Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
202-021
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-08 (PTD 202-021) Perf 09/08/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 1:10 pm, Oct 19, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,030 11,199' & 11,720' feet true vertical 11,267 N/A feet Effective Depth measured 11,942 feet true vertical 11,180 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13Cr 11,298' 10,545' Packers and SSSV (type, measured and true vertical depth)See Above 991' MD / 991 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 9,554', 9,741', 11,170', 11,249', & 11,293' 8,913', 9,084', 10,420', 10,497' & 10,540' WINJ WAG 27,188 Water-Bbl MD 201' 3,328' 9,919' TVD 840 Oil-Bbl measured true vertical Packer 4-1/2" 11,461' 12,029' 20" 284 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL0312799 NORTHSTAR UNIT NS-08 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Casing Pressure Casing 4. Well Class Before Work: 243 Representative Daily Average Production or Injection Data 7571,064 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL Size STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-021 50-029-23068-00-00 5. Permit to Drill Number: Hilcorp Alaska LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-402 758 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 50 Gas-Mcf 51 Tubing Pressure 31,892 N/A measured 1,864' 736' N/A Liner Production Liner Conductor Length 201' 3,328' 9,919' Surface Intermediate 7,240psi 9-5/8" 7" 8,430psi 3,220' 9,247' 10,705' 13-3/8" 2. Operator Name N Senior Engineer: Senior Res. Engineer: Collapse N/A 2,260psi 11,266' 201' 4,760psi 5,410psi 4-1/2" TRMAXX-5E SSSV 9-5/8"x4-1/2" Premier, 9-5/8"x7" LTP, 7'x4-1/2" Premier, Baker S-3, LTP 7,500psi 777-8333 Burst N/A 5,020psi 6,870psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:43 pm, Sep 28, 2021 Chad Helgeson (1517) 2021.09.28 13:38:17 - 08'00' DSR-9/28/21 MGR11OCT2021 DSR-9/29/21 SFD 9/29/2021RBDMS HEW 9/30/2021 Well Name Rig API Number Well Permit Number Start Date End Date NS-08 Eline 50-029-23068-00-00 202-021 9/8/2021 9/8/2021 9/10/2021 - Friday No operations to report. 9/8/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU E-LINE. PERFORATE FROM 9736-9741 AND 9705-9710 WITH 3.125" 6SPF 60PHASE HSC W/MAXFORCE CHARGES. RDMO ELINE. 9/9/2021 - Thursday No operations to report. No operations to report. No operations to report. 9/11/2021 - Saturday No operations to report. 9/14/2021 - Tuesday 9/12/2021 - Sunday No operations to report. 9/13/2021 - Monday _____________________________________________________________________________________ Revised By: DH 9/28/2021 SCHEMATIC Northstar Unit Well: NS-08 Last Completed: 12/25/2005 PTD: 202-021 TD = 12,030’ (MD) / TD =11,267’(TVD) 3 20” RKB Elev.: 55.7’/ GL Elev.: 15.67’ 7” DV Tool @ 1,582’ 5 10 1 1 12 13 14 15 16 9-5/8” 1 17 18 TOC @ 11,695’ PBTD =11,942’(MD) / PBTD =11,180’(TVD) 6 Min ID 3.725” @ 11,220’ 4-1/2” 13-3/8 ” 8 9 7 2 4 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 169 / X-56 / N/A N/A Surface 201’ 13-3/8” Surface 68/ L-80/ BTC 12.415 Surface 3,328’ 9-5/8" Intermediate 47 / L-80 / BTC-M 8.681 Surface 9,919’ 7" Production 26/ L-80/ BTC-M 6.276 9,741’ 11,461’ 4-1/2” Liner 12.6/ 13CR/ VAM-ACE 3.958 11,293’ 12,029’ TUBING DETAIL 4-1/2" Tubing 12.6/ 13CR/ VamTop/ Ace 3.958 Surface 11,298’ JEWELRY DETAIL No Depth Item 1 991’ 4-1/2” TRMAXX-5E SSSV w/ X Profile ID= 3.813” 24,745’ST 1: Port= 0, Dev.= 27, VLV= DMY, Type= SMOR, TVD= 3,745’, 1/9/2006 3 9,466’ 4.5” X Nipple – ID= 3.813” 4 9,529’ 4.5” CIDRA Gauge Mandrel ; Fiber Optic Transducer 5 9,554’ Baker 9-5/8” x 4-1/2” Premier 13CR Packer 6 9,581’ 4-1/2” 12.6# XD Duro Sliding Side Door – Open 7 9,689’ 4-1/2” 12.6# XD Duro Sliding Side Door - Open 8 9,741’ 9-5/8” x 7” Liner Top Packer 9 11,149’ 4.5” X Nipple – ID= 3.813” 10 11,170’ 7” x 4-1/2” Premier 13CR Packer 11 11,199’ 4.5” X Nipple – ID= 3.813” 12 11,220’ 4.5” XN Nipple–ID= 3.725” No Go (11,235’ ELMD) 13 11,231’ 4-1/2” 9CR X 7” 26# Unique Overshot w/ Sheer Pins – Bottom @ 11,241’ 14 11,249’ 7” x 4-1/2” Baker S-3 Packer 15 11,273’ 4.5” X Nipple – ID= 3.813” 16 11,284’ 4.5” XN Nipple –ID= 3.725” No Go 17 11,293’ 7” x 4-1/2” Liner Top Packer 18 11,297’ Wireline Entry Guide 19 11,720’ ELMD CIBP set on 6/22/18 w/ 25’ of cement on top-Placed on 8/17/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 590 sx PF ‘L’, 470 sx Class ‘G’ in 16” Hole 9-5/8" 553 sx Econolite, 517 sx ‘G’ in a 12-1/4” Hole 7” 273 sx Class “G” in 8-1/2” Hole 4-1/2” 105 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,575’ Max Hole Angle = 28 deg. @ 4,654’ Angle at Top Perf = 23 Deg. @ 9,268’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23068-00-00 Drilled, Cased & Completed by Nabors 33E - 3/22/2002 2nd Completion w/ Nabors 33E – 12/25/2005 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 9,628’ 9,668’ 8,980’ 9,017’ 40 12/16/2005 Open Kuparuk A3 9,705’ 9,715’ 9,051’ 9,060’ 10 9/8/2021 Open Kuparuk A2 9,736’ 9,741’ 9,079’ 9,084’ 5 9/8/2021 Open Ivishak 11,755’ 11,910’ 10,995’ 10,250’ 155 8/23/2005 Closed, Sqz’d 11,886’ 11,912’ 11,124’ 10,375’ 26 3/28/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 6/1/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 