMT P INT1 19:00 - 20:00 1.00 CEMT P INT1 20:00 - 21:00 1.00 CEMT P INT1 555 bbl 12.5 ppg "ext" lead, class G cement 97 bbl of 15.8 ppg tail cement class G ICP = 210, FCP= 1037 psi @ 3 BPM Drop top plug, pump 10 bbl sw Displace w/ rig pump 990 bbl drilling mud 24.5 bbl sw, total disp 1024.5 bbl Bump plug, cement in place @ 10:16 Bleed pressure, floats holding OK Blow down circulating lines. RD csg equipment, cmt head, clean and clear floor Blow down rig circulating lines Test kill line to 3000 psi Bull head 265 bbl of 10.5 ppg mud down 13 3/8" annulus Final pump pressre 860 psi, bleed pressure recover 10 bbl Change top pipe rams to 3 1/2" X 6" variables ND BOP's and related equipment, move well head annulus sweep and install VR plug Wait on NS 31 & 29 to be shut in Lift BOP's Set slips with 390 K string weight 1st attempt casing slid though slips 8" without setting 2nd attempt casing slid though slips about 4" taking partial weight 3rd time slips set w/ 1/2" slack off Evaluate options to install 9 5/8" pack off Clearances were not uniform between the 9 5/8" casing and the wellhead pack off bowl Cut and bevel 9 5/8" casing Lay down cut joint Pull riser and move BOPE to install pack off PJSM for critical lift associated with BOPE near NS 31 Dress casing cut and install pack off Run in lock down screws on wellhead NU BOP's Install drilling sweep & riser Remove casing elevators and long bails MU test joint and set test plug Fill BOP with sea water, riser leaking replace gasket, no leaks Test BOPS. Mr. Lou Grimauldi, AOGCC inspector, is onsite to witness testing. Test annular to 250/3500 psi Test pipe and blind rams, choke manifold valves, kill line valves, dart valve, and lBOP to 250/5000 psi. Perform accumulator test, hold all pressure test for 5 minutes All BOP test witnessed by WSL's Darrell Green and Richard Watkins Pump 140 BBL freeze protect diesel down outer annulus Pumped FP @ 4 BPM - 1150 psi, left 700 psi outer annulus Pull test plug and install wear bushing Clear rig floor of casing equipment Printed: 4/14/2006 11:11:52 AM $P EXPLORATION Page 10 of 22 Operations Summary-Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/27/2006 21:00 - 22:00 1.00 CEMT P INT1 Service rig, lubricate rig and top drive 22:00 - 23:00 1.00 DRILL P INT2 Install bails and elevators 23:00 - 00:00 1.00 DRILL P INT2 PU BHA # 6 2/28/2006 00:00 - 03:30 3.50 DRILL P INT2 PU BHA # 6, shallow test MWD 03:30 - 06:00 2.50 DRILL P INT2 PU 49 Jts. 5" drill pipe 06:00 - 13:30 7.50 DRILL P INT2 RIH F/ 1808' T/ 13540', fill DP every 30 stands 13:30 - 15:30 2.00 DRILL P INT2 Cut 145' of drilling line and adjust brakes 15:30 - 16:30 1.00 DRILL P INT2 RIH F/ 13540' T/ 14202' 16:30 - 17:00 0.50 DRILL INT2 Wash F/ 14202' T/ 14392' 17:00 - 19:30 2.50 DRILL P INT2 RU lines pressure test casing T/ 4000 psi for 30 min RD lines and blow down, clear floor 19:30 - 20:00 0.50 DRILL P INT2 Wash down F/ 14392' T/ 14466' 20:00 - 21:30 1.50 DRILL P INT2 Drill float @ 14466', drill cement T/ 14542' DP 1350 psi @ 320 GPM w/ 10.5 PPG, 50 RPM, 21 k torque PU 300K, SO 200K, ROT 245 K 21:30 - 23:00 1.50 DRILL P INT2 Circulate and displace wellbore w/ 12.5 PPG mud 23:00 - 00:00 1.00 DRILL P INT2 Drill cement F/ 14542' T/ 14547 Drill float shoe F/ 14547 T/ 14549' DPP 1750 psi @ 320 GPM SPR pump # 1 - 35 SPM = 310 psi, 45 SPM = 450 psi, SPR pump #2- 35 SPM = 290 psi, 45 SPM= 420 psi MW 12.5 MD 14545' TVD 9558' 3/1/2006 00:00 - 02:30 2.50 DRILL P LNR1 Drilling float shoe @ 14549', WOB 4 K, Torque 23 K DPP 1840 psi @ 320 GPM Lost pump pressure, 300 psi in 10 min Swich to pump # 2, DPP 1350 psi @ 320 GPM Prepare to POOH for possible wash out 02:30 - 10:00 7.50 DRILL P LNR1 POOH to inspect BHA for washout 10:00 - 11:00 1.00 DRILL P LNR1 Stand back jars,flex collars, unable to find W/O MU T/D pump 100 GPM while picking up slowly Fluid squirting from sheared Rhino reamer 11:00 - 13:00 2.00 DRILL P LNR1 Change out Rhino reamer, reconfigure BHA Place stabilizer in BHA, Continue PU BHA # 7 13:00 - 13:30 0.50 DRILL P LNR1 Shallow test Rhino reamer 284 GPM 400 psi Blow down top drive 13:30 - 23:00 9.50 DRILL P LNR1 RIH F/ 106' T/ 14,485', Fill pipe every 20 stds 23:00 - 23:30 0.50 DRILL P LNR1 Wash F/ 14,485 T/ 14550' 23:30 - 00:00 0.50 DRILL P LNR1 Circulate & condition mud OA Pressure 700 psi 3/2/2006 00:00 - 06:00 6.00 DRILL P LNR1 Drill F/ 14549' T/ 14569' Slow ROP, bit balling DDP 1350 psi @ 320 GPM Vary rotory from 40 to 80 RPM Vary WOB from 2K to 15K Pump 30 bbl hi vis sweep, no difference in ROP Pump 30 bbl nut plug sweep, no difference in ROP 06:00 - 08:00 2.00 DRILL P LNR1 Circulate and condition hole for fit test 08:00 - 09:00 1.00 DRILL P LNR1 Perform fit test to 14.5 PPG EMW, Current MW 12.3 PPG, Pressure annulus to 1100 psi Hold 10 minutes, pressure bled off to 1060 psi 09:00 - 15:30 6.50 DRILL P LNR1 Drill F/ 14569' T/ 14601' DPP 1550 psi @ 330 GPM, 120 RPM, TQ 20K WOB 2K to 15K PU 290 K, SO 190 K, ROT 248K Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 11 of 22 Operatiolns Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date. From - To .Hours Task Code NPT Phase. Descriptjon of Operations 3/2/2006 09:00 - 15:30 6.50 DRILL P LNR1 SPR MP # 1 - 25 STKS-160 psi, 35 STKS 270 psi SPR MP # 2- 25 STKS- 180 psi, 35 STKS 280 psi 15:30 - 00:00 8.50 DRILL P LNR1 Drill F/ 14601 T/ 14869' Rhino reamer below casing shoe, Increase flow rate to 570 GPM DPP 3600 psi @ 570 GPM, WOB 30 K, RPM 140, Torque 23K PU 290 K, SO 190, ROT 240 3/3/2006 00:00 - 04:00 4.00 DRILL P LNR1 Drill directional from 14869' to 14,945' Drilling 8 1/2" hole opening to 9 112" hole 04:00 - 05:30 1.50 DRILL N RREP LNR1 Drilling ahead w/ DPP 3500 psi @ 570 GPM Lost 500 psi in 5 minutes. Check surface equip't -all OK. POH to shoe & double check surface equip't. 05:30 - 12:00 6.50 DRILL N RREP LNR1 POOH looking for wash out in string 12:00 - 13:00 1.00 DRILL N RREP LNR1 Pull out of hole to BHA, looking for wash out Did not find wash out during TOH 13:00 - 15:00 2.00 DRILL N RREP LNR1 Perform base line flow test on MWD and BHA Pump 400 GPM to establish base line parameters 15:00 - 00:00 9.00 DRILL N RREP LNR1 RIH and base line pump test every 20 stands Check actual pressures vs. calculated pressures & check MWD turbine RPM to aid in locating wash out. 3/4/2006 00:00 - 03:00 3.00 DRILL N RREP LNR1 RIH checking pump pressure every 20 stands. Pump test while on bottom, pump pressure 800 psi low vs calculated. POOH, found leak in DP body on center Jt. of stand # 149 03:00 - 03:30 0.50 DRILL P LNR1 Adjust brakes on draw works 03:30 - 04:00 0.50 DRILL P LNR1 RIH with 6 stands of drill pipe Stage up pumps to 570 GPM 3900 psi, no fill on bottom 04:00 - 04:30 0.50 DRILL P LNR1 Drill F/ 14946' To 14953', 570 GPM, 3900 psi, 04:30 - 08:00 3.50 DRILL N RREP LNR1 Drilling @ 14953', lost 600 psi pump pressure Prepare to POH looking for wash out Wash out found @ 13237', std # 138, LD stand 08:00 - 09:00 1.00 DRILL P LNR1 RIH /wash down last stand to TD 14953' 09:00 - 00:00 15.00 DRILL P LNR1 Drill F/ 14953' T/ 15191' 3/5/2006 00:00 - 01:00 1.00 DRILL P LNR1 Drill F/ 15191' T/ 15196' 3125 psi' DPP went F/3125 psi T/ 2930 psi 01:00 - 03:00 2.00 DRILL N RREP LNR1 POH to find wash out in pipe Found WO @ Std. # 140, Jt. 418, Remove stand 140 F/ String Break Circ, pump 570 GPM, 3150 psi, turbine RPM = 3164 Blow down top drive & mud line 03:00 - 04:00 1.00 DRILL N RREP LNR1 LD Bad Jt. and 2 more into pipe shed CLN & CLR floor, RIH wash last stand T/ BTM, 15196' Stage up pumps T/ 570 GPM, 3350 psi 04:00 - 04:30 0.50 DRILL N RREP LNR1 RIH w/ DP Replace cap gasket on mud pump. 04:30 - 09:00 4.50 DRILL P LNR1 Drill F/ 15196' T/ 15232' 570 GPM, 3350 psi, 20K TQ on BTM, 18K off BTM 200 SO, RW 245, 140 RPM, Calc ECD 13.6 ppg, actual ECD 13.6 ppg Average rate of penetration 10 FPH 09:00 - 10:00 1.00 DRILL N DFAL LNR1 Monitor well, POOH F/ 15232' T/ shoe 14549' 10:00 - 10:30 0.50 DRILL P LNR1 Service top drive and blocks 10:30 - 13:30 3.00 DRILL P LNR1 Cut and slip 119' of drill line. Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 12 of 22 .Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2006 10:30 - 13:30 3.00 DRILL P LNR1 Pump dry job and prepare T/ POOH 13:30 - 19:00 5.50 DRILL N DFAL LNR1 POOH 158 stands in the derrick 19:00 - 23:30 4.50 DRILL N DFAL LNR1 Inspect BHA, test rhino reamer w/ plugs installed in nozzles - OK UD rhino reamer & POH w/ BHA. Bit missing one nozzle. Test rotary steerable - OK Changed out rotary steerable tools as precautionary due to hours on seals and bit Download, dump MWD tool 23:30 - 00:00 0.50 DRILL N DFAL LNR1 Test MWD and rotory steerable. 3/6/2006 00:00 - 01:00 1.00 DRILL N DFAL LNR1 Tst BHA/MWD. Blow do Top Drive. 01:00 - 09:30 8.50 DRILL N DFAL LNR1 RIH. Fill every 20 stds not exceeding 310 gpm. Verify proper pump press. 09:30 - 10:00 0.50 DRILL N DFAL LNR1 Stage pumps T/ 570 gpm, 3650 psi, 110 rpm, TO 21= 25K ECD = 13.8 wash down T 15,210' torque increase 10:00 - 11:30 1.50 DRILL N DFAL LNR1 Ream down F/ 15210' T/ 15,220' TO 22K, WOB 8K Eratic torque@ 15218', work through same 11:30 - 12:00 0.50 DRILL N RREP LNR1 Pump pressure dropped F/ 3650 psi T/ 3250 psi No leaks @ surface, POOH, pump 3 bpm, 270 psi F/ 15,183' looking for possible wash out in string 12:00 - 15:00 3.00 DRILL N RREP LNR1 Continue pumping out to the shoe to 14,549' keeping pipe full. Blow do top drive and pull to 13,353'. Found washout. Ld Jt. # 414. RIH to 14,269'. 15:00 - 16:30 1.50 DRILL N RREP LNR1 Spot EP mud tube pill from 3312' to 2000'. 16:30 - 18:00 1.50 DRILL N RREP LNR1 LD 31 jts of 5" DP. 18:00 - 20:00 2.00 DRILL N SFAL LNR1 Shim rig on the South end corners Flow line minimim clearence reached 20:00 - 22:30 2.50 DRILL N RREP LNR1 Sort out drill pipe on location to send to Tuboscope Removing ser. #' s SB - SG - RS 22:30 - 23:30 1.00 DRILL N RREP LNR1 Pick up 31 Jts. of drill pipe F/ pipe shed and TIH. Pipe picked up was 4' less than that layed down. 23:30 - 00:00 0.50 DRILL N RREP LNR1 Continue to RIH with drill pipe F/ derrick 3/7/2006 00:00 - 03:00 3.00 DRILL N RREP LNR1 Stage up circ. Wash and ream from 15,065' to 15,232'. Tight spots. Some packing off occurring. Wash and ream to TD, back reaming tight spots from 15,100'. Some shale splinters across shakers. Erratic torque, 18-26K. 500 gpm @ 2950 psi. 03:00 - 13:30 10.50 DRILL P LNR1 Directional drill from 15,232' to 15,331' MD / 10,264' TVD. 120 RPM, WOB 24K, 600 gpm @ 3930 psi, talc. ECD 13.8 ppg, Act. = 13.9 ppg. PU 330K, SO 200K, RW 245K. Took SPR @ 15,241'. 13:30 - 14:00 0.50 DRILL P LNR1 Service top drive. Add oil to swivel. 14:00 - 00:00 10.00 DRILL P LNR1 Directional drill from 15,331' to 15,604' MD/10,511' TVD. Pmp 40 bbl hi-vis weighted sweep at 15,500'. 120 RPM, WOB 24K, 600 gpm @ 3950 psi, calc. ECD 13.76 ppg, Act = 13.8 ppg. PU 310K, SO 200K, RW 220K, Torq 20-25.5K. SPR @ 15,604'MD/10,355TVD: Pmp 1, 35 spm @ 420 psi, 45 spm @ 485 psi; Pmp 2, 35 spm @ 385 psi, 45 spm @ 480 psi w/ 12.5 ppg. Actual rotating time in past 24 hr = 16.52 hrs. 3/8/2006 00:00 - 07:30 7.50 DRILL P LNR1 Dir. dri. from 15,604' to 15,789' MD/10,677' TVD. 120 RPM, WOB 22K, Torq 22K on & 20K off, 591 gpm @ 3950 psi, PU 310K, SO 200K, RW 248K, calc ECD 13.8, actual 13.9 ppg. Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 13 of 22 Operations Summary Report. Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description. of Operations 3/8/2006 00:00 - 07:30 7.50 DRILL P LNR1 SPR at 15,640' MD/ 10,543' TVD & 12.5 ppg: Pmp #1& 2, 25 spm @ 300 psi, 35 spm @ 430 psi. 07:30 - 10:00 2.50 DRILL N RREP LNR1 POH looking for washout. Lost 400 psi while drilling and no leaks in surface equip. Pump out at 2 BPM @ 178 psi. Work through tight spot at 15,278', wipe same-OK. Found washout in slip area below box end of Jt. # 457(1086' below RT). LD Std. # 153. PU 3 singles, new to string. 10:00 - 12:00 .2.00 DRILL N RREP LNR1 RIH. Ream through tight spot at 15,195' & 15,333'. Stage up pumps and wash last stand to bottom at 15,789'. 12:00 - 18:00 6.00 DRILL P LNR1 Dir. drill from 15,789' to 15,896' MD/10,769' TVD; 7" liner point. 112 RPM, WOB 25K, Torq 24K, 591 GPM @ 3950 psi, PU 320K, SO 200K, RW 250K, calc ECD 13.79 ppg, actual 13.9 ppg. SPR at 15,800' MD/10,687' TVD & 12.5 ppg: Pmp #1 35 spm @ 475 psi, 45 spm @ 570 psi; Pmp #2 35 spm @ 435 psi, 45 spm @ 550 psi. Pmp hi-vis sweep at 15,850', evidence of running shale. TD hole at 15,896'. Total rotating time past 24 hrs = 12.17 hrs. 18:00 - 19:30 1.50 DRILL P LNR1 Circ. BU. 570 gpm @ 3900 psi. Monitor well-static. 19:30 - 23:00 3.50 DRILL P LNR1 POH for short trip to 9 5/8" casing shoe. Pmp out at 2 BPM @ 200 psi. Pulled 30 K over at 15,565', 15,222', and 15,200'. Did not require back-reaming. Circ BU at shoe w/ 600 gpm @ 3900 psi. 23:00 - 00:00 .1.00 DRILL P LNR1 RIH. Tight spots at 15,185' & 15,225'. Work through w/o pump OK. Wash last stand down. Tag fill at 15,866' (30' of fill). Wash and ream. 3/9/2006 00:00 - 01:30 1.50 DRILL P LNR1 Stage up pumps. Wash and ream last stand down. Tag fill at 15,866' (30' of fill). Wash to TD w/ 591 gpm @ 3900 psi, 120 RPM, torq 22K, talc ECD 13.79, actual 13.9 ppg. 01:30 - 06:00 4.50 DRILL P LNR1 Circ and cond. hole. Pmp hi-vis sweep after first BU. Pull one stand after 2 BU. Circ 2 more BU. Run stand back to TD. Returns indicate running shale. Rotate at 130 RPM and reciprocate pipe during all circulating. 06:00 - 10:30 4.50 DRILL P LNR1 Incr. mud wt to 12.8 ppg to control shale. Circ and cond mud and hole. Reduce pmp rate to 480 gpm @ 2830 psi to keep ECD from exceeding 14 ppg at higher mud wt. 10:30 - 13:30 3.00 DRILL P LNR1 Monitor well-static. POH pumping at 25 spm @ 300 psi. Wipe tight spots at 15,672' & 15,360'. No rotation while pulling to shoe at 14,549'. SLM. 13:30 - 15:00 1.50 DRILL P LNR1 Circ BU at 14,474' at 130 spm/460 gpm @ 2650 psi. 15:00 - 15:30 0.50 DRILL P LNR1 Blow do top drive. Drop steel DP rabbit with tattle-tail. 15:30 - 23:00 7.50 DRILL P LNR1 POH to BHA. SLM (no correction). 23:00 - 23:30 0.50 DRILL P LNR1 Monitor well-static. 23:30 - 00:00 0.50 DRILL P LNR1 LD BHA # 8. 3/10/2006 00:00 - 02:00 2.00 DRILL LNR1 LD HWDP, jars, flex collars, MWD tools, and bit. 02:00 - 02:30 0.50 DRILL LNR1 Clear floor. PJSM for changing upper rams. 02:30 - 04:30 2.00 BOPSU LNR1 Pull wear ring. Install test plug and lock down. Close blind rams. Change out upper rams to 4.5"X7". 04:30 - 05:00 0.50 BOPSU LNR1 Open blinds and run 5" test jt. RU pr tst equipment. Pressure test ram doors to 250 psi and 5000psi each for 5 min. Record on press. chart. 05:00 - 05:30 0.50 BOPSU LNR1 Rig down test equip. Pull test plug and run wear ring. 05:30 - 07:00 1.50 CASE LNR1 Rig up casing tools for 7" liner. PJSM. 07:00 - 11:30 4.50 CASE LNR1 PU 7", 29# , L-80, Hydril 521 liner with float equip and Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date. .From - To Hotars Task Code NPT Phase Description of .Operations 3/10/2006 07:00 - 11:30 4.50 CASE LNR1 centralizers as per plan. Use Jet-Cube seal guard and torque to 15,000 ft-Ibs. Utilize dog collar on each jt. Fill pipe on the fly and top off every 5 jts. 11:30 - 12:00 0.50 CASE LNR1 Make up Baker 9 5/8" X 7" liner hanger. 12:00 - 00:00 12.00 CASE LNR1 RIH with 5" DP at 1.5 min/stand, filling pipe every row (11 stds). 3/11/2006 00:00 - 01:30 1.50 CASE P LNR1 RIH w/ 7" liner to 14,478' (above 9 5/8" shoe at 14,549') filling every 11 stands. 01:30 - 03:30 2.00 CASE P LNR1 Circ. Stage up slowly to 5 BPM at 1000psi. Circ pipe vol. PU 290K. SO 205K, RW 240K, TQ 18K 03:30 - 06:30 3.00 CASE P LNR1 RIH w/ 7" liner in open hole. Tag firm fill at 15,877' MD/10,757' TVD (31' MD below top of Sag). Attempt to work down with no gain. RU cmt head. 06:30 - 09:00 2.50 CASE P LNR1 Stage up pumps & circulate liner & DP vol. ICP 600 psi @ .5 BPM, FCP 1150 psi @ 5 BPM. 09:00 - 10:30 1.50 CEMT P LNR1 PJSM w/ all personnel involved with cement job. Pump 5 bbls sea water & test lines to 4500 psi. Bleed off pressure & pump 55 bbls 13.5 ppg Mud Push II followed by 100 bbls (365 sx) of 15.8 ppg tail cement. 10:30 - 14:00 3.50 CEMT P LNR1 -Displace cement with rig pumps @ 6 BPM 800 psi. Good pressure increase as cement turned corner with no losses. Slowed pump to 3 BPM before wiper plug shear -sheared wiper plug on calculated strokes with 96% pump efficiency. Increase pump rate to 5.5 BPM slowing down before bumping plug. Bumped plug w/ 308 bbls of mud at 1300 psi and increased pump pressure to 4200 psi to set hanger. - Bleed off pressure & check floats -floats held. CIP @ 11:30. Full returns during cementing. - S/O 60K to ensure hanger set. - P/U string 8' to release from hanger & lower string & set down 50K to set packer. Good surface indication of packer setting. Repeat sequence with rotation to ensure packer set. - P/U string to expose packoff on setting tool w/ 1000 psi on DP -Circulate 30 bbls @ 1.5 BPM - P/U on string & pull setting tool clear of packer & CBU @ 550 GPM 3600 psi. Approximately 20 bbls of cement in contaminated mud @ B/U. 14:00 - 15:00 1.00 CEMT N RREP LNR1 LD 9 jts. 5" DP. 15:00 - 15:30 0.50 CEMT P LNR1 Pmp dry job. BD top drive and mud lines. 15:30 - 22:00 6.50 CEMT N LNR1 Drillpipe Management. LD 18 stands; replace 10 stands with good pipe; move 11 stands of good pipe to top of string. Now have 149 stands of 5" DP in hole. 22:00 - 00:00 2.00 CEMT P LNR1 Cut and slip 116' of drilling line. 3/12/2006 00:00 - 00:30 0.50 CEMT P LNR1 Compl. cutting DL. Clear floor. Blow do all mud lines. 00:30 - 03:00 2.50 CEMT P LNR1 Pump dry job. POH with liner running tool. 03:00 - 03:30 0.50 CEMT P LNR1 Pipe pulling wet. Pump second dry job. Lost lights in derrick board area. Temp. repair. 03:30 - 04:00 0.50 CEMT P LNR1 Cont. POH. 04:00 - 04:30 0.50 CEMT N RREP LNR1 Repair lights in derrick for board area. 04:30 - 10:00 5.50 CEMT P LNR1 Cont. POH to liner tool. 10:00 - 11:00 1.00 CEMT P LNR1 Monitor well-static. Make service breaks and LD liner running tool. Setting tool dogs sheared OK. 11:00 - 13:00 2.00 CEMT P LNR1 RU and test 9 5/8" X 7" casing and liner lap to 3400 psig. Held for 30 min. OK. Drain stack. Pull wear ring. Run test plug. Printed: 4(14/2006 11:11:52 AM BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 -Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task .Code NPT Phase Description of Operations 3/12/2006 13:00 - 15:00 2.00 BOPSU P LNR1 Change out both upper and lower ram blocks. Install 2 7/8" X 5" variable blocks in upper rams and 3 1/2" X 6" variable blocks in lower rams. 15:00 - 20:00 5.00 BOPSU P LNR1 RU to test BOPE. AOGCC field inspector, Chuck Sheve, waived witnessing test. MMS field inspector, Kyle Monkelein, waived witnessining test. Install test joint. Tested annular to 250 psi and 3500 psi, 5 min. each, OK. 20:00 - 00:00 4.00 BOPSU N RREP LNR1 Attempt test on upper rams --failed to hold high press test. Sent for replacement blocks. (Arrived at 21:00). Tested choke manifold and 5" floor valves (250 psi and 5000 psi, 5 min each) while waiting on replacement blocks. Two extra 5" TIWs failed. Install second set of 2 7/8' X 5" variable blocks. Resume testing. Compl testing upper and lower rams on 5" DP at 250 psi & 5000 psi for 5 min each. 3/13/2006 00:00 - 03:30 3.50 BOPSU P LNR1 Compl. BOP test. Pr. tst. annular on 4" tst jt. to 250 psi and 3500 psi, 5 min. each. Test upper and lower rams on 4" tst jt. & 4" floor valves to 250 psi and 5000 psi, 5 min each. Test blind/shear rams to 250 psi and 5000 psi, 5 min each. Perform Koomey function test, OK. Check remote station OK. 03:30 - 04:00 0.50 BOPSU P LNR1 RD BOP tst equip. Pull tst plug, run wear ring (ID: 8.812"). LD tst jt. 04:00 - 04:30 0.50 CASE P LNR1 Blow down all lines. 04:30 - 07:30 3.00 CASE P LNR1 PJSM. MU BHA #9. Install RA source in MWD. 07:30 - 09:00 1.50 CASE P LNR1 Pick up 4", 14#, HT-40 DP & single in. 09:00 - 10:00 1.00 CASE N WAIT LNR1 Make determination whether or not to run a MAD pass in the surface hole. Deferred to trip out of hole. 10:00 - 11:30 1.50 CASE P LNR1 Cont. PU 4" DP (66 jts. total). 11:30 - 18:00 6.50 CASE P LNR1 Chg. elevators & tong die blocks for 5" DP. Shallow test MWD-OK. RIH w/ 5". SLM. 18:00 - 19:30 1.50 CASE P LNR1 Wellbore fluids out of balance and flowing back in DP. Mix and spot dry job. 19:30 - 00:00 4.50 CASE P LNR1 RIH to 15,623'. Washing down at 15,716' @ OO:OOhrs. No problem entering 7" liner top at 14,386'. 3/14/2006 00:00 - 03:30 3.50 CEMT P LNR1 Wash do to top of liner cmt plugs at 15,784' putting LC at 15,786' DPM. Drilled plugs, landing collar, shoe track, and float collar. Cmt drilled medium firm. Drl to 15,868'. Prep to displace to FloPro mud. PU 290K, SO 210K, RW 255K at 15,868'. 03:30 - 09:00 5.50 CEMT P LNR1 Displacing old mud with 9.1 ppg FloPro mud system. Pmp spacer followed by FloPro at 220 gpm @ 2900 psi. 09:00 - 12:00 3.00 DRILL P LNR2 Drill shoe. Clean out rathole and drill 20' of new hole to 15,917' MD, 10,793' TVD. WOB 10K, 80 RPM, TO 11K, 62 spm @ 1830 psi, PU 295K, SO 220K, RW 255K. SPR @ 15,877' MD/10,757' TVD: Pmp 1 & 2; 35 spm @ 980 psi & 45 spm @ 1100 psi w/ 9.2 ppg. Act. rotating time for 20' was 0.25 hrs. 12:00 - 13:00 1.00 DRILL P LNR2 Pull up to shoe at 15,877' and perform FIT w/ 9.2 ppg mwt. Pmp 49 strokes (4.9 bbl) and press. to 1300 psi for an equivalent mud wt. of 11.5 ppg at shoe depth of 10,780' TVD. No indication of formation failure. 13:00 - 00:00 11.00 DRILL P LNR2 Dir drill from 15,917' to 16214' MD/11,076' TVD. WOB 15K, 100 RPM (rotary) + 165 RPM (motor), TO off 15K, TO on 18K, 270 gpm @ 1900 psi, PU 310K, SO 220K, RW 255K. SPR @ 15,905' MD/10,782' TVD: Pmp 1- 23 spm @ 890 psi, 35 spm Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 16 of 22 .Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name; NABORS 33E Rig Number: 33E Date- From - To Hours Task Code NPT Phase Description. of :Operations 3/14/2006 13:00 - 00:00 11.00 DRILL P LNR2 @ 1070 psi; Pmp 2--23 spm @ 910 psi, 35 spm @ 1075 psi w/ 9.2 PPg• Total rotating time last 24 hr. = 9.09 hrs. 3/15/2006 00:00 - 10:30 10.50 DRILL P LNR2 Dir. drlg at 16,265' MD/11,116' TVD to 16,320' MD/11,169' TVD. WOB 5-20K, RPM 100/265, 76 spm @ 2040 psi, TO 15-25K. PU 310K, SO 220K, RW 270K. Torque increasing from 16,165' w/ ROP decreasing. Rotary stalling. Hole possibly out-of-gauge with NB stabilizer binding. Hole getting tight taking 50K over to free. Actual rotating time = 7.82 hrs. 10:30 - 13:30 3.00 DRILL P LNR2 Circ and cond mud. Bring mud wt. from 9.2 ppg to 9.3 ppg. 13:30 - 16:30 3.00 DRILL P LNR2 Run MAD pass with MWD tools from 16,320' MD to 15,811' MD. Pull at 300'/hr. Pmp at 242 gpm @ 1220 psi. 16:30 - 19:30 3.00 DRILL P LNR2 Cut and slip drilling line.. Cut 162' due to bad spots. 19:30 - 20:00 0.50 DRILL N WAIT LNR2 Fire Alarm in PLQ. Smoke in comm. room-no cause known yet. Muster called. 20:00 - 22:30 2.50 DRILL P LNR2 POH to top of 7" liner. Pump out from 15,811' to 14,390' (pump out sub) 22:30 - 00:00 1.50 DRILL P LNR2 Drop dart and open circ sub 180' above bit. Circulate BU X2 with circ sub at 14,380', passing a tool joint every 5 min. (no rotation) and occasionally moving the circ sub down to the liner top at 14,386'. Circ at 13 bpm at 1728 psi. 3/16/2006 00:00 - 01:30 1.50 DRILL P LNR2 Circ from circ sub above 7" liner top to clean hole. 01:30 - 02:00 0.50 DRILL P LNR2 Monitor well--static. 02:00 - 02:30 0.50 DRILL P LNR2 Pump dry job and blow do top drive and mud lines. 02:30 - 11:00 8.50 DRILL P LNR2 POH. 11:00 - 11:30 0.50 DRILL P LNR2 RU to lay do 4" DP and BHA #9. Change elevators and tong blocks for 4" DP. 11:30 - 15:30 4.00 DRILL P LNR2 LD 12 Joints Of 4" HT 40 DP. Unload RA source. Pull and check bit--under gauge. 15:30 - 16:30 1.00 DRILL P LNR2 Break bit and mud motor 16:30 - 17:30 1.00 DRILL P LNR2 PU new bit, mud motor. Download MWD. 17:30 - 20:00 2.50 DRILL P LNR2 PU BHA #10 & RIH w/ 4" DP. Shallow test PDM and MWD. Pmp 249 gpm at 1000 psi. 20:00 - 00:00 4.00 DRILL P LNR2 RIH w/ 5" DP filling every 25 stds. 3/17/2006 00:00 - 05:00 5.00 DRILL P LNR2 RIH to 7" shoe at 15,877'. Circ pipe vol. Prep to ream out-of-gauge hole. Fill pipe every 25 stands. 05:00 - 06:00 1.00 DRILL P LNR2 Circ one DP vol. to clear of air. 06:00 - 08:00 2.00 DRILL P LNR2 Ream from 15,877' to 16,320' w/ new bit. Out-of-gauge in lower section. 08:00 - 12:00 4.00 DRILL P LNR2 Dir drill from 16,320' MD to 16,398' MD / 11,243' TVD. WOB 18K, 110 RPM, TO 16K, 280 gpm @ 1750 psi. PU 310K, SO 230K, RW 270K. Actual rotating time = 3.22 hrs. 12:00 - 15:00 3.00 DRILL P LNR2 Circ BU. Lost 180 to 220 psi pmp press. Mud wt. returns 8.9 to 9.0 ppg. Flow check OK. 15:00 - 18:30 3.50 DRILL P LNR2 POH. Pump out to 7" shoe. LD 2 singles used to reach TD. 18:30 - 19:30 1.00 DRILL P LNR2 RIH to TD. Wash last stand down, 4' firm fill. 19:30 - 23:00 3.50 DRILL P LNR2 Circ. surf to surf; 9.3 ppg in/9.3 ppg out. Raised LubeTex and EMI-776 back to 4%. Conditioned wt back up w/ cal. Garb. Incr. vis to 50+. 23:00 - 00:00 1.00 DRILL P LNR2 POH to run 4.5" liner. Pump out from 16,398' to 15,877' w/ 60 spm @ 1170 psi. PU 315K, SO 230K. Occasional overpull of 15K in open hole. 3/18/2006 00:00 - 01:00 1.00 DRILL P LNR2 POH. Pump out at 60 spm @ 1170 psi. Place circ sub at 7" Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 17 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2006 00:00 - 01:00 1.00 DRILL P LNR2 liner top. 01:00 - 01:30 0.50 DRILL P LNR2 Monitor well--Static. 01:30 - 03:30 2.00 DRILL P LNR2 Cont. POH, pumping out at 60 spm @ 1150 psi. Position circ sub at 14,390' (4' below liner top). 03:30 - 05:00 1.50 DRILL P LNR2 Drop dart. Set dart and test DP to 1200 psi to ensure no washouts. Held pressure. Shear circ sub at 2300 psi. Circ BU at 12 BPM and 1660 psi. 05:00 - 05:30 0.50 DRILL P LNR2 Monitor well-static. 05:30 - 06:00 0.50 DRILL P LNR2 Pump dry job, blow do mud lines, and POH. 06:00 - 11:00 5.00 DRILL P LNR2 POH to 4" DP. Change over to 4" DP equip. 11:00 - 12:30 1.50 DRILL P LNR2 POH w/ 4" DP. Stand back 17 stands. 12:30 - 13:00 0.50 DRILL P LNR2 LD 15 jts. of 4" DP 13:00 - 15:00 2.00 DRILL P LNR2 PJSM and LD BHA #10. Clear floor. 15:00 - 17:00 2.00 DRILL P LNR2 PJSM. Slip and cut 102' of drilling line. 17:00 - 17:30 0.50 DRILL N RREP LNR2 Repair lights in derrick. 17:30 - 20:00 2.50 DRILL P LNR2 RU to run 4.5" liner. 20:00 - 22:30 2.50 DRILL P LNR2 PJSM. PU and run 15 jts. 4.5", 12.6#, 13Cr, VAM Top liner with associated float equip & cent. per plan. Torque to 4650 ft-Ibs. Fill each jt on the fly then top off every 5 jts. 22:30 - 00:00 1.50 DRILL P LNR2 PU Baker 7" X 4.5" Flex Lock liner hanger w/ tie-back sleeve. Fill w/ PAL mix. RD csg tools while PAL setting. 3/19/2006 00:00 - 00:30 0.50 CASE P LNR2 CO DP handling tools from 3 1/2" to 4". 00:30 - 01:30 1.00 CASE P LNR2 RU and pump one liner volume. 01:30 - 03:30 2.00 CASE P LNR2 RIH w/ 4" DP filling pipe on the fly and topping off each 10 stands. CO to 5" handling tools. MU 4"X5" XO. 03:30 - 14:30 11.00 CASE P LNR2 RIH w/ 5" DP to 15,830' (7" shoe at 15,877') filling on the fly and topping off each 10 stds. 14:30 - 15:30 1.00 CASE P LNR2 Stage up pumps and pump pipe vol. Final circ at 5 BPM @ 870 psi. 15:30 - 16:00 0.50 CASE P LNR2 Blow dn.top drive, mud & cmt lines. 16:00 - 17:00 1.00 CASE P LNR2 RIH to 16,398'. No fill. RU cmt head and circ hoses. 17:00 - 21:00 4.00 CASE P LNR2 Circ BU X 1.5 at 5 BPM @ 940 psi. Recip pipe 20' stroke do to 16,398'. PU 310K, SO 225K. 21:00 - 22:30 1.50 CEMT P LNR2 Pr tst. Schlumberger cmt lines to 4500 psi. OK. Batch mixed 28 bbl 15.8 ppg cmt slurry. Pmp 10 bbl CW100 wash, 22 bbl 11.3 ppg Mud Push II, 26 bbl 15.8 ppg CI G slurry. Wash up cmt lines. Release pump-down plug confirmed w/ tattle-tail. Displ cmt w/ 38 bbl viscous perf pill and drl mud. Displaced with Schlumberger pumps at 5 BPM and avg. pr. of 600 psi. Latch up with liner wiper plug after 253.6 bbls total disp. Bump plug after 262 bbl total disp! (14.6 bbl less than calc.) Pr to 2580 psi. CIP at 22:22 hrs. Full returns. Bled back 2.2 bbls and check floats, OK. 22:30 - 23:00 0.50 CEMT P LNR2 Set liner hanger and packer. TOL @ 15,728', shoe at 16,396'. Pr up to 1000 psi. PU and confirmed release at loss of pressure. 23:00 - 00:00 1.00 CEMT P LNR2 Pull out of liner top and and circ at 12 BPM at 1670 psi. Cmt returns (est. 55 bbl cmt contaminated mud). 3/20!2006 00:00 - 01:30 1.50 CEMT P LNR2 Circ at 4.5" liner top. Circ BU X 1.5 at 12 BPM and 1650 psi. 01:30 - 02:00 0.50 CEMT P LNR2 LD cementing head and one single DP. 02:00 - 06:30 4.50 CEMT P LNR2 Circ out drlg mud with 30-bbl hi-vis spacer, 635 bbls saltwater, 30-bbl hi-vis spacer, followed by 1200 bbls of 9.3 ppg clean brine. Brine returns clean at end of disp!. Circ 10-12 BPM @ Printed: 4/14/2006 11:11:52 AM BP-EXPLORATION Page 48 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT .Phase Description of Operations 3/20/2006 02:00 - 06:30 4.50 CEMT P LNR2 900 psi. 06:30 - 07:30 1.00 CEMT P LNR2 Blow do all lines and top drive. Monitor well--static. 