8/28/2008 Closed 11,891’ 11,910’ 11,129’ 11,148’ 19 12/6/2004 Closed Ref Log: SWS Usit on 3/18/2002 (No logs @ PBOC 1/23/2006) – Initial Perf Charge 2906 Powerjet, HMX 6 SPF, Penetration 27”, Hole 0.36”, Phase 60 Degree. Kuparuk A3 9,051’9,060’10 9/8/2021 Open Kuparuk A2 9,079’9,084’5 9/8/2021 Open 9,715’ 9,736’ 9,705’ 9,741’ _____________________________________________________________________________________ Revised By: DH 9/28/2021 SCHEMATIC Northstar Unit Well: NS-08 Last Completed: 12/25/2005 PTD: 202-021 TD = 12,030’ (MD) / TD =11,267’(TVD) 3 20” RKB Elev.: 55.7’/ GL Elev.: 15.67’ 7” DV Tool @ 1,582’ 5 10 1 1 12 13 14 15 16 9-5/8” 1 17 18 TOC @ 11,695’ PBTD =11,942’(MD) / PBTD = 11,180’(TVD) 6 Min ID 3.725” @ 11,220’ 4-1/2” 13-3/8” 8 9 7 2 4 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 169 / X-56 / N/A N/A Surface 201’ 13-3/8” Surface 68/ L-80/ BTC 12.415 Surface 3,328’ 9-5/8" Intermediate 47 / L-80 / BTC-M 8.681 Surface 9,919’ 7" Production 26/ L-80/ BTC-M 6.276 9,741’ 11,461’ 4-1/2” Liner 12.6/ 13CR/ VAM-ACE 3.958 11,293’ 12,029’ TUBING DETAIL 4-1/2" Tubing 12.6/ 13CR/ VamTop/ Ace 3.958 Surface 11,298’ JEWELRY DETAIL No Depth Item 1 991’ 4-1/2” TRMAXX-5E SSSV w/ X Profile ID= 3.813” 24,745’ST 1: Port= 0, Dev.= 27, VLV= DMY, Type= SMOR, TVD= 3,745’, 1/9/2006 3 9,466’ 4.5” X Nipple – ID= 3.813” 4 9,529’ 4.5” CIDRA Gauge Mandrel ; Fiber Optic Transducer 5 9,554’ Baker 9-5/8” x 4-1/2” Premier 13CR Packer 6 9,581’ 4-1/2” 12.6# XD Duro Sliding Side Door – Open 7 9,689’ 4-1/2” 12.6# XD Duro Sliding Side Door - Open 8 9,741’ 9-5/8” x 7” Liner Top Packer 9 11,149’ 4.5” X Nipple – ID= 3.813” 10 11,170’ 7” x 4-1/2” Premier 13CR Packer 11 11,199’ 4.5” X Nipple – ID= 3.813” 12 11,220’ 4.5” XN Nipple–ID= 3.725” No Go (11,235’ ELMD) 13 11,231’ 4-1/2” 9CR X 7” 26# Unique Overshot w/ Sheer Pins – Bottom @ 11,241’ 14 11,249’ 7” x 4-1/2” Baker S-3 Packer 15 11,273’ 4.5” X Nipple – ID= 3.813” 16 11,284’ 4.5” XN Nipple –ID= 3.725” No Go 17 11,293’ 7” x 4-1/2” Liner Top Packer 18 11,297’ Wireline Entry Guide 19 11,720’ ELMD CIBP set on 6/22/18 w/ 25’ of cement on top-Placed on 8/17/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 590 sx PF ‘L’, 470 sx Class ‘G’ in 16” Hole 9-5/8" 553 sx Econolite, 517 sx ‘G’ in a 12-1/4” Hole 7” 273 sx Class “G” in 8-1/2” Hole 4-1/2” 105 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,575’ Max Hole Angle = 28 deg. @ 4,654’ Angle at Top Perf = 23 Deg. @ 9,268’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23068-00-00 Drilled, Cased & Completed by Nabors 33E - 3/22/2002 2nd Completion w/ Nabors 33E – 12/25/2005 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 9,628’ 9,668’ 8,980’ 9,017’ 40 12/16/2005 Open Kuparuk A3 9,705’ 9,715’ 9,051’ 9,060’ 10 9/8/2021 Open Kuparuk A2 9,735’ 9,740’ 9,079’ 9,083’ 5 9/8/2021 Open Ivishak 11,755’ 11,910’ 10,995’ 10,250’ 155 8/23/2005 Closed, Sqz’d 11,886’ 11,912’ 11,124’ 10,375’ 26 3/28/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 6/1/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 8/28/2008 Closed 11,891’ 11,910’ 11,129’ 11,148’ 19 12/6/2004 Closed Ref Log: SWS Usit on 3/18/2002 (No logs @ PBOC 1/23/2006) – Initial Perf Charge 2906 Powerjet, HMX 6 SPF, Penetration 27”, Hole 0.36”, Phase 60 Degree. Superseded 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,030'N/A Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Liner 5,410psi Production Liner 7,500psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade:Tubing MD (ft): COMMISSION USE ONLY Authorized Name: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 202-021 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23068-00-00 Hilcorp Alaska LLC Length Size 11,267' 11,942' 11,180' 1,600 11,199' NORTHSTAR / NORTHSTAR OIL & KUPARUK OIL 201' 201' 12.6 / 13 Cr-80 / Vam Top & Ace TVD Burst 11,298' 8,430psi MD N/A 7,240psi 5,020psi 6,870psi 3,220' 9,247' 10,705' 3,328' 9,919' 4-1/2" 201' 20" 13-3/8" 9-5/8" 3,328' 7"1,864' 9,919' Authorized Signature: 9/3/2021 4-1/2" Perforation Depth MD (ft): See Schematic 9,554 MD/ 8,913 TVD, 9,741 MD/ 9,084 TVD, 11,170 MD/ 10,420 TVD, 11,249 MD/ 10,497 TVD & 11,293 MD/ 10,540 TVD and 991 MD/ 991 TVD See Schematic Perforation Depth TVD (ft): Tubing Size: dgorm@hilcorp.com NORTHSTAR UNIT NS-08 C.O. 458A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12,029' 11,461' 9-5/8" x 4-1/2" Baker Pkr, 9-5/8" x 7" LTP, 7" x 4-1/2" Baker Premier, 7" x 4-1/2" Baker S-3 & 7" x 4-1/" LTP and- /" TRM-4E SCSSSV 736' 11,266' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:59 pm, Aug 16, 2021 321-402 Chad Helgeson (1517) 2021.08.16 13:28:22 - 08'00' X MGR17AUG21 10-404 DLB 08/17/2021 DSR-8/16/21 dts 8/17/2021 JLC 8/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.18 11:49:51 -08'00' RBDMS HEW 8/19/2021 Perf Add (A sand) Well: NS-08 PTD: 202-021 API: 50-029-23068-00-00 Well Name:NS-08 API Number:50-029-23068-00-00 Current Status:Online Rig:E-line Estimated Start Date:September 3, 2021 Estimated Duration:1 Day Reg.Approval Req’std?August 13, 2021 Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:202-021 First Call Engineer:Joleen Oshiro (650)-483-4774 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE: SWIS Entry Required:Yes Current