07:30 - 09:00 1.50 CEMT P LNR2 POH, standing back 21 stands of good DP in derrick. 09:00 - 13:30 4.50 CEMT N RREP LNR2 POH laying down 5" DP singles (drill pipe management). 13:30 - 14:00 0.50 CEMT N RREP LNR2 Clear pipe shed. Adjust brakes. 14:00 - 15:00 1.00 CEMT N RREP LNR2 Cont. LD 5" DP by singles (drill pipe management) 15:00 - 00:00 9.00 CEMT N RREP LNR2 Pipe skate driver spool shaft failed. Tear dn. Acquire parts from Nabors 22E. Clean pits and prepare spud mud for NS34. 3/21/2006 00:00 - 07:30 7.50 CEMT N RREP LNR2 Repair pipe skate driver spool. Clean pits and prepare spud mud for NS34. 07:30 - 13:00 5.50 CEMT N RREP LNR2 LD 5" Drill pipe, Layed down 385 total Joints of 5" DP 13:00 - 14:30 1.50 CEMT P LNR2 C/O elevators and slips to 4" and L/D 4" DP 14:30 - 15:00 0.50 CEMT P LNR2 C/O elevators to 3.5", L/D dog sub & R/T dog sub sheared 15:00 - 16:30 1.50 CEMT P LNR2 Test well bore T/ 3500 psi for 30 minutes and blow down all lines 16:30 - 17:00 0.50 CEMT N RREP LNR2 C/O slips and elevators to P/U 5" DP 17:00 - 00:00 7.00 CEMT N RREP LNR2 P/U 5" DP "Replacement DP" 3/22/2006 00:00 - 03:30 3.50 CEMT N RREP LNR2 PU 5" Drill pipe 03:30 - 08:00 4.50 CEMT N RREP LNR2 POOH w/ 5 "Drill pipe 08:00 - 09:30 1.50 CEMT P LNR2 P/U 5" HWDP and drift 09:30 - 11:00 1.50 CEMT P LNR2 POOH w/5" HWDP "Island power down about 45 minutes" 11:00 - 12:00 1.00 CEMT P LNR2 Drain stack, pull wear ring, and clear rig floor 12:00 - 13:00 1.00 RUNCO RUNCMP RU 4.5 tubing handling equipment 13:00 - 14:30 1.50 RUNCO RUNCMP Run WLEG, and 11 Jts. of 4.5 " 12.6 # L-80 tubing Landed at 514.60' 14:30 - 16:30 2.00 RUNCO RUNCMP Land hanger in wellhead, run in LDS, test to 5000 psi for 15 min 16:30 - 20:00 3.50 RUNCO RUNCMP Change upper and lower rams to 4 1/2" X 7" variabales 20:00 - 00:00 4.00 RUNCO RUNCMP Pull riser and mouse hole N/D BOPE's 3/23/2006 00:00 - 01:30 1.50 RUNCO RUNCMP ND BOPE 01:30 - 02:30 1.00 RUNCO RUNCMP Pick BOP stack & set in storage cradle 02:30 - 03:00 0.50 RUNCO RUNCMP ND drilling spool 03:00 - 04:30 1.50 RUNCO RUNCMP NU Production Tree Test hanger seal to 5K for 10 mins. 04:30 - 06:00 1.50 RUNCO RUNCMP PJSM, RU lines to pump FP diesel 06:00 - 07:00 1.00 RUNCO RUNCMP Pressure test lines to 5K Test production tree to 5K for 10 mins. 07:00 - 07:30 0.50 RUNCO RUNCMP Pull TWC 07:30 - 08:30 1.00 RUNCO RUNCMP Reverse circulate 27 bbls Freeze Protect diesel 08:30 - 09:00 0.50 RUNCO RUNCMP Install BPV 09:00 - 10:00 1.00 RUNCO RUNCMP RD lines & prep for rig move G & I finish injection & RD injection lines Rig Released @ 10:00 Hrs on 3/23/2006 3/30/2006 12:00 - 15:00 3.00 RIGD P PRE Prep rig for move from NS-34 to NS-30 Pump out pits, blow down lines, PU stairs 15:00 - 15:30 0.50 RIGD P PRE PJSM for rig move with Nabors & BP personnel 15:30 - 16:00 0.50 MOB P PRE Lay herculite & mats for rig move after crane moved from well row 16:00 - 20:00 4.00 MOB P PRE Move rig to south 40' and shim as needed to maintain clearances over flowlines Spot rig over NS-30 Accept rig @ 20:00 Hrs on 3/30/2006 Printed: 4/14/2006 11:11:52 AM • $P EXPLORATION Page 19 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Descrjption of Operations 3/30/2006 20:00 - 22:30 2.50 RIGU P PRE Berm rig, set stairs, winterize and prepare cellar 22:30 - 23:30 .1.00 RIGU P PRE RU lines to circulate out freeze protect diesel 23:30 - 00:00 0.50 RIGU P PRE Clear rig floor of 13 3/8" casing running equipment Area on well row had been congested limiting access to rig floor 3/31/2006 00:00 - 03:00 3.00 RIGU P PRE Winterize rig Clean L-pits, Mix 9.3 ppg brine 03:00 - 04:00 1.00 WHSUR P RUNCMP Circulate out 27 bbls of FP diesel to trip tank 04:00 - 06:30 2.50 WHSUB P RUNCMP ND Tree & set on tree stand NS-29 & NS-31 Shut-in for critical lift 06:30 - 07:00 0.50 BOPSU P RUNCMP PJSM for critical lift of BOPE 07:00 - 11:00 4.00 BOPSU P RUNCMP NU ROPE, MU Choke & Kill lines Install Koomey lines & install turnbuckles Install lower riser section 11:00 - 12:00 1.00 BOPSU P RUNCMP Install upper riser section 12:00 - 14:30 2.50 BOPSU P RUNCMP Install 2 7/8" X 5" variables in top set of pipe rams. 14:30 - 15:00 0.50 BOPSU P RUNCMP Pull BPV, Install TWC 15:00 - 17:00 2.00 BOPSU P RUNCMP MU & Install test joint, unable to screw into hanger. Pull test joint and change out x-over. (swap out LH 5.875 acme thread for RH 5.875 acme thread) Run test jt and screw into hanger. 17:00 - 23:30 6.50 BOPSU P RUNCMP MU test equipment, fill stack w/ water Test ROPE per BP & AOGCC specifications AOGCC Rep Chuck Sheve waived witnessing BOPE test BOPE test witnessed by WSLs Mike Dinger & Richard Watkins Test annular preventer to 250 psi & 3500 psi All other BOPE to 250 psi & 5000 psi Choke line hose developed leak in connector during choke manifold testing Tests remaining - #2 valve on choke manifold, choke line & valves on top drive 23:30 - 00:00 0.50 BOPSU N RREP RUNCMP Blow down choke manifold & prepare to replace choke line hose 4/1/2006 00:00 - 04:00 4.00 BOPSU N RREP RUNCMP Replace choke line hose 04:00 - 05:00 1.00 BOPSU N RREP RUNCMP Fill stack & choke lines w/ water Attempt to test choke line & choke manifold valves Newly installed hose began to leak during 5000 psi test Test on last choke manifold valve completed 05:00 - 06:00 1.00 BOPSU P RUNCMP RD testjoint, RU to test IBOP & top drive valves 06:00 - 07:00 1.00 BOPSU P RUNCMP Test IBOP & top drive valves to 250 psi / 5000psi OK 07:00 - 08:00 1.00 BOPSU P RUNCMP RD test equipment, blow down top drive 08:00 - 10:00 2.00 BOPSU N RREP RUNCMP Remove leaking choke line hose 10:00 - 10:30 0.50 BOPSU P RUNCMP Service top drive 10:30 - 13:30 3.00 BOPSU N RREP RUNCMP Install new choke line hose 13:30 - 14:00 0.50 BOPSU P RUNCMP Test new choke line hose & blind rams to 250 psi / 5000 psi OK 14:00 - 14:30 0.50 RUNCO RUNCMP Pull TWC & blow down choke lines and manifold 14:30 - 18:30 4.00 RUNCO RUNCMP RU 4.5" tubing handling equipment RU landing joint, drain stack, pull hanger, LD landing joint & hanger LD 11 jts of 4.5" tubing 18:30 - 19:30 1.00 RUNCO RUNCMP Install wear bushing, RD 4.5" tubing handling equipment 19:30 - 21:00 1.50 RUNCO RUNCMP PJSM, RU equipment to PU 2 7/8" PAC DP Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 20 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 4/1/2006 21:00 - 00:00 3.00 RUNCO RUNCMP PU junk mill, mud motor, X-O sub, circulation sub, 2 - X-Os PU 40 Jts. of 2 7/8" 10.4# S-135 PAC DP 4/2/2006 00:00 - 00:30 0.50 RUNCO RUNCMP PU 25 jts of 2 7/8" DP, Total 2 7/8" DP 65 Jts - 2025.08' 00:30 - 01:30 1.00 RUNCO RUNCMP RD 2 7/8" DP handling equipment RU 5" DP handling equipment 01:30 - 02:00 0.50 RUNCO RUNCMP Circulate through motor & 2 7/8" DP Pump rate 147 GPM @ 425 psi 02:00 - 03:00 1.00 RUNCO RUNCMP Daylight Saving Time 03:00 - 06:00 3.00 RUNCO RUNCMP PU 75 jts of5" DP 06:00 - 13:00 7.00 RUNCO RUNCMP TIH w/ 5" DP to 15,900' 13:00 - 14:30 1.50 RUNCO RUNCMP Wash down from 15,900' to 16,310' Pump rate 110 GPM @ 895 psi String did not take more than 2K of weight or show pump pressure increase while washing down until tagging landing collar @ 16,310' 14:30 - 22:00 7.50 RUNCO RUNCMP Circulate 9.3 ppg brine @ 110 GPM Drop ball to shear circulation sub, tool did not open Pump 30 bbl High Vis sweep & circulate btms up Circulate out very fine solids Drop 2nd ball to open circulation sub, tool did not open Circulate surface to bit, even sea water throughout wellbore Sea water returns turbidity test - 69 NTU 22:00 - 00:00 2.00 RUNCO RUNCMP TOH w/ 5" DP 4/3/2006 00:00 - 05:30 5.50 RUNCO RUNCMP TOH w/ 5" DP, Break out X-Os 05:30 - 06:30 1.00 RUNCO RUNCMP RD 5" DP handling equipment RU 2 7/8" DP handling equipment 06:30 - 10:30 4.00 RUNCO RUNCMP LD 65 jts of 2 7/8" DP, circulation sub, motor, mill. Circ sub sheared 10:30 - 11:30 1.00 RUNCO RUNCMP RD 2 7/8" DP handling equipment. 11:30 - 12:00 0.50 RUNCO RUNCMP Clear rig floor of Baker tools Transport wireline tools & equipment to rig floor 12:00 - 13:30 1.50 RUNCO RUNCMP PJSM, RU Schlumberger wireline equipment 13:30 - 23:30 10.00 RUNCO RUNCMP RIH w/ 6.05 gauge ring & junk basket to 15,734' WLM, recovered 1 cup of fine solids RIH w/ 2.875" Dummy perforating gun, set down @ 16,245' Run SCMT, GR & CCL, set down @ 16,245' Log f/ 16245' to 14,367' 23:30 - 00:00 0.50 RUNCO RUNCMP PJSM, R/U to cut drilling line 4/4/2006 00:00 - 02:00 2.00 RUNCO RUNCMP Slip and cut 206' of drilling line. 02:00 - 02:30 0.50 RUNCO RUNCMP Pull wear bushing. 02:30 - 05:00 2.50 RUNCO RUNCMP Change bales. RU tubing tongs, compensator, and handling tools. 05:00 - 07:00 2.00 RUNCO RUNCMP PJSM. Spot Weatherford fiber optic unit. PU fiber optic sheaves and hang in derrick 07:00 - 08:30 1.50 RUNCO RUNCMP PJSM. PU 4 1/2" completion equipment, packer, and CIDRA mandrel. 08:30 - 09:30 1.00 RUNCO RUNCMP MU fiber optic line to CIDRA mandrel and press. tst. to 7500 psi, OK. 09:30 - 00:00 14.50 RUNCO RUNCMP PU 4 1/2", 12.6#, 13CR80, VAM Top completion string and RIH. Torque Turn each connection to 4440 ft-Ibs. As of 00:00, 160 jts run (6807') 4/5/2006 00:00 - 15:00 15.00 RUNCO RUNCMP Continue running 4 1/2", 12.6#, 13CR80, VAM Top completion string. Printed: 4/14/2006 11:11:52 AM BP EXPLORATION Page 21' of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From = To Hours Task Code NPT Phase Description of Operations 4/5/2006 15:00 - 16:00 1.00 RUNCO RUNCMP MU sub-surface safety valve mandrel. RU to run control line & test to 6000 psi for 15 minutes, OK. 16:00 - 17:00 1.00 RUNCO RUNCMP Continue to RIH w/ 4 1/2" VAM Top tubing. 17:00 - 20:30 3.50 RUNCO RUNCMP Stab into liner tie-back extension. Space out 4 1/2" tubing on downstroke approx. 5' above bottom of tie-back (6' inside). Repeat sequence to confirm. LD last 3 jts of 4 1/2" tbg after spacing out and replace w! 3 Jts. of 5 1/2" X 4 1/2" VIT insulated tubing. MU tubing hanger. PU 220K, SO 155K prior to stabbing into tie-back. Total of 369 jts of 4 1/2" Vam Top 12.6# 13CR80 tubing ran, 3 jts of 4 1/2" x 5 1/2" vacuum insulated tubing. No space out pups required. 20:30 - 22:00 1.50 RUNCO RUNCMP Splice CIDRA fiber optic line & SSSV control line to hanger and land hanger. Test to 5000 psi for 10 minutes, Good test. 22:00 - 00:00 2.00 RUNCO RUNCMP PJSM. RU Schlumberger slickline. RIH w/ PDS CCL memory log. 4/6/2006 00:00 - 06:00 6.00 RUNCO RUNCMP -Run CCL memory log from 16250' to 15,600'. Wireline pickup at 16,250' WLM. Reviewed PDS CCL for proper space out WLEG is 4' above bottom of tie back extention. Running D-16 plug. 06:00 - 08:00 2.00 RUNCO RUNCMP - R/U running tool and D-16 plug , RIH w/ same. 08:00 - 10:00 2.00 RUNCO DPRB RUNCMP -Attempt to set D-16 plug w/o success, POOH w/ same. 10:00 - 14:00 4.00 RUNCO DPRB RUNCMP -POOH w/ slickline and D-16 plug. Visual inspection of spang jars showed layer of pipe dope which would not allow spang jars to function properly while trying to set plug in X nipple. 14:00 - 20:30 6.50 RUNCO DPRB RUNCMP -Discuss options with Anchorage team. - Mobilize tools for pumping while RIH w/ slick line tools. RIH w/ 3.5" gauge ring & brush to 16243'. Pump 3 BPM, 140 psi while RIH. 20:30 - 00:00 3.50 RUNCO DPRB RUNCMP -POOH with slickline and M/U D-16 plug. 4/7/2006 00:00 - 02:00 2.00 RUNCO RUNCMP -Test 4 1/2" tubing to 4200 psi for 10 minutes, "Good test" 02:00 - 04:30 2.50 RUNCO RUNCMP -RIH and retrieve Equalizing plug out of D-plug. 04:30 - 06:00 1.50 RUNCO RUNCMP -RIH and retrieve D-Plug. 06:00 - 08:30 2.50 RUNCO RUNCMP -POOH with slickline and D-16 plug. 08:30 - 11:00 2.50 RUNCO RUNCMP -RIH w/ RHC plug on slickline. 11:00 - 11:30 0.50 RUNCO RUNCMP -Pump down on RHC, 20 SPM @ 100 PSI. 11:30 - 14:00 2.50 RUNCO RUNCMP -Continue to RIH w/ RHC plug and set @ 15,640' 14:00 - 15:30 1.50 RUNCO RUNCMP -POOH R/D slickline & R/U to reverse circulate. 15:30 - 19:30 4.00 RUNCO RUNCMP -PJSM, Reverse circulate annular volume of sea water with 25 gal of EC1124A, & 25 gal of 01 VD121 per 100 bbl of sea water. Inhibited sea water is between packer and GLM. 19:30 - 21:30 2.00 RUNCO RUNCMP -Dropped 1 7/8" ball & rod, pressured up and set packer. Test tubing to 4200 psi for 30 min. Bleed off pressure on tubing & test annulus to 1000 PSI for 5 min. "Good test" B/D lines and R/D testing equipment. 21:30 - 22:30 1.00 RUNCO RUNCMP -PJSM, R/D Weatherfords & Halliburtons sheaves, pull and L/D landing joint. Set TWC. 22:30 - 00:00 1.50 BOPSU P RUNCMP - N/D BOPE. 4/8/2006 00:00 - 05:30 5.50 BOPSU P RUNCMP - N/D BOPE's 05:30 - 09:30 4.00 BOPSU P RUNCMP -Make final fiber optics & control line tie ins to surface equipment from wellhead. test control lines T/ 6000 psi for 10 minutes. R/U for freeze protect and service draw works. Printed: 4/14/2006 11:11:52 AM • • BP EXPLORATION 'Page 22 of 22 Operations .Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2006 09:30 - 11:30 2.00 BOPSU P RUNCMP N/U tree 11:30 - 13:30 2.00 WHSUR P RUNCMP Test Vetco tree and void area to 5000 psi for 10 minutes, "Good Test" R/U line to tree for U-tube & test lines to 4000 psi Pull TWC 13:30 - 15:30 2.00 WHSUR P RUNCMP PJSM, pump down tubing & increase pressure to 2700 psi. Pump down annulus with pressure on tubing and test IA to 4200 psi. Hold test for 30 minutes. Bleed pressure off annulus, then tubing. Pump down annulus & shear valve in GLM 2300 PSI. Pump 2 bbl through tubing & annulus to verify good shear. Close TRSV & pump down annulus & test TRSV to 1000 psi for 10 minutes. 15:30 - 19:30 4.00 WHSUR P RUNCMP PJSM, pressure test lines and freeze protect. Pump 266 bbls 65 degree diesel down IA & U-tube to balance point. 19:30 - 21:00 1.50 RUNCO RUNCMP B/D & R/D lines & secure cellar for rig move. Release rig @ 21:00 hours. Printed: 4/14/2006 11:11:52 AM • • Well: NS30 Accept: 02/04/06 Field: Northstar Unit Spud: 02/05/06 API: 50-029-23293-00-00 Release: 04/08/06 Permit: 205-207 Rig: Nabors 33E POST-RIG WORK 04/12/06 PULLED BALL & ROD. RIH W/4.5 OM1 KOT TO STA # 1 04/13/06 PULLED 1.5 SHEAR VALVE FROM STA # 1. SET 1.5 DGLV IN STA # 1 @ 6647' SLM. PULLED RHC PLUG BODY. BAIL FILL DOWN TO 16,226'SLM + 9' CORRECTION = 16,235' MD. 04/14/06 (PERF #1) RIH W/HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 31', MAX OD = 2.88" CCL TO TOP SHOT = 3.3' /TIE-IN TO ANNOTATED SLB SCMT LOG DATED 3-APR-06 (WILL BE USED FOR ALL PERF RUNS). LOG INTO POSITION & PERFORATE INTERVAL (16204' - 16224') /GOOD INDICATION GUNS FIRED /POOH (PERF #2) RIH W/ HEAD, ERS, UPCT, 10' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 18.3', MAX OD = 2.88". LOG INTO POSITION & PERFORATE INTERVAL (16184' - 16194') /GOOD INDICATION GUNS FIRED /POOH. 04/15/06 CCL TO TOP SHOT = 3.3' /TIE-INTO ANNOTATED SLB SCMT LOG DATED 3-APR-06 (WILL BE USED FOR ALL PERF RUNS), (PERF #3) RIH W/ HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 30.3', MAX OD = 2.88" LOG INTO POSITION & PERFORATE INTERVAL (16152' -16172') /GOOD INDICATION GUNS FIRED /POOH. (PERF #4) RIH W/ HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 30.3', MAX OD = 2.88" LOG INTO POSITION & PERFORATE INTERVAL (16132' - 16152') /GOOD INDICATION GUNS FIRED /POOH. (PERF #5) RiH W/ HEAD, ERS, UPCT, 20'-2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN, TOTAL LENGTH= 30.3',MAX OD=2.88"LOG INTO POSITION & PERFORATE INTERVAL (16,112' -16,132') /GOOD INDICATION GUNS FIRED /POOH. by Client: Field: Structure 1 Slot: Well: Borehole: uwuapla: Survey Name 1 Date: Tort I AHD 1 DDI I ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid NIE YIX: Grid Convergence Angle: NS30 Su BP Exploration Alaska Northstar Northstar PF / NS30 NS30 NS30 50029232930( NS301 February 18, 200E 180.446° 111170.93 ft / 6.468 / 0.99 NAD27 Alaska State Planes, Zone 04, US Fee N 70 29 29.550, W 148 41 36.00: N 6031111.310 ftUS, E 659822.490 ftU: +1.23167644° Resort Schlumberger Vertical Section Azimuth: 97.010° Vertical Section Origin: N 0.000 ft, E 0.000 fl TVD Reference Datum: Rotary Table TVD Reference Elevation: 56.27 ft relative to MSL Sea Bed 1 Ground Level Elevation: 15.67 ft relative to MSL Magnetic Declination: 24.716° Total Field Strength: 57616.109 nT Magnetic Dip: 81.021 ° Declination Date: February 09, 200E Magnetic Declination Model: BGGM 2005 North Reference: Tale North Total Corr Mag North •> True North: +24.716° Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS K I t U.uU U.UU U.UU -5ti.L/ U.UU U.UU U.UU U.UU U.UU U.UU U.UU 6031111.31 ti59t3Zl.49 N 70 29 29.550 W 148 41 36.005 GYD GC SS 50.00 0.56 191.65 -6.27 50.00 -0.02 0.24 0.24 -0.24 -0.05 1.12 6031111.07 659822.45 N 70 29 29.548 W 148 41 36.006 100.00 0.69 175.85 43.73 100.00 0.02 0.79 0.78 -0.78 -0.08 0.43 6031110.53 659822.43 N 70 29 29.542 W 148 41 36.007 150.00 0.96 191.17 93.72 149.99 0.05 1.50 1.50 -1.49 -0.14 0.69 6031109.82 659822.39 N 70 29 29.535 W 148 41 36.009 200.00 0.99 176.52 143.71 199.98 0.09 2.35 2.34 -2.33 -0.19 0.50 6031108.97 659822.35 N 70 29 29.527 W 148 41 36.010 250.00 1.77 132.78 193.70 249.97 0.80 3.50 3.31 -3.29 0.40 2.51 6031108.03 659822.96 N 70 29 29.518 W 148 41 35.993 300.00 2.63 117.10 243.66 299.93 2.50 5.41 4.77 -4.33 1.99 2.08 6031107.02 659824,57 N 70 29 29.507 W 148 41 35.946 354.00 3.45 105.80 297.59 353.86 5.27 8.26 7.09 -5.34 4.66 1.87 6031106.07 659827.26 N 70 29 29.497 W 148 41 35.868 400.00 3.61 100.53 343.50 399.77 8.09 11.09 9.53 -5.98 7.41 0.79 6031105.49 659830.03 N 70 29 29.491 W 148 41 35.787 450.00 4.36 101.38 393.38 449.65 11.55 14.57 12.70 -6.65 10.82 1.50 6031104.90 659833.45 N 70 29 29.485 W 148 41 35.686 500.00 5.10 96.49 443.21 499.48 15.67 18.69 16.57 -7.27 14.89 1.68 6031104.36 659837.54 N 70 29 29.478 W 148 41 35.566 550.00 6.28 90.58 492.96 549.23 20.61 23.64 21.23 -7.55 19.84 2.63 6031104.19 659842.48 N 70 29 29.476 W 148 41 600.00 7.89 88.59 542.58 598.85 26.72 29.81 27.06 -7.49 26.00 3.26 6031104.38 659848.65 N 70 29 29.476 W 148 41 650.00 9.46 86.89 592.00 648.27 34.16 37.35 34.30 -7.19 33.54 3.18 6031104.85 659856.17 N 70 29 29.479 W 148 41 35.018 715.00 11.85 85.46 655.88 712.15 45.96 49.36 45.97 -6.37 45.53 3.70 6031105.92 659868.14 N 70 29 29.487 W 148 41 34.665 806.00 14.03 86.64 744.56 800.83 65.97 69.74 66.04 -4.98 65.85 2.41 6031107.74 659888.43 N 70 29 29.501 W 148 41 34.067 900.00 15.75 89.84 835.41 891.68 89.84 93.89 90.09 -4.28 89.99 2.03 6031108.97 659912.54 N 70 29 29.508 W 148 41 33.357 996.00 16.43 94.71 927.65 983.92 116.33 120.48 116.67 -5.36 116.55 1.57 6031108.46 659939.12 N 70 29 29.497 W 148 41 32.575 Last GYD GC SS 1089.00 18.63 95.40 1016.32 1072.59 144.33 148.49 144.66 -7.84 144.45 2.38 6031106.58 659967.06 N 70 29 29.473 W 148 41 31.754 MWD+IFR 1213.93 25.38 100.03 1132.09 1188.36 191.07 195.25 191.28 -14.38 190.74 5.57 6031101.03 660013.48 N 70 29 29.408 W 148 41 30.392 MWD+IFR 1309.09 24.68 99.95 1218.32 1274.59 231.27 235.51 231.38 -21.37 230.39 0.74 6031094.90 660053.27 N 70 29 29.340 W 148 41 29.225 First MWD+IFR+MS 1400.85 24.90 100.82 1301.62 1357.89 269.68 273.98 269.72 -28.31 268.23 0.46 6031088.78 660091.25 N 70 29 29.272 W 148 41 28.111 1496.11 26.36 99.68 1387.51 1443.78 310.82 315.19 310.83 -35.63 308.78 1.62 6031082.33 660131.94 N 70 29 29.200 W 148 41 26.918 1590.25 30.30 96.30 1470.36 1526.63 355.46 359.84 355.46 -41.75 353.00 4.52 6031077.16 660176.28 N 70 29 29.139 W 148 41 25.617 1686.98 34.35 95.68 1552.08 1608.35 407.16 4 i 1.56 407.17 -47.13 404.44 4.20 6031072.89 660227.82 N 70 29 29.086 W 148 41 24.103 SurveyEditor Ver SP 1.0 Bld( doc40x_56) NS30\NS30\NS30\NS30 Generated 5/5/2006 7:37 AM Page 1 of 5 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d de ft ft ft ft ft ft ft de 100 ft ftUS ftUS l/tfU.;iL ;iy.U4 ytS.1li ltiLEi.`Jl llitS:S.ltf 4til.yl 4fi/.Sl 4ti1.yL -SJ.yEi 45y.// 5.Ly liU3lUti/.14 lilSU'LiS:i.Ltf N /ULyLy.Uly W 7425 47 1"1.4/5 1875.35 43.02 99.39 1698.58 1754.85 525.25 529.68 525.25 -63.56 521.39 4.26 6031058.98 660345.09 N 70 29 28.925 W 148 41 20.662 1969.60 46.02 99.68 1765.78 1822.05 591.26 595.76 591.27 -74.51 586.55 3.19 6031049.43 660410.47 N 70 29 28.817 W 148 41 18.744 2064.27 49.95 99.79 1829.13 1885.40 661.51 666.08 661.53 -86.40 655.86 4.15 6031039.03 660480.01 N 70 29 28.700 W 148 41 16.704 2158.50 53.25 100.32 1887.65 1943.92 735.24 739.92 735.30 -99.30 728.57 3.53 6031027.70 660552.97 N 70 29 28.573 W 148 41 14.565 2251.45 53.30 100.23 1943.23 1999.50 809.62 814.42 809.74 -112.59 801.87 0.09 6031015.99 660626.54 N 70 29 28.442 W 148 41 12.408 2348.78 52.69 100.03 2001.82 2058.09 887.23 892.14 887.41 -126.26 878.39 0.65 6031003.97 660703.32 N 70 29 28.308 W 148 41 10.156 2441.92 55.63 100.01 2056.35 2112.62 962.62 967.64 962.87 -139.39 952.73 3.16 6030992.44 660777.93 N 70 29 28.178 W 148 4 1 7.969 2536.00 54.44 101.15 2110.26 2166.53 1039.57 1044.73 1039.91 -153.54 1028.52 1.61 6030979.92 660853.99 N 70 29 28.039 W 148 4 1 5.739 2631.93 55.38 99.95 2165.41 2221.68 1117.91 1123.23 1118.36 -167.91 1105.68 1.42 6030967.22 660931.44 N 70 29 27.898 W 148 4 1 3.468 2726.75 55.18 100.27 2219.41 2275.68 1195.73 1201.16 1196.27 -181.59 1182.41 0.35 6030955.19 661008.44 N 70 29 27.763 W 148 41 1 0 2821.26 55.79 98.08 2272.97 2329.24 1273.54 1279.03 1274.13 -194.00 1259.28 2.02 6030944.43 661085.56 N 70 29 27.641 W 148 40 2917.25 55.65 98.00 2327.04 2383.31 1352.84 1358.35 1353.44 -205.10 1337.81 0.16 6030935.03 661164.31 N 70 29 27.532 W 148 40 3011.89 55.82 98.15 2380.32 2436.59 1431.05 1436.57 1431.65 -216.08 1415.25 0.22 6030925.71 661241.96 N 70 29 27.424 W 148 40 54.358 3106.00 54.01 97.15 2434.41 2490.68 1508.05 1513.57 1508.65 -226.34 1491.57 2.11 6030917.10 661318.47 N 70 29 27.322 W 148 40 52.113 3201.11 53.64 97.43 2490.55 2546.82 1584.82 1590.35 1585.40 -236.08 1567.73 0.46 6030909.00 661394.81 N 70 29 27.227 W 148 40 49.872 3296.62 55.59 97.55 2545.85 2602.12 1662.68 1668.21 1663.25 -246.23 1644.93 2.04 6030900.51 661472.21 N 70 29 27.127 W 148 40 47.600 3390.27 57.48 97.70 2597.49 2653.76 1740.80 1746.33 1741.37 -256.60 1722.36 2.02 6030891.81 661549.84 N 70 29 27.024 W 148 40 45.322 3484.28 56.72 96.77 2648.56 2704.83 1819.73 1825.26 1820.28 -266.54 1800.66 1.16 6030883.55 661628.33 N 70 29 26.926 W 148 40 43.018 3576.79 56.58 95.92 2699.42 2755.69 1897.00 1902.54 1897.51 -275.08 1877.46 0.78 6030876.66 661705.29 N 70 29 26.842 W 148 40 40.758 3674.03 54.45 96.36 2754.47 2810.74 1977.14 1982.69 1977.60 -283.65 1957.15 2.22 6030869.81 661785.14 N 70 29 26.758 W 148 40 38.413 3769.16 55.59 97.19 2809.01 2865.28 2055.08 2060.63 2055.51 -292.85 2034.55 1.40 6030862.28 661862.71 N 70 29 26.667 W 148 40 36.135 3862.93 56.69 97.48 2861.25 2917.52 2132.94 2138.49 2133.37 -302.79 2111.77 1.20 6030854.00 661940.13 N 70 29 26.569 W 148 40 33.863 3958.91 56.90 98.09 2913.81 2970.08 2213.24 2218.80 2213.68 -313.67 2191.34 0.58 6030844.83 662019.91 N 70 29 26.462 W 148 40 31.521 4053.53 54.49 97.46 2967.14 3023.41 2291.39 2296.96 2291.83 -324.25 2268.78 2.61 6030835.92 662097.55 N 70 29 26.358 W 148 40 29.243 4147.82 52.56 97.08 3023.19 3079.46 2367.20 2372.77 2367.64 -333.85 2343.98 2.07 6030827.94 662172.94 N 70 29 26.263 W 148 40 27.030 4243.18 53.79 95.71 3080.34 3136.61 2443.53 2449.10 2443.93 -342.34 2419.84 1.73 6030821.08 662248.95 N 70 29 26.179 W 148 40 24.798 4339.07 54.31 96.65 3136.64 3192.91 2521.14 2526.73 2521.52 -350.70 2497.01 0.96 6030814.38 662326.28 N 70 29 26.097 W 148 40 22.527 4392.28 53.53 96.76 3167.98 3224.25 2564.15 2569.73 2564.51 -355.72 2539.72 1.48 6030810.28 662369.08 N 70 29 26.047 W 148 40 21.270 4458.86 53.12 96.76 3207.74 3264.01 2617.55 2623.13 2617.90 -362.01 2592.75 0.62 6030805.14 662422.23 N 70 29 25.985 W 148 40 4552.75 54.04 97.55 3263.49 3319.76 2693.10 2698.68 2693.44 -371.42 2667.71 1.19 6030797.34 662497.37 N 70 29 25.892 W 148 40 4648.63 54.61 97.42 3319.40 3375.67 2770.98 2776.57 2771.32 -381.57 2744.93 0.60 6030788.86 662574.79 N 70 29 25.792 W 148 40 15.232 4741.88 54.29 97.01 3373.62 3429.89 2846.85 2852.44 2847.19 -391.10 2820.20 0.50 6030780.95 662650.24 N 70 29 25.698 W 148 40 13.017 4835.78 55.53 96.80 3427.60 3483.87 2923.68 2929.27 2924.01 -400.33 2896.47 1.33 6030773.36 662726.69 N 70 29 25.607 W 148 4010.773 4929.16 56.32 96.88 3479.91 3536.18 3001.03 3006.62 3001.34 -409.54 2973.27 0.85 6030765.80 662803.66 N 70 29 25.516 W 148 40 8.513 5021.99 56.40 96.95 3531.34 3587.61 3078.31 3083.90 3078.62 -418.85 3049.99 0.11 6030758.14 662880.56 N 70 29 25.425 W 148 40 6.256 5119.36 56.56 97.63 3585.11 3641.38 3159.49 3165.08 3159.79 -429.15 3130.51 0.60 6030749.58 662961.27 N 70 29 25.323 W 148 40 3.887 5213.81 56.68 97.56 3637.08 3693.35 3238.35 3243.95 3238.66 -439.57 3208.69 0.14 6030740.84 663039.65 N 70 29 25.220 W 148 40 1.586 5308.72 56.56 98.25 3689.30 3745.57 3317.59 3323.20 3317.91 -450.47 3287.19 0.62 6030731.63 663118.36 N 70 29 25.113 W 148 39 59.276 5405.07 56.33 98.66 3742.55 3798.82 3397.86 3403.49 3398.20 -462.28 3366.61 0.43 6030721.53 663198.01 N 70 29 24.996 W 148 39 56.940 5500.92 55.80 98.77 3796.06 3852.33 3477.35 3483.02 3477.71 -474.33 3445.22 0.56 6030711.18 663276.85 N 70 29 24.877 W 148 39 54.627 5594.45 55.37 98.92 3848.92 3905.19 3554.47 3560.18 3554.86 -486.19 3521.46 0.48 6030700.96 663353.33 N 70 29 24.760 W 148 39 52.383 5687.92 55.33 98.15 3902.07 3958.34 3631.33 3637.07 3631.75 -497.60 3597.50 0.68 6030691.18 663429.59 N 70 29 24.648 W 148 39 50.146 5784.53 55.90 98.36 3956.63 4012.90 3711.04 3716.80 3711.47 -509.05 3676.40 0.62 6030681.43 663508.71 N 70 29 24.535 W 148 39 47.824 SurveyEditor Ver SP 1.0 Bld( doc4Ox_ 56) NS3O\NS3O\NS3O\NS3O Generated 5/5/2006 7:37 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 5t3 /t3.1 U 55.5t3 5t3.:SU 5970.90 55.72 98.65 6064.46 55.68 98.14 6158.69 55.92 97.87 6254.33 56.03 97.98 6349.96 56.01 97.53 6445.02 56.14 97.63 6541.38 55.56 97.74 6636.58 54.97 97.88 6733.67 54.86 97.22 6827.25 54.73 97.24 6923.99 54.87 97.31 7019.02 54.96 96.83 7112.45 54.94 96.88 7208.03 54.50 97.31 7303.43 54.27 96.78 7398.96 54.22 97.15 7494.21 54.10 97.83 7589.48 54.49 99.16 7682.33 54.83 98.77 7778.45 54.70 99.31 7872.90 54.96 99.44 7968.10 55.08 99.40 8063.18 55.19 98.41 8157.78 55.32 98.07 8250.74 55.30 97.05 4UU5.U:S 4U1i5.:SU :3/t3tS.54 4061.12 4117.39 3865.31 4113.85 4170.12 3942.58 4166.81 4223.08 4020.50 4220.33 4276.60 4099.76 4273.78 4330.05 4179.05 4326.83 4383.10 4257.93 4380.92 4437.19 4337.67 4435.17 4491.44 4415.89 4490.97 4547.24 4495.34 4544.92 4601.19 4571.80 4600.69 4656.96 4650.85 4655.31 4711.58 4728.61 4708.97 4765.24 4805.10 4764.17 4820.44 4883.12 4819.73 4876.00 4960.68 4875.55 4931.82 5038.20 4931.32 4987.59 5115.41 4986.92 5043.19 5192.75 5040.63 5096.90 5268.44 5096.08 5152.35 5346.90 :i/54.57 :S/t3t3.55 -5LU.LtS 3/5:3.1U 3871.11 3865.78 -531.60 3829.06 3948.40 3943.07 -542.88 3905.52 4026.34 4021.01 -553.74 3982.70 4105.60 4100.27 -564.67 4061.20 4184.90 4179.57 -575.37 4139.78 4263.78 4258.45 -585.77 4217.97 4343.53 4338.19 -596.43 4297.00 4421.76 4416.43 -607.07 4374.50 4501.21 4495.87 -617.50 4453.26 4577.67 4572.33 -627.13 4529.12 4656.72 4651.38 -637.14 4607.53 4734.49 4729.13 -646.71 4684.71 4810.97 4805.61 -655.84 4760.64 4889.00 4883.63 -665.47 4838.07 4966.55 4961.17 -674.99 4915.04 U.'IU tiU:iUti/1.135 titi:35tf5.1i3 N /U Z514.4Z4 W 1413 35 45.5(it3 0.42 6030662.17 0.45 6030652.54 0.35 6030643.34 0.15 6030634.11 0.39 6030625.10 0.16 6030616.38 0.61 6030607.41 0.63 6030598.45 0.57 6030589.71 0.14 6030581.72 0.16 6030573.40 0.42 6030565.49 0.05 6030557.99 0.59 6030550.03 0.51 6030542.17 663661.81 663738.49 663815.88 663894.60 663973.38 664051.77 664131.00 664208.71 664287.67 664363.71 664442.32 664519.67 664595.78 664673.40 664750.55 664827.68 664904.43 664981.16 665056.20 665133.98 N 70 29 24.312 W 148 39 43.333 N 70 29 24.201 W 148 39 41.083 N 70 29 24.094 W 148 39 38.812 N 70 29 23.986 W 148 39 36.502 N 70 29 23.880 W 148 39 34.190 N 70 29 23.777 W 148 39 31.890 N 70 29 23.672 W 148 39 29.565 N 70 29 23.567 W 148 39 27.284 N 70 29 23.464 W 148 39 24.967 N 70 29 23.369 W 148 39 N 70 29 23.270 W 148 39 N 70 29 23.175 W 148 3918.157 N 70 29 23.085 W 148 3915.923 N 70 29 22.990 W 148 3913.645 N 70 29 22.896 W 148 3911.380 N 70 29 22.803 W 148 39 9.116 N 70 29 22.703 W 148 39 6.863 N 70 29 22.590 W 148 39 4.612 N 70 29 22.474 W 148 39 2.411 N 70 29 22.352 W 148 39 0.130 5044.08 5038.69 -684.39 4991.99 0.32 6030534. 43 5121.29 5115.90 -694.45 5068.55 0.59 6030526. 01 5198.65 5193.26 -705.88 5145.06 1.21 6030516. 23 5274.39 5268.98 -717.68 5219.88 0.50 6030506. 04 5352.90 5347.47 -730.02 5297.41 0.48 6030495. 37 5150.48 5206. 75 5424.05 5430.11 5424.65 -742.60 5373.59 5205.06 5261. 33 5501.98 5508.11 5502. 63 -755.36 5450.54 5259.41 5315. 68 5579.95 5586.13 5580. 63 -767.44 5527.61 5313.33 5369. 60 5657.66 5663.86 5658. 36 -778.58 5604.54 5366.24 5422. 51 5734.09 5740.29 5734. 