Bottom Hole Pressure:2500 psi @ 9,000’ TVDss (Based on BHP of offset Kuparuk producers taken in late 2020) MPSP:1600 psi (0.1 psi/ft gas gradient) Max Deviation: 28° at 4,654’ Minimum ID: 3.725” XN Nipple @ 11,220’ and 11, 284’. Reference Log:SLB, USIT Log, 3/18/2002 Brief Well Summary: NS-08 is the first Kuparuk producer at Northstar (Kuparuk only since 2010). NS-08 is currently online, producing from the Kuparuk C2 and C1 sands; it currently makes 250 bopd and 26 mmscfd of gas. The Kuparuk A3 and A2 sands are identified pay zones that are not yet perforated in NS-08. Objective: Add perforations in the Kupaurk A3 and A2 sands Gun Run # Perf Top Perf Bottom Perf Length Formation 1 ±9,735’ MD ±9,740’ MD 5’ Kuparuk A2 2 ±9,705’ MD ±9,715’ MD 10’ Kuparuk A3 Total 15’ Table 1: NS-08 Proposed Perf Gun Run Note: Final depths to be confirmed in “Final Approved Perf Sheet” Procedure: Slickline 1. RU SL unit. Pressure test PCE to 250 psi low / 3,500 psi high. 2. Drift with BHA that sufficiently emulates a 10’ x 3-1/8’’ Halliburton MaxForce 230 perforation gun run (max swell in liquid = 3.338’’) a. Target drift depth 9,760’ MD. b. If drift will not get down to target depth, change up BHA length and size. If still does not get down to target depth, contact OE. 3. RD SL unit. Eline (Approved Sundry required prior to proceeding) 4. RU EL unit and pressure test to 250psi low 2,500psi high. 5. RIH and correlate perforation gun run to Tie-In Log. Contact OE (contact info above) prior to perforating for final approval of tie in. 6. MU perforating tool strings with 3-1/8” Halliburton MaxForce 230 guns (6 spf, 60deg phasing) Perf Add (A sand) Well: NS-08 PTD: 202-021 API: 50-029-23068-00-00 7. Perforate as per Table 1: NS-08 Proposed Perf Gun Run. POOH. a. Note any tubing pressure change in WSR. b. Ensure Correlation Pass and Shooting Passes have GR/CCL displayed 8. RD Eline. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 9/7/2018 SCHEMATIC Northstar Unit Well: NS-8 Last Completed: 12/25/2005 PTD: 202-021 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 9,628’ 9,668’ 8,980’ 9,017’ 40 12/16/2005 Open Ivishak 11,755’ 11,910’ 10,995’ 10,250’ 155 8/23/2005 Closed, Sqz’d 11,886’ 11,912’ 11,124’ 10,375’ 26 3/28/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 6/1/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 8/28/2008 Closed 11,891’ 11,910’ 11,129’ 11,148’ 19 12/6/2004 Closed Ref Log: SWS Usit on 3/18/2002 (No logs @ PBOC 1/23/2006) – Initial Perf Charge 2906 Powerjet, HMX 6 SPF, Penetration 27”, Hole 0.36”, Phase 60 Degree. TD = 12,030’ (MD) / TD =11,267’(TVD) 3 20” RKB Elev.: 55.7’/ GL Elev.: 15.67’ 7” DV Tool @ 1,582’ 5 10 11 12 13 14 15 16 9-5/8” 1 17 18 TOC @ 11,695’ PBTD = 11,942’ (MD) / PBTD = 11,180’(TVD) 6 4-1/2” 13-5/8” 8 9 7 2 4 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 169 / X-56 / N/A N/A Surface 201’ 13-3/8” Surface 68/ L-80/ BTC 12.415 Surface 3,328’ 9-5/8" Intermediate 47 / L-80 / BTC-M 8.681 Surface 9,919’ 7" Production 26/ L-80/ BTC-M 6.276 9,741’ 11,461’ 4-1/2” Liner 12.6/ 13CR/ VAM-ACE 3.958 11,293’ 12,029’ TUBING DETAIL 4-1/2" Tubing 12.6/ 13CR/ VamTop/ Ace 3.958 Surface 11,298’ JEWELRY DETAIL No Depth Item 1 991’ 4-1/2” TRMAXX-5E SSSV w/ X Profile ID= 3.813” 24,745’ST 1: Port= 0, Dev.= 27, VLV= DMY, Type= SMOR, TVD= 3,745’, 1/9/2006 3 9,466’ 4.5” X Nipple – ID= 3.813” 4 9,529’ 4.5” CIDRA Gauge Mandrel ; Fiber Optic Transducer 5 9,554’ Baker 9-5/8” x 4-1/2” Premier 13CR Packer 6 9,581’ 4-1/2” 12.6# XD Duro Sliding Side Door – Open 7 9,689’ 4-1/2” 12.6# XD Duro Sliding Side Door - Open 8 9,741’ 9-5/8” x 7” Liner Top Packer 9 11,149’ 4.5” X Nipple – ID= 3.813” 10 11,170’ 7” x 4-1/2” Premier 13CR Packer 11 11,199’ 4.5” X Nipple – ID= 3.813” 12 11,220’ 4.5” XN Nipple–ID= 3.725” No Go (11235’ ELMD) 13 11,231’ 4-1/2” 9CR X 7” 26# Unique Overshot w/ Sheer Pins – Bottom @ 11,241’ 14 11,249’ 7” x 4-1/2” Baker S-3 Packer 15 11,273’ 4.5” X Nipple – ID= 3.813” 16 11,284’ 4.5” XN Nipple –ID= 3.725” No Go 17 11,293’ 7” x 4-1/2” Liner Top Packer 18 11,297’ Wireline Entry Guide 19 11,720’ ELMD CIBP set on 6/22/18 w/ 25’ of cement on top-Placed on 8/17/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 590 sx PF ‘L’, 470 sx Class ‘G’ in 16” Hole 9-5/8" 553 sx Econolite, 517 sx ‘G’ in a 12-1/4” Hole 7” 273 sx Class “G” in 8-1/2” Hole 4-1/2” 105 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,575’ Max Hole Angle = 28 deg. @ 4,654’ Angle at Top Perf = 23 Deg. @ 9,268’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23068-00-00 Drilled, Cased & Completed by Nabors 33E - 3/22/2002 2nd Completion w/ Nabors 33E – 12/25/2005 _____________________________________________________________________________________ Revised By: TDF 8/12/2021 PROPOSED Northstar Unit Well: NS-8 Last Completed: 12/25/2005 PTD: 202-021 TD = 12,030’ (MD) / TD =11,267’(TVD) 3 20” RKB Elev.: 55.7’/ GL Elev.: 15.67’ 7” DV Tool @ 1,582’ 5 10 1 1 12 13 14 15 16 9-5/8” 1 17 18 TOC @ 11,695’ PBTD =11,942’(MD) / PBTD = 11,180’(TVD) 6 4-1/2” 13-3/8” 8 9 7 2 4 19 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 169 / X-56 / N/A N/A Surface 201’ 13-3/8” Surface 68/ L-80/ BTC 12.415 Surface 3,328’ 9-5/8" Intermediate 47 / L-80 / BTC-M 8.681 Surface 9,919’ 7" Production 26/ L-80/ BTC-M 6.276 9,741’ 11,461’ 4-1/2” Liner 12.6/ 13CR/ VAM-ACE 3.958 11,293’ 12,029’ TUBING DETAIL 4-1/2" Tubing 12.6/ 13CR/ VamTop/ Ace 3.958 Surface 11,298’ JEWELRY DETAIL No Depth Item 1 991’ 4-1/2” TRMAXX-5E SSSV w/ X Profile ID= 3.813” 24,745’ST 1: Port= 0, Dev.