79 -788.64 5680.31 8345.14 55.17 96.27 5420.07 5476.34 5811.64 8440.47 54.81 97.04 5474.76 5531.03 5889.72 8532.32 54.78 96.85 5527.71 5583.98 5964.77 8626.31 54.69 96.60 5581.98 5638.25 6041.51 8721.11 54.73 94.93 5636.75 5693.02 6118.87 8814.99 54.79 94.31 5690.92 5747.19 6195.47 8909.90 55.05 93.60 5745.46 5801.73 6273.03 9001.75 55.02 93.48 5798.10 5854.37 6348.17 9098.26 55.36 93.41 5853.19 5909.46 6427.25 9190.82 55.50 94.31 5905.71 5961.98 6503.35 9287.78 55.51 94.37 5960.63 6016.90 6583.18 9383.56 55.32 94.24 6014.99 6071.26 6661.94 9477.95 55.10 93.55 6068.85 6125.12 6739.35 9574.37 54.75 94.15 6124.26 6180.53 6818.14 9667.45 54.69 93.85 6178.02 6234.29 6894.02 9760.64 54.43 93.17 6232.06 6288.33 6969.80 9857.12 54.09 93.04 6288.41 6344.68 7047.93 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) 5817.84 5812.32 5895.92 5890.38 5970.97 5965.42 6047.71 6042.15 6125.09 6119.48 6201.77 6196.03 6279.44 6273.53 6354.71 6348.60 6433.95 6427.63 6510.16 6503.68 6590.08 6583.47 6668.93 6662.20 6746.45 6739.56 6825.36 6818.31 6901.34 6894.17 6977.27 6969.92 7055.58 7048.01 NS30\NS30\NS30\NS30 -797.63 -806.68 -815.75 -824.74 -832.51 -838.69 -844.04 -848.69 -853.45 -858.58 -864.63 -870.55 -875.82 -881.11 -886.41 -891.06 -895.31 5757.33 5834.89 5909.39 5985.60 6062.58 6139.01 6216.49 6291.62 6370.72 6446.76 6526.44 6605.07 6682.41 6761.14 6836.94 6912.72 6990.92 0.30 6030484.44 0.13 6030473.33 0.86 6030462.91 0.33 6030453.43 0.90 6030445.00 0.69 6030437.67 0.76 6030430.29 0.17 6030422.82 0.24 6030415.47 1.44 6030409.36 0.54 6030404.83 0.67 6030401.14 0.11 6030398.11 0.36 6030395.05 0.81 6030391.55 0.05 6030387.22 0.23 6030382.99 0.64 6030379.39 0.63 6030375.79 0.27 6030372.12 0.66 6030369.10 0.37 6030366.54 665210.40 665287.61 665364.91 665442.06 665518.02 665595.22 665672.94 665747.61 665824.00 665901.12 665977.66 666055.23 666130.44 666209.61 666285.74 666365.53 666444.27 666521.69 666600.52 666676.41 666752.26 666830.53 N 70 29 22.228 W 148 38 57.889 N 70 29 22.102 W 148 38 55.625 N 70 29 21.982 W 148 38 53.357 N 70 29 21.872 W 148 38 51.094 N 70 29 21.773 W 148 38 48.865 N 70 29 21.684 W 148 38 46.598 N 70 29 21.594 W 148 3844.317 N 70 29 21.504 W 148 38 N 70 29 21.415 W 148 38 N 70 29 21.338 W 148 38 N 70 29 21.277 W 148 38 35.369 N 70 29 21.224 W 148 38 33.089 N 70 29 21.177 W 148 38 30.879 N 70 29 21.130 W 148 38 28.551 N 70 29 21.079 W 148 38 26.314 N 70 29 21.018 W 148 38 23.970 N 70 29 20.960 W 148 38 21.656 N 70 29 20.907 W 148 3819.381 N 70 29 20.854 W 148 3817.064 N 70 29 20.801 W 148 3814.834 N 70 29 20.755 W 148 3812.604 N 70 29 20.713 W 148 3810.304 Generated 5/5!2006 7:37 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting latitude Longitude Depth Section Departure ft de de ft ft ft ft ft k ft de 1100 ft ftUS ftUS 7J.7 I.J.7 .7Y.VJ ~J.IW OJ4J./L 10046.42 53.96 93.67 6399.60 10142.30 54.30 93.46 6455.79 10238.28 55.25 92.83 6511.15 10332.20 55.96 93.05 6564.20 10426.23 55.61 92.57 6617.07 10522.10 54.92 92.57 6671.70 10617.53 53.89 91.39 6727.24 10713.34 53.31 92.35 6784.10 10806.34 52.96 93.19 6839.89 10901.68 52.92 93.59 6897.35 10993.53 52.85 94.68 6952.78 11089.91 52.95 95.13 7010.91 11184.42 53.03 95.66 7067.80 11277.56 53.52 96.67 7123.50 11372.03 53.78 96.06 7179.49 11468.95 53.44 95.90 7236.99 11562.89 53.16 96.40 7293.14 11658.17 52.82 96.03 7350.49 11753.29 52.43 95.57 7408.23 11849.05 51.89 96.55 7466.98 11943.54 51.21 97.73 7525.73 12039.87 50.11 98.60 7586.80 12135.00 49.29 98.71 7648.33 12230.60 48.23 99.33 7711.35 12324.63 46.88 99.81 7774.81 12418.16 45.64 99.65 7839.47 12511.87 44.51 98.85 7905.65 12606.92 43.64 98.18 7973.93 12702.59 42.45 97.73 8043.85 12796.55 42.11 98.04 8113.37 12890.57 41.28 98.48 8183.57 12985.01 41.16 99.53 8254.61 13076.90 41.65 99.55 8323.53 13172.44 41.85 98.84 8394.81 13266.52 41.53 98.00 8465.06 13356.86 40.76 98.51 8533.09 13457.35 39.88 99.40 8609.71 13552.36 39.07 100.25 8683.05 13647.91 38.09 100.25 8757.74 13743.56 36.83 100.93 8833.67 13836.92 35.42 101.09 8909.08 13929.97 34.93 99.96 8985.14 vJ~~.ea 6455.87 6512.06 6567.42 6620.47 6673.34 6727.97 6783.51 6840.37 6896.16 6953.62 7009.05 7067.18 7124.07 7179.77 7235.76 7293.26 7349.41 / IL4.UJ / IJ 1.8/ / IL4.lU -ByJ.JJ /Up/.lU U.VO OUJUJ04.13 7200.79 7208.78 7200.83 -903.85 7143.88 0.54 6030361.28 7278.34 7286.47 7278.37 -908.68 7221.42 0.40 6030358.12 7356.57 7364.88 7356.58 -912.98 7299.71 7433.87 7442.38 7433.88 -916.96 7377.11 7511.42 7520.13 7511.42 -920.77 7454.77 7589.97 7598.92 7589.97 -924.30 7533.48 7667.26 7676.51 7667.27 -926.99 7611.02 7744.07 7753.63 7818.27 7828.03 7894.20 7904.12 7967.35 7977.36 8044.17 8054.23 8119.60 8129.70 8194.25 8204.35 8270.33 8280.44 8348.34 8358.46 8423.65 8433.78 7744.08 7818.30 7894.24 7967.40 8044.23 8119.68 8194.33 8270.41 8348.42 8423.74 -929.50 7688.10 -933.10 7762.42 -937.60 7838.36 -942.88 7911.41 -949.45 7988.00 -956.55 8063.14 -964.56 8137.36 -973.00 8212.98 -981.13 8290.57 -989.20 8365.46 7406.76 8499.72 8509.86 8499.82 -997.43 7464.50 8575.30 8585.45 8575.40 -1005.07 7523.25 8650.91 8661.07 8651.01 -1013.05 7582.00 8724.90 8735.07 8725.01 -1022.25 7643.07 8799.39 8809.57 8799.49 -1032.82 7704.60 8871.91 8882.12 8872.00 -1043.74 7767.62 8943.75 8954.01 8943.83 -1055.01 7831.08 9013.07 9023.39 9013.13 -1066.54 7895.74 9080.56 9090.97 9080.62 -1077.96 7961.92 9146.86 9157.31 9146.90 -1088.63 8030.20 9212.95 9223.43 9212.99 -1098.42 8100.12 9278.24 9288.73 9278.28 -1107.46 8169.64 9341.45 9351.94 9341.48 -1116.14 8239.84 9403.97 9414.48 9404.00 -1125.12 8310.88 9466.16 9476.71 9466.19 -1134.86 8379.80 9526.88 9537.48 9526.90 -1144.93 8451.08 9590.45 9601.10 9590.46 -1155.09 8521.33 9653.00 9663.67 9653.01 -1164.26 8589.36 9712.43 9723.11 9712.44 -1172.79 8665.98 9777.41 9788.14 9777.42 -1182.91 8739.32 9837.74 9848.54 9837.74 -1193.21 8814.01 9897.23 9908.12 9897.23 -1203.81 8889.94 9955.29 9966.29 9955.29 -1214.50 8965.35 10010.19 10021.33 10010.19 -1225.01 9041.41 10063.69 10074.94 10063.70 -1234.80 8441.09 8516.29 8591.49 8664.92 8738.66 8810.39 8881.39 8949.81 9016.41 9081.89 9147.28 9211.95 9274.56 9336.45 9397.91 9457.85 9520.65 9582.54 9641.37 9705.60 9765.11 9823.75 9880.93 9934.95 9987.65 1.13 6030355.50 0.78 6030353.19 0.56 6030351.05 0.72 6030349.21 1.48 6030348.19 1.01 6030347.33 0.81 6030345.34 0.34 6030342.47 0.95 6030338.76 0.39 6030333.84 0.46 6030328.36 1.02 6030321.94 0.59 6030315.13 0.38 6030308.67 0.52 6030302.22 0.47 6030295.61 0.56 6030289.59 0.99 6030283.23 1.21 6030275.61 1.34 6030266.63 0.87 6030257.25 1.21 6030247.51 1.48 6030237.46 1.33 6030227.47 1.35 6030218.21 1.04 6030209.83 1.28 6030202.18 0.42 6030194.86 0.94 6030187.21 0.74 6030178.79 0.53 6030170.01 0.54 6030161.20 0.68 6030153.37 0.93 6030146.10 1.05 6030137.37 1.02 6030128.35 1.03 6030119.01 1.39 6030109.56 1.51 6030100.21 0.88 6030091.55 800`JVO./ / N /U Ly ZV.O/Z VV 748 38 8.U6Z 666983.62 N 70 29 20.627 W 148 38 5.803 667061.25 N 70 29 20.579 W 148 38 3.522 667139.60 N 70 29 20.536 W 148 38 1.218 667217.06. N 70 29 20.496 W 148 37 58.941 667294.78 N 70 29 20.458 W 148 37 56.656 667373.54 N 70 29 20.422 W 148 37 54.340 667451.13 N 70 29 20.395 W 148 37 52.059 667528.23 N 70 29 20.370 W 148 37 49.791 667602.60 N 70 29 20.333 W 148 37 47.604 667678.62 N 70 29 20.288 W 148 37 45 0 667751.77 N 70 29 20.236 W 148 37 667828.47 N 70 29 20.170 W 148 37 667903.74 N 70 29 20.100 W 148 37 38.757 667978.11 N 70 29 20.020 W 148 37 36.573 668053.88 N 70 2919.936 W 148 37 34.348 668131.63 N 70 2919.855 W 148 37 32.065 668206.66 N 70 2919.775 W 148 37 29.862 668282.45 N 70 2919.693 W 148 37 27.637 668357.80 N 70 2919.617 W 148 37 25.425 668433.15 N 70 2919.538 W 148 37 23.212 668506.75 N 70 2919.447 W 148 37 21.052 668580.70 N 70 2919.342 W 148 37 18.883 668652.63 N 70 2919.234 W 148 37 16.773 668723.85 N 70 2919.122 W 148 37 14.684 668792.50 N 70 2919.008 W 148 37 12.671 668859.32 N 70 2918.895 W 148 37 10.712 668925.02 N 70 2918.789 W 148 37 8.786 668990.59 N 70 2918.692 W 148 37 669055.44 N 70 2918.602 W 148 37 669118.22 N 70 2918.516 W 148 37 669180.29 N 70 2918.427 W 148 37 1.297 669241.94 N 70 2918.331 W 148 36 59.489 669302.07 N 70 2918.231 W 148 36 57.726 669365.07 N 70 2918.130 W 148 36 55.879 669427.14 N 70 2918.039 W 148 36 54.058 669486.13 N 70 2917.954 W 148 36 52.327 669550.56 N 70 2917.854 W 148 36 50.438 669610.28 N 70 2917.752 W 148 36 48.687 669669.12 N 70 2917.647 W 148 36 46.963 669726.52 N 70 2917.541 W 148 36 45.280 669780.75 N 70 2917.437 W 148 36 43.691 669833.65 N 70 2917.340 W 148 36 42.141 SurveyEditor Ver SP 1.0 Bld( doc40x_56) NS30\NS30\NS30\NS30 Generated 5/5!2006 7:37 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de d ft ft ft ft ft ft ft d 1100 ft ftUS ftUS 14UL/.UD J4A0 IUU.34 yU04.Y 1 J7L I. l0 7V 1.18.`J4 lUl3U.L0 -IUllB.`J4 --IL44AD 7VU4L.lL U.44 OV3UU8L.`J8 bby888.3U rV /V Ly 1 /.L94 VV 148 3b 4V.b3y 14121.99 34.10 100.15 9143.31 9199.58 10172.40 10183.81 10172.40 -1254.08 10094.80 0.50 6030074.59 669941.18 N 70 2917.149 W 148 36 38.989 14214.68 33.83 100.30 9220.18 9276.45 10224.10 10235.59 10224.11 -1263.27 10145.77 0.31 6030066.49 669992.32 N 70 2917.058 W 148 36 37.490 14308.64 33.55 99.75 9298.36 9354.63 10276.15 10287.71 10276.16 -1272.34 10197.09 0.44 6030058.53 670043.83 N 70 2916.968 W 148 36 35.981 14583.88 27.93 98.02 9534.84 9591.11 10416.68 10428.33 10416.71 -1294.23 10335.99 2.07 6030039.63 670183.16 N 70 29 16.751 W 148 36 31.895 14679.31 26.18 95.11 9619.83 9676.10 10460.07 10471.73 10460.10 -1299.23 10379.10 2.30 6030035.56 670226.36 N 70 2916.701 W 148 36 30.627 14774.22 24.46 91.91 9705.62 9761.89 10500.57 10512.31 10500.59 -1301.75 10419.59 2.32 6030033.91 670266.89 N 70 2916.676 W 148 36 29.435 14868.56 24.52 90:39 9791.47 9847.74 10539.47 10551.42 10539.49 -1302.53 10458.69 0.67 6030033.97 670306.00 N 70 2916.668 W 148 36 28.285 14958.76 25.21 94.52 9873.32 9929.59 10577.26 10589.33 10577.27 -1304.17 10496.56 2.07 6030033.14 670343.89 N 70 2916.651 W 148 36 27.171 15058.78 25.65 96.27 9963.65 10019.92 10620.19 10632.28 10620.20 -1308.22 10539.31 0.87 6030030.02 670386.72 N 70 2916.611 W 148 36 25.913 15147.70 25.79 95.50 10043.76 10100.03 10658.77 10670.86 10658.78 -1312.17 10577.70 0.41 6030026.89 670425.18 N 70 2916.571 W 148 36 24 15241.27 26.16 94.00 10127.88 10184.15 10699.72 10711.84 10699.72 -1315.56 10618.54 0.81 6030024.38 670466.07 N 70 2916.537 W 148 36 15337.12 26.39 92.94 10213.82 10270.09 10742.06 10754.27 10742.07 -1318.13 10660.89 0.55 6030022.72 670508.47 N 70 2916.511 W 148 36 15431.41 25.55 92.19 10298.59 10354.86 10783.23 10795.56 10783.23 -1319.98 10702.14 0.96 6030021.76 670549.74 N 70 2916.493 W 148 36 21.123 15526.93 25.52 92.04 10384.78 10441.05 10824.25 10836.74 10824.25 -1321.50 10743.28 0.07 6030021.12 670590.91 N 70 2916.477 W 148 36 19.912 15621.24 25.52 91.14 10469.89 10526.16 10864.70 10877.37 10864.70 -1322.63 10783.90 0.41 6030020.87 670631.54 N 70 2916.465 W 148 36 18.717 15714.29 25.54 90.58 10553.86 10610.13 10904.57 10917.47 10904.58 -1323.23 10823.99 0.26 6030021.13 670671.64 N 70 2916.459 W 148 36 17.538 15804.20 25.47 90.76 10635.00 10691.27 10943.05 10956.18 10943.06 -1323.68 10862.71 0.12 6030021.51 670710.34 N 70 2916.454 W 148 36 16.399 15956.52 25.45 94.17 10772.54 10828.81 11008.30 11021.65 11008.31 -1326.50 10928.10 0.96 6030020.10 670775.78 N 70 2916.425 W 148 36 14.475 16050.98 22.40 96.13 10858.87 10915.14 11046.58 11059.95 11046.59 -1329.89 10966.25 3.34 6030017.52 670813.99 N 70 2916.391 W 148 36 13.353 16148.27 19.43 97.62 10949.74 11006.01 11081.30 11094.67 11081.32 -1334.02 11000.72 3.10 6030014.14 670848.54 N 70 2916.350 W 148 36 12.338 16240.24 18.16 98.69 11036.81 11093.08 11110.92 11124.30 11110.94 -1338.21 11030.06 1.43 6030010.58 670877.96 N 70 2916.309 W 148 36 11.476 Last MWD+IFR+MS 16277.70 17.79 98.41 11072.44 11128.71 11122.48 11135.86 11122.49 -1339.93 11041.49 1.01 6030009.10 670889.42 N 70 2916.292 W 148 36 11.139 MWD+IFR 16356.21 16.54 100.83 11147.45 11203.72 11145.62 11159.03 11145.63 -1343.79 11064.33 1.83 6030005.74 670912.34 N 70 2916.253 W 148 36 10.467 TD (Projected) 16398.00 16.54 100.83 11187.51 11243.78 11157.49 11170.93 11157.50 -1346.02 11076.01 0.00 6030003.76 670924.07 N 70 2916.231 W 148 36 10.124 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 - (MWD +IFR corcection -- In-field referenced MWD with time-varying field applied. Model is applicable whether or not Short Collar type correction is applied. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) MWD+IFR-MS - (In-field referenced MWD with mutt-station analysis and corcedion applied in post-processing. Assumes a BHA sag corcection is applied to enhance inclination accuracy. ) Leaal Description: Northing IY) [ftUS] Easting (X) (ftUS] Surface : 1338 FSL 649 FEL S11 T13N R13E UM 6031111.31 659822.49 BHL : 5264 FSL 44 FEL S18 T13N R14E UM 6030003.76 670924.07 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) NS30\NS30\NS30\NS30 Generated 5/5/2006 7:37 AM Page 5 of 5 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi DRLG~ DRA 13 3/8", 68#/ft, L-80, BTC @ 4442' N 4 1/2", 12.6#/ft, 13-Cr, Vam-T TUBING ID: 3.958" CAPACITY: 0.01522 BBL/Fl 9-5/8" 53.5# L-80 BTM-C @ 14549 4.5" X NIPPLE, @ 15648' t 3.813" 4.5" X NIPPLE, @ 15717' t 3.813" 4.5" XN NIPPLE, @ 15728' t 3.725" 4.5 Self Aligning WLEG @15739' 3.958' 7", 29#!ft L-80, Hydril 5~ @ 15877' MD PBTD @ 1624: TD @ 16396' ,,,,~, GINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15,9' ' S-1/2" x 4-1/2",12.6 # @44' TMD/TVD /2" TRSSSV @ 1026' TMD/TVD PPG DIESEL FREEZE PROTECTION +/- 3000' TVD (3000'MD) 4 1/2" GLM @ 4500' TVD (6666' MD) w! 4.62" ID w/RP Shear Valve t" LINER TOP @ 14367' MD 4.5" Fiber Optic Transducer 3.958" ID @ 15669 MD 'ACKER,13 Cr @ 15694' MD 4.5" LINER TOP @ 15728` MD 4.5", 12.6#, 13Cr Vam TOP DATE REV. BY COMMENTS Northstar PMH ntlcl ate a rox. WELL: NS30 API NO: 50-029-23293 Revision BP Exploration (Alaska) ' NS30 Completion BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: NS30 Common Name: NS30 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 2/14/2006 FIT 4,480.0 (ft) 3,277.0 (ft) 8.60 (ppg) 670 (psi) 2,134 (psi) 12.54 (ppg) 3/2/2006 FIT 14,569.0 (ft) 9,573.0 (ft) 12.30 (ppg) 1,090 (psi) 7,207 (psi) 14.49 (ppg) 3/14/2006 FIT 15,877.0 (ft) 10,780.0 (ft) 9.20 (ppg) 1,300 (psi) 6,452 (psi) 11.52 (ppg) r~ ._ J Printed: 4/14/2006 11:11:46 AM ~:Q r-i ~~ FILE ifiPY U.S. Department of the Interior Minerals Management Service (MMS) Submk oNginal plus THREE copies, with ONE copy maAred '7ubllc MformaUon." END OF OPERATIONS REPORT FOR OMB Control No. 1010-0141 OMB Approval Expires 8/31/2008 1. © COMPLETION ~ ABANDONMENT CORRECTION 4. WELL NAME (CURRENT) 5. SIDETRACK NO. (CURRENT) NS30 ST00 2. MMS OPERATOR NO. 00113 6. BYPASS NO. (CURRENT) BP00 3. OPERATOR NAME and ADDRESS ~srnrtmhrg ~~~~ BP Exploration Alaska PO Box 196612 Anchorage AK 7. API WELL NO. (CURRENT SIDETRACK /BYPASS) (12 DIGITS; 50-029-23293-00-00 8. PRODUCING INTERVAL CODE S01 , 99519-6613 WELL AT TOTAL DEPTH 9. LEASE NO. OCS-Y0181 10. AREA NAME Beechey Pt. 11. BLOCK NO. 12. LATITUDE 516 NAD 27 (GOM & Pacific) NAD 83 Alaska 13. LONGITUDE NAD 27 (GOM & Pacific) NAD 83 Alaska) WELL STATUS INFORMATION 14. WeII Status COM 15. Type Code POW 18. Web Status Date April 15, 2006 17 Mp 16398 rvD 11244 Total Depth 16398 WELL AT PRODUCING ZONE 18. LEASE NO. OCS-Y0181 19. AREA NAME Beechey Pt. 20. BLOCK NO. 516 21. LATITUDE NAD 27 (GOM & Pack) NAD 83 (Alaska) 22 LONGITUDE NAD 27 (GOM 8 Pacific) NAD 83 (Alaska) 23.COMPLETION GATE: April 14, 2006 24.DATE OF FIRST PRODUCTION: AprII 15, 2006 25. ISOLATED DATE: PERFORATED INTERVALS THIS COM PLETION 28.TOP (MD): 27. BOTTOM (MD) 28. TOP (TVD) 29. BOTTOM (TVD): 16112' 16172' 10972' 11028' 16184' 16194' 11040' 11049' 16204' 16224' 11059' 11078' 30. RESERVOIR NAME(S): Ivishak 31. NAME(S) OF PRODUCING FORMATION(S) THIS COMPLETION Top ~ Ivishalt HYDROCARBON BEARING IN TERVALS 32. INTERVAL NAME: 33. TOP MO 34. BOTTOM MD 35. TYPE OF HYDROCARBON Top Sag River 15846' 10729' Oil Top of Shublik 15948' 10821' Oil Top of Ivishak 16052' 10916' Oil SIGNIFICANT MARKER S Penetrated account for all markers identified on APD 36. INTERVAL NAME: 37. TOP MD 38. REASON IF MARKER NOT PENETRATED Top of Kuparuk 13909' Top of Sag River 15846' Top of Ivishak 16052' SUBSEA COMPLETIO N 39. SUBSEA COMPLETIONS Yes/No (~ 40. IF YES: PROTECTION PROVIDEDS Yes/No 41. BUOY INSTALLEDS Yes/No 42. TREE HEIGHT ABOVE ML(ft): MMS Form MMS-125 (October 2005 -Supersedes aU previous versions of (orrn MMS-125 which may not be used.) Page 1 of 2 • • END OF OPERATIONS REPORT (EOR1 ABANDONMENT HISTORY OF WELL 43. CASING SIZE: 44. CASING CUT DATE: 45. CASING CUT METH: 46. CASING CUT DEPTH: 47. Type of Obstruction: 48. Protection Provided: Yes/No 49. Obstruction Heigh Above ML (ft): 50. Buoy Installed? Yes/No CONTACT NAME: 3~ti Paul Hanson, CONTACT TELEPHONE NO.: 907 564-4195 `C~u~ 5~,~(_ CONTACT E-MAIL ADDRESS: Hansp5@bp.com ~h~~~~~~.e~,~ PAPERWORK REDUCTION ACT OF 1895 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 ~ seq.) requires us to inform you that we collect this information to obtain knowledge of equipment and procedures to be used in drilling operations. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form is estimated to averege between 1-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Management Service, 1849 C Street, NW, Washington, DC 20240. MMS Fomt MMS-125 (Or4ober 2005 - Supersedes aN previous v~ersbns of form MMS-125 which may not be used.) Page 2 of 2 BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2006 19:00 -00:00 5.00 RIGU PRE Prep rig for move to NS-30, Lay mats & heroulite PJSM & ATP with all personnel involved with rig move Move rig from NS-14 to NS-30 2/4!2006 00:00 - 17:30 17.50 RIGU P PRE Move rig to NS 30 Monitoring flowline, well house & pipe rack Gearances Laying Hercuiite 8~ spotting mats Finish rig move & spot over NS 30 17:30 - 20:00 2.50 RIGU P PRE Connect water lines, connect to island electrical power Buik1 berm around G 8 I and rig Set stairs & landings 20:00 -00:00 4.00 RIGU P PRE Accept rig ~ 20:00 hrs on 2/4/2006 Nipple up riser Load pipe shed w/MWD tools &HWDP 2/5/2006 00:00 - 02:00 2.00 RIGU P PRE Load pipe shed w/ BHA #1 NU surface riser, install valves on conductor Mix red spud mud 02:00 - 02:30 0.50 RIGU PRE Gean up mud spilt, 4.5 bbis contained in rig, .5 bbis on herculite 02:30 - 04:00 1.50 RIGU P PRE Move gyro tools, bit, subs ~ stabilizers to rig floor NU surface riser 04:00 - 05:30 1.50 RIGU P PRE PU 21 jts of 5"HWDP 8~ stand in derrick 05:30 -06:00 0.50 RIGU PRE Fill riser w/sea water & check for leaks 06:00 - 08:00 2.00 RIGU P PRE RU wireline & gyro equipment 08:00 -09:00 1.00 RIGU P PRE HSE standdown -Focus areas: Spills -valve alignment, need to double check Safety -PPE needs for every job, hand safety, watch out for inexperienced employees Pre spud mtg -review surface hole plans & potential problems Review D 7 conditions, responsibilities, evacuation plans & remote well monitoring 09:00 -11:00 2.00 DRILL P SURF PU BHA #1 11:00 -11:30 0.50 ORILL P SURF RIH w/ 2 stands of HWDP 11:30 -12:30 1.00 DRILL P SURF Displace sea water w/ spud mud Cirrxrlate m 200' 12:30 -13:30 1.00 DRILL P SURF Circulate 8 Condition 13:30 -14:00 0.50 DRILL P SURF Drill from 200' to 23T 14:00 -15:00 1.00 DRILL P SURF w Run gyro on wireline 15:00 -16:00 1.00 DRILL P SURF Direr~ional drill, slide from 23T to 32T 16:00 -16:30 0.50 DRILL P SURF Run gyro on wireline 16:30 -17:30 1.00 DRILL P SURF POH, LD stabliizers 17:30 -19:00 1.50 DRILL P SURF PU BHA #2 19:00 -19:30 0.50 DRILL P SURF RIH 19:30 -20:30 1.00 DRILL P SURF HSE starxldoNm -Foals areas: Spies -valve alignment, need too double check Sally -PPE needs for every job, hand safety, watch out for ~ employees Pre spud mtg - review surface hole plarrs >~ potential problems Review D 7 axrlditiorrs, responsp~ifities, evacuation plans & remote well monitoring 20:30 - 21:00 0.50 DRILL P SURF Directional drip, rotate ~ slide from 32T b 383' 21:00 - 21:30 0.50 DRILL P SURF Run gyro on wireflne 21:30 - 23:00 1.50 DRILL P SURF Directional drill, gate & sects from 383' to 542" 23:00 - 23:30 0.50 DRILL P SURF Run gyro on wirepne arnrsd: M~uzoos t~:~te2~ BP EXPLORATION Page 2 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2006 23:30 -00:00 0.50 DRILL P SURF Directional drill, slide from 542' to 566' 2/6/2006 00:00 - 11:00 11.00 DRILL P SURF Directional drill from 566' to 1285' Run gyro surveys every stand DP pressure 1175 psi @ 728 GPM WOB 20-30K, Torque 8K PU wt 131 K, SO wt 124K, Rot wt 131 K 11:00 -11:30 0.50 DRILL P SURF Pump sweep RD wireline 8~ gyro equipment 11:30 -12:30 1.00 DRILL P SURF Circulate & condition hole for trip to shoe Pulsation problems w/mud pumps 12:30 -14:00 1.50 GRILL N RREP SURF POH to oa-ductor shoe 14:00 - 21:30 7.50 DRILL N RREP SURF Replace pulsation dampener bladders on both mud pumps Charge pulsation bladders to 1150 psi w/ nitrogen Service top drive 21:30 -22:30 1.00 DRILL N RREP SURF RIH from 200' to 1195' 22:30 - 23:00 0.50 DRILL N RREP SURF Wash to btm from 1195' to 1282' 23:00 -00:00 1.00 DRILL P SURF Directional drill from 1282' to 1380' 100% slide 2/7/2006 00:00 - 01:00 1.00 DRILL P SURF Directional drill from 1380' to 1460' (sliding). PU 140K, SO 124K, RW 131 K, 740 GPM,1320 psi, Torq on 8K, Torq off 6K 01:00 - 02:00 1.00 DRILL P SURF Unable to build angle. Pmp sweep and circ. BU at 500 gpm @690 psi. 02:00 - 03:30 1.50 GRILL P SURF POH check BHA, run check w/ MWD at known gyro survey depth MWD OK. Continue POH. 03:30 - 05:30 2.00 DRILL P SURF POH w/ BHA. Inspect motor and bit, OK. 05:30 -06:00 0.50 GRILL P SURF Gear and clean floor. 06:00 -08:00 2.00 DRILL P SURF Adjust motor angle from 1.83 to 2.38. Move stab. to just above motor. RIH w/ BHA 08:00 -09:00 1.00 DRILL P SURF RIH b 137T. Stage up pumps. Precautionary wash to btrn, OK, no fill. 09:00 -09:30 0.50 DRILL P SURF Dir. drill from 1460' to 1519'. 09:30 -10:00 0.50 DRILL N SFAL SURF Lost electrical power' fr+orrr Prod. Facility. PU off btm and dro at 100 gpm. 10:00 -11:00 1.00 DRILL P SURF Dir. drill from 1519' to 1662' (sliding) at 700 gpm Q 1153 psi. PU 137K, SO 125K. Hole angle increasing. 11:00 -12:00 1.00 DRILL P SURF Pmp sweep and reap. high side at 500 gpm and 623 psi. 12:00 -15:00 3.00 DRILL P SURF POH to adjust BHA. 15:00 -16:00 1.00 DRILL P SURF Adjust PDM angle to 1.83 deg. and reposition stabilizer (moved up 20') 16:00 -17:00 1.00 DRILL P SURF RIH. Precautionary wash from 1570' to 1662'. 17:00 -00:00 7.00 DRILL P SURF Dir. ~ at 2323' Q 00:00 hrs. PU 140K, SO 120K. RW 130K, WOB 20-30K, Rot 0-30 rpm, 775 gpm, 1540 psi, Total Rot time 1.3 fxs & slide time 4.7 hrs in past 24 hrs. Hob conditions good on connections. Back rearm through slide sections on coruredions,l2K tD 14K torq whtie bads n9arning. 2/8/2006 00:00 -00:00 24.00 DRILL P SURF Dir. drilling from 2323' id 4375'. 850 gpm at 1850 psi; WOB 10/40K; Rot. 40 rpm; torq on 11 K, br'q off 9K; PU 145K, SO 124K, RW 134K. Total slide time = 5.8 hrs & rnt. time = 7.83 hn3 in fast 24 hrs. Sliding 20-30'/stand to maMtain hob angle. Bads ream slide Mtervais. Hob conditions appear good. 2/912006 00:00 - 01:00 1.00 DRILL P SURF Oir drl from 4375 to 4460' MD(3258' TVD) to surface casing t~rrwsa: snv2oon t1:tt~2/lfrt BP EXPLORATION Page 3 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2006 00:00 - 01:00 1.00 DRILL P SURF point. 840 gpm @ 1980 psi, 40 RPM, WOB 30K, PU 185K, SO 125K, RW 130K, Torq on 13.8K, torq off 10.5K, Act. rot Gme = 0.5 hrs, Act. slide time = 0.0 hrs. 01:00 - 04:00 3.00 DRILL P SURF Circ BU X 3 at 900 gpm. Redp. & rotate while lrc. Pump 50 bbl weighted sweep on first BU. Hole leaning OK. Sweep back at 10% over calculated hole volume. 04:00 - 07:00 3.00 DRILL P SURF B/D top drive ~ flnes. POH. Wipe tight spots at 2558' 8 2332', OK. Started swabbing ~ 2130. MU top drive to pump. 07:00 -08:30 1.50 DRILL P SURF Stage up pumps b 7 bpm. Establish dre and POH w/ pmp to 1280'. POH from 1280' tp 1180' w/o pmp, OK. 08:30 -10:00 1.50 DRILL P SURF B/D surf lines. RIH to 4410'. Wash to 4460', no fill. No tight hole on trip in. 10:00 -13:30 3.50 DRILL P SURF Circ & cond mud and hole. Pmp weighted sweep. Redp 8 rot 40 rpm, 875 gpm, and 2200 psi. 13:30 - 20:30 7.00 DRILL P SURF POH to BHA. Hole conditions good. 20:30 - 21:30 1.00 ORILL P SURF LD parts of the BHA. Stand bads collars and HWDP. 21:30 - 23:00 1.50 DRILL N SFAL SURF Level derrick before running casing. Clear 8 dean rig floor. 23:00 -00:00 1.00 DRILL P SURF RU to run 13 3!8" surface casing. Gean both mud pmp suction screens. PJSM. Chg bales and RU Franks Fillup tool 2/10/2006 00:00 - 02:00 2.00 CASE P SURF Rig up 350 ton elevators, casing tongs, pickup dwker. 02:00 - 03:00 1.00 CASE P SURF PJSM. PU 13 3/8" shoe joint, shoe track and float collar jt. Circ. shoe track vol. Check floats, OK. 03:00 -15:00 12.00 CASE P SURF Run total of 106 jts 133/8", 68# L-80 BTC surface casing as per plan. Make up to triangle, avg torque was 8200 ft-Ibs. Used B-O-L 2000 ihrd comp. Fill each jt. Casing collars frequently hanging upon inside edge of landing ring thru jt #33. Hole tight at 2240'. Wash through tight spots from 2240' to 2252' ~ from 2300' to 2310' at 5 bpm 250 psi. No further washing required below 2340'. PU landing jt and hanger, land wl shoe at 4442' MD (3248' TVD). Land w/ 1ti51C on fluted mandrel hanger. 15:00 -15:30 0.50 CASE P SURF LD Franks Fillup tool. MU cementng head loaded w/ top and bottom plugs. 15:30 -19:30 4.00 CASE P SURF Circ and cond. mud and hole. Grc BU X 2. Slowly stage up b 10 BPM with final dreulating pressure ~ 450 psi. Held PJSM while circulating. 19:30 -22:30 3.00 CEMT P SURF Cementing. Pr tst lines b 3500 psi OK. Pmp. 25 bbl CW-101, 75 bbl 10.5 ppg Mud Push II, drop bottom plug, pump 516 bbls (610 sx) of 10.7 ppg lead slurry. During the switdr b tail slurry, slurry mbdng jet plugged foring water bads into the cement sib piping, Plugging those tines. Shut down commenting. 22:30 -00:00 1.50 CEMT N SURF Displace spacers and teed slurry out of the hole. Stage up rig PAP ro 7 bpm at 500 psi and dre. Clear and blow dn. cant 8~ wtr lines. 2/11/2006 00:00 -02:00 2.00 CEMT N CEMT SURF Circulate out and dear hole of spacers and lead shirty. OZ:00 -13:00 11.00 (:EMT N CEMT SURF Circ and oond. hole and mud waitMg on cement resupply. Haul in and RU second cmt sib unit 13:00.13:30 0.50 CEMT N CEMT SURF Install bottom plug in cementing head. Reinstall top plug. 13:30 -16:00 2.50 CEMT N CEMT SURF PJSM. Pr tst flees to 3500 psi. Mix arrd pmp 25 bbl CW-101 spacer, 75 bbl Mud Push fl (1 ppg over mud wt). bottom plug, 607 sx (515 bbl)10.7 ppg ASL lead slurry. 466 sx (94 bbi)15.8 ppg CI G taN skury, lop pkig, and 25 bbl saltwater. 16:00 -19:30 3.50 CEMT P SURF Switch b rig pump and displace with mud at 90 spm (9 bpm) Pnnrea: an~r2ooe tt:rt~z~uYr BP EXPLORATION Page 4 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3!2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/11/2006 16:00 -19:30 3.50 CEMT P SURF and 700 psi. Contaminated cement to surface 280 bbl into displ. Slow pump to 70 spm (730 psi). Good lead slurry retums at 450 bbls into displ. Incr. pmp to 90 spm. Slow pmp to 5 bpm 10 bbl before plug to bump. Pr. incr to 1250 psi. Bumped plug with 1761 psi at 629 bbls. CIP at 19:15 hrs. Held pr for 3 min. Bled back. Floats held OK. Full retums throughout job. Est. 251 bbls of lead slurry to surface. 19:30 -22:00 t.50 CEMT P SURF Rig down cementing head, tongs, and 350-ton elevators. Release and pail landing joint and lay down same. 22:00 -00:00 2.00 CEMT P SURF Wash out and begin rigging down riser. 2/12/2006 00:00 - 01:00 1.00 BOPSU P SURF Rig do riser. 01:00 - 03:30 2.50 BOPSU P SURF Remove cement from lower riser, ND and secure same. Clean cement from 133/8" mandrel hanger neck. Clean t_ pit. Work on mixing hopper. 03:30 -04:00 0.50 BOPSU N WAIT SURF Wait on Prod. to allow moving NS30 tree and stand for more room. 04:00 -04:30 0.50 BOPSU P SURF Reposition tree to make room in cellar area for NU. 04:30 -06:00 1.50 BOPSU P SURF NU casing spool. Pr. tst 13 3/8" landing neck and spool seat to 1000 psi for 10 min. OK. NU drilling spool. 06:00 -09:00 3.00 BOPSU N WAIT SURF Wait on Prod to shut in adjacent wells to pick up and set BOP stack. Cont. to clean pits and adjust mud pump suction valves in pits. 09:00 - 17:00 8.00 BOPSU P SURF NU BOPE. Hook up Koomey lines and kill line. Function tst BOP, OK. 17:00 - 00:00 7.00 BOPSU P SURF Test BOPS. Mr. Jeff Jones, AOGCC inspector, is onsite to witness testing. Test annular to 250/3500 psi for 5 min. OK. Upper pipe rams leaked. Replaced 2 7/8X5 w/ 31/2X6. Ram door leaking-tighten. One TIW failure. Packing glands on weNhead leaking-tighten. Test H2S and Methane gas detectors and alamrs, OK. 2/13/2006 00:00 -09:00 9.00 BOPSU P SURF Testing ROPE. Numerous component leaks (manifokd, TIW, a9 head packing glands, rams, test piping). Minimized components tested to more easily identify leaking cmnponents. Regrease drilling spool valves and choice manifold valves. Tested upper and k„nrer pipe rams, blind shear rams, dart valve, floor TIW, manual and HCR kill and cwke valves, choke manifold, upper and knaer IBOPs to 250/5000 psi for 5 min. OK. Performed Koomey test, OK. Ati testing witnessed by Mr. Jeff Jones, AOGCC inspector, with Mike Dinger and Bret Allard. 