= 27, VLV= DMY, Type= SMOR, TVD= 3,745’, 1/9/2006 3 9,466’ 4.5” X Nipple – ID= 3.813” 4 9,529’ 4.5” CIDRA Gauge Mandrel ; Fiber Optic Transducer 5 9,554’ Baker 9-5/8” x 4-1/2” Premier 13CR Packer 6 9,581’ 4-1/2” 12.6# XD Duro Sliding Side Door – Open 7 9,689’ 4-1/2” 12.6# XD Duro Sliding Side Door - Open 8 9,741’ 9-5/8” x 7” Liner Top Packer 9 11,149’ 4.5” X Nipple – ID= 3.813” 10 11,170’ 7” x 4-1/2” Premier 13CR Packer 11 11,199’ 4.5” X Nipple – ID= 3.813” 12 11,220’ 4.5” XN Nipple–ID= 3.725” No Go (11235’ ELMD) 13 11,231’ 4-1/2” 9CR X 7” 26# Unique Overshot w/ Sheer Pins – Bottom @ 11,241’ 14 11,249’ 7” x 4-1/2” Baker S-3 Packer 15 11,273’ 4.5” X Nipple – ID= 3.813” 16 11,284’ 4.5” XN Nipple –ID= 3.725” No Go 17 11,293’ 7” x 4-1/2” Liner Top Packer 18 11,297’ Wireline Entry Guide 19 11,720’ ELMD CIBP set on 6/22/18 w/ 25’ of cement on top-Placed on 8/17/2018 OPEN HOLE / CEMENT DETAIL 13-3/8” 590 sx PF ‘L’, 470 sx Class ‘G’ in 16” Hole 9-5/8" 553 sx Econolite, 517 sx ‘G’ in a 12-1/4” Hole 7” 273 sx Class “G” in 8-1/2” Hole 4-1/2” 105 sks Class “G” in 6-1/8” Hole WELL INCLINATION DETAIL KOP @ 1,575’ Max Hole Angle = 28 deg. @ 4,654’ Angle at Top Perf = 23 Deg. @ 9,268’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23068-00-00 Drilled, Cased & Completed by Nabors 33E - 3/22/2002 2nd Completion w/ Nabors 33E – 12/25/2005 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C 9,628’ 9,668’ 8,980’ 9,017’ 40 12/16/2005 Open Kuparuk A3 ±9,705’ ±9,715’ ±9,051’ ±9,060’ 10 Future Pending Kuparuk A2 ±9,735’ ±9,740’ ±9,079’ ±9,083’ 5 Future Pending Ivishak 11,755’ 11,910’ 10,995’ 10,250’ 155 8/23/2005 Closed, Sqz’d 11,886’ 11,912’ 11,124’ 10,375’ 26 3/28/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 6/1/2006 Closed 11,886’ 11,912’ 11,124’ 10,375’ 26 8/28/2008 Closed 11,891’ 11,910’ 11,129’ 11,148’ 19 12/6/2004 Closed Ref Log: SWS Usit on 3/18/2002 (No logs @ PBOC 1/23/2006) – Initial Perf Charge 2906 Powerjet, HMX 6 SPF, Penetration 27”, Hole 0.36”, Phase 60 Degree. • • • of 77. ewe\����//7- �� THE STATE Alaska Oil and Gas ofALASKA Conservation Commission Sf# 333 West Seventh Avenue Anchorage, Alaska 99501-3572 *h , GOVERNOR BILL WALKER g Main: 907.279.1433 (4 ALAS*P- Fax: 907.276.7542 www.aogcc.alaska.gov Bo York SCANNED Operations Manager Hilcorp Alaska LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Northstar Field,Kuparuk Undefined Oil Pool,NU NS-08 Permit to Drill Number: 202-021 Sundry Number: 318-089 Dear Mr. York: 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, Hollis S. French Chair DATED this 6 day of March,2018. RP11:!S L MA - 2118 E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR2 Q APPLICATION FOR SUNDRY APPROVALS DIS 3/4(ice ,. r3 e 20 AAc 25.280 A . 1.Type of Request: Abandon ❑ Plug Perforations❑, • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . 202-021 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23068-00-00 • 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 U NORTHSTAR UNIT NS-08 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799• NORTHSTAR/KUPARUK UNDEF 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): 12,030' ' 11,267' 11,942' 11,180' 4,063 11,199' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,328' 13-3/8" 3,328' 3,220' 5,020psi 2,260psi Intermediate 9,919' 9-5/8" 9,919' 9,247' 6,870psi 4,760psi Liner 1,864' 7" 11,461' 10,705' 7,240psi 5,410psi Production Liner 736' 4-1/2" 12,029' 11,266' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/13 Cr-80/Vam Top&Ace 11,298' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 4-1/2"Baker Pkr,9-5/8"x 7"LTP,7"x 4-1/2"Baker Premier,7"x 4- 9,554 MD/8,913 TVD,9,741 MD/9,084 TVD, 11,170 MD/10,420 TVD,11,249 MD/ 1/2"Baker S-3&7"x 4-1/"LTP and-I"TRM-4E SCSSSV 10,497 TVD&11,293 MD/10,540 TVD and 991 MD/991 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑� Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 3/16/2018 Commencing Operations: OIL Q • 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. qe./L.I( Authorized Name: Bo York Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrivard(p,hiIcorp.com Contact Phone: 777-8547 Authorized Signature:f7/, ''.----Date: 3/2/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: rd — C551 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1' 1 Spacing Exception Required? Yes ❑ No Ei Subsequent Form Required: / 0 Li o R } I"i 't i�IS APPROVED BY / /� Approved by: COZDC/NCOMMISSIONER THE COMMISSION Date: 3 Ib t CJ Submit Form and Form 10-403 Revised 4/2017 Approved appli as o �1 �Ici'bIN0 S rom the date of approval. achme sin Duplicate • II • • Ivishak P&A Well: NS-08 PTD: 202-021 Hilcora Alaska,LLQ API: 50-029-23068-00-00 Well Name: NS-08 API Number: 50-029-23068-00-00 Current Status: SI Rig: SL Estimated Start Date: Mar 16, 2018 Estimated Duration: 7 day Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 202-021 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Well EZ Required Yes Current Bottom Hole Pressure: 3,553 psi @ 9,000'TVDSS (Based on KUP SBHPS, NS-08 5/8/17) • Maximum Expected BHP: 5,173 psi @ 11,100'TVDSS (Based on IVISH SBHPS, NS-13 4/13/17) Max. Proposed Surface Pressure: 4,063 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 2,467psi (Taken on 3/1/18) Min ID: 3.725" ID XN Nip @ 11220' Reference Log: SLB Cement Evaluation Log dated 3/18/2002 Brief Well Summary: The NS-08 well was originally completed as an Ivishak producer but was recompleted with the option to produce from the Kuparuk formation through a sliding sleeve in 2005. Starting in 2010,the Ivishak was isolated with a tubing tail plug and the sliding sleeve was shifted open to begin producing from the Kuparuk only.The well continues to be highly successful as a Kuparuk producer with no future potential for conversion back to the Ivishak. The Ivishak reservoir abandonment should be finalized to ensure continued isolation between the two reservoirs. r d3,,'z w/ ` T Notes Regarding Wellbore Conditions: • Slow down while running in hole past sliding sleeves at 9581' and 9689'to avoid inadvertently opening sleeves.This is especially important when there is no plug providing additional isolation between the Ivishak and Kuparuk. Objective: • Use slickline to shift Kuparuk sliding sleeve closed then pull TTP. • Set a CIBP above the Ivishak perfs and dump bail cement to complete P&A of the Ivishak. • Open sliding sleeves back up for production from Kuparuk. Sundry Procedure(Approval Required to Proceed): Slickline& Hot Oil 1. RU SL unit and pressure test to 300psi low/4500 psi high. 2. RIH and shift closed 4-1/2"XD Sliding Sleeve at 9581'then POOH. 1('1 a. Sleeve is Shift Up to close. WSR Note from sleeve opening on 10/4/10: "S/D IN SLIDING SLEEVE @ 9537 SLM/9581'MD,JAR DOWN LIGHTLY, SEE TUBING PRESSURE START TO FALL. TUBING PRESSURE DROPPED TO 3100 PSI, RESUME JARRING DOWN,AFTER ^'10-MIN. FELL THRU SLV, PULLED BACK UPHOLEAND PASSED THRU A COUPLE TIMES....- USED 4280 SHIFTING TOOL WITH SELF-RELEASING KEYS" b. Drawdown wellbore to flowline pressure,SI and monitor for 30 min to verify sleeve holding i. Well flows unassisted from Kuparuk to"'750 psi. Drawdown test needed to confirm sleeve closed and Kuparuk isolated before proceeding to plug pull. 3. RIH and equalize 4-1/2" PXN Plug at 11220' MD. • • Ivishak P&A Well: NS-08 PTD: 202-021 flilcorp Alaska,LU API: 50-029-23068-00-00 a. Apply ^'3000 psi gas pressure to the tubing prior to equalizing plug. b. WSR note from 10/3/10 PXN set: "T/1/0: 3800/50/50 RIH WITH 4 1/2" PXN PLUG BODY(4 X 3/16"eq. ports) .SHIFT X-LINE IN X-NIPPLE @ 11,156'SLM. S/D @ 11,176'SLM ATTEMPT TO SET PLUG FOR 25 MIN, PULL TEST&PULLED OUT OF NIPPLE @ 1100 lbs. CREW CHANGE TO WADDELL. JAR DOWN 30 min, SEE DOUBLE BOBBLE. PULL TEST. SHEAR OFF 1 LICK. LOST WEIGHT, POOH" 4. Pull 4-1/2" PXN Plug body at 11220' MD. 5. MU Cement Bailer drift and drift to at least 11,850'. POOH. 6. MU 4-1/2" CIBP Drift and drift to 11,850'. POOH 7. Rig up LRS unit to 500 bbl Upright tank prefilled with at least 400 bbls ambient seawater 8. Roll tanks while heating seawater until heated to at least—70 degF. 9. Rig up hardline from LRS skid to Pump In Sub and pressure test to 300psi low/4500psi high. 10. Begin to pump hot seawater from upright tank into the well at max rate until at least 270 bbls away. a. Wellbore volume of 4-1/2 tubing and liner is (.0152 bpf* 11,800' =± 180 bbls) b. Seawater heated to at least 70degF needed to minimize contraction forces on tubing 11. Once 270 bbls away, decrease rate but continue to pump as needed to maintain fluid pack. 12. Rig up GR/CCL memory tools. a. Record length from Quick Connect to GR/CCL Reference Point. 13. RIH and begin to pull GR/CCL Tie-In pass up from 11,850' SLM 14. Stop and paint flag at—11,750'SLM, continue logging up to 11,200' SLM. POOH. a. Reference Log: SLB Cement Evaluation Log dated 3/18/2002 b. Obtain corrected Quick Connect depth at flag c. Avoid trimming wire, changing lubricator or reconfiguring tool string above Quick Connect between tie-in and setting runs. 15. MU 4-1/2" CIBP and setting tool. a. Record length from Quick Connect to CIBP Mid Element. RIH. 16. Swap pumping to diesel and ensure tubing freeze protected to ± 1600' (At least 25 bbls diesel) prior to plug set. 17. RIH to flag and reset counter to corrected Quick Connect depth.Add Quick Connect to Mid Element Length to depth. 1. Confirm flag and depth corrections with OE Wyatt Rivard at 1(509) 670-8001 or Taylor Wellman at I,! 