09:00 -10:00 1.00 BOPSU P SURF Puff test plug. Install wear bushing (ID =12 5116", OD =13 5/8", t.engtl~ =35.5") 10:00 -10:30 0.50 BOPSU P SURF Blow down tines and top drive. 10:30 -14:00 3.50 CASE P SURF Cut and sfip driNing Nne; 93'. Torque tie down and adjust brakes. 14:00 -15:00 1.00 CASE P SURF Run NVVOP and POH tay&rg dowm same. 15:00 -16:30 1.50 CASE P SURF PU BHA #5. Perform shallow test of rotary steerable tool and MWD. 16:30 -20:30 4.00 CASE P SURF RIH picking up additional 5" DP. Singling M. 20:30 - 21:30 1.00 CASE P SURF Circ. and test MWD. Pmp 715 gpm a 670 psi. Blow do mud lines and tiop drive. 21:30 -22:30 1.00 CASE N RREP SURF Repair leak on Iron Rougturedc. 22:30 - 23:30 1.00 CASE P SURF Continue singling M 5" DP. RIH to 2349' and till drill pipe. Circ ar„esa: 4nv2ooa »:tt~2~r BP EXPLORATION Page 5 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/13/2006 22:30 - 23:30 1.00 CASE P SURF at 700 gpm @ 760 psi. 23:30 - 00:00 0.50 CASE P SURF Continue RIH picking up 5" OP. At 2535' at 00:00 hrs. 2/14/2006 00:00 - 01:30 1.50 BOPSU P SURF RIH to 3581'. 01:30 - 02:00 0.50 BOPSU P SURF Circ. one pipe vol. Check MWD tools. 02:00 - 03:00 1.00 CASE P SURF RIH to 4320'. Wash do last stand. Rot. 50 rpm; 200 spm @ 1300 psi; torq 11 K. 03:00 - 03:30 0.50 CASE P SURF Circ. surf. to surf. to clear air from borehole and pipe in prep for a9. tst. Circ 9.4 ppg in and out. 03:30 -04:30 1.00 CASE P SURF Close pipe rams and pr. tst. 133/8" surf casing to 3500 psi for 30 min., OK. 04:30 -08:00 3.50 CASE P SURF Tag cmt plugs at 4356'. Dri plugs, float collar, shoe track, that shoe, rat hole, and 21' of new hole (4481'MD). Began pumping new 8.6 ppg LSND mud when drilling float shoe. 08:00 - 09:00 1.00 CASE P SURF Finish displacing to new 8.6 ppg mud, in and out. 09:00 - 10:00 1.00 ORILL P SURF Conduct Formation Integrity Test to 12.5 ppg pressuring up to 670 psi with 8.6 ppg mud. Held for 10 min. OK. Pmp in 1.9 bbis, bled back 1.9 bbis. 10:00 - 12:00 2.00 DRILL P INT1 Dir. Drf. from 4481' to 4706'. Rot 120 rpm, WOB 10K, Torq 12K, 212 spm/900 gpm @ 1200 psi. PU 175K, SO 135K, RW 150K. SPR: 182, 30 spm & 60 psi; 40 spm 8 100 psi (4481' Md/3271' TVD) 12:00 - 15:00 3.00 DRILL N RREP INT1 POH to shoe and adjust top drive pipe handling torque valves. Change saver sub. RIH. 15:00 -00:00 9.00 DRILL P INT1 Dir. Drl. from 4706' to 6221' MDl4260' TVD. Pmp weighted sweeps at 5621' 8 621 T. Rot 120 rpm, WOB 10K, Torq 15K, 212 spm/900 gpm @ 1750 psi. PU 180K, SO 145K, RW 160K. SPR @5500' MD/3853' TVD: 1&2, 35 spm 8140 psi; 45 spm 8180 psi, w/ 9.1 ppg. Total rotating hours in last 24 hours = 6.24 hrs. 2/15/2006 00:00 -04:00 4.00 ORILL P INT1 Dir. driN from 6221' to 6792'. 04:00 - 05:30 1.50 DRILL N RREP INT1 Work on saver sub problems (breaking out at knnrer IBOP). OP grabber dies dragging on saver sub bevel. Unable to make up with TD pipe handler. Move pipe OK while working on Top Drive. 05:30 - 08:30 3.00 DRILL N RREP INT1 POH to 4423' (above shoe) to repair Top Drive. 08:30 -13:00 4.50 DRILL N RREP INT1 Remove pipe handler. Torque saver sub to Top Drive with rig tongs. Adjust spacing of saver sub/pipe handler dies. Trouble shoot torque wrench solenoid valve and adjust to Vary specs. 13:00 -13:30 0.50 DRILL P INT1 Service rig and Top Drive. 13:30 -15:00 15:00 -00:00 1.50 9.00 DRILL DRILL N P RREP INT1 INT1 RIH. Wash last stand down, precautionary. Dir. drill from 6792' to 7933' MD/5243' TVD. Pump hi-vis sweeps at 7000' 8 7500' MD. Rot 120-140 rpm;212 spm/900 gpm Q 2150 psi; torq 14K; WOB 10K; PU 205K, SO 155K, RW 180K. SPR at 7743' fu~/5o99' TvD: Pmps 1 8 2.35 spm ~ 190 psi, 45 spm ~ 210 psi. 2/16/2006 00:00 -00:00 24.00 DRILL P INT1 Oirectlonal drilling from 7933' MD/5243' TVO to 9728' MOJ6273' TVO. Rot 140 rpm, WOB 10K, Torq 17K-23K, 212 spm/900 gpm ~ 2350 psi, PU 250K, SO 165K, RW 200K. SPR ~ 8968' MD/583T 7VD 8 9.1 ppg: Pmps 1 8 2 - 35 spm ~ 200 psi, 45 spm ~ 210 psi. Total rotating tame kr past 24 hrs = 18.32 hrs. Driving oxasional hard streaks (1-5 itltu). Prmrp sweeps every 500'. Hole condition good. Torque increasing. wxKSa: vr~rmos tt:~t:s2~rrr BP EXPLORATION Page 6 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/16/2006 00:00 -00:00 24.00 DRILL P INT1 Raised tube additives (Lubetex and EMI 920) from 2°k to 3%. 2/17/2006 00:00 - 07:00 7.00 DRILL P INT1 Directional drilling from 9728' MD to 10,107' MD. Pumping hi-vis sweep every 500'. WOB 15K, 140 rpm, Torque 23K, 215 spm/911 gpm @ 2500 psi; PU 250K, SO 170K, RW 205K. SPR @ 10,10T MD/ 6542' TVD: Pmps 1 t;< 2; 35 spm @ 180 psi, 45 spm @ 230 psi w/ 9.1 ppg. 07:00 - 07:30 0.50 DRILL P INT1 Service top drive. 07:30 -15:30 8.00 DRILL P INT1 Directional drilling from 10,10T MD to 10,730' MD. 15:30 -16:30 1.00 DRILL N RREP INT1 Replace liner, swab, and wear plate in Pump #1, #1 cylinder. 16:30 -00:00 7.50 DRILL P INT1 Directional drill from 10,730' MD to 10,960' MD/ 6992' TVD. Pumping sweeps every 500'. WOB 15K, 140 rpm, Ta+que 22K, 213 spm/902 gpm @ 2500 psi; PU 260K, SO 175K, RW 210K. SPR @ 10960' MD/6992' TVD: Pmps 1 & 2; 35 spm @220 psi, 45 spm @ 280 ppg w/ 9.1 ppg. Total rotating time in past 24 hours = 17.41 hrs. Hole conditions good on connections. 2/18/2006 00:00 - 05:30 5.50 DRILL P INT1 Directional drill from 10,960' to 11,530' MD/7331' TVD. Pump hi-vis sweeps every 500'. WOB 20K, 140 rpm, torq 18-25K, 213 spm/902 gpm @ 2550 psi, PU 275K, SO 192K, RW 222K. SPR @ 11,528' Md / 7330' TVD: 9.1 ppg, Pmp 18.235 spm @ 250 psi, 45 spm @ 310 psi. 05:30 - 07:00 1.50 DRILL N SFAL INT1 Lost electrical power on the island. Started 2 rig generator sets and established circulation while restoring Island power back to the rig. 07:00 -00:00 17.00 DRILL P INT1 Directional drill from 11,530' to 13,13T MD/842T TVD. Pump hi-vis sweeps every 500'. WOB 20K, 140 rpm, torq 18-25K, 213 spm/902 gpm @ 3050 psi, PU 300K, SO 195K, RW 240K. SPR @ 12,474' MD ! 7933' TVD: 9.4 ppg, Pmp 1 & 2, 35 spm @ 260 psi, 45 spm @ 310 psi. Actual rotating time past 24 haws =14.6 hrs. 2/19/2006 00:00 -05:00 5.00 DRILL P INT1 Dir drill from 13,13T MD to 13421' MDI8638' TVD. Prep for short Lip to shoe. Pmp hi-vis wt. sweep while drilling at 13,288'. WOB 29K, 140 rpm, torque 24K, 212 gpm/902 gpm @ 3100 psi, PU 300K, SO 195K, RW 245K. SPR @ 13,421' MD/8638' TVD: Pmps 1 & 2; 35 spm @ 180 psi, 45 spm @ 230 psi, 9.5 ppg. Actual rotating time past 24 hours = 3.27 hrs. 05:00 - 07:00 2.00 DRILL P INT1 Ciro. Pmp second hi-vis wt. sweep at TD and prep to POH on short trip. Monitorwell -static. 07:00 -15:30 8.50 DRILL P INT1 POH from 13,421' to 8780'. Began pulling tight (30-40K over) between 8780' and 802T. Waked through, no swabbing until 802T. Mae swabbed boa, up and dean. 15:30 -22:00 6.50 DRILL P INT1 POM with pumps on hole from 802T to 6983' (140 apm/600 gpm ~ 1100 psi). Pipe freeing up. Attempt tD pud w/o pump from 6983' to 669T. Swabbing. Continue POH w/ IMP and ~~~ at 40 rpm. POM b 4233'. 22:00 -22:30 0.50 DRILL P INT1 RIH m 4455 ~ drrwlate sweeps for Leaning hae. Bit and rotary-steerable pads below shoe. 22:30 -00:00 1.50 DRILL P INT1 CMc. 25 bbl 11.8 ppg, hi-vis sweeps at 212 spm/902 gpm @ 1600 psi. 120 rpm. Large quantities of day bads, coal, and drilled solids over shaker with sweeps. 2/20/2006 00:00 -04:00 4.00 DRILL P INT1 Circ. 2~0 bbl 11.8 ppg hi-vis sweeps from 4455'. Considerable amormt of day and day bads over shakers on first sweep. PrMked: 4/tUIIOO6 17:112 MA BP EXPLORATION Page 7 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/20/2006 00:00 -04:00 4.00 DRILL P INT1 Hole Leaning OK. 04:00 - 05:00 1.00 DRILL P INT1 Service Top Drive, drawworlcs, and crown. Check and sync rig generators to island power. Using 2 generators to supplement power due to high torque and pump pressure. 05:00 - 06:00 1.00 DRILL P INT1 Circ BU at 4450'. Blow down mud lines and top drive. 06:00 - 10:30 4.50 GRILL P INT1 RIH to 13,421'. Fill DP every 30 stds. Washed last 2 stands to btm, precautionary. Hole conditions good. 10:30 -14:30 4.00 DRILL P INT1 Circ. 8 cond. mud, displadng to 10.5 ppg mud. Adding glycol. 14:30 -00:00 9.50 DRILL P INT1 Dir. drill from 13,421' to 13,802' MD / 8938' TVO. Torque in~xeasing to +/-27K. Adding drilling beads to system, currently 1#/bbi and incr. tube products to 4°Jo/vol. Torque decreased t/-4K. 2/21/2006 00:00 - 05:00 5.00 DRILL P INT1 Directional drill from 13,802' to 14,085' MD. WOB 20K, 140 rpm, TQ 26K, 180 spm/800 gpm @ 3750 psi., PU 355K, SO 205K, RW 255K. SPR at 13,991' MO /9084' TVD: Pmp 1, 35 spm @ 350 psi, 45 spm @ 410 psi; Pmp 2, 35 spm@ 340 psi, 45 spm @ 430 psi, 10.5 ppg. 05:00 - 05:30 0.50 DRILL P INT1 Rig service. Service Top Drive. 05:30 -12:30 7.00 DRILL P INT1 Dir. dr1. from 14,085' MD to 14,395' / 942T TVD. 12:30 - 15:00 2.50 DRILL N RREP INT1 Repair cap gasket on pmp #1/ #1 cylinder. Bring 2 generators back on line, had kiLced off earlier. 15:00 - 20:30 5.50 DRILL P INT1 Dir. drl from 14,395' to intermediate casing point at 14,549' MD 19556' TVD. WOB 18K, 140 rpm, TQ 26K, 165 spm/ 700 gpm @ 2900 psi, PU 325K, SO 210K, RW 260K. SPR at 14,549' MD / 9556' MD: Pmp 1, 35 spm @ 320 psi, 45 spm@ 410 psi; Pmp 2, 35 spm @ 330 psi, 45 spm @ 410 psi, 10.5 ppg. Actual rotating time past 24 hrs. = 11.85 hrs. MWO logging tool quit at 14,408' MD! 943T TVD. 20:30 -00:00 3.50 DRILL P INT1 Circ. & coed hole. Pmp 40 bbl weighted hi-vis sweep at 190 spm/900 gpm @3600 psi, 120 rpm. No notable quantities of cuitirgs across shakers. Prep for second sweep. 2/22/2006 00:00 - 03:30 3.50 DRILL P INT7 Circ & coed hole. Pmp hauls sweep. Hole dean. Prep for short trip. 03:30 -11:30 8.00 DRILL N WAIT INT1 Circulate and move pipe waiting on wind abatement. 11:30 -15:30 4.00 GRILL P INT1 POH from 14,549' to 13,043' short trip. Pump out each stand. 30-40K overpull first 2 stds. Work pipe thraigh tight spots. 20-30tC on remainder of trip. Bkrnr do top drive. 15:30 -16:30 1.00 DRILL P INT1 RIH. Circ last stand dawn, precautionary. 16:30 -19:00 2.50 GRILL P INT1 Circ 60 bbl 13 ppg hauls sweep at 180 spm @ 3500 psi and 140 rpm. BU gas after short trip peaked at 320 units, averaging 260 units. 19:00 - 21:00 2.00 GRILL P INT1 Pult one std and dre 2nd 60~b1 weighted hauls sweep from 14,462' MD. tide appears dean. Badcgr+ound gas at +/- 80 units. Monitor weN~static. 21:00 -00:00 3.00 DRILL P INT1 . POW to rtm c'sg. Pmp out from 14,462' to 12,949' at 60 spm/265 gpm and 650 psi. Pulled 40K over at 13850'. Waited pipe through tight spot, OK. 2/23/2006 00:00 - 01:30 1.50 DRILL P INT1 Grculate btm up 8~ condition mud @ 12,949' 01:30 - 04:00 2.50 DRILL P INT1 Monitorwell- static. POH from 12.949' to 11,150' without pump 20-3010 overpuA typical. Occasional 40K overpuli 04:00 -04:30 0.50 DRILL P INT1 Spot 160 bbl G Seal pill from 11,150' to 10.000' MD. PrkKed: U71/2008 ~ 1:11 ~2 AM BP EXPLORATION Page 8 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/23/2006 04:30 - 05:30 1.00 DRILL INT1 POH from 11,150' to 9916' 05:30 - 13:00 7.50 GRILL P INT1 Pump dry job, POH from 9916' to 4442' Monitor well 10 mins, well static POH from 4442' to 3100' 13:00 - 14:30 1.50 DRILL P INT1 Well began to swab while POH @ 3100' Pump 40 bbl high vis sweep Circulate to dean hole DP pressure 1600 psi @ 800 GPM Pump dry job, monitor well -static 14:30 -17:00 2.50 DRILL P INT1 POH from 3100' to 271', No problems Monitor well 17:00 - 20:30 3.50 DRILL P INT1 LD BHA #5 Clear ~ dean rig floor 20:30 - 00:00 3.50 CASE P INT1 Puli wear bushing RU test joint, set test plug PJSM, Change upper pipe rams to 9 5/8" 2/24Y2006 00:00 - 01:00 1.00 CASE P INT1 Test door seals on BOPS to 3000 psi 01:00 - 01:30 0.50 CASE P INT1 RD test joint 8 test plug 01:30 -04:30 3.00 CASE P INT1 RD DP handling equipment RU tools & equipment to run 9 5/8" casing 04:30 - 05:00 0.50 CASE P INT1 PJSM, Running 9 5/8" casing Discuss safety hazards w/ focus on body placement and hand safety 05:00 - 07:00 2.00 CASE N HMAN INT1 Thaw mud line valves 07:00 - 08:30 1.50 CASE INT1 Level rig 08:30 -09:30 1.00 CASE P INT1 Run 2 joints 9 5/8" casing 09:30 -10:30 1.00 CASE N INT1 Level rig 10:30 -11:30 1.00 CASE P INT1 Run 2 joints 95/8" casing 11:30 -14:00 2.50 CASE N HMAN INT1 Thaw mud lines, test mud lines to 2800 psi 14:00 -14:30 0.50 CASE P INT1 Circulate though float equipment and d,e~k floats 14:30 -22:00 7.50 CASE P INT1 Run 71 joints of 95/8° casing Fflling every joint w/ Franks fill up tool 22:00 -00:00 2.00 CASE P INT1 Move rig 3" to the South Rig alined over wellbore 2/25/2006 00:00 - 01:00 1.00 CASE P INT1 Air boot on riser, check for leaks T'~ghen tumtwdtles ~ BOP stack 01:00 - 03:00 2.00 CASE P INT1 Run 95/8" casing 03:00 -04:00 1.00 CASE P INT1 Circulate casing volume @ shoe- 4442' Pump pressure 663 Q 9 bpm Total volume pumped 315 bbls 04:00 -16:30 12.50 CASE P INT1 Run 95/8" casing 16:30 -18:00 1.50 CASE P INT1 Change out elevates Control valve failure 18:00 -22:30 4.50 CASE P INT1 Run 95/8". 53.5 #, L-80, BTM casing Total Jts. ran 336, casing landed ~ 1454T 22:30 - 23:00 0.50 CASE P INT1 RD longs and casing handling equipment 23:00 - 23:30 0.50 CASE P INT1 RU cementing head and dreulatir-g line 23:30 -00:00 0.50 CASE P INT1 Break drariafion ~ 1454T Pump pressure 800 psi ~ 2 BPM 2126/2006 00:00 -04:30 4.50 CASE P INT1 Circxlate and condition mud for cement job Pump pressure 670 ~ 7 BPM, Reduce mud to 10.5 ppg 04:30 -05:00 0.50 INT1 PJSM, discuss cementing operations rn~a: ~n4r2ooe tt:t~e2rua BP EXPLORATION Page 8 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Stale 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 2/26/2006 05:00 - 06:00 1.00 CEMT P INT1 Pump 5 bbl sea water ,pressure test lines to 3000 psi Pump 35 bbl CW 101, 75 bbl 11.0 ppg mud push 06:00 - 10:30 4.50 CEMT P INT1 Drop bottom plug, pump cmt per design 555 bbl 12.5 ppg "ext" lead, class G cement 97 bbl of 15.8 ppg tail cement class G ICP = 210, FCP= 1037 psi @ 3 BPM Drop top plug. pump 10 bbl sw Displace w/ rig pump 990 bbl drilling mud 24.5 bbl sw, total disp 1024.5 bbl Bump plug, cement in place @ 10:16 10:30 -11:00 0.50 CEMT P INT1 Bleed pressure, fbats holding OK Bkn~v down circulating lines. 11:00 -12:00 1.00 CEMT P INT1 RD a9 equipment, cmt head, clean and clear floor 12:00 - 13:00 1.00 CEMT P INT1 Blow down rig circulating lines Test kill line to 3000 psi 13:00 - 16:00 3.00 CEMT P INT1 Bull head 265 bbl of 10.5 ppg mud down 13 318" annulus Final pump pressre 860 psi, bleed pressure recover 10 bbl 16:00 - 17:30 1.50 CEMT P INT1 Change top pipe rams to 3 1/2" X 6" variables 17:30 - 20:00 2.50 CEMT P INT1 ND BOP's and related equipment, move well head annulus sweep and install VR plug 20:00 - 21:00 1.00 CEMT P INT1 Wait on NS 31 8 29 to be shut in 21:00 - 21:30 0.50 CEMT P INT1 Lift BOP's 21:30 - 00:00 2.50 CEMT P INT1 Set slips with 390 K string weight 1st attempt casing slid though slips 8" without setting 2nd attempt casing slid though slips about 4" taking partial weight 3rd time slips set w/ 1/2" slack off 2/27/2006 00:00 - 03:00 3.00 CEMT P INT1 Evaluate options to install 9 5/8" pads off gearances were not uniform between the 9 5/8" casing and the wellhead pads off bowl 03:00 -04:30 1.50 CEMT P INT1 Cut and bevel 9518" casing Lay down cut joint 04:30 - 05:30 1.00 CEMT P INT1 Pull riser and move ROPE to install pads off 05:30 -06:00 0.50 CEMT P INT1 PJSM for critical lift assodated wiih ROPE near NS 31 06:00 -08:00 2.00 CEMT P INT1 Dress casing cut and install pads off Run in lock down screws on wellhead 08:00 -10:00 2.00 CEMT P INT1 NU BOP's 10:00 -12:00 2.00 CEMT P INT1 InstaQ drilling sweep & riser 12:00 -13:00 1.00 CEMT P INT1 Remove casing elevators and kxig bails 13:00 -13:30 0.50 CEMT P INT1 MU test joint and set test plug 13:30 -15:00 1.50 CEMT P INT1 FiU BOP with sea water, riser leaking replace gasket, no leaks 15:00 -19:00 4.00 CEMT P INT1 Test BOPs. Mr. Lou Grimauidi, AOGCC Inspector. Ls onsite to witness testing. Test annular>o 250/3500 psi Test pie and bflnd rams. dwke mardfdd valves, k~ Nne valves. dart valve. and IBOP ~ 25015000 psi. Perform accumulator test, hold all pressure test for 5 minutes All BOP test witriessed by WSL's Darrell Green and Ridiard Watkins Pwnp 140 BBL freeze protect diesel down outer annulus Pumped FP Q 4 BPM -1150 psi, left 700 psi outer annulus 19:00 -20:00 1.00 CEMT P INT1 Pub test plug and kistaU wear bushing 20:00 - 21:00 1.00 CEMT P INT1 gear rig floor of casing equipment PnrKed: vtuzoos ~~:tt~z~wt BP EXPLORATION Page 10 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: GRILL+COMPLETE Start: 2/3/2006 End: Contractor Name:. NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT I Phase 2/27/2006 21:00 - 22:00 1.00 CEMT P INT1 22:00 - 23:00 1.00 DRILL P INT2 23:00 - 00:00 1.00 DRILL P INT2 2/28/2006 00:00 - 03:30 3.50 DRILL P INT2 03:30 -06:00 2.50 DRILL P INT2 06:00 - 13:30 7.50 DRILL P INT2 13:30 -15:30 2.00 DRILL P INT2 15:30 -16:30 1.00 DRILL P INT2 16:30 - 17:00 0.50 DRILL INT2 17:00 - 19:30 2.50 DRILL P INT2 19:30 - 20:00 0.50 DRILL P INT2 20:00 - 21:30 1.50 DRILL P INT2 21:30 - 23:00 1.50 DRILL P INT2 23:00 - 00:00 1.00 DRILL P INT2 00:00 - 02:30 I 2.501 DRILL I P I I LNR1 10:00 -11:00 I 1.00 I DRILL I P I I LNR1 11:00 -13:00 I 2.001 DRILL 1 P I I LNR1 13:00 -13:30 0.50 DRILL P LNR1 13:30 - 23:00 9.50 DRILL P LNR1 23:00 - 23:30 0.50 DRILL P LNR1 23:30 -00:00 0.50 DRILt P LNR1 3/2!2006 00:00 - 06:00 6.00 DRILL P LNR1 06:00 -08:00 2.00 DRILL P LNR'I 08:00 -09:00 1.00 DRILL P LNR1 -15:30 I 6.501 DRILL I P Description of Operations Service rig, lubricate rig and top drive Install bails and elevators PU BHA # 6 PU BHA # 6, shallow test MWD PU 49 Jts. 5"drill pipe RIH F/ 1808' T/ 13540', fill DP every 30 stands Cut 145' of drilling line and adjust brakes RIH F/ 13540' T/ 14202' Wash F/ 14202' T/ 14392' RU Gees pressure test casing T/ 4000 psi for 30 min RD lines and bkniv down, dear floor Wash down F/ 14392' T/ 14466' Drill float @ 14466', drill cement T/ 14542' DP 1350 psi ~ 320 GPM w/ 10.5 PPG, 50 RPM, 21 k torque PU 300K, SO 200K, ROT 245 K Circulate and displace wellbore w/ 12.5 PPG mud Drill cement F/ 14542' T/ 14547 Drill float shoe F/ 14547 T/ 14549' DPP 1750 psi ~ 320 GPM SPR pump # 1 - 35 SPM = 310 psi, 45 SPM = 450 psi, SPR pump #2- 35 SPM = 290 psi, 45 SPM= 420 psi MW 12.5 MD 14545' TVD 9558' Drilling float shoe @ 14549', WOB 4 K, Torque 23 K DPP 1840 psi (a~ 320 GPM Lost pump pressure, 300 psi in 10 min Swish to pump # 2, DPP 1350 psi @ 320 GPM Prepare to POOH fa possible wash out POOH to inspect BHA for washout Stand bads jars,flex collars, unable tD find W/O MU T/D pump 100 GPM while picking up skmAy Fkrid squirting from sheared Rhino reamer Change out Rhino reamer, reconfigure BHA Place stabilizer in BHA, Continue PU BHA # 7 Shallow test Rhino reamer 284 GPM 400 psi Bkrnv down top drive RIH F/ 106' T/ 14,485', Fill pipe every 20 stds Wash F/ 14,485 T/ 14550' Circulate & condition mud OA Pressure 700 psi Drip F/ 14549' T/ 14569' Slow ROP, bit balling DDP 1350 psi ~ 320 GPM Vary rotory from 40 to 80 RPM Vary WOB from 2K 6015K Pump 30 bbl hi vis sweep, no difference ~ ROP Pump 30 bbl nut plug sweep. no difference h ROP Cirrxriate and oon~flon hole for fd test Perform fit test tD 14.5 PPG EMW, Current MW 12.3 PPG, Pressure annulus to 1100 psi Hold 10 minutes, pressure bled off to 1060 psi Drip F! 14569' T/ 14601' DPP 1550 psi ~ 330 GPM, 120 RPM, TQ ZOK WOB 2K to 15K PU 290 K, SO 190 K, ROT 248K rn~osa: urartooa rr:rr~znr~ BP EXPLORATION Page 11 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/2/2006 09:00 - 15:30 6.50 DRILL P LNR1 SPR MP # i - 25 STKS-160 psi, 35 STKS 270 psi SPR MP # 2- 25 STKS- 180 psi, 35 STKS 280 psi 15:30 - 00:00 8.50 DRILL P LNR1 Drill F/ 14601 T/ 14869' Rhino reamer below casing shoe, Increase flow rate to 570 GPM DPP 3600 psi @ 570 GPM, WOB 30 K, RPM 140, Torque 23K PU 290 K, SO 190, ROT 240 3/3/2006 00:00 -04:00 4.00 DRILL P LNR1 Drill directional from 14869' to 14,945' Drilling 81/2" hole opening to 91/2" hole 04:00 - 05:30 1.50 DRILL N RREP LNR1 Drilling ahead w/ DPP 3500 psi Q 570 GPM Lost 500 psi in 5 minutes. Check surface equip't -all OK. POH to shoe 8~ double check surface equip't. 05:30 - 12:00 6.50 DRILL N RREP LNR1 POOH looking for wash out in string 12:00 - 13:00 1.00 DRILL N RREP LNR1 Pull out of hole to BHA, looking for wash out Did not find wash out during TOH 13:00 - 15:00 2.00 DRILL N RREP LNR1 Perform base line flow test on MWD and BHA Pump 400 GPM to establish base line parameters 15:00 -00:00 9.00 DRILL N RREP LNR1 RIH and base line pump test every 20 stands Check actual pressures vs. calculated pressures & check MWD turbine RPM to aid in locating wash out. 3/4/2006 00:00 - 03:00 3.00 DRILL N RREP LNR1 RIH checking pump pressure every 20 stands. Pump test while on bottom, pump pressure 800 psi low vs calculated. POOH, found leak in DP body on center Jt. of stand # 149 03:00 - 03:30 0.50 DRILL P LNR1 Adjust brakes on draw works 03:30 -04:00 0.50 DRILL P LNR1 RIH with 6 stands of drill pipe Stage up pumps to 570 GPM 3900 psi, no fill on bottom 04:00 -04:30 0.50 DRILL P LNR1 Drill F/ 14946' To 14953', 570 GPM, 3900 psi, 04:30 -08:00 3.50 DRILL N RREP LNR1 Drfliing ~ 14953', lost 600 psi pump pressure Prepare to POH looking for wash out Wash out found ~ 1323T, std # 138, LD stand 08:00 -09:00 1.00 DRILL P LNR1 RIH /wash down last stand to TD 14953' 09:00 -00:00 15.00 DRILL P LNR1 Drill F/ 14953' T/ 15191' 3/5/2006 00:00 - 01:00 1.00 DRILL P LNR1 Drill F/ 15191' T/ 15196' 3125 psi' DPP went F/3125 psi T/ 2930 psi 01:00 - 03:00 2.00 DRILL N RREP LNR1 POH to find wash out in pipe Found WO ~ Std. # 140, Jt. 418, Remove stand 140 F/ String Break Grc, pump 570 GPM, 3150 psi, turbine RPM = 3164 Bkwv down top drive & mud Fne 03:00 -04:00 1.00 DRILL N RREP LNR1 LD Bad Jt. and 2 more into pipe shed G_N 8~ GJ2 floor. RIH wash last stand T/ BTM, 15196' Stage up pumps T/ 570 GPM, 3350 psi 04:00 - 04:30 0.50 DRILL N RREP LNR1 RIH w/ DP Replace ceP gasket on mud p~np. 04:30 -09:00 4.50 DRILL P LNR1 Orfli F/ 15196' T/ 15232' 570 GPM, 3350 psi, 20K TQ on BTM, 18K off BTM 200 SO, RW 245,140 RPM, Cad ECD 13.6 ppg, actual ECD 13.6 ppg Average rate of penetration 10 FPH 09:00 -10:00 1.00 DRILL N DFAL LNR1 Monitor well, POOH F/ 15232' T/shoe 14549' 10:00 -10:30 0.50 DRILL P LNR1 Service top drive and bloats 10:30 -13:30 3.00 DRILL P LNR1 Cut and slip 119' of drift line. tiarose: uterzoos tt:»:52rue BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2006 10:30 - 13:30 3.00 DRILL P LNR1 Pump dry job and prepare T/ POOH 13:30 - 19:00 5.50 DRILL N DFAL LNR1 POOH 158 stands in the derrick 19:00 - 23:30 4.50 ORILL N DFAL LNR1 Inspect BHA, test rhino reamer w/ plugs installed in nozzles - OK UD rhino reamer 8 POH w/ BHA. Bit missing one nozzle. Test rotary steerable - OK Changed out rotary steerable tools as precautionary due to hours on seals and bit Download, dump MWD tool 23:30 -00:00 0.50 DRILL N DFAL LNR1 Test MWD and rotory steerable. 3/6/2006 00:00 - 01:00 1.00 DR1LL N DFAL LNR1 Tst BHA/MWD. Blow do Top Drive. 01:00 - 09:30 8.50 DRILL N DFAL LNR1 RIH. Fill every 20 stds not exceeding 310 gpm. Verify proper pump press. 09:30 - 10:00 0.50 DRILL N DFAL LNR1 Stage pumps T/ 570 gpm, 3650 psi, 110 rpm, TO 21= 25K ECD = 13.8 wash down T 15,210' torque increase 10:00 - 11:30 1.50 DRILL N DFAL LNR1 Ream down F/ 15210' T/ 15,220' TQ 22K, WOB 8K Eratic torque@ 15218', work through same 11:30 - 12:00 0.50 DRILL N RREP LNR1 Pump pressure dropped F/ 3650 psi T/ 3250 psi No leaks @ surface, POOH, pump 3 bpm, 270 psi F/ 15,183' looking for possible wash out in string 12:00 -15:00 3.00 DRILL N RREP LNR1 Continue pumping out to the shoe to 14,549' keeping pipe full. Blow do top drive and pull to 13,353'. Found washout. Ld Jt. # 414. RIH to 14,269'. 15:00 -16:30 1.50 DRILL N RREP LNR1 Spot EP mud lube pill from 3312' to 2000'. 16:30 -18:00 1.50 DRILL N RREP LNR1 LD 31 jts of 5" DP. 18:00 - 20:00 2.00 DRILL N SFAL LNR1 Shim rig on the South end comers Fkrnr line minimim dearence reached 20:00 -22:30 2.50 DRILL N RREP LNR1 Sort out drill pipe on location to send to Tuboscope Removing ser. #' s SB - SG - RS 22:30 - 23:30 1.00 DRILL N RREP LNR1 Pick up 31 Jts. of drill pipe F/ pipe shed and TIH. Pipe picked up was 4' less than that layed down. 23:30 -00:00 0.50 DRILL N RREP LNR1 Continue to RIH with drill pipe F/derrick 3/7/2006 00:00 - 03:00 3.00 DRILL N RREP LNR1 Stage up dre. Wash and ream from 15,065' to 15,232'. Tight spots. Some packing off occurring. Wash and ream to TD, back naaming f~ht spots from 15,100'. Some shale splinters across shakers. Erratic torque, 18-26K. 500 gpm @2950 psi. 03:00 -13:30 10.50 DRILL P LNR1 Directional drill from 15,232' to 15,331' MD / 10,264' TVD. 120 RPM, WOB 24K, 600 gpm @ 3930 psi, caic. ECD 13.8 ppg, AcL =13.9 ppg. PU 330K, SO 200K, RW 245K. Took SPR @ 15,241'. 13:30 -14:00 0.50 DRILL P LNR1 Servik;e top drive. Add oU to swivel. 14:00 -00:00 10.00 DRILL P LNR1 Directional drib from 15,331' to 15,604' M0/10,511' TVD. Pmp 40 bbl him weighted sweep at 15,500'. 120 RPM, WOB 24K, 600 gpm @3950 psi, talc. ECD 13.76 ppg, Act =13.8 ppg. PU 310K, SO ZOOK, RW 220K, Torq 20-25.5K. SPR @ 15,604'MD/10,355TVD: Pmp 1, 35 sprn @ 420 psi, 45 spm @ 485 psi: Pmp 2, 35 spm @385 psi, 45 spm @480 psi w/ 12.5 ppg. Actual rotating time kt past 24 hr =16.52 hrs. 3/8/2006 00:00 - 07:30 7.50 DRILL P LNR1 Dir. drl. from 15.604' b 15,789' AAD/10,67T 1'VD. 120 RPM, WOB 22K, Torq 22K on 8 20K off, 591 gpm ~ 3950 psi. PU 310K, SO 200K, RW 248K, talc ECD 13.8, actual 13.9 ppg. Pnrxee: utsnoos ++:1+~2AM BP EXPLORATION Page 13 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA GRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/8/2006 00:00 - 07:30 7.50 DRILL P LNR1 SPR at 15,640' MD/ 10,543' TVD 8.12.5 ppg: Pmp #18 2, 25 spm @ 300 psi, 35 spm @ 430 psi. 07:30 - 10:00 2.50 DRILL N RREP LNR1 POH looking for washout. Lost 400 psi while drilling and no leaks in surface equip. Pump out at 2 BPM @ 178 psi. Work through tight spot at 15,278', wipe same-0K. Found washout in slip area below box end of Jt. # 457(1086' below RT). LD Std. # 153. PU 3 singles, new to string. 10:00 -12:00 2.00 DRILL N RREP LNR1 RIH. Ream through tight spot at 15,195' 815,333'. Stage up pumps and wash last stand to bottom at 15,789'. 12:00 - 18:00 6.00 DRILL P LNR1 Dir. drill from 15,789' to 15,896' MDl10,769' TVD; 7" liner point. 112 RPM, WOB 25K, Torq 24K, 591 GPM @ 3950 psi, PU 320K, SO 200K, RW 250K, talc ECO 13.79 ppg, actual 13.9 ppg. SPR at 15,800' MD/10,687 TVD 812.5 ppg: Pmp #1 35 spm @ 475 psi, 45 spm @ 570 psi; Pmp #2 35 spm @ 435 psi, 45 spm @ 550 psi. Pmp havis sweep at 15,850', evidence of running shale. TD hole at 15,896'. Total rotating time past 24 hrs = 12.17 hrs. 18:00 - 19:30 1.50 DRILL P LNR1 Circ. BU. 570 gpm @ 3900 psi. Monitor well-static. 19:30 - 23:00 3.50 DRILL P LNR1 POH for short trip to 95/8" casing shoe. Pmp out at 2 BPM @ 200 psi. Pulled 30 K over at 15,565', 15,222', and 15.200'. Did not require back-reaming. Circ BU at shoe w/ 600 gpm @ 3900 psi. 23:00 - 00:00 .1.00 DRILL P LNR1 RIH. Tight spots at 15,185' 8 15,225'. Work through w/o pump OK. Wash last stand down. Tag fill at 15,866' (30' of fill). Wash and ream. 3/9/2006 00:00 - 01:30 1.50 DRILL P LNR1 Stage up pumps. Wash and ream last stand down. Tag fill at 15,866' (30' of fill). Wash to TD w/ 591 gpm @ 3900 psi, 120 RPM, torq 22K, talc ECD 13.79, actua113.9 ppg. 01:30 -06:00 4.50 DRILL P LNR1 Circ and cond. hole. Pmp hi-vis sweep after first BU. Pull one stand after 2 BU. Circ 2 more BU. Rwi stand bads to TD. Returns indicate running shale. Rotate at 130 RPM and redprocate pipe during all circulating. 06:00 -10:30 4.50 DRILL P LNR1 Inrx. mud wt to 12.8 ppg to emitrol shale. Circ and coed mud and hole. Reduce pmp rate to 480 gpm @ 2830 psi to keep ECD from exceeding 14 ppg at higher mud wG 10:30 -13:30 3.00 DRILL P LNR1 Monitor well-static POH pumping at 25 spm @300 psi. Wipe tight spots at 15,672' 8 15,360'. No rotation while pulling to shoe at 14,549'. SLM. 13:30 -15:00 1.50 DRILL P LNR1 Circ BU at 14,474' at 130 spm/460 gpm @ 2650 psi. 15:00 -15:30 0.50 DRILL P WR1 Blanc do top drive. Drop steel DP rabbit with tattle-tail. 15:30 - 23:00 7.50 DRILL P LNR1 POIi to BHA. SLM (no correction). 23:00 - 23:30 0.50 DRILL P LNR1 Monitorwell-static. 23:30 -00:00 0.50 DRILL P LNR1 LD BHA # 8. 3/10/2006 00:00 -02:00 2.00 DRILL LNR1 LD HWDP, jars, flex ootlars, MWD tools. and bit. 02:00 -02:30 0.50 DRILL LNR1 pear floor. PJSM for changing upper rams. 02:30 -04:30 2.00 BOPSU LNR1 Puff wear rMg. Irrstatl test plug and lock down. Close blMd rams. Change out upper rams to 4.5"X7". 04:30 -05:00 0.50 BOPSU LNR1 Open blinds and run 5" test jt. RU pr tst equipment. Pressure test ram doors to 250 psi and 5000psi each for 5 min. Record on press. d~arL 05:00 -05:30 0.50 BOPSU LNR1 Rig down test equip. Putl test plug and nm wear ring. 05:30 - 07:00 1.50 CASE LNR1 Rig up casing tools for T Inter. PJSM. 07:00 -11:30 4.50 CASE LNR1 PU T, 29# , L-80, Hydril 521 Nner with float equip and PAMeQ: M1~R008 11:11S2AM BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3!2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NA60RS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2006 07:00 -11:30 4.50 CASE LNR1 centralizers as per plan. Use Jet-Cube seal guard and torque to 15,000 ft-Ibs. Utilize dog collar on each jt. Fill pipe on the fly and top off every 5 jts. 11:30 - 12:00 0.50 CASE LNR1 Make up Baker 9 5/8" X 7" liner hanger. 12:00 - 00:00 12.00 CASE LNR1 RIH with 5" DP at 1.5 min/stand, filling pipe every row (11 stds). 3/11/2006 00:00 - 01:30 1.50 CASE P LNR1 RIH w/ 7" liner to 14,478' (above 9 5!8" shoe at 14,549') filling every 11 stands. 01:30 - 03:30 2.00 CASE P LNR1 Ciro. Stage up skwvly to 5 BPM at 1000psi. Circ pipe vol. PU 290K. SO 205K, RW 240K, TQ 18K 03:30 -06:30 3.00 CASE P LNR1 RIH w/ 7" liner in open hole. Tag firm fill at 15,87T MD/10,757' TVD (31' MD bekrnr top of Sag). Attempt to work down with no gain. RU cmt head. 06:30 - 09:00 2.50 CASE P LNR1 Stage up pumps 8 circulate liner ~ DP vol. ICP 600 psi @ .5 BPM, FCP 1150 psi @ 5 BPM. 09:00 - 10:30 1.50 CEMT P LNR1 PJSM w/ all personnel involved with cement job. Pump 5 bbis sea water 8~ test lines to 4500 psi. Bleed off pressure ~ pump 55 bbis 13.5 ppg Mud Push II followed by 100 bbls (365 sx) of 15.8 ppg tail cement. 10:30 - 14:00 3.50 CEMT P LNR1 - Displace cement with rig pumps @ 6 BPM 800 psi. Good pressure increase as cement fumed comer with no losses. Slowed pump to 3 BPM before wiper plug shear -sheared wiper plug on calculated sUokes with 96% pump efficiency. Increase pump rate to 5.5 BPM slowing down before bumping plug. Bumped plug w/ 308 bbis of mud at 1300 psi and increased pump pressure to 4200 psi to set hanger. - Bleed off pressure & check floats -floats held. CIP @ 11:30. Full returns during cementing. - S/O 60K to ensure hanger set. - P/U string 8' to release from hanger & knver string ~ set down 50K ~ set packer. Good surface indication of packer setting. Repeat sequence with rotation to ensure packer set. - P/U string to expose padcoff on setting tool w/ 1000 psi on DP -Circulate 30 bbls @ 1.5 BPM - P/U on string 8 pull setting tool dear of packer 8 CBU @ 550 GPM 3600 psi. Approximately 20 bbis of cement in contaminated mud @ B/U. 14:00 -15:00 1.00 CEMT N RREP LNR1 LD 9 jts. 5" DP. 15:00 -15:30 0.50 CEMT P LNR1 Pmp dry job. BO top drive and mud lines. 15:30 -22:00 6.50 CEMT N LNR1 Drilipipe Management. LD 18 stands; replace 10 stands with good pipe; move 11 stands of good pipe to top of string. Now have 149 stands of 5" DP in hole. 22:00 -00:00 2.00 CEMT P LNR1 Cut and slip 116' of driNing Nne. 3/12/2006 00:00 -00:30 0.50 CEMT P LNR1 Comps. kwtting DL. Clear floor. Blow do aN mud Nnes. 00:30 -03:00 2.50 CEMT P WR7 Pump dry job. POH with liner mm~ing tod. 03:00 -03:30 0.50 CEMT P LNR1 Pie puNing wet Pump second dry job. Lost Nghts in derrick board area. Temp. repair. 03:30 -04:00 0.50 CEMT P LNR7 Cont. POH. 04:00 -04:30 0.50 CEMT N RREP LNR1 Repair tights in derrick for board area. 04:30 -10:00 5.50 CEMT P LNR1 Cont POH b Neer tool. 10.-00 -11:00 1.00 CEMT P LNR1 Monitor w~eN-static. Make service breaks and LD Nner mm~ing tool. Setting tod dogs sheared OK. 11:00 -13:00 2.00 CEMT P LNR1 RU and test 9 5N3" X T caskrg and Nner lap to 3400 pstg. Held for 30 min. OK. Drain stack. PuN wear ring. Run test plug. rnneee: ~nv2ooe rr:rr~zµt BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5!2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/12/2006 13:00 - 15:00 2.00 BOPSU P LNR1 Change out both upper and lower ram blocks. Install 2 7/8" X 5" variable blocks in upper rams and 3 1/2" X 6" variable blocks in lower rams. 15:00 - 20:00 5.00 BOPSU P LNR1 RU to test ROPE. AOGCC field inspector, Chuck Sheve, waived witnessing test. MMS field inspector, Kyle Monkelein, waived witnessining test. Install test joint. Tested annular to 250 psi and 3500 psi, 5 min. each, OK. 20:00 -00:00 4.00 BOPSU N RREP LNR1 Attempt test on upperrams -failed to hold high press test. Sent for replacement bk~Gcs. (Arrived at 21:00). Tested choke manifold and 5" floor valves (250 psi and 5000 psi, 5 min each) while waiting on replacement bkx~cs. Two extra 5" TIWs failed. Install second set of 2 7/8' X 5° variable blocks. Resume testing. Comp! testing upper and lower rams on 5" DP at 250 psi 85000 psi for 5 min each. 3/13/2006 00:00 - 03:30 3.50 BOPSU P LNR1 Compl. BOP test. Pr. tst. annular on 4" tst jt. to 250 psi and 3500 psi, 5 min. each. Test upper and lower rams on 4" tst jt. 8 4" floor valves to 250 psi and 5000 psi, 5 min each. Test blind/shear rams to 250 psi and 5000 psi, 5 min each. Perform Koomey function test, OK. Check remote station OK. 03:30 - 04:00 0.50 BOPSU P LNR1 RD BOP tst equip. Pull tst plug, run wear ring (ID: 8.812"). LO tst jt. 04:00 - 04:30 0.50 CASE P LNR1 Blow down a-I lines. 04:30 - 07:30 3.00 CASE P LNR1 PJSM. MU BHA #9. Install RA source in MWD. 07:30 -09:00 1.50 CASE P LNR1 Pick up 4", 14#, HT-40 DP 8 single in. 09:00 - 10:00 1.00 CASE N WAIT LNR1 Make determination whether or not to run a MAD pass in the surface hole. Deferred to trip out of hole. 10:00 -11:30 1.50 CASE P LNR1 Cont. PU 4" DP (66 jts. total). 11:30 - 18:00 6.50 CASE P LNR1 Chg. elevators 8 tong die blocks for 5° DP. Shallow test MWD-0K. RIH w/ 5". SLM. 18:00 -19:30 1.50 CASE P LNR1 Welibore fluids out of balance and flowing bads in DP. Mix and spot dry job. 19:30 -00:00 4.50 CASE P LNR1 RIH to 15,623'. Washing down at 15,716' @ OO:OOhrs. No problem entering T' liner top at 14,386'. 3/14/2006 00:00 - 03:30 3.50 CEMT P LNR1 Wash do to top of liner cmt plugs at 15,784' putting LC at 15,786' DPM. Grilled plugs, landing collar, shoe track, and float collar. Cmt drilled medium firm. Dri to 15,868'. Prep to displace to FbPro mud. PU 290K, SO 210K, RW 255K at 15,868'. 03:30 -09:00 5.50 CEMT P LNR1 Displadng old mud with 9.1 ppg Fk~Pro mud system. Pmp spacer folkmred by FIoPro at 220 gpm ~ 2900 psi. 09:00 -12:00 3.00 DRILL P LNR2 Drill shoe. Clean out rathole and drill 20' of new hole to 15,91 T MD, 10,793' TVD. WOB 10K, 80 RPM, TQ 11K, 62 spm ~ 1830 psf, PU 295K, SO 220K, RW 255K. SPR ~ 15,877' MD110,75T TVD: Pmp 1 8 2; 35 spm ~ 980 psi ~ 45 spm ~ 1100 psi w/ 92 ppg. Ad. rotating time for 20' was 025 hrs. 12:00 -13:00 1.00 ORtLL P LNR2 PuU up to shoe at 15,87T and perform FIT w/ 92 ppg mwt. Pmp 49 strokes (4.9 bbl) and press. tD 1300 psi for an equivalent mud wL of 11.5 ppg at shoe depth of 10,780' TVD. No indication of formation failure. 13:00 -00:00 11.00 DRILL P LNR2 D~ drill from 15.91 T to 16214' MO/11,07G TVD. WOB 15K, 100 RPM (rotary) + 165 RPM (motor), TQ off 15K, TQ on 18K, 270 gpm ~ 1900 psi. PU 310K, SO 220K, RW 255K. SPR Q 15,905' MD/10,782' TVD: Pmp 1- 23 spm ~ 890 psi, 35 spm a~a: ~nvzoos ~t:tt~2~urr BP EXPLORATION Page 16 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23!2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/14/2006 13:00 - 00:00 11.00 DRILL P LNR2 @ 1070 psi; Pmp 2-23 spm @ 910 psi, 35 spm @ 1075 psi w/ 9.2 ppg. Total rotating time last 24 hr. = 9.09 hrs. 3/15/2006 00:00 - 10:30 10.50 GRILL P LNR2 Dir. drlg at 16,265' MD/11,116' TVD to 16,320' MD/11,169' TVD. WOB 5-20K, RPM 100/265, 76 spm @ 2040 psi, TO 15-25K. PU 310K, SO 220K, RW 270K. Torque increasing from 16,165' w/ ROP decreasing. Rotary stalling. Hole possibly out-0f-gauge with NB stabilizer binding. Hole getting fight taking 50K over to free. Actual rotating time = 7.82 hrs. 10:30 -13:30 3.00 DRILL P LNR2 Circ and c~nd mud. Bring mud wl from 9.2 ppg to 9.3 ppg. 13:30 - 16:30 3.00 DRILL P LNR2 Run MAD pass with MWD tools from 16,320' MD to 15,811' MD. Pull at 300'/hr. Pmp at 242 gpm @ 1220 psi. 16:30 -19:30 3.00 DRILL P LNR2 Cut and slip drilling line.. Cut 162' due to bad spots. 19:30 - 20:00 0.50 DRILL N WAIT LNR2 Fire Alarm in PLO. Smoke in comm. room-no cause known yet. Muster called. 20:00 - 22:30 2.50 DRILL P LNR2 POH to top of T liner. Pump out from 15,811' to 14,390' (pump out sub) 22:30 - 00:00 1.50 DRILL P LNR2 Drop dart and open Circ sub 180' above bit. Circulate BU X2 with Circ sub at 14,380', passing a tool joint every 5 min. {no rotation) and occasionally moving the dro sub down to the liner top at 14,386'. Circ at 13 bpm at 1728 psi. 3/16/2006 00:00 - 01:30 1.50 DRILL P LNR2 Circ from Circ sub above 7" liner top to clean hole. 01:30 - 02:00 0.50 DRILL P LNR2 Monitor well-static. 02:00 - 02:30 0.50 DRILL P LNR2 Pump dry job and blow do top drive and mud lines. 02:30 - 11:00 8.50 DRILL P LNR2 POH. 11:00 -11:30 0.50 DRILL P LNR2 RU to lay do 4" DP and BHA #9. Change elevators and tong blocks for 4" DP. 11:30 -15:30 4.00 DRILL P LNR2 LD 12 Joints Of 4" HT 40 DP. Unload RA source. Pull and check bit-under gauge. 15:30 -16:30 1.00 DRILL P LNR2 Break bit and mud motor 16:30 -17:30 1.00 DRILL P LNR2 PU new bit, mud motor. Download MWD. 17:30 - 20:00 2.50 DRILL P LNR2 PU BHA #10 8 R1H w/ 4" DP. Shallow test PDM and MWD. Pmp 249 gpm at 1000 psi. 20:00 - 00:00 4.00 DRILL P LNR2 RIH w/ 5" DP filling every 25 stds. 3/17/2006 00:00 - 05:00 5.00 DRILL P LNR2 RIH to T shoe at 15,87T. Circ pipe vol. Prep to ream out-of-gauge hole. Fill pipe every 25 stands. 05:00 -06:00 1.00 DRILL P LNR2 Circ one DP vol. to clear of air. 06:00 -08:00 2.00 DRILL P LNR2 Ream from 15,877' to 16,320' w/new bit. Out-0f~auge in 08:00 -12:00 4.00 DRILL P LNR2 lower section. Dir drill from 16,320' MD to 16,398' MD / 11,243' TVD. WOB 18K, 110 RPM, TO 16K, 280 gpm @ 1750 psi. PU 310K, SO 230K, RW 270K. Actual rotating time = 3.22 hrs. 12:00 -15:00 3.00 DRILL P LNR2 Circ BU. Lost 180 >b 220 psi pmp press. Mud wL returns 8.9 10 9.0 ppg. Fkriv check OK. 15:00 -18:30 3.50 DRILL P LNR2 POH. Pump out b T shoe. i.D 2 singles used to reach TD. 18:30 -19:30 1.00 DRILL P LNR2 RIH to TD. Wash last stand down, 4' firm fill 19:30 - 23:00 3.50 DRILL P LNR2 Circ. surf to surf; 9.3 ppg in/9.3 ppg ouL Raised LubeTex and EMI-776 bads to 496. Conditioned wt bads up w/cal. cart. Incr. vis to 50+. 23:00 -00:00 1.00 DRILL P LNR2 POH to run 4.5" der. Pump out from 16.398' to 15,87T w/ 60 spm @ 1170 psi. PU 315K, SO 230K. Occasional overpull of 15K In open hole. 3/18/2006 00:00 - 01:00 1.00 DRILL P LNR2 POH. Pump out at 60 spm @ 1170 psi. Place dro sub at T RMtea: vtv2ooe t1:11~2AM BP EXPLORATION Page`17 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE State 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2006 00:00 - 01:00 1.00 DRILL P LNR2 liner top. 01:00 - 01:30 0.50 DRILL P LNR2 Monitor well-Static. 01:30 - 03:30 2.00 DRILL P LNR2 Cont. POH, pumping out at 60 spm @ 1150 psi. Position arc sub at 14,390' (4' below liner top). 03:30 - 05:00 1.50 DRILL P LNR2 Drop dart. Set dart and test DP to 1200 psi to ensure no washouts. Held pressure. Shear arc sub at 2300 psi. Circ BU at 12 BPM and 1660 psi. 05:00 - 05:30 0.50 DRILL P LNR2 Monitor well-static. 05:30 -06:00 0.50 DRILL P LNR2 Pump dry job, blow do mud lines, and POH. 06:00 - 11:00 5.00 DRILL P LNR2 POH to 4" DP. Change over to 4" DP equip. 11:00 - 12:30 1.50 DRILL P LNR2 POH w/ 4" DP. Stand back 17 stands. 12:30 - 13:00 0.50 DRILL P LNR2 LD 15 jts. of 4" DP 13:00 -15:00 2.00 DRILL P LNR2 PJSM and LD BHA #10. Clear floor. 15:00 - 17:00 2.00 DRILL P LNR2 PJSM. Slip and cut 102' of drilling line. 17:00 - 17:30 0.50 DRILL N RREP LNR2 Repair lights in derrick. 17:30.20:00 2.50 DRILL P LNR2 RU to run 4.5" liner. 20:00 - 22:30 2.50 DRILL P LNR2 PJSM. PU and run 15 jts. 4.5", 12.6#, 13Cr, VAM Top liner with associated float equip & cent. per plan. Torque to 4650 ft-Ibs. Fill each jt on the fly then top off every 5 jts. 22:30 -00:00 1.50 DRILL P LNR2 PU Baker 7" X 4.5" Flex Lock liner hanger w/ tie-back sleeve. Fill w/ PAL mix. RD ce9 tools while PAL setting. 3/19/2006 00:00 - 00:30 0.50 CASE P LNR2 CO DP handling tools from 3 1/2" to 4". 00:30 - 01:30 1.00 CASE P LNR2 RU and pump one liner volume. 01:30 - 03:30 2.00 CASE P LNR2 RIH w/4" DP filling pipe on the fly and topping off each 10 stances. CO to 5" handling tools. MU 4"X5" XO. 03:30 - 14:30 11.00 CASE P LNR2 RIH w/ 5" DP to 15,830' (7" shoe at 15,87T) filling on the fly and topping off each 10 stds. 14:30 -15:30 1.00 CASE P LNR2 Stage up pumps and pump pipe vol. Final CIrC at 5 BPM @ 870 psi. 15:30 -16:00 0.50 CASE P LNR2 Blow dn.top drive, mud 8~ cmt lines. 16:00 -17:00 1.00 CASE P LNR2 RIH ~ 16,398'. No fill. RU cmt head and arc hoses. 17:00 - 21:00 4.00 CASE P LNR2 Grc BU X 1.5 at 5 BPM ~ 940 psi. Reap pipe 20' stroke do to 16,388'. PU 310K, SO 225K. 21:00 - 22:30 1.50 CEMT P LNR2 Pr tst. Schlumberger cmt lines to 4500 psi. OK. Batch mixed 28 bbl 15.8 ppg cmt slurry. Pmp 10 bbl CW 100 wash, 22 bbl 11.3 ppg Mud Push II, 26 bbl 15.8 ppg G G slurry. Wash up cmt lines. Release pump~own plug confirmed w/ tattle-tail. Displ cmt w/ 38 bbl viscous perf pill and drt mud. Displaced with Schlumberger pumps at 5 BPM and avg. pr. of 600 psi. Latch up with liner wiper plug. after 253.6 bbls total disp. Bump plug after 262 bbl total disp) (14.6 bbl less tllan cad.) Pr to 2580 psi. CIP at 22:22 hrs. Fufi returns. Bled bads 22 bbls and check tbats, OK. 22:30 -23:00 0.50 CEMT P LNR2 Set finer hanger and packer. TOL ~ 15,728'. shoe at 16.396'. Pr up bo 1000 psi. PU and confirmed release at k>ss of 23:00 -00:00 1.00 CEMT P LNR2 Pressure. Pull out of liner top and and arc at 12 BPM at 1670 psi. Cmt returns (est 55 bbl cmt r~ntaminated mud). 3/20/2006 00:00 - 01:30 1.50 CEMT P LNR2 Grc at 4.5" finer top. Grc BU X 1.5 at 12 BPM and 1650 psi. 01:30 - 02:00 0.50 CEMT P LNR2 LO cementing head and one single DP. 02:00 -06:30 4.50 CEMT P LNR2 Gr+c out drlg mud with 30-bbl hi-vis spacer, 635 bbls saltwater. 30~bb1 hi-vis spacer, followed by 1200 bbls ~ 9.3 ppg dean brine. Brine returns dean at end of displ. Grc 10-12 BPM ~ P~irked: M1~11006 11:11.~,i2AM BP EXPLORATION Page 18 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/20/2006 02:00 -06:30 4.50 CEMT P LNR2 900 psi. 06:30 - 07:30 1.00 CEMT P LNR2 Blow do all lines and top drive. Monitor well-static. 07:30 - 09:00 1.50 CEMT P LNR2 POH, standing back 21 stands of good DP in derrick. 09:00 - 13:30 4.50 CEMT N RREP LNR2 POH laying down 5" DP singles (drill pipe management). 13:30 - 14:00 0.50 CEMT N RREP LNR2 Clear pipe shed. Adjust brakes. 14:00 -15:00 1.00 CEMT N RREP LNR2 Cont. LD 5" DP by singles (drill pipe management) 15:00 -00:00 9.00 CEMT N RREP LNR2 Pipe skate driver spool shaft failed. Tear dn. Acquire parts from Nabors 22E. Gean pits and prepare spud mud for NS34. 3/21/2006 00:00 - 07:30 7.50 CEMT N RREP LNR2 Repair pipe skate driver spool. Clean pits and prepare spud mud for NS34. 07:30 -13:00 5.50 CEMT N RREP LNR2 LD 5" Drill pipe, Layed down 385 total Joints of 5" DP 13:00 - 14:30 1.50 CEMT P LNR2 C/O elevators and slips to 4" and L/D 4" DP 14:30 -15:00 0.50 CEMT P LNR2 C/O elevators to 3.5", L!D dog sub & RR dog sub sheared 15:00 - 16:30 1.50 CEMT P LNR2 Test well bore T/ 3500 psi for 30 minutes and blow down all lines 16:30 - 17:00 0.50 CEMT N RREP LNR2 C/O slips and elevators to P/U 5" OP 17:00 -00:00 7.00 CEMT N RREP LNR2 P/U 5" DP "Replacement DP" 3/22!2006 00:00 - 03:30 3.50 CEMT N RREP LNR2 PU 5" Drill pipe 03:30 -08:00 4.50 CEMT N RREP LNR2 POOH w/ 5 "Drill pipe 08:00 -09:30 1.50 CEMT P LNR2 P/U 5" HWDP and drift 09:30 -11:00 1.50 CEMT P LNR2 POOH w/5"HWDP "Island power down about 45 minutes" 11:00 --12:00 1.00 CEMT P LNR2 Drain stack, pull wear ring, and clear rig floor 12:00 - 13:00 1.00 RUNCO RUNCMP RU 4.5 tubing handling equipment 13:00 - 14:30 1.50 RUNCO RUNCMP Run WLEG, and 11 Jts. of 4.5 " 12.6 # L-80 tubing Landed at 514.60' 14:30 - 16:30 2.00 RUNCO RUNCMP Land hanger in wellhead, run in LDS, test to 5000 psi for 15 min 16:30 - 20:00 3.50 RUNCO RUNCMP Change upper and knver rams to 4 1/2" X 7" variabales 20:00 -00:00 4.00 RUNCO RUNCMP Puil riser and mouse hole N/D BOPE's 3/23/2006 00:00 - 01:30 1.50 RUNCO RUNCMP NO ROPE 01:30 - 02:30. 1.00 RUNCO RUNCMP Pidc BOP stack 8 set in storage cradle 02:30 - 03:00 0.50 RUNCO RUNCMP ND drilling spool 03:00 -04:30 1.50 RUNC RUNCMP NU Production Tree Test hanger seal to 5K for 10 mins. 04:30 -06:00 1.50 RUNCO RUNCMP PJSM, RU lines to pump FP diesel 06:00 - 07:00 1.00 RUNCO RUNCMP Pressure test lines to 5K Test production tree to 5K for 10 mins. 07:00 - 07:30 0.50 RUNCO RUNCMP Pull TWC 07:30 -08:30 1.00 RUNCO RUNCMP Reverse circulate 27 bbls Freeze Protect diesel 08:30 -09:00 0.50 RUNCO RUNCMP Install BPV 09:00 -10:00 1.00 RUNCO RUNCMP RD Nees & prep for rig move G 8~ I finish injection 8~ RD injection tines Rig Released ~ 10:00 Hrs on 3/23J2006 3,130/2006 12:00 -15:00 3.00 RIGO P PRE Prep rig for mows from NS-34 to NS-30 ~P out Pte. bkriv down ones. PU stairs 15.-00 -15:30 0.50 RlGD P PRE PJSM for rig move with Nabors & BP personnel 15:30 -16:00 0.50 MOB P PRE Lay herculite 8~ mats for rig move after crane moved from well row 16:00 - 20:00 4.00 MOB P PRE Move rig tD south 40' and shim as needed b maintain clearances over floMAines Spot d9 over NS~O Accept rig ~ 20:00 Hrs on 3/3012006 PrlrKed: 4M4/2006 11:11 ~2 AM BP EXPLORATION Page 19 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING ! Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 3/30/2006 20:00 - 22:30 2.50 RIGU P PRE Berm rig, set stairs, winterize and prepare cellar 22:30 - 23:30 1.00 RIGU P PRE RU lines to circulate out freeze protect diesel 23:30 - 00:00 0.50 RIGU P PRE Clear rig floor of 13 3/8" casing running equipment Area on well row had been congested limiting access to rig floor 3/31/2006 00:00 - 03:00 3.00 RIGU P PRE Winterize. rig Clean L-pits, Mix 9.3 ppg brine 03:00 -04:00 1.00 WHSUR P RUNCMP Circulate out 27 bbls of FP diesel to trip tank 04:00 -06:30 2.50 WHSUB P RUNCMP ND Tree & set on tree stand NS-29 & NS-31 Shut-in for critical lift 06:30 - 07:00 0.50 BOPSU P RUNCMP PJSM for cxitical lift of ROPE 07:00 - 11:00 4.00 BOPSU P RUNCMP NU BODE, MU Choke & Kill lines Install Koomey lines Z£ install turnbuckles Install lower riser section 11:00 - 12:00 1.00 BOPSU P RUNCMP Install upper riser section 12:00 - 14:30 2.50 BOPSU P RUNCMP Install 2 7/8" X 5" variables in top set of pipe rams. 14:30 - 15:00 0.50 BOPSU P RUNCMP Pull BPV, Install TWC 15:00 - 17:00 2.00 BOPSU P RUNCMP MU & install test joint, unable to screw into hanger. Pull test joint and change out x-over. (swap out LH 5.875 acme thread for RH 5.875 acme thread) Run test jt and screw into hanger. 17:00 - 23:30 6.50 BOPSU P RUNCMP MU test equipment, fill stack w/ water Test ROPE per BP & AOGCC specifications AOGCC Rep Chuck Sheve waived witnessing BOPE test BOPE test witnessed by WSLs Mike Dinger & Richard Watkins Test annular preventer to 250 psi & 3500 psi All other BOPE to 250 psi 8 5000 psi Choke line hose developed leak in connector during choke manifold testing Tests remaining - #2 valve on choke manifold, choke tine & valves on top drive 23:30 -00:00 0.50 BOPSU N RREP RUNCMP Bbw dawn choke manffoid & prepare to replace choke line hose 4/1/2006 00:00 -04:00 4.00 BOPSU N RREP RUNCMP Replace choke line hose 04:00 - 05:00 1.00 BOPSU N RREP RUNCMP Fill stack 8 choke lines w/ water Attempt to test choke line 8 choke manifold valves Newly installed hose began to leak during 5000 psi test Test on last choke manffokd valve canpleted 05:00 -06:00 1.00 BOPSU P RUNCMP RD test joint, RU to test IBOP 8 top drive valves. 06:00 - 07:00 1.00 BOPSU P RUNCMP Test IBOP & top drive valves to 250 psi / 5000psi OK 07:00 -08:00 1.00 BOPSU. P RUNCMP RD test equipment, blow down top drive 08:00 -10:00 2.00 BOPSU N RREP RUNCMP Remove leaking droke line hose 10:00 -10:30 0.50 BOPSU P RUNCMP Service tatop drive 10:30 -13:30 3.00 BOPSU N RREP RUNCMP Instep new d~olce Nne hose 13:30 -14:00 0.50 BOPSU P RUNCMP Test new choke line hose 8 blind rams b 250 psi /5000 psi OK 14:00 -14:30 0.50 RUNCO RUNCMP PuN TWC ~ blow down choke lines and manifold 14:30 -18:30 4.00 RUNCO RUNCMP RU 4.5" tubing handling equipment RU landing joint, drain stack, pull hanger, LO landing joint & hanger LD 11 jts of 4.5" tubing 18:30 -19:30 1.00 RUN RUNCMP Instep wear bushing, RD 4.5" tubing handling equipment 19:30 - 21:00 1.50 RUN RUNCMP PJSM, RU equipm~t fp PU 2 7/8" PAC DP Prkked: vt~rtoos 11:11:62 AM BP EXPLORATION Page 20 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contracrtor Name: NABORS ALASKA DRILLING 1 Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 4/1/2006 21:00 -00:00 3.00 RUNCO RUNCMP PU junk mill, mud motor, X-0 sub, circulation sub, 2 - X-0s PU 40 Jts. of 2 7/8" 10.4# S-135 PAC DP 4/2/2006 00:00 -00:30 0.50 RUNCO RUNCMP PU 25 jts of 2 7/8" DP, Total 2 7/8" DP 65 Jts - 2025.08' 00:30 - 01:30 1.00 RUNCO RUNCMP RD 2 7/8" DP handling equipment RU 5" DP handling equipment 01:30 - 02:00 0.50 RUNCO RUNCMP Circulate through motor 8~ 2 7/8" DP Pump rate 147 GPM @ 425 psi 02:00 - 03:00 1.00 RUNCO RUNCMP Daylight Saving Time 03:00 -06:00 3.00 RUNCO RUNCMP PU 75 jts of5" DP 06:00 - 13:00 7.00 RUNCO RUNCMP T1H w/ 5" DP to 15,900' 13:00 -14:30 1.50 RUNCO RUNCMP Wash down from 15,900' to 16,310' Pump rate 110 GPM @ 895 psi String did not take more than 2K of weight or show pump pressure increase while washing down until tagging landing collar @ 16,310' 14:30 - 22:00 7.50 RUNCO RUNCMP Circulate 9.3 ppg brine @ 110 GPM Drop ball to shear circulation sub, tool did not open Pump 30 bbl High Vs sweep 8 circulate btms up Circulate out very fine solids Drop 2nd ball to open circulation sub, tool did not open Circulate surface to bit, even sea water throughout wellbore Sea water returns turbidity test - 69 NTU 22:00 -00:00 2.00 RUNCO RUNCMP TOH w15" DP 4/3/2006 00:00 - 05:30 5.50 RUNCO RUNCMP TOH wJ 5" DP, Break out X-Os 05:30 -06:30 1.00 RUNCO RUNCMP RD 5" DP handling equipment RU 2 7/8" DP handling equipment 06:30 -10:30 4.00 RUNCO RUNCMP LD 65 jts of 2 7/8" DP, arculation sub, motor, mill. Ciro sub sheared 10:30 - 11:30 1.00 RUNCO RUNCMP RD 2 7/8" DP handling equipment. 11:30 -12:00 0.50 RUN RUNCMP Clear rig floor of Baker tools Transport wireline toils 8~ equipment to rig floor 12:00 -13:30 1.50 RUNCO RUNCMP PJSM, RU Schiumberger wireline equipment 13:30 - 23:30 10.00 RUNCO RUNCMP RIH wJ 6.05 gauge ring & junk basket to 15,734' WLM, recovered 1 cup of fine solids RIH w/ 2.875" Dummy perforating gun, set down @ 16,245' Run SCMT, GR Z£ CCL, set down @ 16,245' Log U 16245' to 14,36T 23:30 -00:00 0.50 RUNCO RUNCMP PJSM, t2/U to cut drilling line 4/4/2006 00:00 -02:00 2.00 RUNCO RUNCMP Slip and rxrt 206' of drilling line. 02:00 - 02:30 0.50 RUNCO RUNCMP Pull wear bushing. 02:30 -05:00 2.50 RUN RUNCMP Change bales. RU tubing tongs, compensator, and handling tools. 05:00.07:00 2.00 RUN RUNCMP PJSM. Spot Weatherford fiber optic unit. PU fiber optic sheaves and gang in derrick 07:00 -08:30 1.50 RU RUNCMP PJSM. PU 41/2" completion equipment, padc~, and CIDRA mandrel. 08:30 -09:30 1.00 RUNCO RUNCMP MU fiber optic Nne to CIDRA mandrel and press. tst. to 7500 psi, OK. 09:30 -00:00 14.50 RUNCO RUNCMP PU 41/2", i2.6fJ, 13CR80, VAM Top cwnpletion sMng and RIH. Torque Tum each connectbn to 4440 ft-tbs. As of 00:00. 160 jts nm (680T) 4/5/2006 000 -15:00 15.00 RUN RUNCMP Continue mm~ing 41/2", 12.6lJ,13CR80, VAM Top completion string. r~rwea: ut~rtooa 'It:tt~2AM BP EXPLORATION Page 21 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2006 15:00 - 16:00 1.00 RUNCO RUNCMP MU sub-surface safety valve mandrel. RU to run control line 8 test to 6000 psi for 15 minutes, OK. 16:00 - 17:00 1.00 RUNCO RUNCMP Continue to RIH w/ 4 1/2" VAM Top tubing. 17:00 - 20:30 3.50 RUNCO RUNCMP Stab into liner tie-back extension. Space out 4 1/2" tubing on downstroke approx. 5' above bottom of tie-back (6' inside). Repeat sequence to confine. LD last 3 jts of 4 112" tbg after sparing out and replace w/ 3 Jts. of 5 1/2" X 41/2" VIT insulated tubing. MU tubing hanger. PU 220K, SO 155K prior to stabbing into tie-bads. Total of 369 jts of 4 1 /2" Vam Top 12.6# 13CR80 tubing ran, 3 jts of 4 1/2" x 5 1/2" vacuum insulated tubing. No space out pups required. 20:30 - 22:00 1.50 RUNCO RUNCMP Splice CIDRA fiber optic line & SSSV control line to hanger and land hanger. Test to 5000 psi for 10 minutes, Good test. 22:00 -00:00 2.00 RUNCO RUNCMP PJSM. RU Schlumberger slickline. RIH w/ PDS CCL memory log. 4/6/2006 00:00 - 06:00 6.00 RUNCO RUNCMP -Run CCL memory log from 16250' to 15,600'. Wireline pickup at 16,250' WLM. Reviewed PDS CCL for proper space out WLEG is 4' above bottom of tie back extention. Running D-16 plug. 06:00 - 08:00 2.00 RUNCO RUNCMP - R/U running tool and D-16 plug . RIH w/ same. 08:00 - 10:00 2.00 RUNCO DPRB RUNCMP -Attempt to set D-16 plug w/o success, POOH w/ same. 10:00 -14:00 4.00 RUNCO DPRB RUNCMP -POOH w/ slickline and D-16 plug. Usual inspection of spang jars showed layer of pipe dope which would not allow spang jars to function properly while trying to set plug in X nipple. 14:00 - 20:30 6.50 RUNCO DPRB RUNCMP -Discuss options with Androrage team. - Mobilize tools for pumping while RIH w/ slidk tine toots. RIH w/ 3.5" gauge ring & brush to 16243'. Pump 3 BPM, 140 psi while RIH. 20:30 -00:00 3.50 RUNCO DPRB RUNCMP -POOH with siickline and MN D-16 plug. 4R/2006 00:00 - 02:00 2.00 RUNCO RUNCMP -Test 41/2" tubing to 4200 psi for 10 minutes, "Good test" 02:00 -04:30 2.50 RUNCO RUNCMP -RIH and retrieve Equalizing plug out of D-plug. 04:30 -06:00 1.50 RUNCO RUNCMP -RIH and retrieve D-Plug. 06:00 -08:30 2.50 RUNCO RUNCMP -POOH with slickline and D-16 plug. 08:30 -11:00 2.50 RUNCO RUNCMP - RIH w/ RHC plug on slidcline. 11:00 -11:30 0.50 RUNCO RUNCMP -Pump down on RHC, 20 SPM ~ 100 PSI. 11:30 -14:00 2.50 RUNCO RUNCMP -Continue to RIH w/ RHC plug and set Q 15,640' 14:00 -15:30 1.50 RUNCO RUNCMP -POOH R/D slickline & RN to reverse crculate. 15:30 -19:30 4.00 RUNCO RUNCMP -PJSM, Reverse crculate annular volume of sea water with 25 gal of EC1124A, & 25 gal of 01VD121 per 100 bbl of sea water. Inhibited sea water is between packer and GLM. 19:30 - 21:30 2.00 RU RUNCMP -Dropped 1 7/8' baq 8 rod, pressured up and set packer. Test tubing ~ 4200 psi for 30 min. Bleed off press~ue on tubing 8 test anrwlus to 1000 PSI for 5 min. " Gaod test' B/D lines and R/D testing equipment. 21:30 -22:30 1.00 RUNCO RUNCMP -PJSM, R/D Weatherfords & Halliburtons sheaves, pull and L/D landing joint Set TWC. 22:30 -00:00 1.50 BOPSU P RUNCMP - W/D BOPE. 4/8/2006 00:00 -05:30 5.50 BOPSU P RUNCMP - NID BOPE's 05:30 -09:30 4.00 BOPSU P RUNCMP -Make Baal fiber optics 8 control line tie ins b surface equipment from wellhead. hest control Nnes T/ 6000 psi for 10 minutes. R/U for freeze protect and service draw works. Pricked: Uts/20o6 i1:11~2AM BP EXPLORATION Page 22 of 22 Operations Summary Report Legal Well Name: NS30 Common Well Name: NS30 Spud Date: 2/5/2006 Event Name: DRILL+COMPLETE Start: 2/3/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/23/2006 Rig Name: NABORS 33E Rig Number: 33E Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2006 09:30 - 11:30 2.00 BOPSU P RUNCMP NN tree 11:30 - 13:30 2.00 WHSUR P RUNCMP Test Vetco tree and void area to 5000 psi for 10 minutes, "Good Test" R/U line to tree for U-tube 8 test lines to 4000 psi Pull TWC 13:30 - 15:30 2.00 WHSUR P RUNCMP PJSM, pump down tubing & increase pressure to 2700 psi. Pump down annulus with pressure on tubing and test IA to 4200 psi. Hold test for 30 minutes. Bleed pressure off annulus, then tubing. Pump down annulus & shear valve in GLM @ 2300 PSI. Pump 2 bbl through tubing & annulus to verify good shear. Close TRSV 8 pump down annulus & test TRSV to 1000 psi for 10 minutes. 15:30 -19:30 4.00 WHSUR P RUNCMP PJSM, pressure test lines and freeze protect. Pump 266 bbls 65 degree diesel down IA 8 U-tube to balance point. 