1(907) 947-9533 prior to plug set for final approval of tie in. 18. Set 4-1/2" CIBP at a mid-element set depth of± 11,720' MD. Following set,tag CIBP to confirm. POOH a. ±11,720' MD places CIBP 35ft above uppermost perforations and 10' below 4-1/2" liner joint. i 19. MIT-T to 2000 psi for 30 minutes. Chart 20. RDMO Hot Oil 21. Following good MIT, dump bail minimum of 25' of cement onto plug a. 4-1/2" Liner volume of 2.184 gpf should require at least 55 gallons of cement b. BHT is 250 degF for cement blend 22. Verify with final tag that Top of Cement is at±11,695' at least 25' above plug. 23. RIH and shift 4-1/2"XD Sliding Sleeve at 9689' to Open 24. Shift 4-1/2" XD Sliding Sleeve at 9581'to Open. POOH 25. RDMO SL Attachments: Proposed Schematic/Well Schematic • Northstar Unit 11 • Well: NS-8 PROPOSED Last Completed: 12/25/2005 Hamra Alaska,LLC PTD:202-141 TREE&WELLHEAD RKB Elev.:55.7'/GL Elev.:15.67' Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20 I OPEN HOLE/CEMENT DETAIL 13-3/8" 590 sx PF'L',470 sx Class'G'in 16"Hole 1 9-5/8" 553 sx Econolite,517 sx'G'in a 12-1/4"Hole I 7" 273 sx Class"G"in 8-1/2"Hole DVTooI 4-1/2" 105 sks Class"G"in 6-1/8"Hole @ 1,582' 13-5/8" I' CASING DETAIL 1. Size Type Wt/Grade/Conn ID Top Btm 2 20" Conductor 169/X-56/N/A N/A Surface 201' 13-3/8" Surface 68/L-80/BTC 12.415 Surface 3,328' 9-5/8" Intermediate 47/L-80/BTC-M 8.681 Surface 9,919' 7" Production 26/L-80/BTC-M 6.276 9,741' 11,461' 44 t4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 11,293' 12,029' TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VamTop/Ace 3.958 Surface 11,298' 4-.7- , 3 WELL INCLINATION DETAIL j•; KOP @ 1,575' 4 Max Hole Angle=28 deg. @ 4,654' 5 Angle at Top Perf=23 Deg.@ 9,268' •(•c•',6 JEWELRY DETAIL •c•(• 7 No Depth Item 991' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" 8 2 4,745' ST 1:Port=0,Dev.=27,VLV=DMY,Type=SMOR,TVD= 3,745', 1/9/2006 9-5/8"1 t 1 3 9,466' 4.5"X Nipple-ID=3.813" 4 9,529' 4.5"CIDRA Gauge Mandrel;Fiber Optic Transducer 5 9,554' Baker 9-5/8"x 4-1/2"Premier 13CR Packer Ii 9 6 9,581' 4-1/2"12.6#XD Duro Sliding Side Door-Open _ 7 9,689' 4-1/2"12.6#XD Duro Sliding Side Door-Open f� 10 8 9,741' 9-5/8"x 7"Liner Top Packer 4 11 9 11,149' 4.5"X Nipple-ID=3.813" 10 11,170' 7"x 4-1/2"Premier 13CR Packer a 11 11,199' 4.5"XNipple-ID=3.813" *- 12 12 11,220' 4.5"XN Nipple-ID=3.725"No Go 13 11,231' 4-1/2"9CR X 7"26#Unique Overshot w/Sheer Pins-Bottom @ 11,241' 13 ' 14 11,249' 9-5/8"x 4-1/2"Baker S-3 Packer f ,:t 14 15 11,273' 4.5"X Nipple-ID=3.813" 16 11,284' 4.5"XN Nipple-ID=3.725"No Go g umoti 15 . 17 11,293' 7"x 4-1/2"Liner Top Packer 18 11,297' Wireline Entry Guide r16 19 ±11,720' CIBP w/25'of cement on top PERFORATION DETAIL to; , r, ;p 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 18 7" a t 9,628' 9,668' • 8,980' 9,017' 40 12/16/2005 Open 11,755' 11,895' • 10,995' 10,250' 140 3/19/2002 Open 11,755' 11,910' . 10,995' 10,250' 155 8/23/2005 Partial Sqz "" t` Kuparuk Undef. 11,886' 11,912' 11,124' 10,375' 26 3/28/2006 Open ±11,69` 11,886' 11,912' 11,124' 10,375' 26 6/1/2006 Open 11,886' 11,912' 11,124' 10,375' 26 8/28/2008 Open 19 11,891' 11,910' • 11,129' 11,148' 19 12/6/2004 Open ' Ref Log:SWS Usit on 3/18/2002(No logs @ PBOC 1/23/2006)-Initial Perf Charge 2906 Powerjet,HMX 6 SPF, Penetration 27",Hole 0.36",Phase 60 Degree. 41/Y' * GENERAL WELL INFO API:50-029-23068-00-00 TD=12,030'(MD)/TD=11,267'(TVD) Drilled,Cased&Completed by Nabors 33E -3/22/2002 PBTD=11,942'(MD)/PBTD=11,180'(TVD) 2nd Completion w/Nabors 33E-12/25/2005 Revised By:TDF 3/2/2018 Northstar Unit B 0 • Well: NS-8 SCHEMATIC Last Completed: 12/25/2005 Flacon)afazl,.LLC PTD: 202-141 TREE&WELLHEAD RKB Elev.:55.7'/GL Elev.:15.67' Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20 J. �' OPEN HOLE CEMENT DETAIL , 13-3/8" 590 sx PF'L',470 sx Class'G'in 16"Hole 4I 1 a 9-5/8" 553 sx Econolite,517 sx`G'in a 12-1/4"Hole ■ 7" 273 sx Class"G"in 8-1/2"Hole DV Tool 4-1/2" 105 sks Class"G"in 6-1/8"Hole @1,582' 13-5/8CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 2 20" Conductor 169/X-56/N/A N/A Surface 201' 13-3/8" Surface 68/L-80/BTC 12.415 Surface 3,328' 9-5/8" Intermediate 47/L-80/BTC-M 8.681 Surface 9,919' 7" Production 26/L-80/BTC-M 6.276 9,741' 11,461' 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 11,293' 12,029' TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VamTop/Ace 3.958 Surface 11,298' WELL INCLINATION DETAIL 4 KOP @ 1,575' MIA IMax Hole Angle=28 deg. @ 4,654' 5 Angle at Top Perf=23 Deg.@ 9,268' 4' 44(.' 6 JEWELRY DETAIL .(.c. 7 No Depth Item 1 991' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" k 8 2 4,745' ST 1:Port=0,Dev.=27,VLV=DMY,Type=SMOR,TVD= 3,745', 1/9/2006 9-5/8"a A 3 9,466' 4.5"XNipple-ID=3.813" 4 9,529' 4.5"CIDRA Gauge Mandrel;Fiber Optic Transducer 5 9,554' Baker 9-5/8"x 4-1/2"Premier 13CR Packer WC 9 6 9,581' 4-1/2"12.6#XD Duro Sliding Side Door-Open 7 9,689' 4-1/2"12.6#XD Duro Sliding Side Door-Closed 10 8 9,741' 9-5/8"x 7"Liner Top Packer 11 9 11,149' 4.5"X Nipple-ID=3.813" 10 11,170' 7"x 4-1/2"Premier 13CR Packer + 11 11,199' 4.5"X Nipple-ID=3.813" 30 12 12 11,220' 4.5"XN Nipple w/PXN Plug-ID=3.725"No Go 13 11,231' 4-1/2"9CR X 7"26#Unique Overshot w/Sheer Pins-Bottom @ 11,241' ' �74 E,13.:� 14 11,249' 9-5/8"x 4-1/2"Baker S-3 Packer w 1 14 15 11,273' 4.5"X Nipple-ID=3.813" � Sc. ` 16 11,284' 4.5"XN Nipple-ID=3.725"No Go -5 15 17 11,293' 7"x 4-1/2"Liner Top Packer 18 11,297' Wireline Entry Guide 16 PERFORATION DETAIL 17 �* 18 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status t . 9,628' 9,668' 8,980' 9,017' 40 12/16/2005 Open 7" A 11,755' 11,895' 10,995' 10,250' 140 3/19/2002 Open 11,755' 11,910' 10,995' 10,250' 155 8/23/2005 Partial Sqz Kuparuk Undef. 