19:30 - 21:00 1.50 RUNCO RUNCMP BID 8 RID lines & secure cellar for rig move. Release rig @ 21:00 hours. AiMed: 4/1412008 11:11:52 AM • • Well: NS30 Accept: 02/04/06 Field: Northstar Unit Spud: 02/05/06 API: 50-029-23293-00-00 Release: 04/08/06 Permit: 205-207 Rig: Nabors 33E POST-RIG WORK 04/12/06 PULLED BALL & ROD. RIH W/4.5 OM1 KOT TO STA # 1 04/13/06 PULLED 1.5 SHEAR VALVE FROM STA # 1. SET 1.5 DGLV IN STA # 1 @ 6647' SLM. PULLED RHC PLUG BODY. BAIL FILL DOWN TO 16,226'SLM + 9' CORRECTION =16,235' MD. 04/14/06 (PERF #1) RIH W/ HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 31', MAX OD = 2.88" CCL TO TOP SHOT = 3.3' /TIE-IN TO ANNOTATED SLB SCMT LOG DATED 3-APR-06 (WILL BE USED FOR ALL PERF RUNS). LOG INTO POSITION & PERFORATE INTERVAL (16204' -16224') /GOOD INDICATION GUNS FIRED /POOH {PERF #2) RIH W/HEAD, ERS, UPCT, 10' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH =18.3', MAX OD = 2.88". LOG INTO POSITION 8~ PERFORATE INTERVAL (16184' - 16194') /GOOD INDICATION GUNS FIRED /POOH. 04/15/06 CCL TO TOP SHOT = 3.3' /TIE-IN TO ANNOTATED SLB SCMT LOG DATED 3-APR-06 (WILL BE USED FOR ALL PERF RUNS), (PERF #3) RIH W/HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 30.3', MAX OD = 2.88" LOG INTO POSITION & PERFORATE INTERVAL (16152' -16172') /GOOD INDICATION GUNS FIRED /POOH. (PERF #4) RIH W/HEAD, ERS, UPCT, 20' - 2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN. TOTAL LENGTH = 30.3', MAX OD = 2.88" LOG INTO POSITION 8~ PERFORATE INTERVAL (16132' -16152') /GOOD INDICATION GUNS FIRED /POOH. (PERF #5) RIH W/HEAD, ERS, UPCT, 20'-2.88" HSD 6 SPF 60 DEG PHASED PJ2906 GUN, TOTAL LENGTH= 30.3',MAX OD=2.88"LOG INTO POSITION & PERFORATE INTERVAL (16,112' -16,132') /GOOD INDICATION GUNS FIRED /POOH. NS30 Su Repoli Datrx 19•Mer-08 CMS ~ Explora8on Alaskt Riald: NorBtstar Stnrcturo 1 Slot NttrCtemr PF / NS30 Wad NS30 Borahala: N330 IIYWAPM: 50029232930( Savoy Name 1 Date NS901 Fetxuary 18,200E tart IAHD i DDI1 ERD redo: 180.448.111170.93 ft/8.48810.99• GAd CoordlnaN Syataet: NA027 Alaska State Planes, Zeta 04, US Fee toeacbrr LaH.ang: N 70 29 29.550, W 148 4136.00: Lotadorr Grid NIE YDC: N 6031111.3101tUS, E 659822.490 tlU; Grid Convargana Arrplrx +1.23187644` ort Schlumberger Vertlal SeeNon Azimuth: 97.010` Vertical Section Origin: N 0.00011,E 0.000 fl TVD Reference Datum: Rotary Table TVD Reference Elevation: 56.27 R reladve tD MSl Sea Bed 1 Ground Leval Elevation: 15.87 R reladve to MSL Magnetic Declination: 24.716` Total Field Strength: 57816.109 n1 Magnetic Dip: 81.021' Declnation Dace: February 09, 200E Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corc Mag North •> True North: •24.71 B' • Corranarda M Mrefhradon ArJmudr Sul-Sea TYD TVD Vertcal Along Hob Closuro NS EW DLS Northing Eaadng l.atftude Lagauda Depth Sedlon Departuro ft d ft ft ft ft ft ft ft 100 ft ftUS ftUS RTE U.W U.UU U.W -Sf3.Z/ U.UU U.W U.UU U.UU U.UU U.AU U.UU 6U37111.31 t3bt>fC"l1.48 N /U ~ Z8.D5t1 W l~ 41 36.W5 GYD GC SS 50.00 0.58 191.85 -8.27 50.00 -0.02 0.24 0.24 -0.24 -0.OS 1.12 6031111.07 859822.45 N 70 29 29.548 W 148 41 38.008 100.00 0.89 175.85 43.73 100.00 0.02 0.79 0.78 -0.78 -0.08 0.43 8031110.53 659822.43 N 70 29 29.542 W 148 41 38.007 150.00 0.98 191.17 93.72 149.99 0.05 1.50 1.50 -1.49 -0.14 0.69 6031109.82 659822.39 N 70 29 29.535 W 148 41 38.009 200.00 0.99 178.52 143.71 199.98 0.09 2.35 2.34 -2.33 -0.19 0.50 6031108.97 659822.35 N 70 29 29.527 W 148 41 36.010 250.00 1.77 132.78 193.70 249.97 0.80 3.50 3.31 -3.29 0.40 2.51 6031108.03 859822.98 N 70 29 29.518 W 148 41 35.993 300.00 2.83 117.10 243.68 299.93 2.50 5.41 4.77 -4.33 1.99 2.08 6031107.02 859824.57 N 70 29 29.507 W 148 41 35.946 354.00 3.45 105.80 297.59 353.86 5.27 8.26 7.09 -5.34 4.66 1.87 6031106.07 859827.28 N 70 29 29.497 W 148 41 35.868 400.00 3.81 100.53 343.50 399.77 8.09 11.09 9.53 -5.98 7.41 0.79 6031105.49 859830.03 N 70 2929.491 W 148 4135.787 450.00 4.38 101.38 393.38 449.65 11.55 14.57 12.70 -6.65 10.82 1.50 6031104.90 659833.45 N 70 29 29.485 W 148 41 35.688 500.00 5.10 96.49 443.21 499.48 15.67 18.69 16.57 -7.27 14.89 1.88 6031104.36 659837.54 N 70 29 29.478 W 148 41 550.00 8.28 90.58 492.96 549.23 20.61 23.64 21.23 -7.55 19.84 2.63 6031104.19 859842.48 N 7029 29.476 W 148 41 1 800.00 7.89 88.59 542.58 598.85 28.72 29.81 27.06 -7.49 28.00 3.26 6031104.38 859848.65 N 70 29 29.478 W 148 41 35.240 850.00 9.48 88.89 592.00 848.27 34.16 37.35 34.30 -7.19 33.54 3.18 6031104.85 659858.17 N 70 29 29.479 W 148 41 35.018 715.00 11.85 85.46 855.88 712.15 45.96 49.36 45.97 -6.37 45.53 3.70 6031105.92 859888.14 N 70 29 29.487 W 148 41 34.685 806.00 14.03 88.64 744.58 800.83 65.97 69.74 68.04 -4.98 65.85 2.41 8031107.74 659888.43 N 70 29 29.501 W 148 41 34.067 900.00 15.75 89.84 835.41 891.88 89.84 93.89 90.09 -4.28 89.99 2.03 6031108.97 859912.54 N 70 T9 29.508 W 148 41 33.357 998.00 18.43 94.71 927.65 983.92 118.33 120.48 118.67 -5.38 118.55 1.57 6031108.46 659939.12 N 70 29 29.497 W 148 41 32.575 Last (3YD GC SS 1089.00 18.83 95.40 1018.32 1072.59 144.33 148.49 144.68 -7.84 144.45 2.38 6031106.58 659987.06 N 70 2929.473 W 148 41 31.754 MWD+IF12 1213.93 25.38 100.03 1132.09 1188.36 191.07 195.25 191.28 -14.38 190.74 5.57 6031101.03 880013.48 N 70 29 29.408 W 148 41 30.392 MWD+IFR 1309.09 24.68 99.95 1218.32 1274.59 231.27 235.51 231.38 -21.37 230.39 0.74 6031094.90 680053.27 N 70 29 29.340 W 148 4129.225 First DAWD+IFR+MS 1400.85 24.90 100.82 1301.82 1357.89 289.68 273.98 269.72 -28.31 268.23 0.46 8031088.78 860091.25 N 70 29 29.272 W 148 41 28.111 1498.11 28.38 99.88 1387.51 1443.78 310.82 315.19 310.83 -35.63 308.78 1.62 6031082.33 680131.94 N 70 29 29.200 W 148 41 26.918 1590.25 30.30 98.30 1470.38 1526.83 355.46 359.84 355.48 -41.75 353.00 4.52 8031077.16 880178.28 N 70 29 29.139 W 148 4125.617 1686.98 34.35 95.68 1552.08 1808.35 407.16 411.56 407.17 -47.13 404.44 4.20 6031072.89 880227.82 N 70 29 29.086 W 148 41 24.103 SunreyEditor Ver SP 1.0 Bld( doc40x_56) NS30\NS30\NS30\NS30 Generated 5/5/2008 7:37 AM Page 1 of 5 Commtrd: ~ ludlmtlOn A~nMAth Sut-Sa TVD iVD VSeetl~on ADe~pgtrh~ro Cloture NS EW OLS NoRhMg EtstMg Ltdtudt ~ongNud~ h h h h R h R h d 100 h hUS hUS ..w.ac ~a.~-. av.co ~oco.a, ivas.,a voc.ai goi.~~ qa[.y[ -~~.M[i 4~8.rr 5.z8 t1U31Uti7.24 660283.28 N702929.019 W 1484122.475 1878.38 43.02 99.39 1898.58 1754.85 525.25 529.68 525.25 -83.56 521.39 4.26 6031058.98 880345.09 N 70 29 28.925 W 148 4120.882 1969.80 46.02 99.68 1765.78 1822.05 591.26 595.76 591.27 -74.51 586.55 3.19 8031049.43. 660410.47 N 7029 28.817 W 148 41 18.744 2064,27 49.95 99.79 1829.13 1885.40 681.51 666.08 661.53 -86.40 855.88 4,15 6031039.03 680480.01 N 70 29 28.700 W 148 41 16.704 2158.50 53.25 100.32 1887.65 1943.92 735.24 739.92 735.30 -99.30 728.57 3.53 6031027.70 660552.97 N 70 29 28.573 W 148 41 14.565 2251.45 53.30 100.23 1943.23 1999.50 809.62 814.42 809.74 -112.59 601.87 0.09 6031015.99 860626.54 N 70 29 28,442 W 148 41 12.408 2348.78 52.69 100.03 2001.82 2058.09 887.23 892.14 887.41 -126.26 878.39 0.65 6031003.97 660703.32 N 70 29 28.308 W 148 41 10.156 2441.92 55.63 100.01 2058.35 2112.82 962.62 967.64 962.87 -139,39 952.73 3.16 6030992.44 660777.93 N 70 29 28.178 W 148 41 7.969 2538.00 54.44 101.15 2110.26 2166.53 1039.57 1044.73 1039.91 -153.54 1028.52 1.61 6030979.92 680853.99 N 70 29 28.039 W 148 41 5.739 2631.93 55.38 99.95 2165.41 2221.68 1117.91 1123.23 1118.36 -167.91 1105.88 1.42 6030967.22 660931.44 N 7029 27.898 W 148 41 3.488 2728.75 2821.28 55.18 55.79 100.27 98.08 2219.41 2272.97 2275.68 2329.24 1185,73 1273.54 1201.16 1279.03 1196.27 1274.13 -181.59 -194.00 1182.41 1259.28 0.35 2.02 6030955.19 6030944.43 661008.44 661085.58 N 70 2927.763 W 148 4 N 70 29 27.841 W 148 40 2917.25 55.65 98.00 2327.04 2383.31 1352,84 1358.35 1353.44 -205.10 1337.81 0.16 6030935.03 661184.31 N 7029 27.532 W 14840 56.637 3011.89 55.82 98.15 2380.32 2436.59 1431,05 1436.57 1431.65 -216.08 1415.25 0.22 6030925.71 661241.98 N 702927.424 W 14840 54.358 3108.00 54.01 97.15 2434.41 2490.68 1508,05 1513.57 1508.65 -226,34 1491.57 2.11 6030917.10 661318.47 N 70 29 27.322 W 148 40 52.113 3201.11 53.64 97,43 2490.55 2546.82 1584.82 1590.35 1585.40 -238.08 1567.73 0.46 6030909.00 661394.81 N 70 29 27.227 W 148 40 49.872 3298.62 55.59 97.55 2545.85 2802.12 1662.68 1668.21 1663.25 -246.23 1844.93 2.04 6030900.51 661472.21 N 70 29 27.127 W 14840 47.800 3390.27 57.48 97.70 2597.49 2853.76 1740.80 1746.33 1741.37 -256.80 1722.36 2.02 6030891.81 661549.84 N 70 29 27.024 W 1484045.32'1 3484.28 56.72 96.77 2646.56 2704.83 1819.73 1825.26 1820.28 -266.54 1800.66 1.16 6030883.55 661628.33 N 70 29 26.926 W 14840 43.018 3576.79 56.58 95.92 2699.42 2755.69 1897.00 1902.54 1897.51 -275.08 1877.46 0.78 6030876.66 661705.29 N 70 29 26.842 W 14840 40.758 3674.03 54.45 98.36 2754.47 2810.74 1977.14 1982.69 1977.60 -283.65 1957.15 2.22 6030869.81 681785.14 N 70 29 26.758 W 14840 38.413 3789.16 55.59 97.19 2809.01 2865.28 2055.08 2060.63 2055.51 -292.85 2034.55 1.40 6030862.28 661862.71 N TO 29 26.867 W 14840 38.135 3862.93 56.69 97.48 2881.25 2917.52 2132.94 2138.49 2133.37 -302.79 2111.77 1.20 6030854.00 661940.13 N 70 29 26.569 W 14840 33.863 3958.91 56.90 98.09 2913.81 2970.08 2213.24 2218.80 2213.68 -313.67 2191.34 0.58 6030844.83 662019.91 N 7029 26.462 W 14840 31.521 4053.53 54.48 97.46 2967.14 3023.41 2291.38 2296.96 2291.83 -324.25 2288.78 2.61 6030835.92 662097.55 N 70 29 26.358 W 148 40 29.243 4147.82 52.56 97.08 3023.19 3079.46 2387.20 2372.77 2367.64 -333.85 2343.98 2.07 6030827.94 662172.94 N 70 29 26.263 W 14840 27.030 4243.18 53.79 95.71 3080.34 3136.61 2443.53 2449.10 2443.93 -342.34 2419.84 1.73 6030821.08 662248.95 N 70 29 26.179 W 14840 24.798 4339.07 54.31 96.65 3136.84 3192.91 2521.14 2526.73 2521.52 -350.70 2497.01 0.96 6030814.38 662326.28 N 70 2926.097 W 14840 22.527 4392.28 53.53 98.76 3187.98 3224.25 2564.15 2569.73 2564.51 -355.72 2539.72 1.48 6030810.28 662369.08 N 702926.047 W 14840 4458.86 53.12 98.76 3207.74 3284.01 2817.55 2623.13 2617.90 -362.01 2592.75 0.62 6030805.14 662422.23 N 70 29 25.985 W 14840 4552.75 54.04 97.55 3263.49 3319.76 2693.10 2698.68 2693.44 -371.42 2667.71 1.19 6030797.34 662497.37 N 7029 25.892 W 1484017.504 4648.83 54.61 97.42 3319.40 3375.67 2770.98 2776.57 2771.32 -381.57 2744.93 0.60 6030788.86 682574.79 N 70 29 25.792 W 1484015.232 4741.88 54.29 97.01 3373.62 3429.89 2846.85 2852.44 2847.19 -391.10 2820.20 0.50 6030780.95 662650.24 N 70 29 25.698 W 1484013.017 4835.78 55.53 96.80 3427.80 3483.87 2923.68 2929.27 2924.01 -400.33 2896.47 1.33 6030773.36 662726.69 N 70 29 25.607 W 1484010.773 4929.16 56.32 96.88 3479.91 3538.18 3001.03 3008.82 3001.34 -409.54 2973.27 0.85 6030765.80 662803.68 N 70 29 25.516 W 148 40 8.513 5021.99 58.40 96.95 3531.34 3587.61 3078.31 3083.90 3078.62 -418.85 3049.99 0.11 6030758.14 662880.56 N 7029 25.425 W 14840 6.256 5119.38 58.58 97.83 3585.11 3641.38 3159.49 3165.08 3159.79 -429.15 3130.51 0.60 6030749.58 862981.27 N 7029 25.323 W 14840 3.887 5213.81 58.68 97.56 3637.06 3893.35 3238.35 3243.95 3238.86 -439.57 3208.89 0.14 6030740.84 663039.85 N 70 29 25.220 W 148401.588 5308.72 58.56 98.25 3689.30 3745.57 3317.59 3323.20 3317.91 -450.47 3287.19 0.62 6030731.63 863118.36 N 7029 25.113 W 14839 59.278 5405.07 58.33 98.86 3742.55 3798.82 3397.86 3403.49 3398.20 -462.28 3366.61 0.43 6030721.53 663198.01 N 7029 24.996 W 148 39 56.940 5500.92 55.80 98.77 3798.08 3852.33 3477.35 3483.02 3477.71 -474.33 3445.22 0.56 6030711.18 663276.85 N 7029 24.877 W 148 39 54.627 5594.45 55.37 98.92 3848.92 3905.19 3554.47 3560.18 3554.86 -486.19 3521.46 0.48 6030700.96 683353.33 N 70 29 24.760 W 14839 52.383 5687.92 55.33 98.15 3902.07 3958.34 3831.33 3637.07 3631.75 -497.60 3597.50 0.68 6030691.18 663429.59 N 70 29 24.648 W 14839 50.146 5784.53 55.90 98.36 3956.63 4012.90 3711.04 3716.80 3711.47 -509.05 3676.40 0.62 6030681.43 663508.71 N 70 29 24.535 W 148 39 47.824 SurveyEdRor Ver SP 1.0 Bid( doc40x_56) NS30\NS30\NS301NS30 Generated 5/5/2006 7:37 AM Page 2 of 5 Co~anlnb d ~ bdlnatlon ~~ Sut-SeaTVD TVD Vertkal Seaton AlongNole Departure Closure NS EW DLS Northing EastMg Latlhide t.onpRude R R R R R R R R d 100 R RUS RUS w~v.~v w.aV aV.JV TIVa.VJ TIVJ.JV 'J/00.JY J/DY.JI J(00..7.7 -VLV.LO J/.7J.IV V,IV OVJVO/ 1.0.7 OOJ.70.7.W n /V (Y (4,4(4 W 14tl JM 4D.~l'i8 5970.90 55.72 98.85 4081.12 4117.39 3885.31 3871.11 3865.78 -531.60 3829.08 0.42 6030662.17 883881.81 N 70 29 24.312 W 148 3943.333 8084.48 55.68 98.14 4113.85 4170.12 3942.58 3948.40 3943.07 -542.88 3905,52 0.45 8030852.54 883738.49 N 70 29 24.201 W 148 39 41.083 8158.89 55.92 97.87 4188.81 4223.08 4020.50 4026.34 4021.01 -553.74 3982.70 0.35 6030643.34 883815.88 N 70 29 24.094 W 148 39 38.812 6254.33 58.03 97.98 4220.33 4278.80 4099.78 4105.80 4100.27 -564.67 4081.20 0.15 6030834.11 883894.80 N 70 2923.986 W 14839 38.502 6349.98 58.01 97.53 4273.78 4330.05 4179.05 4184.90 4179.57 -575.37 4139.78 0.39 6030625.10 883973.38 N 70 29 23.880 W 148 39 34.190 6445.02 58.14 97.83 4328.83 4383.10 4257.93 4263.78 4258.45 -585.77 4217.97 0.18 6030616.38 684051.77 N 70 29 23.777 W 148 39 31.890 8541.38 55.58 97.74 4380.92 4437.19 4337.67 4343.53 4338.19 -596.43 4297.00 0.81 8030607.41 664131.00 N 7029 23.872 W 14839 29.585 6838.58 54.97 97.88 4435.17 4491.44 4415.89 4421.76 4416.43 -807.07 4374.50 0.63 8030598.45 664208.71 N 70 29 23.567 W 14839 27.284 8733.87 54.88 97.22 4490.97 4547.24 4495.34 4501.21 4495.87 -817.50 4453.26 0.57 6030589.71 884287.87 N 7029 23.464 W 14839 7 6827.25 54.73 97.24 4544.92 4801.19 4571.80 4577.67 4572.33 -627.13 4529.12 0.14 6030581.72 884383.71 N 70 29 23.369 W 148 39 8923.99 54.87 97.31 4800.89 4658.98 4850.85 4858.72 4651.38 -637.14 4607.53 0.18 8030573.40 664442.32 N 70 29 23.270 W 148 39 20.428 7019.02 54.98 96.83 4855.31 4711.58 4728.81 4734.49 4729.13 -846.71 4884.71 0.42 8030585.49 684519.87 N 70 29 23.175 W 148 3918.157 7112.45 54.94 98.88 4708.97 4785.24 4805.10 4810.97 4805.61 -655.84 4780.84 0.05 8030557.99 684595.78 N 70 29 23.085 W 148 3915.923 7208.03 54.50 97.31 4784.17 48'10.44 4883.12 4889.00 4883.83 -665.47 4838.07 0.59 6030550.03 664873.40 N 70 29 22.990 W 148 3913.645 7303.43 54.27 96.78 4819.73 4878.00 4980.68 4966.55 4961.17 -674.99 4915.04 0.51 6030542.17 664750.55 N 70 29 22.898 W 148 3911.380 7398.98 54.22 97.15 4875.55 4931.82 5038.20 5044.08 5038.69 -884.39 4991.99 0.32 6030534.43 684827.68 N 70 29 22.803 W 148 39 9.118 7494.21 54.10 97.83 4931.32 4987.59 5115.41 5121.29 5115.90 -694.45 5088.55 0.59 6030526.01 684904.43 N 7029 22.703 W 148 39 8.863 7589.48 54.49 99.18 4988.92 5043.19 5192.75 5198.65 5193.26 -705.88 5145.06 1.21 6030516.23 684981.18 N 70 29 22.590 W 148 39 4.812 7882.33 54.83 98.77 5040.83 5098.90 5288.44 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148 3848.598 8440.47 54.81 97.04 5474.78 5531.03 5889.72 5895.92 5890.38 -808.68 5834.89 0.76 6030430.29 885872.94 N 7029 21.594 W 14838 7 8532.32 54.78 98.85 5527.71 5583.98 5984.77 5970.97 5965.42 -815.75 5909.39 0.17 6030422.82 885747.81 N 70 29 21.504 W 148 38 8828.31 54.89 96.60 5581.98 5638.25 8041.51 8047.71 8042.15 -824.74 5985.80 0.24 6030415.47 685824.00 N 70 29 21.415 W 148 38 8721.11 54.73 94.93 5838.75 5893.02 8118.87 6125.09 6119.48 -832.51 6082.58 1.44 6030409.36 685901.12 N 70 29 21.338 W 148 38 37.817 8814.98 54.79 94.31 5890.92 5747.19 8195.47 6201.77 8196.03 -838.69 8139.01 0.54 6030404.83 885977.86 N 70 29 21.277 W 148 38 35.369 8909.90 55.05 93.80 5745.48 5801.73 8273.03 8279.44 6273.53 -844.04 8218.49 0.67 6030401.14 666055.23 N 70 29 21.224 W 148 38 33.089 9001.75 55.02 93.48 5798.10 5854.37 8348.17 6354.71 6348.60 -848.69 8291.82 0.11 8030398.11 868130.44 N 70 29 21.177 W 148 38 30.879 9098.28 55.38 93.41 5853.19 5909.48 6427.25 6433.95 6427.83 -853.45 6370.72 0.36 6030395.05 688209.81 N 70 29 21.130 W 148 38 28.551 9190.82 55.50 94.31 5905.71 5981.98 8503.35 6510.16 6503.68 -858.58 6448.76 0.81 6030391.55 888285.74 N 70 29 21.079 W 14838 28.314 9287.78 55.51 94.37 5980.63 8018.90 8583.18 6580.08 8583.47 -864.63 8528.44 0.05 6030387.22 666385.53 N 70 29 21.018 W 148 38 23.970 9383.58 55.32 94.24 8014.99 8071.28 6681.94 6688.93 8662.20 -870.55 8805.07 0.23 6030382.99 888444.27 N 70 29 20.980 W 148 38 21.856 9477.95 55.10 93.55 8088.85 8125.12 8739.35 8746.45 6739.56 -875.82 8882.41 0.64 8030379.39 668521.69 N 70 29 20.907 W 148 3819.381 9574.37 54.75 94.15 8124.28 8180.53 8818.14 8825.36 6818.31 -881.11 8761.14 0.83 6030375.79 886800.52 N TO 29 20.854 W 148 3817.064 9887.45 54.89 93.85 8178.02 6234.29 6894.02 6901.34 6894.17 -886.41 6838.94 0.27 8030372.12 866678.41 N 70 29 20.801 W 148 3814.834 9760.84 54.43 93.17 8232.08 6288.33 8969.80 8977.27 8969.92 -891.06 8912.72 0.86 8030369.10 688752.28 N 70 29 20.755 W 148 3812.604 9857.12 54.09 93.04 8288.41 8344.88 7047.93 7055.58 7048.01 -895.31 8990.92 0.37 6030366.54 668830.53 N 70 29 20.713 W 148 3810.304 SurveyEditor Ver SP 1.0 Bid( doc40x_56) NS30\NS30\NS301NS30 Generated 5/5/2006 7:37 AM Page 3 of 5 Comnalks McNR+don IslmuM SutrSa i'VD 1YD S~ ~ rt~ Closuro NS EW DLS Northing Eutlnp LrtRud~ Lggkud~ R ene• e~ ~. ..~ wn .., R ew.w ~ .. R ........ .... h ---• -- R ---• R R R d 100 R RUS RUS ~_~ ..~~ 10048.42 ~ ..~~ 53.96 ~~.~-. 93.67 wT.. ~ 6399.60 wwv.rr 8455.87 • fa-r.vv 7200.79 f f.s I.V f 7208.78 f Icy. f V 7200.83 v.~a.•fJ -903.85 f W(. I V 7143.88 V.W 0.54 VVJVJV'!. IJ 6030361.28 gpppVp./ ( 686983.62 1\ /Y {y {V.O/{ YY 798 38 B.UOL N 702920.627 W 14838 5.803 10142.30 54.30 93.46 6455.79 6512.06 7278.34 7286.47 7278.37 -908.68 7221.42 0.40 6030358.12 667061.25 N 70 29 20.579 W 148 38 3.522 10238.28 55.25 92.83 6511.15 8567.42 7356.57 7364.88 7358.58 -912.98 7299.71 1.13 6030355.50 867139.60 N 70 2920.536 W 148 381.218 10332.20 55.96 93.05 6564.20 8620.47 7433.87 7442.38 7433.88 -916.96 7377.11 0.78 6030353.19 667217.06. N 7029 20.496 W 148 37 58.941 10426.23 55.81 92.57 6617.07 6673.34 7511.42 7520.13 7511.42 -920.77 7454.77 0.56 6030351.05 667294.78 N 70 29 20.458 W 148 37 56.656 10522,10 54.92 92.57 6671.70 6727.97 7589.97 7598.92 7589.97 •924.30 7533.48 0.72 6030349.21 687373.54 N 70 29 20.422 W 148 37 54.340 10617.53 53.89 91.39 6727.24 6783.51 7667.26 7676.51 7667.27 -926.99 7611.02 1.48 6030348.19 667451.13 N 70 29 20.395 W 148 37 52.059 10719.34 53.31 92.35 6784.10 6840.37 7744.07 7753.63 7744.08 -929.50 7688.10 1.01 6030347.33 667528.23 N 70 2920.370 W 148 37 49.791 10808.34 52.96 93.19 6839.89 6896.16 7818.27 7828.03 7818.30 -933.10 7762.42 0.81 6030345.34 667602.80 N 70 29 20.333 W 148 37 10901.68 52.92 93.59 6897.35 6953.62 7894.20 7904.12 7894.24 -937.60 7838.36 0.34 6030342.47 667678.62 N 70 29 20.288 W 148 37 10993.53 52.85 94.68 8952.78 7009.05 7967.35 7977.36 7967.40 -942.88 7911.41 0.95 6030338.76 867751.77 N 70 29 20.236 W 148 37 11089.91 52.95 95.13 7010.91 7067.18 8044.17 8054.23 8044.23 -949.45 7988,00 0.39 6030333.84 667828.47 N 70 29 20.170 W 148 37 40.967 11184.42 53.03 95.66 7067.80 7124.07 8119.60 8129.70 8119.68 -956.55 8063.14 0.46 6030328.36 667903.74 N 70 29 20.100 W 148 37 38.757 11277.56 53.52 98.67 7123.50 7179.77 8194.25 8204.35 8194.33 -964.56 8137.36 1.02 6030321.94 867978.11 N 70 29 20.020 W 148 37 36.573 11372.03 53.78 98.06 7179.49 7235.76 8270.33 8280.44 8270.41 -973.00 8212.98 0.59 6030315.13 668053.88 N 70 2919.936 W 148 37 34.348 11468.95 53.44 95.90 7236.99 7293.26 8348.34 8358.46 8348.42 -981.13 8290.57 0.38 6030308.67 668131.63 N 70 2919.855 W 148 37 32.085 11562.89 53.16 96.40 7293.14 7349.41 8423.65 8433.78 8423.74 -989.20 8365.46 0.52 6030302.22 668206.66 N 70 2919.775 W 148 37 29.862 11658.17 52.82 96.03 7350.49 7408.76 8499.72 8509.86 8499.82 -997.43 8441.09 0.47 6030295.61 668282.45 N 70 2919.893 W 148 37 27.637 11753.29 52.43 95.57 7408.23 7464.50 8575.30 8585.45 8575.40 -1005.07 8516.29 0.56 6030289.59 668357.80 N 70 2919.617 W 148 37 25.425 11849.05 51.89 96.55 7466.98 7523.25 8650.91 8661.07 8651.01 -1013.05 8591.49 0.99 6030283.23 668433.15 N 70 2919.538 W 148 37 23.212 11943.54 51.21 97.73 7525.73 7582.00 8724.90 8735.07 8725.01 -1022.25 8664.92 1.21 6030275.61 668506.75 N 70 2919.447 W 148 37 21.052 12039.87 50.11 98.60 7588.80 7843.07 8799.39 8809.57 8799.49 -1032.82 .8738.66 1.34 6030266.63 668580.70 N 70 2919.342 W 148 37 18.883 12135.00 49.29 98.71 7848.33 7704.60 8871.91 8882.12 8872.00 -1043.74 8810.39 0.87 6030257.25 668652.63 N 70 2919.234 W 148 3718.773 12230.60 48.23 99.33 7711.35 7767.62 8943.75 8954.01 8943.83 -1055.01 8881.39 1.21 6030247.51 668723.85 N 70 2919.122 W 148 37 14.684 12324.63 46.88 99.81 7774.81 7831.08 9013.07 9023.39 9013.13 -1066.54 8949.81 1.48 6030237.46 668792.50 N 70 2919.008 W 148 3712.671 12418.16 45.64 99.65 7839.47 7895.74 9080.56 9090.97 9080.62 -1077.96 9016.41 1.33 6030227.47 668859.32 N 70 2918.895 W 148 3710.712 12511.87 44.51 98.85 7905.65 7961.92 9146.86 9157.31 9146.90 -1088.63 9081.89 1.35 6030218.21 688925.02 N 70 2918.789 W 148 37 8.786 12806.92 43.84 98.18 7973.93 8030.20 9212.95 9223.43 9212.99 -1098.42 9147.28 1.04 6030209.83 668990.59 N 70 2918.892 W 148 3 12702.59 42.45 97.73 8043.85 8100.12 9278.24 9288.73 9278.28 -1107.46 9211.95 1.28 6030202.18 669055.44 N 70 2918.602 W 148 37 12798.55 42.11 98.04 8113.37 8169.84 9341.45 9351.94 9341.48 -1116.14 9274.56 0.42 6030194.86 669118.22 N 70 2918.516 W 148 37 3.118 12890.57 41.28 98.48 8183.57 8239.84 9403.97 9414.48 9404.00 -1125.12 9336.45 0.94 6030187.21 669180.29 N 70 2918.427 W 148 371.297 12985.01 41.16 99.53 8254.61 8310.88 9466.16 9476.71 9466.19 -1134.86 9397.91 0.74 6030178.79 669241.94 N 70 2918.331 W 148 36 59.489 13076.90 44.65 99.55 8323.53 8379.80 9526.88 9537.48 9526.90 -1144.93 9457.85 0.53 6030170.01 669302.07 N 70 2918.231 W 148 36 57.726 13172.44 41.85 98.84 8384.81 8451.08 9590.45 9601.10 9590.46 -1155.09 9520.65 0.54 6030161.20 869365.07 N 70 2918.130 W 148 36 55.879 13266.52 41.53 98.00 8465.06 8521.33 9653.00 9663.67 9653.01 -1164.26 9582.54 0.68 6030153.37 669427.14 N 70 2918.039 W 148 36 54.058 13358.86 40.76 98.51 8533.09 8589.36 9712.43 9723.11 9712.44 -1172.79 9841.37 0.93 6030146.10 669486.13 N 70 2917.954 W 14838 52.327 13457.35 39.88 99.40 8609.71 8865.98 9777.41 9788.14 9777.42 -1182.91 9705.60 1.05 6030137.37 869550.56 N 70 2917.854 W 148 36 50.438 13552.36 39.07 100.25 8883.05 8739.32 9837.74 9848.54 9837.74 -1193.21 9765.11 1.02 6030128.35 669810.28 N 70 2917.752 W 14836 48.687 13847.91 38.09 100.25 8757.74 8814.01 9897.23 9908.12 9897.23 -1203.81 9823.75 1.03 6030119.01 669669.12 N 70 2917.647 W 148 36 48.963 13743.56 38.83 100.93 8833.67 8869.94 9955.29 9966.29 9955.29 •1214.50 9880.93 1.39 6030109.56 669726.52 N 70 2917.541 W 148 36 45.280 13836.92 35.42 101.09 8909.08 8965.35 10010.19 10021.33 10010.19 -1225.01 9934.95 1.51 6030100.21 669780.75 N 70 2917.437 W 14836 43.691 13929.97 34.93 99.96 8985.14 9041.41 10063.69 10074.94 10063.70 -1234.80 9987.65 0.88 6030091.55 669833.65 N 70 2917.340 W 148 36 42.141 SurveyEdttor Ver SP 1.0 Bid( doC40x_56) NS30\NS30\NS301NS30 Generated 5/5/2006 7:37 AM Page 4 of 5 Cata~erda ~ MteNtntlon Arlnndh Sub~SeaTt+D 1YD ~~ AtHpaturoe Closure NS EW DLS Northing Eaethig Latitude LongnuM n d n n n n n n n too n nus nus rwcr.va a~.ao ~w..ay auoy.a i a it ~. io w ~ 70.aq w73u.to lu ~ ~a.aw - ~owa.aa ~ VV9t.lt V.94 oV3WOL.a0 ooaoo8.3U rv N to 1 /.t44 W l46 J6 4U.~3lJ 14121.99 34.10 100.15 9143.31 9199.58 10172.40 10183.81 10172.40 -1254.08 10094.80 0.50 6030074.59 669941.18 N 70 2917.149 W 148 38 38.989 14214.88 33.83 100.30 9220.18 9276.45 10224.10 10235.59 10224.11 -1263.27 10145.77 0.31 6030066.49 669992.32 N 70 2917.058 W 148 36 37.490 14308.64 33.55 99.75 9298.36 9354.83 10276.15 10287.71 10276.16 -1272.34 10197.09 0.44 6030058.53 670043.83 N 70 2918.968 W 14836 35.981 14583.88 27.93 98.02 9534.84 9591.11 10416.68 10428.33 10416.71 -1294.23 10335.99 2.07 6030039.63 670183.16 N 70 2916.751 W 148 36 31.895 14679.31 26.18 95.11 9619.83 9676.10 10460.07 10471.73 10460.10 -1299.23 10379.10 2.30 6030035.56 670226.36 N 70 2916.701 W 148 36 30.627 14774.22 24.46 91.91 9705.62 9761.89 10500.57 10512.31 10500.59 -1301.75 10419.59 2.32 6030033.91 670266.89 N 70 2916.676 W 148 36 29.435 14868.56 24.52 90.39 9791.47 9847.74 10539.47 10551.42 10539.49 -1302.53 10458.69 0.67 6030033.97 670306.00 N 70 2916.668 W 148 36 28.285 14958.76 25.21 94.52 9873.32 9929.59 10577.26 10589.33 10577.27 -1304.17 10496.56 2.07 6030033.14 670343.89 N 70 2916.651 W 148 36 27.171 15058.78 25.65 96.27 9963.65 10019.92 10620.19 10632.28 10620.20 -1308.22 10539.31 0.87 6030030.02 670386.72 N 70 2916.611 W 148 36 25.913 15147.70 25.79 95.50 10043.76 10100.03 10658.77 10670.86 10658.78 -1312.17 10577.70 0.41 6030026.89 670425.18 N 70 2916.571 W 148 36 15241.27 28.16 94.00 10127.88 10184.15 10699.72 10711.84 10699.72 -1315.56 10618.54 O.Sf 6030024.38 670466.07 N 70 2916.537 W 148 36 15337.12 26.39 92.94 10213.82 10270.09 10742.06 10754.27 10742.07 -1318.13 10660.89 0.55 6030022.72 670508.47 N 70 2916.511 W 148 36 22.336 15431.41 25.55 92.19 10298.59 10354.86 10783.23 10795.56 10783.23 -1319.98 10702.14 0.96 6030021.76 670549.74 N 70 2916.493 W 148 36 21.123 15526.93 25.52 92.04 10384.78 10441.05 10824.25 10836.74 10824.25 -1321.50 10743.28 0.07 6030021.12 670590.91 N 70 2916.477 W 148 3619.912 15621.24 25.52 91.14 10489.89 10526.16 10864.70 10877.37 10864.70 -1322.63 10783.90 0.41 6030020.87 670631.54 N 70 2918.465 W 148 3818.717 15714.29 25.54 90.58 10553.86 10810.13 10904.57 10917.47 10904.58 -1323.23 10823.99 0.26 6030021.13 670671.64 N 70 2916.459 W 148 3817.538 15804.20 25.47 90.76 10635.00 10891.27 10943.05 10956.18 10943.06 -1323.68 10862.71 0.12 6030021.51 670710.34 N 70 2918.454 W 148 3618.399 15956.52 25.45 94.17 10772.54 10828.81 11008.30 11021.65 11008.31 -1326.50 10928.10 0.96 6030020.10 670775.78 N 70 2916.425 W 148 3614.475 16050.98 22.40 96.13 10858.87 10915.14 11046.58 11059.95 11046.59 -1329.89 10966.25 3.34 6030017.52 670813.99 N 70 2916.391 W 148 3613.353 16148.27 19.43 97.62 10949.74 11006.01 11081.30 11094.87 11081.32 -1334.02 11000.72 3.10 6030014.14 670848.54 N 70 2916.350 W 148 36 12.338 16240.24 18.16 98.89 11036.81 11093.08 11110.92 11124.30 11110.94 -1338.21 11030.06 1.43 6030010.58 670877.96 N 70 2916.309 W 148 3611.476 Last MWD+IFR+MS 18277.70 17.79 98.41 11072.44 11128.71 11122.48 11135.86 11122.49 -1339.93 11041.49 1.01 6030009.10 670889.42 N 70 2916.292 W 148 36 11.139 MWD+IFR 16356.21 16.54 100.83 11147.45 11203.72 11145.62 11159.03 11145.63 -1343.79 11064.33 1.83 6030005.74 670912:34 N 70 2916.253 W 148 3610.467 TD (Projected) 16398.00 16.54 100.83 11187.51 11243.78 11157.49 11170.93 11157.50 -1346.02 11076.01 0.00 6030003.76 670924.07 N 70 2916.231 W 148 3610.124 8urvay Type: Deflnithre 8utvey NOTES: OYD (iC S8 • (Oyrodata -gyro single shots » tiyrodata gyro orientation surveys. Not to be run above 70 degrees Inclination. ) MWD + IFR • (MWD t IFR correction » Infield referenced MWD with Nme-varying field applied. Model is applicable whether or not Short Collar type eorroction Is applied. Assumes a BHA sag correction is applied to enhance Inclination accuracy.) MWD+IFR-M8 - (In-field referenced MWD with multatsNon analysis and correction applied in post-processing. • Assumes a BHA sag correction K applied to enhance Incli nation accuracy. ) Lestal Descriction: Northing (lr1 [ftU3] Easting (x) [ftUS] Surface : 1338 FSL 649 FEL S11 T13N R13E UM 6031111.31 659822.49 BHL : 5264 FSL 44 FEL S18 T13N R14E UM 6030003.76 670924.07 SurveyEditor Ver SP 1.0 Bld( doc40x_56) NS30\NS30\NS301NS30 Generated 5/5/2006 7:37 AM Page 5 of 5 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: NS30 Common Name: NS30 Test Date Test Type Test Depth (TMD) Teat Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 2/14/2006 FIT 4,480.0 (ft) 3,277.0 (ft) 8.60 (ppg) 670 (psi) 2,134 (psi) 12.54 (ppg) 3/2/2006 FIT 14,569.0 (ft) 9,573.0 (ft) 12.30 (ppg) 1,090 (psi) 7,207 (psi) 14.49 (ppg) 3/14/2006 FIT 15,877.0 (ft) 10,780.0 (ft) 9.20 (ppg) 1,300 (psi) 6,452 (psi) 11.52 (ppg) PfIRtBtl: 4l14IZ1706 11:11:4F3 AM Date: OS-OS-2006 Transmittal Number:92778 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 Lo Run To De th Bottom De th Lo T e NS30 03-17-2006 SCH 1-10 200 16398 RUVE VERTICAL COMPOSITE RECORDED NS30 03-17-2006 SCH 1-10 200 16398 MEASURED DEPTH COMPOSITE RECORDED NS30 03-17-2006 SCH 1-10 200 16398 TRUE VERTTCAL 2 INCH SCALE COMPOSITE NS30 03-17-2006 SCH 1-10 200 16398 MEASURED DEPTH 2 INCH SCALE COMPOSITE NS30 03-17-2006 SCH 329 16389 CD/ROM Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Howard Okland Ignacio Herrera Tim Ryherd Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 <''_.~~'~- ~J U.S. Department of the Inte~ Submit orfptnat ptus TrfREE copies, • OMB Control No. 1010-0141 Minerals Management Service (MMS) wtfh tNVEogoymaArad "PuWfc Mlo-mat/on.- OMB Approval Expires 8/31/2008 Application for Permit to Drill (APD) 1. PROPOSAL TO DRILL 2. MMS OPERATOR NO. 3. OPERATOR NAME and ADDRESS X^ NEW WELL ^ SIDETRACK ^ BYPASS ^ DEEPEN 00113 (SubmHdng otRce) 4 WELL NAME (CURRENT 5 SIDETRACK NO CURRENT RR NT BP Exploration Alaska . ) NS30 . . ( ) ST00 8. BYPASS NO. (CU ) E BP00 PO BOx 196612 AK Anchorage 7. PROPOSED START DATE 8. PLAN CONTROL NO. (NEW WELL ONLY) , 99519-6613 January 18, 2006 9. AP1 WELL NO. (CURRENT SIDETRACK !BYPASS) (12 DIGITS) 10. ^ Revision ff feVIS10f1, 11. please list changes: WELL AT TOTAL DEPTH (PROPOSED) WELL AT SURFACE 12. LEASE NO. 17. LEASE NO. OCS-Y0181 ADL312799 13. AREA NAME 18. AREA NAME Beechey Point Beechey Point 14. BLOCK NO. 19. BLOCK NO. 516 515 15. LATITUDE 18. LONGITUDE 20. LATITUDE 21. LONGITUDE (® NAD 83 / ^ NAO 27) (® NAO 831 ^ NAD 27) (® NAD 831 ^JAD 27) (® NAD 83 / ^ NAD 27) LIST OF SIGNI FICANT MARK ERS ANTICIPATED 22. NAME 23. TOP (MD) 24. TOP (TVD) 22. NAME 23. TOP (MD) 24. TOP (TVD) Top of Ugnu 7207' 4760' Top of Kuparuk 14003' 9075' Top of Schrader Bluff 10118' 6470' Top Sag River 15890' 10744' 25. LIST ALL ATTACHMENTS (Attach complete well prognosis and attaclxnerds required by 30 CFR 250.414(b) through (g) or 30 CFR 250.1817 (c) and (d), as appropriate.) NS30 Well plan, NS30 Directional Survey, AOGCC Permft to Drill and MMS-123S form, Well completion schematic diagram. 28. CONTACT NAME 27. CONTACT TELEPHONE NO. 28. CONTACT E-MAIL ADDRESS Paul Hanson 564-4195 HanspS~bp.com 29. AUTHORIZING OFFICIAL (Type or print name) 30. TITLE Pat Archey Senior Drilling Engineer 31. A RIZI SIGNA RE 32. GATE TN/S SPACE FOR MMS USE ONLY APPROVED: .BY :TITLE ^ WMh Attadfed Carldftlons :GATE API WELL NO. ASSIGNED TO THIS WELL MMS FORM MMS-123 (October2005 -Supersedes all prevbus versions of form MMS-123 which may not be used.) Page 1 of 2 • • Application for Permit to Drill (APD) Information Sheet 33) Question Information Sheet Questions Response Remarks A) Will you maintain quantities of mud and mud ® YES material (including weight materials and additives) ^ NO sufficient to raise the entire system mud weight 1/2 ^ N/A ppg or more? ;rte -: f• a ~y ~ wR, ~,~ ,~~' ~;.R ;~''~ ,r. ~ ;' „ .,zj ~ ~ °r; B) If hydrocarbon-based drilling fluids were used, is ^ YES the drilling rig outfitted for zero discharge and will ^ NO zero discharge proc edures be followed? ® N/A +~~ C) If drilling the shallow casings strings riserless, will ^ YES you maintain kill weight mud on the rig and monitor ^ NO the wellbore with an ROV to ensure that it is not ® N/A flowing? ,y[y- 5~ ~~_~'yi(-~. :;.Y~~ , '~„""A~/ 4.--~~n ~ Y'7'1• F. $,~.~ iSS~'{,Y~. ~ .~+~ _~ ^f~Y _ x .h. r". D) If requesting a waiver of the conductor casing, ^ YES have you submitted a log to MMS G8G that is with ^ NO in 500 feet of the proposed bottom hole location for ® N/A the proposed surtace casing point? I ~~.:k' ~ ~ •• ,.t~ ,;'~ k - 'g.+T~ .: r-A ~. '.i, l.. i.~Y- Yr,. _, t .~ '~:~ r'~'+Af: ., ., _:, ;mac '~ Y,., (~ -iy,~ ~~iM' Fb, '~`~'_f J =~~ 'F,^-'~ E) Will the proposed operation be COVered by an ^ YES Att ' ~",~ 1NaS ~' "`~~ ~s Se S ~ d! sQoSz ( inlc ~ ~G G1 EPA Discharge Permit? (please provide permit ^ NO , 35 t~ a~o~v.a ~ s ~ number in remarks for this question) ® N/A ~l~ c ~~~L . u7~ ~~ V-0 e , ~ YES F) Will all wells in the well bay and related ^ NO production equipment be shut-in when moving on to or off of an offshore platform, or from well to well on ~ N/A the platform? If not, please explain. PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 et. seq.) requires us to inform you ihat we collect this information to obtain knowledge of equipment and procedures to be used in drilling operetions. MMS uses the information to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drifting operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may not conductor sponsor, and a person is not required to respond to, a oolledion of information unless k displays a currently valid OMB Control Number. Public reporting burden for this form, MMS-123, is estimated to average between 2.5-3 hours per response, depending on whether it is a paper submittal or electronic submittal. This includes the tirr>e for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Oirect comments regarding the burden estimate or any other aspect of this forth to the Information Collection Clearance Officer, Mail Stop 4230, Minerals Managemen! Service, 1849 C Street, NW, Washington, DC 20240. MMS Fonm MMS-123 (October2005 -supersedes an previous versior-s ~ roan MMS-123 which may not be used.) Page 2 of 2 U.S. Department ~ Interior Minerals Management Service Control No. 1010-0141 OMB Approval Expires 8/31/2008 Supplemental APD Information Sheet (Casing Design) 1 O rotor Name: BP lion Alaska Inc. 2 Well Name P : NS30 ST: 00 BP: 00 3 Bottom Hole Lease: OCS-YOt81 4 Surface Lease: ADL 312799 5 API Number. 6 T of Well: O ®Deve ant ~) X Absent QCnown Unknown 8) HZS Activation Plan Depth (1'VD) (ft): wA 9 R' Name: Nabors 33 E 10 Subsea BOP: DYes ®No 11 Water De ft : 39' 12 RKB He' ht ft :55.80' 13 Mineral Code: 14 Drive Pi Size in : 20' 15 Drive Pi De ft :200' 16 Yes ~No 17) Well Design Information Interval Number. One Type: t6• Name: Surface Section Number Casing Size (in) Casing Weight #/ft Casing Grade Burst Rating Collapse Rating (psi) Depth (ft) MD ND Pore Pressure si 1 13-3/8' 68# L-80 5024 2590 4467/3208 8.65 GENERAL INFORMA TION PREVENTE R INFORMATION TEST INFORMATION Hole Size in 16' T HYDRIL Annular Test si 3500 Mud We' ht 9.5 Size in 13.5/8' BOP/Diverter Test i 5000 Mud T Code WB Wellhead Rati i 5000 Mud Test Wei ht 9.5 Frac Gradient 13 Annular Ratin si 35~ Casi leer Test si 3376 Liner T De th ft Surface BOP/Diverter Kati i 5000 Formation Test 12.5 Cement Volume ft 3431 Interval Number. Two Type: 12-1/4' Name: Intermediate I Section Number Casing Size (in) Casing Weight (#/ft) Casing Grade Burst Rating (Psi) Collapse Rating (psi) Depth (ft) MD ND Pore Pressure (Psi) 2 9-5/8" 53.55 L-80 7927 6617 14573/9612 8.65 GENERAL INFORMAT ION PREVENTE R INFORMATION TEST INFORMATION Hole Size in 12-1/4' T H ril Annular Test si 3500 Mud Wei ht 10.5 Size in 13-5J8' BOP/D'rverterTest si 5000 Mud T Code WB Wellhead Rati i 5~ Mud Test Wei ht 10.5 Frac Gradient 15 Annular Rati si 3500 Casi 'her Test i 4624 Liner To De ft Surface BOP/Diverter Ratin i 5000 Formation Test 1a-t/2' Cement Volume ft 3391 Interval Number. Three Type: Drilling Liner Name: Intermediate II Secxion Number Casing Siz (in) Casing Weigh () Casing Grade Burst Rating (Psi) Collapse Rating (psi) Depth (ft) MD ND Pore Pressure (P~) 3 T 29# 1521 8160 7020 15897/tO9ot 8.95 GENERAL INFORMAT ION PREVENTE R INFORMATION TEST INFORMATION Hole Size in 9-1/2' T rii Annular Test i 3500 Mud We M 12 Size in 13-5/e' t30PlDiverter Test i 5000 Mud T Code WB Wellhead Rati '5000 Mud Test We' M 12 Frac Gradient t5 Annular Rati 3500 Casi 'her Test i 3983 Liner T th ft 14423 BOP/Diverter Rati 5000 Formation Test 14.5 Cement Volume ft 534 • NOTE' For edditlor-al casirtgl8rter Mtervals, please sutxMt an additional Form MMS-123S. PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 et. seq.) requires ~ b inform you that we oogect 8da information b obtain knowledge of equipmerN and procedures to be used in driNirrg operetions. MMS uses the kdortnatlon id evaluate and approve or disapprove the adequacy of the equipment arrdlor protxidures to safely perform the proposed driging operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency may rat conduct or sponsor. and a person is rat required to respond to, a collection of iMorrnation unless it displays a cwreMly vaNd OMB Control Nrxrrber. Pubbc reporting burden for tlus form. MMS-123S. is estimated to averege between 1-3 tours per response, depending on whether it is a paper subrr4ttal or electronic submittal. Tttis Includes the time for reviewing inshtrctions, gathering and maintaining data and oomple6rrp ~d reviewing ure forrrr. Direct comments regarding the burden estimate or any o8rer aspect of this forth to the Irrformadon ColbrAion Cleararae OlRoer, MaH Stop 4230. Minerals Management Service. 1849 C Street, NW, Washington. DC 20240. MMS Forth MMS-1235 (oa zoos . supe,sedes ~ prertous versbns a roan MMSt23S welch may rat be used.) Pe9e t a t U.S. Department ~ Interior Minerals Management Service Control No. 1010-0141 OMB Approval Expires 8/31/2008 Supplemental APD Information Sheet (Casing Design) 1 O rotor Name: BP Etgtloration Alaska Inc. 2 Well Name Pro : NS30 ST: 00 BP: 00 3 Bottom Hole Lease: OCS-YOt81 4 Surface Lease: ADL 312799 5 API Number: 6 T of Weil: O ~ Develo nt 7) HzS: X Absent ~(nown Unknown 8) H2S Activation Plan Depth (1'VD) (ft): N/A 9 Name: Nabors 33 E 10 Subsea BOP: oyes ®No 11 Water ft : 39' 12 RKB Hei ht ft :55.80' 13 Mineral Code: 14 Drive Pi Size in : 20• 15 Drive Pi De ft :200' 16 Anchors pYes ~No 17) Well Design Information Interval Number. Four Type: production Name: Production user SetXiort Number Casing Size (in) Casing Weight #/ft Casing Grade Burst Rating si Collapse Rating (psi) Depth (ft) MD TVD Pore Pressure si 4 4-1/2' 12.8# 13Cr-80 8430 7500 1635a/1t2as 8.95 GENERAL INFORMATION PREVENTER INFORMATION TEST INFORMATION Hole Size in 6' T HYDRIL Annular Test '3500 Mud We' ht 9.3 Size in 13-5/8' BOP/Diverter Test i 5000 Mud T Code WB Wellhead Rati '5000 Mud Test We' ht 9.3 Frac Gradient 15 Annular Rati i 3500 Casin 'ner Test si 3536 Liner T tit ft 15847 BOP/Diverter Rati '5000 Formation Test WA Cement Volume ft 113 Interval Number. Type: Name: Section Number Casing Size (in) Casing Weight (#/ft) Casing Grade Burst Rating (Psi) Collapse Rating (psi) Depth (ft) MD TVD Pore Pressure (psi) GENERAL INFORMA TION PREVENTE R INFORMATION TEST INFORMATION Hole Size in T Annular Test si Mud We' ht Size in BOP/Diverter Test i Mud T Code Wellhead Ratin si Mud Test Wei ht Frac Gradient Annular Rati i Casin 'ner Test si Liner T De ft BOP/Diverter Rati i Formation Test Cement Volume ft Interval Number. Type: Name: Sedbrt Number Casing S (in) Casing Weight () Casing Grade Burst Rating (Psi) Collapse Rating (psi) Depth (ft) MD TVD Pore Pressure (Psi) GENERAL INFORMA TION PREVENTE R INFORMATION TEST INFORMATION Hole Size in T Annular Test i Mud W ' ht Size n BOP/Drverter Test i Mud T Code Wellhead Rati i Mud Test We' ht Frac Gradient Annular Rati Corsi 'ner Test i Liner T th ft BOP/Diverter Rati Fomlation Test Cement Volume ft NOTE' For additional casktglNrrter intervals, please submit an additional Form MMS-123S. PAPERWORK REDUCTION ACT OF 1995 (PRA) STATEMENT: The PRA (44 U.S.C. 3501 et seq.) requires us to iMorm you that we ooller:t this krfamatron to obtain knowledge of equiprtrertt end procedures to be used in drsling operations. MMS uses the iMorrnatlon to evaluate and approve or disapprove the adequacy of the equipment andlor procedures to safely pertorn the proposed driging operation. Responses are mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.196. An agency mey rat conduct or sponsor. and a person is rat required to respond to, a collection a iMormation unless rt displays a arrently valid OMB Corks Number. Public reporting burden for tl-Ia fomt, MMS-123S. is estlmated to average ttetween 1-3 tours per response. depending on whether >< is a paper submittal or electronic submidal. This includes the time for reviewing insauckions. gathering and rtreintafning data. and nomplefing era revfeMring the form. Direct wntrnents regarding tt>a burden estimate or any other aspect of tnfs form to the Urforrrratbn Copecfion Clearerae Officer. MaG stop 4230, Minerels Management service. 1849 C street. Nw, waehington. DC 20240. MMS Form MMS-1235 (txt 2006 - supersedes all prevbus versbra a torn MMS-t23S wNCn may nor be used.) Page t a t ~~ a ~ ~ jl'~ yS ~, ~~~ ~ ~~ ' ~° ~ 1 ~ ~ :"~ ~ ~`?_~ ~ ~ ~ ~~ ~ ~~ 3, ~ FRANK H. MURKOWSK/, GOVERNOR :~~ ~ ~~ ~ ~, ~7~ O~ ~ u~1a7 ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA'1'IO1~T COMI~'IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519 Re: Northstar 30 BP Exploration (Alaska) Inc. Permit No: 205-207 Surface Location: 1339' FSL, 649' FEL, SEC. 11, T13N, R13E, UM Bottomhole Location: 5247' FSL, 31' FEL, SEC. 18, T 13N, R 14E, 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 an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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 (ga~er~. DATED this day of December, 2005 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. --~lGk- tt-~2~(2-oor ALASKA (7TiL AND GAS CONSERVATION CONI~iSSION ~~~' PERMIT TO DRILL 20 AAC 25.005 ~ 1 a. Type of work ®Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Sir>~Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number:. NS30 ~~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 16354 TVD 11236 12. Field /Pool(s): Northstar Unit 4a. Location of Well (Governmental Section): Surtace: 1339' FSL 649' FEL 11 T13N SEC R13E UM ~ 7. Property Designation: ADL 312808, YOi8i , , . , , , Top of Productive Horizon: 5264' FSL, 168' FEL, SEC. 18, T13N, R14E, UM 8. Land Use Permit: LO-N96-006 13. Approximate Sp te: Janua 18 006 Total Depth: 5247' FSL, 31' FEL, SEC. 18, T13N, R14E, UM ~ 9. Acres in Property: 3433 14. Distance to Nea est Property: 6500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 659822 y- 6031111 Zone- ASP4 10. KB Elevation (Height above GL): 56 feet 15. Distance to Nearest Well Within Pool 4700' away from NS12 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole Angle: 86 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 5180 Surface: 3832 18. asing rogram: Size SpeCifiCations Setting Depth To Bottom uant~ty o entent c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 20" 20" 169# X-56 Welded 200' Surface Surface 200' 200' Driven 16" 13-3/8" 68# L-80 BTC 4467' Surface Surface 4467' 3206' 03 sx AS Lite, 452 sx Class 'G' 12-1/4" 9-5/8" 53.5# L-80 BTC-M 14573' Surtace Surface 14573'- 9612' 1305 sx Ext. Slur , 431 sx'G' -~` 8-1/2" 7" 29# L-80 H dril 521 1574' 14423' 9484' 15997' 10901' 40 sx Class 'G' 6" 4-1/2" 12.6# 13CR80 Vam Ace 507' 15847' 10769' 16354' 11236' 0 sx Class 'G' 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Len th Size Cement Volume MD TVD r r n r Pr i n 'n Pertoration Depth MD (ft): Pertoration Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Pat Archey Title Senior Drilling Engineer Prepared ey NameMumber. Si nature {' ~,., Phone 564-5803 Date ~~ Z 7 ~ S/ Sondra Stewman, 564-4750 Commission Use Only Permit To Drill Number: ZD S - 20 ~ API Number: 50- d ZQ - Z 3 Z 9 3 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~ No Mud Log Required ^ Yes ~No _ Hy rogen Sulfide Measures ,Yes ^ No Directional Survey Required Yes ^ No O er: t eS't ~d ILL- Sc~oe~ ~o~ . ~W 2D ~4kG Z . 0 5 k) Lt~, 4,~~'-~-'~a-~~ ~~ ~L`- ~ s a.~j71~7t1ec( . P~e.-' ~ Z Ck) L z~ ~ t~r% J~-rte-r r e~ ui~wc ~t ~' s wai ve d . - APPROVED BY A roved THE COMMISSION Date ~ ~~g~ Form 10-401 ise 6/2 DEC ~ '~C~[~5 Submit In Duplicate °n by iii 1~~N ~d~i~ti BP Exploration Alaska Inc. To: Winton Aubert - AOGCCI Kyle Monkelien MMS Date: December 19, 2005 From: Paul Hanson Northstar Drilling Engineer Subject: Northstar NS30 Application for Drilling Permit Mr. Aubert and Mr. Monkelein, NS30 is currently scheduled to be drilled by Nabors 33E with operations commencing on January 18, 2006. Maximum anticipated surface pressure (full column of gas from TD to surface) is 3 psi. We will be utilizing Nabors 33E 5000 psi four preventer stack (3 rams a an annular). The drilling operation will require running 1574 feet of 7" intermediate liner. We are requesting a variance to the requirement to have two ram preventers to cover the 7" liner and 2 ram preventers for the 5" DP. We would like to use a variable bore ram on top that can cover both DP and casing. This would provide one ram and the annular for the 7" ~-- liner and two rams for the DP and does not necessitate changing rams after picking up the 7" liner. In the event of a well control incident, our standard practice is to immediately cross-over to DP to allow ram to ram stripping (if required) and we would prefer not to have to change out rams during ashut-in. Although the NS30 well plan passes Major Risk criteria, there are close approach issues for this well with NS29 and NS31, which pass within 1.41' and 3.18' respectively of the allowable deviation at 460' MD. NS29 and NS31 are significant gas injectors. Therefore, in accordance with Policy covering close approach above the SSSV, these wells will be "Minor Risked" by closing the SSSV and bleeding the tubing pressure off and loading the annulus until the point of intersection is passed and it has been demonstrated / that NS30 has been drilled "on plan" to a depth below 460'. If it cannot be demonstrated that NS30 has been drilled "on plan" to below this depth, then NS29 and NS30 will remain shut it until surface casing has been run and cemented. NS30 will utilize gas detection equipment but is not planned for mudloggers. A Diverter waiver is also requested on NS30. To date, no development well drilled through the Northstar upper stratigraphic intervals has experienced any difficulty with ~- shallow gas. All 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 the • • exception of one well, which extends into the SV5 3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Please find attached the NS30 Well Plan Summary, directional plan, and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-4195. SincQrel , Pain M. 1-t~awsow BP Northstar Operations Drilling Engineer 564-4195 NS30 Permit to Drill • • Pre-Rig 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. Rig Operations: ~~~ 1. MIRU Nabors 33E. j tit 2. Nipple up and function test 21-1 /4" diverter system, if required. NOTE: A diverter dispensation has been requested 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the top of the SV6 marker at approximately 4191' MD (3044' tvd rkb). Surface casing point has been picked at 4467' MD (3206' tvd rkb). POOH. j 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. G~- 5. NU casing / multi-bowl wellhead. NU BOPE and test to 250/ ~~~ si (Hydri13500 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. Dri1120' of new formation below 13-3/8" shoe and perform FIT j 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 14573' 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 adown-squeeze on the 9-5/8" x 13-3/8" annulus with one i` annular volume of mud upon installing and testing the pack off. Down-squeeze diesel to 2000' TVD (2000' md) for freeze protection after WOC. 10. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4700 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 11.5 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 o''~ 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 15890' MD (10876 TVD RKB). The Intermediate casing point has been picked at 15997' MD. POOH. 13. Run and cement a 7" 29# Hydril 521 drilling liner. Displace cement with mud. Set the liner j hanger and liner top packer. Circulate excess cement from well bore. 14. POOH and lay down liner running tools. Test 9 5/8" 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. RIH w/ 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. Dri1120' 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 16354' MD. Condition mud weight to 9.3 ppg prior to POOH. 12/27/2005 Page 1 of 12 NS30 Permit to Drill 18. Run and cement the 4-1/2" 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 to confirm pressure integrity. 20. Change well over to clean seawater through the inner string (less than 80 NTU'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 %Z" liner to 4000 psi for 30 minutes. This liner lap test assumes a 15.5 ppg LOT at 7" shoe (10901' TVDrkb) + 500 psi. 24. Run and land the 4-1/2" 12.6# 13-CR80 Vam Ace tubing string with fiber optics' as per completion diagram. Pressure test the control lines and tubing hanger seals to 5000 psi. ~ 25. Set 7" X 4 %2" 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-Rig Work: 1. Tie-in and FCO. 2. MIRU 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. Insta1141h" SCSSSV. 12/27/2005 Page 2 of 12 NS30 Permit to Drill • General Information T e of Well roducer or in'ector): Pre-produced Injector • Northstar Slot: NS30 Surface Location: 1339' FSL, 649' FEL, Sec. 11, T13N, R13E, UM X = 659,822.49 Y = 6,031,111.30 AOR (NS10 or NS30) Well does not enter area of review for NS 10 or NS30. Target (Top of SAG): 200' Radius 5263.62 FSL, 168.40 FEL, Sec. 18, T13N, R14E, UM X = 670,800 Y = 6,030,000 10744 TVDrkb Bottom Hole Location: 200' Radius 5246.56 FSL, 31.26 FEL, Sec. 18, T13N, R14E, UM X = 670937.6 Y = 6,029,986.08 11236 TVDrkb AFE Number: Estimated Start Date: 1/18/2006 1Z Nabors 33E Operating days to complete: 34 MD: 16354 TVDrkb: 11236 RKB/Surface Elevation: (a.m.s.l.) 55.80'/ 15.67' Well Desi n conventional, slimhole, etc.: Modified Bi Bore Ob'ective: Ivishak Pre- roduced In'ector Well Name: NS30 API Number: BHP: 5180psi 11,236' TVDss EMW: 8.87 p g BHT: 254 °F @ 11,100' TVDss Land Use Permit: LO-N96-006 Distance to Nearest Pro er 6500 ft Distance to Nearest Well within Pool: 4700' to NS 12. MECHANICAL CONDITION: Cellar box: Elevation above MSL = 15.67' RKB to Cellar box: 40.13' (Estimated) Ri Elevation: RKB +MSL = 55.8' Conductor: 200' MDrkb of 20", 169#, X-56 (pre-driven) 12/27/2005 Page 3 of 12 NS30 Permit to Drill • General Information • Formation Estimated Depths Pore Press. Top (TVDss) TVDrkb MDrkb (Psi) (ppg EM Top Permafrost 1,149 1,205 1,242 542 8.65 Base Permafrost 1,519 1,575 1,712 708 8.65 SV6 -top confining zone 2988 3,044 4,191 1369 8.65 Surface casing point 3,150 3,206 .4,467 8.65 SV5 -base confining zone 3,268 3,324 4,668 1495 SV4 3,800 3,856 5,573 1734 8.65 SV2 -top upper injection zone 4,227 4,283 6,300 1926 8.65 SV1 -top major shale barrier 4,388 4,444 6,574 1999 8.65 TMBK -top lower injection zone - Top U nu 4,760 4,816 7,207 2166 8.65 WS1 -top Schrader Bluff -Base U nu 6,470 6,526 10,118 2935 8.65 CM3 -Base lower injection zone (top Colville 7,050 7,106 11,105 3196 8.65 THRZ -Top HRZ 8,991 9,047 13,900 4069 8.65 BHRZ -Base HRZ 9,025 9,081 13,942 4085 8.65 Top Kuparuk 9,075 9,131 14003 4265 9.29 Kuparuk C 9,175 9,231 14,124 4428 9.38 Top Miluveach 9,556 9,612 14,573 Intermediate casing point 9,556 9,612 14,573 Intermediate logging point 9,556 9,612 14,573 Top Kingak 9,880 9,936 14,943 Fault rar_210 -throw = 70 feet 10,452 10,508 15,575 5026 Top Sag River 10,744 10,800 15,890 5015 Geol target #1 10,744 10,800 15,890 Intermediate casing point 10,845 10,901 15,997 8.95 Top Shublik - 90 10,890 10,946 16,045 5094 8.95 Top Ivishak 10,980 11,036 16,141 Oil -Water contact 11,100 11,156 16,269 5176 8.95 Total Depth 11,180 11,236 16,354 5180 8.87 Notes: Anomalous high gas readings reported in Seal A-01 mud log at the following interval: 3690- 3775; 3925 - 4050; 4140 -4425, 4510 - 4700 MD - No significant Gas shows in NS10 through NS17 through this interval -max gas = 70 units Depth predictions based on NS13, NS14, NS27, Seal A-1, NS29, Seal A-3 wells and comparison to 3D seismic volume. Pore pressures estimated using data from offset wells. Details found in Section (8) of this SOR. 9, 3 td~l ~2~~ 12/27/2005 Page 4 of 12 NS30 Permit to Drill General Information CASING/TUBING PROGRAM: C i St i Hole Size C i D i i Measured Depth Vertical Depth h F t as ng r ng as ng escr pt on Top Bottom Top Bottom Lengt ee 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 4467 Surface 3206 4467 Intermediate Csg 12 1/4 9-5/8" 53.5# L-80 BTC-M Surface 14573 Surface 9612 14573 Intermediate Liner 8 1/2 7" 29.0# L-80 Hydril 521 14423 15997 9483 10901 1574 Production Liner 6 4-1 /2" 12.6# 13-CR80 Vam Ace 15847 16354 10769 11236 507 Tubing - 4-1/2" 12.6# 13-CR80 Vam Ace Surface 15847 Surface 10769' 13473 Formation Integrity Testing: Test Point Depth Shoe Test T e EMW Estimated Casin Liner Test 13 3/8" Surface Casin 20' min below shoe FIT 12.5 EMW 3400 si w/ 9.3 9 5/8" Intermediate Casin 20' min below shoe FIT 14.5.0 p EMW 4700 psi w/ 10.3 pp 7" Intermediate Liner 20' min from 7" shoe FIT 11.5 EMW 3600 si w/ 12.3/8.65 4 %2" Production Liner N/A N/A N/a 4000 si w/ 8.6 MUD PROGRAM SUMMARY' Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -4467' MD / 3206' TVD -150' TVD below to SV6 . Interval Density Viscosity seconds YP Gel 10 sec API FL pH Initial to base PF *8.8 - 9.3 100 - 200 50 - 70 25 - 40 15 - 20 8.5 - 9.5 Base PF to the to of SV sands *9.0 - 9.3 100 - 150 30 - 45 15 - 25 6 -10 8.5 - 9.5 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. Intermediate Hole Mud Properties: Seawater Polymer Mud 12-1/4" Hole Section From Surface Casing Shoe into the Top of the Miluveach (14573' MD / 9612' TVD). Interval Density (ppg) PV YP API / HTTP FL pH Initial 8.6-9.3 10-16 20-30 6-10 8.5-9.5 TopHRZ 10.1-10.5 10-16 20-25 4-6/<12 8.5-9.5 Top Kuparuk to Miluveach 10.1 -10.5 10 - 18 20 - 28 4-6 / <12 8.5 - 9.5 12/27/2005 Page 5 of 12 • NS30 Permit to Drill General Information Drilling Liner Hole Mud Properties: Inhibited KCL Mud 8-1/2" Hole Section From Intermediate Casing Shoe to 15997' MD / 10901' TVD (top of Sag) Interval Densit PV YP API FL pH Miluveach & Kingak to top of Sag 11.5 12.5 25 - 30 20 - 30 4-6 / <12 8.5 - 9.5 Production Hole Mud Pro erties: Seawater/CaC03 Drill-In Fluid 6" Hole Section From Intermediate Casing Shoe to 16354' MD / 11,236' 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: 300' TMD/TVD Build Rates 1.5°/100' to 3.5°/100' Maximum Hole Angle: (54.02° Close Approach Wells: Surface- 10' well spacing to well NS31 and NS29. All wells passed the major risk rule, however NS29 and NS31 pass within 1.41' and 3.18' ' respectively of the allowable deviation at 460 MD. NS29 and NS31 are significant gas injectors. Therefore, in accordance with Policy covering close approach above the SSSV, these wells will be "Minor Risked" by closing the SSSV and bleeding the tubing pressure off and loading the annulus until the point of intersection is passed and it has been demonstrated that NS30 has been drilled "on plan" to a depth below 460'. Gyro will be used for the initial surveys and kickoff. Survey Program: Gyros as required from surface to +/-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. NS29 and NS31 will be shut in as stated above until it has been demonstrated that surface hole has been drilled on plan to a depth below 460'. Should NS30 surface hole not be on plan to a depth below 460', NS31 and 29 will remain shut in until surface hole is cased and cemented in accordance with BP SIMOPS Policy. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 12/27/2005 Page 6 of 12 • • NS30 Permit to Drill 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 - svv o 4~lGk- Based upon the calculations below, BOP equipment will be tested to.48~66-psi. Maximum Surface Pressure -Full Column of Gas from TD - 0.12 si/ft radient Gradients -psi/ft Pressures 12'/4" Intermediate Hole Section: TVD - ss Formation Gas BHP Surface 1.2 Surface Kuparuk C 9,231 9.28 0.12 4428 3320 3984 8'/z" Intermediate Hole Section: Sa River 10800 8.95 0.12 5026 3730 4476 6" Production Hole Section: Total Depth 11236 7 0.12 5180 832 4598 Planned BOP test reesure: 0 si annular to 3500 si Planned completion fluid: pp Brine / 6.8 pp Diesel 12/27/2005 Page 7 of 12 • NS30 Permit to Drill LOGGING PROGRAM: • Well Evaluation 12 1/4" Intermediate 9" Intermediate Pro ram 16" Surface Hole Hole Hole 6" Production Hole Interval - MDrkb de the From TO From TO From TO From TO MWDILWD Directional Surface 4,467 4,467 14,573 Int. shoe 15,997 15,997 16354 Gamma Ra Surface 4,467 4,467 14,573 Int. shoe 15,997 15,997 16354 G ro As re uired None None None PWD None 4,467 14,573 Int. shoe 15,997 None Resistivi -recorded mode None 4,467 14,573 None 15,997 16,354 Resistivit -real time mode None 4,467 14,573 None 15,997 16,354 Densit None None None 15,997 16,354 Neutron None None None 15,997 16,354 Sonic (ISONIC) None None None None Wireline based Open Hole to s G R None None None Contin ent Resistivi HALS None None None Contin ent Neutron HGNS None None None Contin ent Densi HRMS None None None Contin ent Sonic None None None None FMI 4 arm tali er None None None None CMR None None None None RFT None None None None MDT None None None None Cased Hole log - SCMT / USIT / CBL None None None Int. shoe 16,354 Mudlogging Gas Detection None None None None Cuttin s Sam les None None None None Increments None None None None Geochem cans None None None None Increments None None None None Comments Im ortance Definitions Wireline Los MWD/LWD to s Intermediate Hole 1: PWD Resistivity and LWD in real time mode in the Low Do not run if unsuccessful. If tool fails -drill ahead Intermediate hole #1 Intermediate Hole 1: Med. Re-run if unsuccessful except if conditioning trip required to run casin . Intermediate Hole II: Cased hole gamma ray to be run . High Re-run if unsuccessful even if If unsuccessful -POOH and repair if for primary depth control after conditioning trip required. DP possible. Willing to run back in hole ri moves off location conve ed to in not re uired. without tool re aired Production Hole: If LWD logs fail while drilling then V. High Re-run if unsuccessful even if DP drill ahead to planned TD. conveyed logging needed Contingent Wireline log run needed should LWD logs fail. 12/27/2005 Page 8 of 12 NS30 Permit to Drill • Production Hole Lo in Continued Cement bond log over 7" interval . needed for later injection, to be run Critical Re-run if unsuccessful even if side- If unsuccessful -POOH and wait to fix after 4 1/2" production liner track or DPC logging needed before proceeding even if rig remains cemented into lace idle. Required Materials: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13CR Liner: 12/27/2005 4467' 13 3/8", 68# L-80 BTC 1 - 13 3/8" HES Super Seal II Float Shoe (4.25" valve) 1 - 13 3/8" HES Super Seal II Float Collar (4.25" valve) 1 -set HES Cement Plug Set 17 - 13 3/8" x 15 3/4" SV Rigid Centralizers 17 -13 3/8" x 15 3/4" Stop Bands 1 - 20" x 13 3/8" ABB-VGI Fluted hanger -BTC down, 11 '/" external ACME landing thread 1 - 13 5/8" ABB-VGI Casing Head/Tbg head 14573' 9 5/8", 53.5# L-80 BTC-MOD 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 - 9 5/8"x12" 1574' • 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 Hydri1511 1 - 8 %z" BBL reamer shoe 1 - 7" HES Super Seal II Float Collar 7 - 7" x 8 1/4" SV Rigid Centralizers 7 - 7" x 8 1/4" Stop Bands 1 - 7" x 9 5/8" Baker Double-Grip Flex Lock Hydraulic Set Liner Hanger -Rotating hanger. 1 - 7" x 9 5/8" Baker ZXP Liner Top Packer 1 - 7" Baker HRD running tool 1 - 7" Baker Landing Collar and plug set 507' 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" 4-1/2", 12.6# 13 Cr-80Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar SV Rigid Centralizers Stop Bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set Page 9 of 12 • NS30 Permit to Drill • 13Cr 15847' 4-1/2", 12.6# 13Cr-80 Vam Ace Completion: 1 4'/s" ABB-VGI tubing hanger 1 4 %z" ABB-VGI adapter flange 1 4 %z" ABB-VGI 5-1/8" SK Swab Valve w/ tree cap 1 CIDRA mandrel and 0.25" fiber optic cable (w/ 4 %z" cable clamps). 1 4 %z" SVLN and 1 - 0.25" control lines 1 4 %z" x 1 %z" GLM with dummy valve installed 1 4 %z" x 1 %z" GLM with RP Shear valve installed 7" x 4 %z" Baker 13 Cr packer S-3. 4 %z" WLEG (Self-Aligning Mule Shoe) 4 %z" 13 Cr X nipples 4 ``/z" 13 Cr XN nipple 12/27/2005 Page 10 of 12 • • NS30 Permit to Drill PERMAFROST: The 13-3/8" surface casing will be run approximately 2755' TVD below the permafrost Base at 1712'MD) to 4467' MD/ 3206' 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. The following cement calculations are based upon a single stage job. Casing 113-3/8" 68# BTC Surface Basis: Stage 1: Lead: Based on 200' cased hole capacity,;from surface to 200' MD, 125% excess to 1712' MD, 50% to 3717'. Lead TOC: S ac Tail: Based on 750' and of 16" gauge open hole + 50% excess + 80' shoe joint. Tail TOC: 3717' MD. Shoe at 4467' MD. Total Cement / S acer Preflush 25 bbl CW101 Spacer 75 bbl MudPush II Spacer Lead ~ S~,A~bl (60,3isk of 10.7 ppg Arcticset Lite Cement. Tail ~~7 bbl //45?~s"k of 15.8 ppg Premium `G' w/ 2% BHST 70° / BHCT 60° 9-5/8" 53.5# BTC-M asis: Stage 1: ead: Based on705 12 1/4" open hole x 9 5/8" csg +30% excess ead TOC: At 630 MD (4283' TVD - SV2) ail: Based on ' of 12 %" open hole x 9 5/8" csg + 30% excess + 80' shoe joint. ail TOC: At ~ 13352' MD (8612' TVD) Shoe at 14573' MD. Stage 1: Total Cement / I Preflush 135 bbls CW101 >pacer 75 bbl M Lead 2 bbl / cf/sk 92.bb1 /t 7" 29# 521 Hydril Drlg II Spacer of 12.5 ppg Extended Slurry. of 15.8 ppg Premium `G'. el: y: Based on 1424' of 9 1/2" open hole x 7" csg + 50% excess + 150' 9 5/8" csg x 7" csg lap + 200' 9-5/8"-csg x 5" drillpipe above TOL + 80' shoe joint. Slurry TOC: At 1: Total Cement / 'MD Spacer 55 bbl MudPush II Spacer Slurry X91 / t~4q'sk of 15.8 ppg Premium `G'. 12/27/2005 Page 11 of 12 ~ • NS30 Permit to Drill asing ~-1/2" 12.6# 13Cr-80 Prod asis: Stage 1: Slurry: Based on 357' of 6" open hole x 4 '/z liner + 100% excess + 150' of 7" csg x 4 1/2" csg liner lap + 200' of 7" csg x 4" drillpipe above TOL + 40' shoe joint. Slurry TOC: At 1.296' MD 15 X4.7 ~ I~GA-- Stage 1: Total Spacer 30 bbl MudPush II Spacer Cement /Spacer .~-~ Slurry ~2 ~lj / '~ of 15.8 ppg Premium `G' . Big Bore Pre-Produce njecto Casing Specifications " ry Surface Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Wei t Grade Connection ID in Drift in Min/Mac Coupline OD Strength (1000 lbs) Strength (10001bs) Strength (osi) Strength (usi) 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 Wei t Grade Connection ID in Drift in Min/Max Coupling OD Strength (1000 lbs) Strength (1000 lbsl 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 Wei t Grade Connection ID in Drift in Min/Max Coupling OD Strength (10001bs) Stren Stren h S~tl 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 Wei t Grade Connection ID in Drift in Min/Max Coupling OD Strength (1000 lbs) Strength (1000 lbs) Strength (psi) Strength (psi) 4.5" 12.6 13CR-80 VAM ACE 3.958 3.833 3600 4.964 288 288 8430 7500 12/27/2005 Page 12 of 12 by Schlumberger NS30 (P6) Proposal Report Date: October 31, 2005 Survey) DLS Computation Method: Minimum Curvature / Lubinski CIieM: BP Exploration Alaska Vertical Section Azimuth: 97.010° Field: Northstar Structure 1 Slot: Northstar PF / NS30 ~ ~r~ Vertical Section Origin: ~y TVD Reference Datum: N 0.000 ft, E 0.000 ft KB Well: NS30 ; ~'~ TVD Reference Elevation: 56.00 ft relative to MSL ~~~; ~ Borehole: Plan NS30 Sea Bed 1 Ground Level Elevation: 15.67 ft relative to MSL UWIIAPgk: 50029 Magnetic Declination: 24.737° Survey Name I Date: NS30 (P6) NE Tgt /October 31, 2005 Total Field Strength: 57616.040 nT Tort I AHD 1 DDI 1 ERD ratio: 88.042° / 11172.74 ft / 6.156 10.994 Magnetic Dip: 81.020° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: January 20, 2006 Location LatlLong: N 70.49154166, W 148.69333464 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 6031111.310 ftUS, E 659822.490 ftUS North Refer~ca: True North Grid Convergence Angle: +1,23167644° Total Corr Mag North a True North: +24.737° Grid Scale factor. 0.99992902 local Coordinates Referenced To: Well Head Comments p g ~ Inclination Azimuth Sub-Sea TVD TVD S ~ o l NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude e e cti n k d d ft k h k ft de 100 k d de 100 ft d 1100 k ftUS kUS RTE= U.UU U.UU ~J/.U1 -bb.UU U. UU U.UU U.UU U. UU U.UU y/.U1M U.VV U.VU bU3l "Ill.3l bb`Ji3LL.4`J N /U.4`31b4"Ibb VV 148. b`J3334b4 KOP Bid 1.5/100 300.00 0.00 97.01 244.00 300. 00 0.00 0. 00 0. 00 0.00 97.01M 0.00 0.00 6031111.31 659822.49 N 70.49154166 W 148. 69333464 Bld 2.5/100 400.00 1.50 97.01 343.99 399. 99 1.31 -0. 16 1. 30 1.50 97.01M 1.50 0.00 6031111.18 659823.79 N 70.49154122 W 148. 69332402 500.00 4.00 97.01 443.87 499. 87 6.11 -0. 75 6. 06 2.50 97.01 M 2.50 0.00 6031110.70 659828.56 N 70.49153962 W 148. 69328510 Crv 3.5/100 540.00 5.00 97.01 483.74 539. 74 9.24 -1. 13 9. 18 2.50 O.OOG 2.50 0.00 6031110.38 659831.69 N 70.49153857 W 148 .69325964 600.00 7.10 97.01 543.40 599. 40 15.57 -1. 90 15. 45 ~50 O.OOG 3.50 0.00 6031109.74 659837.98 N 70.49153646 W 148 .69320834 700.00 10.60 97.01 642.20 698. 20 30.95 -3. 78 30. 72 3.50 O.OOG 3.50 0.00 6031108.19 659853.28 N 70.49153134 W 148 .69308354 800.00 14.10 97.01 739.87 795. 87 52.34 -6. 39 51. 94 3.50 O.OOG 3.50 0.00 6031106.04 659874.56 N 70.49152420 W 148. 69291004 900.00 17.60 97.01 836.05 892. 05 79.64 -9. 72 79. 05 3.50 O.OOG 3.50 0.00 6031103.29 659901.72 N 70.49151510 W 148. 69268848 1000.00 21.10 97.01 930.39 986. 39 112.77 -13. 77 111. 93 3.50 O.OOG 3.50 0.00 6031099.95 659934.68 N 70.49150405 W 148. 69241970 1100.00 24.60 97.01 1022.53 1078. 53 151.60 -18. 51 150. 46 3.50 O.OOG 3.50 0.00 6031096.04 659973.31 N 70.49149110 W 148. 69210470 1200.00 28.10 97.01 1112.12 1168. 12 195.98 -23. 92 194. 51 3.50 O.OOG 3.50 0.00 6031091.57 660017.46 N 70.49147629 W 148. 69174 1300.00 31.60 97.01 1198.84 1254. 84 245.74 -30. 00 243. 90 3.50 O.OOG 3.50 0.00 6031086.56 660066.96 N 70.49145969 W 148. 69134 1400.00 35.10 97.01 1282.36 1338. 36 300.71 -36. 71 298. 46 3.50 O.OOG 3.50 0.00 6031081.03 660121.65 N 70.49144135 W 148 .69089495 1500.00 38.60 97.01 1362.37 1418 .37 360.67 -44. 03 357. 97 3.50 O.OOG 3.50 0.00 6031074.99 660181.30 N 70.49142135 W 148 .69040846 1600.00 42.10 97.01 1438.57 1494 .57 425.41 -51. 93 422. 22 3.50 O.OOG 3.50 0.00 6031068.47 660245.70 N 70.49139975 W 148 .68988326 1700.00 45.60 97.01 1510.67 1566. 67 494.67 -60. 39 490. 97 3.50 O.OOG 3.50 0.00 6031061.49 660314.61 N 70.49137664 W 148 .68932129 1800.00 49.10 97.01 1578.41 1634. 41 568.21 -69. 37 563. 96 3.50 O.OOG 3.50 0.00 6031054.09 660387.77 N 70.49135209 W 148. 68872467 1900.00 52.60 97.01 1641.54 1697 .54 645.75 -78. 83 640. 92 3.50 O.OOG 3.50 0.00 6031046.28 660464.91 N 70.49132622 W 148 .68809560 End Crv 1940.61 54.02 97.01 1665.80 1721 .80 678.31 -82. 81 673. 24 3.50 O.OOG 3.50 0.00 6031043.00 660497.30 N 70.49131535 W 148 .68783144 13-3/8" Csg Pt 4466.96 54.02 97.01 3150.00 3206. 00 2722.73 -332. 40 2702. 36 0.00 O.OOG 0.00 0.00 6030837.09 662531.17 N 70.49063223 W 148. 67124562 Drp 0.75/100 11413.08 54.02 97.01 7230.74 7286 .74 8343.76 -1018. 65 8281. 35 0.00 -180.OOG 0.00 0.00 6030270.96 668123.22 N 70.48874625 W 148 .62564944 11500.00 53.37 97.01 7282.21 7338 .21 8413.81 -1027. 20 8350. 87 0.75 -180.OOG -0.75 0.00 6030263.91 668192.90 N 70.48872267 W 148 .62508130 WeIlOesign Ver SP 1.0 Bld( doc40x_56) NS30\NS30\Plan NS30\NS30 (P6) NE Tgt Generated 10/31/2005 2:19 PM Page 1 of 3 Measured Vertical Comments inclination Azimuth Sub-Sea ND ND NS EW DLS Tool Face Build Rate Walk Rate Northing Easting LatiWde Longitude Depth Section ft d d ft ft ft ft ft d 100 ft d d 1100 ft d 100 ft ftUS ftUS 11600.00 52.61 9/.01 7342.40 73913.40 13493 .67 -1036. 95 5430.13 0./5 -160 .006 -0./5 0.00 6030"155.18/ 6615'1/'1.35 N /U .46tf695/9 W 146.62443359 11700.00 51.87 97.01 7403.62 7459.62 8572. 73 -1046. 61 8508. 60 0.75 -180 .006 -0.75 0.00 6030247.90 668351.00 N 70 .48866918 W 148.62379232 11800.00 51.12 97.01 7465.88 7521.88 8650 .98 -1056. 16 8586. 27 0.75 -180 .006 -0.75 0.00 6030240.02 668428.85 N 70 .48864284 W 148.62315762 11900.00 50.37 97.01 7529.16 7585.16 8728 .42 -1065. 61 8663. 12 0.75 -180 .006 -0.75 0.00 6030232.22 668505.88 N 70 .48861677 W 148.62252957 12000.00 49.62 97.01 7593.45 7649.45 8805 .01 -1074. 96 8739. 15 0.75 -180 .006 -0.75 0.00 6030224.51 668582.09 N 70 .48859098 W 148.62190830 12100.00 48.87 97.01 7658.73 7714.73 8880 .76 -1084. 21 8814. 33 0.75 -180 .006 -0.75 0.00 6030216.88 668657.45 N 70 .48856548 W 148.62129391 12200.00 48.12 97.01 7725.00 7781.00 8955. 65 -1093. 35 8888. 66 0.75 -180 .006 -0.75 0.00 6030209.34 668731.95 N 70 .48854026 W 148.62068651 12300.00 47.37 97.01 7792.24 7848.24 9029. 67 -1102. 39 8962. 12 0.75 -180 .006 -0.75 0.00 6030201.88 668805.58 N 70 .48851533 W 148.62008619 12400.00 46.62 97.01 7860.45 7916.45 9102. 79 -1111. 32 9034. 70 0.75 -180 .006 -0.75 0.00 6030194.52 668878.33 N 70 .48849070 W 148.61949307 12500.00 45.87 97.01 7929.61 7985.61 9175. 02 -1120. 14 9106. 39 0.75 -180 .006 -0.75 0.00 6030187.24 668950.19 N 70 .48846638 W 148.6189 12600.00 45.12 97.01 7999.70 8055.70 9246. 34 -1128. 84 9177. 18 0.75 -180 .006 -0.75 0.00 6030180.06 669021.14 N 70 0 .48844235 W 148.61832 12700.00 44.37 97.01 8070.73 8126.73 9316. 74 -1137. 44 9247. 04 0.75 -180 .006 -0.75 0.00 6030172.97 669091.17 N 70 .48841864 W 148.61775 12800.00 43.62 97.01 8142.67 8198.67 9386. 19 -1145. 92 9315. 98 0.75 -180 .006 -0.75 0.00 6030165.98 669160.27 N 70 .48839524 W 148.61719451 12900.00 42.87 97.01 8215.51 8271.51 9454. 70 -1154. 28 9383. 98 0.75 -180 .006 -0.75 0.00 6030159.08 669228.43 N 70 .48837216 W 148.61663884 13000.00 42.12 97.01 8289.25 8345.25 9522 .26 -1162. 53 9451. 03 0.75 -180 .006 -0.75 0.00 6030152.27 669295.63 N 70 .48834940 W 148.61609096 13100.00 41.37 97.01 8363.86 8419.86 9588. 84 -1170. 65 9517. 11 0.75 -180 .006 -0.75 0.00 6030145.57 669361.87 N 70 .48832696 W 148.61555095 13200.00 40.62 97.01 8439.34 8495.34 9654. 43 -1178. 66 9582. 21 0.75 -180 .006 -0.75 0.00 6030138.96 669427.13 N 70 .48830486 W 148.61501891 13300.00 39.87 97.01 8515.67 8571.67 9719. 04 -1186. 55 9646. 34 0.75 -180 .006 -0.75 0.00 6030132.46 669491.40 N 70 .48828309 W 148.61449493 13400.00 39.12 97.01 8592.83 8648.83 9782. 64 -1194. 31 9709. 46 0.75 -180 .006 -0.75 0.00 6030126.05 669554.67 N 70 .48826165 W 148.61397910 13500.00 38.37 97.01 8670.83 8726.83 9845. 22 -1201. 95 9771. 58 0.75 -180 .006 -0.75 0.00 6030119.75 669616.93 N 70 .48824056 W 148.61347151 13600.00 37.62 97.01 8749.63 8805.63 9906. 78 -1209. 47 9832. 67 0.75 -180 .006 -0.75 0.00 6030113.55 669678.17 N 70 .48821981 W 148.61297224 13700.00 36.87 97.01 8829.24 8885.24 9967. 30 -1216. 85 9892. 74 0.75 -180 .006 -0.75 0.00 6030107.46 669738.38 N 70 .48819941 W 148.61248139 13800.00 36.12 97.01 8909.63 8965.63 10026. 77 -1224. 11 9951. 77 0.75 -180 .006 -0.75 0.00 6030101.47 669797.55 N 70 .48817936 W 148.61199902 13900.00 35.37 97.01 8990.79 9046.79 10085. 19 -1231. 25 10009. 75 0.75 -180 .006 -0.75 0.00 6030095.58 669855.66 N 70 .48815967 W 148.61152524 14000.00 34.62 97.01 9072.71 9128.71 10142. 54 -1238. 25 10066. 67 0.75 -180 .006 -0.75 0.00 6030089.81 669912.72 N 70 .48814033 W 148.61106011 14100.00 33.87 97.01 9155.38 9211.38 10198. 81 -1245. 12 10122. 52 0.75 -180 .006 -0.75 0.00 6030084.14 669968.70 N 70 .48812136 W 148.61060372 14200.00 33.12 97.01 9238.77 9294.77 10254. 00 -1251. 85 10177. 29 0.75 -180 .006 -0.75 0.00 6030078.59 670023.60 N 70 .48810275 W 148.61015614 14300.00 32.37 97.01 9322.88 9378.88 10308. 09 -1258. 45 10230. 98 0.75 -180 .006 -0.75 0.00 6030073.14 670077.41 N 70 .48808452 W 148.60971746 14400.00 31.62 .97.01 9407.69 9463.69 10361. 07 -1264. 92 10283. 57 0.75 -180 .006 -0.75 0.00 6030067.80 670130.12 N 70 .48806665 W 148.609287 14500.00 30.87 97.01 9493.18 9549.18 10412. 94 -1271. 25 10335. 05 0.75 -180 .006 -0.75 0.00 6030062.58 670181.72 N 70 .48804916 W 148.60886 9-5/8" Csg Pt 14531.20 30.64 97.01 9520.00 9576.00 10428. 89 -1273. 20 10350. 88 0.75 -180. 006 -0.75 0.00 6030060.97 670197.59 N 70. 48804378 W 148.608737 14600.00 30.12 97.01 9579.35 9635.35 10463. 68 -1277. 45 10385. 41 0.75 -180 .006 -0.75 0.00 6030057.47 670232.20 N 70 .48803205 W 148.60845551 14700.00 29.37 97.01 9666.18 9722.18 10513. 30 -1283. 50 10434. 65 0.75 -180 .006 -0.75 0.00 6030052.48 670281.56 N 70 .48801531 W 148.60805313 14800.00 28.62 97.01 9753.64 9809.64 10561. 77 -1289. 42 10482. 76 0.75 -180 .006 -0.75 0.00 6030047.59 670329.78 N 70 .48799897 W 148.60766001 14900.00 27.87 97.01 9841.74 9897.74 10609. 09 -1295. 20 10529. 73 0.75 -180 .006 -0.75 0.00 6030042.83 670376.86 N 70 .48798300 W 148.60727620 15000.00 27.12 97.01 9930.44 9986.44 10655. 26 -1300. 83 10575. 55 0.75 -180 .006 -0.75 0.00 6030038.18 670422.79 N 70 .48796743 W 148.60690178 15100.00 26.37 97.01 10019.74 10075.74 10700. 26 -1306. 32 10620. 22 0.75 -180 .006 -0.75 0.00 6030033.65 670467.56 N 70 .48795225 W 148.60653681 15200.00 25.62 97.01 10109.63 10165.63 10744. 08 -1311. 67 10663. 72 0.75 -180 .006 -0.75 0.00 6030029.24 670511.16 N 70 .48793747 W 148.60618135 15300.00 24.87 97.01 10200.07 10256.07 10786. 73 -1316. 88 10706. 05 0.75 -180 .006 -0.75 0.00 6030024.94 670553.59 N 70 .48792308 W 148.60583547 15400.00 24.12 97.01 10291.07 10347.07 10828. 19 -1321. 94 10747. 20 0.75 -180 .006 -0.75 0.00 6030020.77 670594.83 N 70 .48790910 W 148.60549921 15500.00 23.37 97.01 10382.61 10438.61 10868. 46 -1326. 85 10787. 16 0.75 -180 .006 -0.75 0.00 6030016.71 670634.89 N 70 .48789551 W 148.60517265 WeIlDesign Ver SP 1.0 Bld(doc40x_56) NS30\NS30\Plan NS30\NS30 (P6) NE Tgt Generated 10/31/2005 2:19 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Verbcal NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de d ft ft ft ft ft de 100 k d de 1100 ft d 1100 ft ftUS ftUS 1 bbUU.UU ZZ. bZ `J/.U7 lU4/4. bb 1U93U.66 lU`JU/.bZ -1331.bZ lUifZb. `J3 U./5 -7 tSU.UUIi -V./b U.UV bU3UUlL ./a O/UO/3./b IV /V.46/88LJ3 VV 148.bU46bbtSJ 15700.00 21. 87 97.01 10567. 22 10623.22 10945.38 -1336.24 10863. 50 0.75 -180.OOG -0.75 0.00 6030008 .97 670711.41 N 70.48786956 W 148.60454881 15800.00 21. 12 97.01 10660. 26 10716.26 10982.02 -1340.71 10899. 87 0.75 -180.OOG -0.75 0.00 6030005 .28 670747.86 N 70.48785720 W 148.60425165 15900.00 20. 37 97.01 10753. 78 10809.78 11017.44 -1345.04 10935. 03 0.75 -180.OOG -0.75 0.00 6030001 .72 670783.10 N 70.48784525 W 148.60396439 End Crv 15949.24 20. 00 97.01 10800. 00 10856.00 11034.43 -1347.11 10951. 89 0.75 O.OOG -0.75 0.00 6030000 .00 670800.00 N 70.48783952 W 148.60382659 15949.24 20. 00 97.01 10800. 00 10856.00 11034.43 -1347.11 10951. 89 0.00 O.OOG 0.00 0.00 6030000. 00 670800.00 N 70.48783952 W 148.60382658 7" Csg Pt 15997.13 20. 00 97.01 10845. 00 10901.00 11050.81 -1349.11 10968. 15 0.00 O.OOG 0.00 0.00 6029998. 36 670816.30 N 70.48783399 W 148.60369375 TD / 4-1/2" Lnr 16353.63 ~ 20. 00 97.01 11180. 00 11236.00 11172.74 -1363.99 11089. 16 0.00 O.OOG 0.00 0.00 6029986 .08 670937.60 N 70.48779285 W 148.60270487 • ~J WeIlDesign Ver SP 1.0 Bld(doc40x_56) NS30\NS30\Plan NS30\NS30 (P6) NE Tgt Generated 10/31/2005 2:19 PM Page 3 of 3 by • • Scl~~'A~' WELL NS30 (P6) EIE`D Northstar B,RDCTUgF Northstar PF Magrdnc f'aramMers SuKace toc&bn NADD Arab S1&e Ylann, ions g6. US Feel Mivca~laneous MoOei: BGGM 2005 Dry: 81.020° Dad: January 20, 2008 Lat NT02929.550 N°edbg: fi031111.3i MIS Gri0 C0nv: •1231h7fi0a° Sbl: NS30 IVD Rat KB 15G.00 ^a9ew MSl} Mq Dec: .24.T3T' FS: 5Tfi18.0 nT Lon: WiM 4136.005 Eaadq: 659822x9 MIS Sud FaR 0.9999290159 Vdn: N&30 rye}NE TgI Srvy Dad: GLb5er 31.2W5 2000 4000 6000 8000 10000 2000 4000 0= O O O N ~ 6000 II 0) D3 U 8000 loooo 12000 .~ ..RTE............t ...............................{..............................y...............................j...............................j........................ KOP Bid LSnOQ ela z.snoo c Crv 9.Sn00 End Crv .:................ .............................................:...............................:..............................y.............................. y........................ 13-310° CKg Pl Y . ~ ............................... ~...,....................... .~...............................~...............................1...............................:........................ .:...............................:...............................:...............................:....... .....................:...............................:........................ Dry 0.751100 9-510" Cag D Eoa crv e 7~ Csg PI TD 1:4112" LnF S3C 2000 4000 6000 8000 loooo NE Tgt 12000 2000 4000 6000 8000 10000 Vertical Section (ft) Azim = 97.01 °, Scale = 1(in):2000(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger WELL FIELD STRUCTURE NS30 (P6) Northstar Northstar PF Magralic Parametere SuRace Location NN02] Abaka Slate Planes, Zone 04, U5 Feat Miace4aneous MWeI: BGGM 2005 Dip: 61.020° Dale: January 20, 2006 Lal: N]02929.550 NoMing: 6031111.311tUS Gritl Conv: .12316]644° SbL NS30 NO Ref: KB X56.00 KaEOVe MSL) Mag Oec: .24.]3]° FS'. 5]fi16.0 nT Lon: W1464136.005 Easlmg: 65962249 flU9 Scale Fact: 0.9999290159 Plan: NS30 ~PfiJ NE TgI Srvy Dale: October 31, 2005 1500 3000 4500 6000 7500 9000 10500 O O c u 0) U N 1500 -1500 -3000 -4500 2.51100 :rv 3.51700 End Crv Bld 7.5N00 _ N ......... .......................... .......................... ............................5...................... Drp 0.751700; aus° cBg r 1500 3000 4500 6000 7500 9000 ri cBg ~ 1500 NS30 (P ) NE Tgt .;..... ~............ -1500 Tb 14112" Lnr \ .....:....................°.. -3000 ...........° ................ .4500 10500 u «< W Scale = 1(in):1500(ft) E »> BP Alaska Anticollision Report Company: BP Amoco Date: 10/31/2005 Time: 1424:39 Page: 1 Field: Northstar Reference Site: Northstar PF Co-ordinate(NE) Reference: Well: NS3 0, True North Reference Well: NS30 Vertical (TVD) Reference: NS30 Plan 56.0 Reference VVellpath: Plan NS30 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Princi pal Plan 8~ PLANNED PROGRAM ! Interpolation Method : MD Interval: 20.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.10 to 16353.63 ft Scan Method: Trav Cylinder North ~ Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing --_Y g - - P _ Surve Pro ram for Definitive Well ath --- - _. _ .._--- -- - - - - -__ _ _ . _ - __ -- Date: 5/20/2005 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft - - -- - - GC-SS ngle shots a 1 00.00 2400.00 Planned: Pla n #6 V1 MWD MWD Standa ti ! 1000.00 16353.63 Planned: Pla n #6 V1 MWD+IFR +MS MWD +IFR + Multi Station Casing Points Mll TVD Diameter Hole Size Name ft ft in in - - 4466.96 3206.00 13.375 - - 16.000 13 3/8" -- ~ 14531.20 9576.00 9.625 12.250 9 5/8" " ~, 15997.13 10901.00 7.000 8.750 7 i 16353.63 11236.00 4.500 6.125 4 1/2" Summary - - - - - - - <----------- OlI'set 1Vellpath -- > Reference OfTset Ctr-Ctr - No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Northstar Island NORTHSTAR1 NORTHSTAR1 VS Out of range i, !, Northstar Island NORTHSTAR2 NORTHSTAR2 V2 Out of range ', Northstar Island NORTHSTAR2 NSTAR2P61 V1 Out of range Northstar PF NS05 NS05 V4 801.06 800.00 245.93 13.72 232.21 Pass: Major Risk Northstar PF NS05 NS05P61 V8 801.06 800.00 245.93 13.72 232.21 Pass: Major Risk ', Northstar PF NS06 NS06 V35 803.29 800.00 239.20 14.48 224.71 Pass: Major Risk Northstar PF NS07 NS07 V34 139.88 140.00 231.06 2.93 228.13 Pass: Major Risk i Northstar PF NS07 Plan NS07A V3 Plan: PI 139.88 140.00 231.06 2.93 228.13 Pass: Major Risk ~ Northstar PF NS08 NS08 V19 840.35 840.00 220.02 15.01 205.01 Pass: Major Risk ~ Northstar PF Northstar PF NS09 NS09 NS09 V15 Plan NS09A V5 Plan: PI 838.63 838.63 840.00 840.00 208.66 208.66 14.03 13.87 194.63 194.79 Pass: Major Risk Pass: Major Risk ~, Northstar PF NS10 NS10 V17 740.62 740.00 183.73 11.52 172.21 Pass: Major Risk i Northstar PF NS12 NS12 V30 1202.74 1220.00 160.80 21.86 138.93 Pass: Major Risk Northstar PF NS13 NS13 V15 759.63 760.00 170.76 12.74 158.01 Pass: Major Risk Northstar PF NS14 NS14 V13 839.92 840.00 150.33 15.00 135.33 Pass: Major Risk Northstar PF NS14 Plan NS14A V2 Plan: PI 839.92 840.00 150.33 15.00 135.33 Pass: Major Risk ~ I Northstar PF NS15 NS15 V20 679.13 680.00 150.32 12.23 138.09 Pass: Major Risk i Northstar PF NS16 NS16 V40 577.82 580.00 138.87 10.93 127.94 i Pass: Major Risk Northstar PF NS17 NS17 V16 699.81 700.00 131.59 11.52 120.08 Pass: Major Risk JI Northstar PF ! NS18 NS18 V15 658.38 660.00 116.74 12.10 104.64 Pass: Major Risk Northstar PF NS19 NS19 V18 861.49 860.00 104.64 16.14 88.51 Pass: Major Risk i Northstar PF NS20 NS20 V14 698.48 700.00 95.68 12.04 83.65 Pass: Major Risk Northstar PF NS20 NS20P61 V11 698.48 700.00 95.68 12.04 83.65 Pass: Major Risk i Northstar PF NS21 NS21 V60 675.34 680.00 81.30 12.47 68.83 Pass: Major Risk ~ ! Northstar PF NS22 NS22 V14 951.51 960.00 41.17 16.63 24.54 Pass: Major Risk I Northstar PF NS23 NS23 V36 636.93 640.00 66.85 11.64 55.21 Pass: Major Risk I~ Northstar PF NS24 NS24 V16 620.06 620.00 57.73 10.89 46.84 Pass: Major Risk IC Northstar PF NS25 NS25 V4 759.30 760.00 53.01 13.59 39.43 I Pass: Major Risk Northstar PF NS25 NS25P61 V10 759.30 760.00 53.01 13.59 39.43 Pass: Major Risk ', Northstar PF NS25 NS25PB2 V4 759.30 760.00 53.01 13.59 39.43 Pass: Major Risk Northstar PF NS26 NS26 V24 600.17 600.00 41.13 9.62 31.50 Pass: Major Risk Northstar PF NS27 NS27 V30 579.68 580.00 29.38 9.50 19.89 Pass: Major Risk '; Northstar PF NS28 NS28 V8 499.71 500.00 17.03 8.59 8.44 Pass: Major Risk Northstar PF NS29 NS29 V23 459.57 460.00 9.69 8.27 1.41 Pass: Major Risk Northstar PF NS31 NS31 V15 459.87 460.00 11.62 8.44 3.18 Pass: Major Risk Northstar PF NS32 NS32 V12 300.07 300.00 23.15 5.60 17.54 Pass: Major Risk Northstar PF NS34 Plan NS34 V3 Plan: Pla 440.25 440.00 40.96 8.45 32.51 Pass: Major Risk NORTHSTAR3 NORTHSTAR3 NORTHSTAR3 V7 Out of range Seal Island SEAL-A-03 SEAL-A-03 V4 578 74 580.00 200.12 10.66 189.45 Pass: Major Risk ~ • • Field: Northstar Site: Northstar PF ~ Well: NS30 i Wellpath: Plan NS30 '~,I t too 100 tau Travelling Cylinder .4zimnih (TFO+AZI) [deg] vs Centre to Centre Separation [1006/in] I TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8", 68#/ft, L-80, BTC @ 4467' MD 4 1/2", 12.6#/ft, 13-Cr, Vam-TOI TUBING ID: 3.958" CAPACITY: 0.01522 BBUFT 9-5/8" 53.5# L-80 BTM-C @ 14573` h 4.5" X NIPPLE, @ 15777` M[ 3.813" 1[ 4.5" X NIPPLE, @ 15817' M[ 3.813" 1[ 4.5" XN NIPPLE, ~ 15827` M[ 3.725" 1[ 4.5 Self Aligning WLEG @15837`M 3.958" 7", 29#/ft L-80, Hydril 521 15997' MD PBTD @ 16274' TD @ 16354' M., DATE 1 REV. BY NS30 Completion COMMENTS ~IGINAL KB. ELEV = 56` r KB-BF. ELEV = 40.1' CB. ELEV = 15.9` 5-1/2" x 4-1/2",12.6 # ~300TMD/TVD '2" SSSV Q 1000' TMD/TVD PPG DIESEL FREEZE PROTECTION +/- 3000' TVD (3000'MD) 4 1/2" GLM @ 4000' TVD (4019' MD) w/ 4.62" I D ~" LINER TOP @ 14423' MD >•.5" Fiber Optic Transducer 3.958" ID @ 15757 MD 'ACKER,13 Cr ~ 15797' MD 4.5" LINER TOP @ 15847' MD 4.5", 12.6#, 13Cr Vam TOP BP Exploration (Alaska) ' TERRIE L RUBBLE as-sitz5z 244 BP EXPLORATION AK INC ^Mastercard Check" PO BOX 196612 MB 7-5 Ov2 ~I ANCHORAGE, AK 99519-6612 oATE PAY TO THE CC. '~ (0 ~ ~ ~ _ ORDER OF First National Bank Alaska _ Anchorage, AK 99501 ;~~ t ~) MEMO `~S~ ~(n/ }v9~+'~ ~: L 2 5 200060:99 i4~~~6 2 2 7~~~ L 5 56~~' 0 244 ~~ • • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLtiDED IN TRANSMITTAL LETTER WELL NAME ~~ O PTD# ,~.~3 S- 2-.~~ CHECK WHAT APPLIES ADD-ONS "CLUE" MULTI ~ The permit is for a new wetlbore segment of LATERAL ~ existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits ' a function of the original API number stated are between 60-69) ~ above. PILOT HOLE ; In accordance with 20 AAC 25.005(f), all (per i records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (~0 - 70/80) from records, data and logs acquired for welt (name on permit). SPACL~iG i The permit is approved subject to full EXCEPTION ',i compliance with 20 AAC 25.05. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE ~ Commission must be in no greater than 30' j sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01!05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST' Field & Pool NORTHSTAR, NOf~THSTAR OIL - 590100 --- - ~ ~J______ -Well Name: NORTHSTAR 30___-_-_____ ___ --Program DEV______.___-__ Well bore seg iJ PTD#;2052070. ~lC~,oc~panyi;BP_EXPLORATION~LASKA~_I__NC _-.__-_ lnitu~BCtassfType __ DEV/1.OI_L__GeoArea ____ ___ _-__._ Unit ___ OnlOffShore On_____AnnularDisposal [_I Administration 1, Permit-feeat!ached-----.----------------- ---------- ---- YeS- -----------. 2 Lease number appropriate - - Yes . j3 Uniq~ewell-name.andnumbe( - Yes ~4 Well located m a_defined pool - - - - - _ - - Yes _ _ 5 Well located proper distance from-drilling unitboundarX _ Yes _ _ _ _ _ _ _ I6 Well located proper distance. from other wells- - _ . _ - - Yes - - - ~7 Sufficient acreage ayailaple in-drilling unit - - - - Yes - - - . - . - I8 If deviated, is_weJlbore plat-included _ - - - - - - _ - Yes _ _ _ _ _ _ _ _ - - ~9 Operator only affected party- - - -- - Yes - - I10 Operator has appropriaie_bond inforce - _ Yes - . _ : - 11 Permit can be issued without conservation order___--___-----_ _---_- .:Yes- -------- -----.--.-.- -- - - --- Appr Date ;12 Pe[mitean be issued without administrative_appCOYaI _ .. : , - - _ _ - - _ - Yes - . _ - . _ .. - _ - - . - .. - - - _ - - - - - . - _ _ _ - _ _ - - - - RPC 12122/2005 X13 Can permit be approved before 15-day wait. - _ . _ Yes - - _ _ _ _ - _ _ 1 (' j14 Well located within area and-strata authorized by Injection Order # (pUt 10# in comments)_(For_ NA_ _ ~1~ All wells-within 114_mileare_a of (eyiew identified (For service well only)- - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ 1,16 Pre-produced in}ector: duration of pre production less than_3months-(For service well only) NA_ - - - - - - - - . - - II ACMPFindingofOonsistency_has4@enisst~ed-for-thisp[o~ect__. ------ -._-_---NA__ ____ ________________________ __________..-.-- - -- -- ----- I-- Engineering i18 - - - -- ---- -- ---- Conductorstnntj ~cbt!ided --- Yes - 20" ~ 200'. x,19 Surface casing_protectsa!l-known_USDWs - _ . - - _ _ - ._ _ _ _ _ - - Yes _ - - - - _ - _ X20 CMT.votadequate_to circulake_on conducto[& surfcsg _ , - _ _ - .. Yes Adequate excess. - 29 CMT_vol adeguate_to tie-in long string to surf csg . .. . . . . . . . . :. . . . . No- - - - - - - - - 22 CMT will cover all known-productive horizons- - - - - - - - - - - - -- - - - - - - - - - - _ _ _ _ Yes : _ - - - - - - _ _ _ - ~~~23 _CasingdesignsadequateforC,T,B&_permafrost---------------- -.-------Yes- - _ .. -------=- ---- -_.- 24 Adequate tan_kage_or reserve pit - - - - - - - - - - - - - - -- - - - -- Yes _ _ Nabors-33E._ X25 If a-re-drill, has_a 10-403 for abandonment been approved - -- - - - - - - - - - - - - - - NA_ _ New well. - 26 Adequate wellbdre separation -proposed - Yes Two_ close a roaches. PR X27 If diverter required; does it meet regulations- - - - - - - - - - - - - -- - - - - - - - - - - - - - - NA_ Waiver_approved.- Appr Date X28 Drilling Huid_program schematic & equip list adequate- _ Yes - - - - - -Max MW 12~5- pPg• WGA 1212812005~29> BOPEs,dotheymeetregu_lation_------------------ Yes ---- - ---------- --_------- - ------- .---- .----- ---------- --- 130 BOPE-press rating appropriate;test to-(put prig in comments)- Yes _ _ Test to 5000 psi. _MSP $832 psi.- 31 Choke.manifgldcomplieswlAPI_RP-53(M_ay84)____________ ___ __ _ __ ____Yes: ____ ____ __-______ __.___ _ --_-_._- ---.._-- - 32 Work willoccurwithoutoperationshutdown---- ----------------- ---------Yes- .-.-_--._ .,- I,33 Ispresence_ofH2$gasprobable- - - - - - - - - - - - - - - - - _ _ No- - - ,.- 34 Mechanical condition of wells whhin AOR verified ~For.sennce well only) - - - _ - NA_ Geology I35 i _Permitcan be issued wlo-hydrogen_sulfide measures _ _ No_ _ _ 36 Data_presented on potential overpressure zones - - _ _ _ _ - - - - - - - - - - - - - - - - - - - NA_ _ __ _ _ _ _ - - - - - - - Appr Date 37 Seismic analysis_of shallow gas zones- _ . - _ - _ . _ - - - - - - - - - - - - - - - - - - - - - - - NA_ . RPC 12122!2005 ~i38 Seabed condition survey (ifoff-shore) . - . - - NA_ - 39 Contact namelphone for weekly-progress reports [exploratory only] _ - - - NA Geologic mmissionee Co Engineering Public Date: Commissioner: Date Comm' er Date ~ / / 9 •