11,886' 11,912' 11,124' 10,375' 26 3/28/2006 Open 11,886' 11,912' 11,124' 10,375' 26 6/1/2006 Open z 11,886' 11,912' 11,124' 10,375' 26 8/28/2008 Open 11,891' 11,910' 11,129' 11,148' 19 12/6/2004 Open Ref Log:SWS Usit on 3/18/2002(No logs @ PBOC 1/23/2006)-Initial Perf Charge 2906 Powerjet,HMX 6 SPF, Penetration 27",Hole 0.36",Phase 60 Degree. GENERAL WELL INFO API:50-029-23068-00-00 41/2 i ii Drilled,Cased&Completed by Nabors 33E -3/22/2002 TD=12,030 (MD)/TD=11,267'(TVD) 2"d Completion w/Nabors 33E-12/25/2005 PBTD=11,942'(MD)/PBTD=11,180'(TVD) Revised By:TDF 3/2/2018 • • z/ Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 RECEIVED 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 NOV 1 5 201? Phone:907/777-8300 Fax:907/777-8301 11/13/17 AOGCC Ms. Cathy Foerster Chair,Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue,Suite 100 Anchorage,AK 99501-3572 SCANNED • RE: Well Status Report of NS08,NS18 and NS15 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17,2010 attached are the 10-409s containing the NS08,NS18, and NS15 Kuparuk Formation well tests acquired for the period of July 15`,2017 to September 30th, 2017. The NS15 came on production August 28th, 2017,well testing commenced at that point. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, Leanne Watkins Production Analyst,North Slope — > Z 2Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z• Z Z a a 2 0 CD (n Cn (A (n (n CO (n (n (n (n (n (n (n (n (n (n (n (n (n (n (n cn (n O Q r (D " m 000000 * o C) " Q Cl)_ Cn Cn Cn (n 01 Cn 01 Cn 01 Cn Cn Cn Cn Co Co Co Co Co Co Co CO CO Co Co Co (D C) N O N .< Cn — CD y A.) O 8 7 77 Z 3 .. m 3 .7' m m o D O C Q n ` A ai 3 Q fv m Q O :��T" Z 71 r- Co CD CD CD O < t- C 3 5 n N (D N o * D < r CO coN Cn 01 cn cn Cn cn cn Cn 01 cn to cn Cn cn al fn cn cn cn cn Cn cn cn cn cn 0 co 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D_ N 0) O O C0 0 0 0 0 0 0 0 C7 O O O C0 O O O C7 0 0 0 0 0 0O O CO N N Na N N N N N N N N N N N N N N N N N N N N N N N 01 c) o Q (O CO Co Co CO CO CO Co CO Co CO CO CO CO CO CO CO CO Co Co CO (0 CD CO Co co W co ti• N N N N N N N N N N N N N N N N N N N N N N N N N N N co w CO CO CO CO CO CO CO w w CO w CO w CO CO w CO CO CO w w w w D D v 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v co N p): V V J -4 J -4 V J -4 -4 J -4 -4 0 0 0 0 0 0 0 ()) O O 0) O y W W W W W W W W W W CO W W N N N N Na N 00 00 0) W W 00 Z CO O O 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O CO Cl) C1 o O o o O o O O o 0 O o o 0 0 0 O O o o O O O O o ��C( WO O O O O O O O O O O O O O O O O O O O O O O O O O X c W O O O O O O O O O O O 0 O 0 O O O 0 O O O O O O O v 0 o CD O 3 S 3 CD Cr 0 Co 0 0, 77 0 CO CO CO 0 Co CO 0 Co 00 Co CO Co \ CO 00 - rn O N N N Na s 1 -+ O Cfl 63 W N N N 0 N N J N 0 R3 N J O r CO A co N Cn N N -+ O CO W ? A O CJl -0 ? Co ? N N N N N N N N N N N N N N N N N N N N N N N N N —Ir t. r x .< cr. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CD 'A co 2 -4 J -4 -4 V V -4 -4 -4 J J V J V V V V V J J J J J V V ND com (7 Z 11 (`—D `� m a m > b Q N S N 0 = Q > 0) O O N 0 O _. CO C Q J (D � C1 C11 /� d ' V/ O Cn 3 W N p O 0 7 _ N CD O CD 7- O X r Z Coor Co CO Co CO CO Co Co Co Co Co Co CO CO CO Co Co Co Co Co Co CO co Co CO O O C� �' Cl) D 0) Q 0 0 o 0 0 0 o 0 0 0 0 0 o 0 o O o 0 0 0 o O 0 o o 3 v rn Z C c 3 n CO ( V O T Z jO A o CA A A A A A A A A A V (n J J Co J CT Cn C V N A CO -4 Cn Cn Cn CA J Co Co Co Co -4 CO C) Co N CD Co V N C) W x m cn N 0 13 C ^^� O o co CD 0 l J Z O N N Q Z co 0 N CO CD CO c0 0o Cj O Cb OODD OD Cj 0 0o 0 0 0 0 0 0 = C UN) 0 Cr) m ID. Cp D (n A CO N O Cn 0 01 C) 0) 0) C) 0) J A A A A A A O G IF) 01 A CO N -4 O Co N CO J A J N N A A 0 03 W W CO W CO O N 0 n) ^ X O N Q O u, D (n D -A m ? c 0 vN (0 O O 0 J J J V V J J J J V V V V J J J J J J -4 j V -4 J J ) ZO 3 4, 0 M J O. V Cjj O n > v 0 CD r 0 A A A A A A A A A A A A A A A A A A O 0 CO O U) -AGI Z (n O Co CO co co CO CO Co Co Co Co Co Co '' O -' s 0 0 -' 3 y g O z°- 0 0 cn (n w o 09 0) cn Cn (n cn w W Co 2 2 00 00 CO CD 00 a 00 00 77 m C) i 0 v m T 0 rn 0 co N• W * Z 0) CA cr-4CWWW CC0 0 ( O2W - NNN 0 7 51) O 01 Cn (n (n Cn (n Cn 01 (n Cn (n cn cn cn Cn 01 (n 01 Cn Cn Cn 01 Cn cn Cn Cn Cn Cn (n Cn cn 01 01 01 01 (n (n (n 01 (n Cn (n 01 Cn 01 Cn Cn Cn (n (n = G ,C O Q C o_. 5- - '.. A A CO N N N N N N CO Co Co Co CO CO -- 3 N O W W N — Co W A Cn Cn -4 CO CO 01 Cn W C D CA CoNN N Cn N A CO N A A O OD CA Co CO Co 00 (O 00 J W CO N N A 0 CD O 01 V 0C N 7c CO Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z m y D D D D D D D D D D D D D D D D D D D D D D D D D 0) <—�• 0 0 0 0 co s W W W W CO A A A A A A A 0 0) V A 01 A CO CO O_ N A Cn o 1 CO CO Co CO Co o O co 00 00 00 0o M A CO J O) CO 01 co V N O V N A V 00 N N Cn (n Co Co CO M Co — (n A 00 W O (n J A C) CO O) A CO CO A Cn A CO Co Co 0 O) V A -4 CO A (n Cn CO O Co O A V -A CO 0 J N -4 CO 0 W CO CO N CO W CO CO CO W W CO W A A A A A A W W W W W W -n N +n C) Cn (n CO A CO CO J W CD 0) CA -4 cn cr) CD A J W O N A OD O (D V fD 0 O Cn -� A J W in ? 0 0 0 W N W O N CO W o N CO 0o 01 J Cn A Co j Co Cn Co 00 (l1 co CO O W 0 0o A o N V Co A CO N 00J Co N co 0o N A CO CO Co CO QC) Q W CA W A J J W A V 0 A J A -� 0 CO 0 W co CO o Co A J V • C = Cn 00 4 (n A W 8/18/17 ert rV Ms. Cathy Foerster AUJi 2 z , .2 Chair, Commissioner 0/I Alaska Oil and Gas Conservationil and Gas AO 333 W. 7th Avenue, Suite 100 LL Anchorage,AK 99501-3572 RE: Well Status Report of NS08 and N518 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached are the 10-409s containing the NS08 and NS18 Kuparuk Formation well tests acquired for the period of April 1St,2017 to June 30th 2017. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, SCANNED AUG 2 3 2.01-1 �� ,! Leanne Watkins Production Analyst,North Slope 1.0 CO CO • ._ M V V N N CO I.- N. N/- • O 0 - co r 'Ct Ni. (0 1.0 N- CO co Lcs to M r 10 O) 0) 0 Co cp EtU CO M t() [t t0 (O IO O (9,3 (n 0 1L CO CO CO CO MV Nt cl- W U CV• 0)) CO LO NN c0 M ,- CO NI. N c0 N t0 t0 O t0 CO r 0 N. CO N Ull •— [V7 0 1,1 w .G ( \) J V 1 Z Z Z Z Z Z Z Z Z Z Z Z Po C N Q. IQ' m CO r 00 00 0) COMO n V t• I. C M M ct M N.- M ,s1.-- 00) 0)) 0)) OCD) CO t 7 O :` M M M C) M CO N- N- N- N N- r a 5 = co. (O CO CO CO CO 0 0 0 0 0 0 02 O <) Ni. v v v a tO to to ) to O to to to to 0 LO In 1.0 1.0 tUo to U))t) O N Co C O V/H N 0 N CO CO0 O O N 7Oz mNUl N CO N E Wco L o EO 1'� O O f6 m 000x0) 0) 0 00o 0 Z o co `m 0 0 0 0 x 0 0 0 0 0 0 0 0 OO Z (A as F' a) co r N C 0 O 1 0 c• I— Co CZ 0 Q U v (0 M u) v 00 v v O t- O h V W O O '�t ti' et CO N CO M C o r 0 Z 1 N. N. t` t` N. N. N. r r N. N. N- Co - O (/) m _ u o co m O o N W � a o c C0 cn j (' � m Co a m w CCN N V V ! CO CO CO O Cr) O Co N a) LU Q W Cl (f) N 7 C 0 0 0 0 0 0 : CO Q Ci) Z N O m m C ~ O Z a c d m Z0 a U coC W 0 Lc) tO N 0 Cr) CO 0 CO V N. 0) NI- 0 C Z N m o o 0 N. CO 0 0 0) N. N. N. N. O 0 C oowool� r oocor� r� rl� r- 0• 0 O n a H U 7 o CL Y 0 F- C X Z W a) N 0 0 0 0 0 0 V O 0 0 C Z Q CO a a) m O O) W W CA W to CA O 0) to Cr O C �C N N O � oza7Um 0 0 0 d m a m 1. N N N O N ai 0) v _c n = o a a) PL ° 3 LL Z d' Q 2 3 O < Cl) N- r• r N. N. N. N. N• N- N- N- N. C N Y J F N N N N N N N N N N N N E J p r r_ M CO �_ (17 r CO Cotj 2 N N N O 0+ V 4 10(C) CO co O U 0 0 Q Co N al N JD w a) L xx L O ) 2 a) i O O O O O co O O O O co O C O C)0 9 O O O O O O O O O O O O -cocO Lo E 0 0 0 0 0 0 co O O O O O -O 0 7 O O O O O O O O O O O O U C C W Z W co co co c0 00 N CV N CV CV N U Co 'y CO CO CO CO CO CO 0 0 0 0 0 0 CO a) Q Q coM coM M coC0+) M M coM coM coM coC') coC') co w co a N N N N N N N N N N N N N N 0 0) x CA CA 0) Cr) 0) 0) 0) W 0) W 0) -O N 0 (O (0 N N N N N N N N N N N N CO m C N 0O 0 0 0 0 0 0 0 0 0 0 0 0 E _G (6 CV L C7 CD 0 0 0 0 0 0 0 0) O O N O o O O to U) U) U) U) CO IC) t0 u) U) t0 O) J j Q 3 O a) a) a) CL U w c m E 7 a) Jal J Z w Z m o o c 't m = co w o n m a) - E E o 'c o- o < cu co ai a) LL c Z o oa a ix Co a) — co T m OU m 00 00000000o00tn d 0 a J -o co U CO' U U (n V) U ch (n U U U — a) 0 2 Q co ZZZZZZZZZZZZ Q — • LO 2__ 0 2 ` Hilcorp Alaska, LLC RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 MAY 12 2017 3800 Centerpoint Drive Suite 100 /� Anchorage,AK 99503 1\OG CC Phone: 907/777-8300 Fax:907/777-8301 5/11/17 Ms. Cathy Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7`''Avenue, Suite 100 Anchorage,AK 99501-3572 RE: Well Status Report of N508 and NS18 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached are the 10-409s containing the NS08 and NS18 Kuparuk Formation well tests acquired for the period of January 1", 2017 to March 31`h, 2017. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, SCANNED 1\11.4.' 2 'Lb!o I Leanne Watkins Production Analyst, North Slope • - M N No f� N N U) M • 7 • OWO N _ LON CO O M V W r CO M W in • 607, V' I- M M W M O M M V U) CO M CO N O I� N O m O M aO U) O N• N W V' N. CO CP N CO W CA • C[) N Cr) N N CO N CT M d' co o CO U O N LL O M U) V V M O O r U, W W N M CA O U,Q. M M M M M M m M M 4 M U,M V 4- M M LL C.) O CO V V' N N CO M O) N d' (0 U, N. r U) CO N 2 0) M U) V O) M (0CO 0 '4' N. 0) V U) r CO CO N. O U) CO V N CO O) V C) W V' N M W CO U) V' M O O 0 0) CS) N U) NIV N. N- U) V M U M N N CO U) W LC) U) a d' V V V V V V V V V V V NId' 0 T '> N < < < < < < < < < < < < < < < < < < < N T O Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z HO o) C 7 N O W U) W r U) O CO M r CO .7CA O V' O CO r CI m (0 V M 7 N N W M O O N Y W N M O O U) U) C V V V •p .7 'd' r N N N N ," N- N- 0 0 0 0 0 O O ▪ U = D .T .. M M M M M M N. N. N. r N. N.. N. N. N. r N. N. N. Cfl CO CO CO Cfl CO O O O O O O O o 0 0 0 0 0 E2L CV 0 444444 U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) CO0 O 56 VL -'8171 N N O O ` U O CO N O O Lf) v- e- e C // Z i6 m N N N N N N V/ N W J L_ o IL E H o 0 (L d' N M (T N N O M O O O 0 Z O o L o 0 0 o 0 0 0 0 0 0 o c O o m a) ° • HD Z CO I- co a C C ) N C Gc O F V' V' V V V' V V V V V V V V V V V V V V 0 T O J Ja c QQY Z 0 LLUO ° v (0vCON. MAMMO ) NOU) va) Wrv VVV VVVMV 1' VddddVV 1' -O COr • N N. N. N. N- rN- rrrN. rN- N. N. N-. 1. - rh Cm U oULL _ Q O Nv • Ofn > Ct CDY 2 u) LL J ct• N w M N M V N M O - N. M O CO <- W C0 (0 U - M 0 LL QWn O m V V VVVNNAr000WWWWWW OOOOOOOO CZ CZ 6d (., et V) zUN a) 7 .0 c N a) H 0 2 LL Z c m v Y C O 0 Q QD a o v. . ____ Y WUCO ) MNN ) WNMN- OU) MOO C �— CA 0 0 0 0 0 0 CA CT ) CT M N N O O O O CA o C Q N C co CO CO CO W CO N o O O CO CO CO CO W CO W co r- O n o = r - 7 N 1--- 0a Y L ~ c 2 - v. Z W 0 0 0 0 0 0 U) O U) W v v v v v v v v v -o 2 Q L "O . -8 CA O O Cn CA ) N. W W CA U) U) U) U) U) U) U) U) U) C - O a) C4 O O = a Z 0 o 0 O MN N 2. C CD < -O -c O j C -0 Q ) a) C O C a) N J▪ //� LL Z CC • 0 N Ja) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 WT J H N NNNNNNNNNNNNNNNNNN a E O 2 . \ Cfl — W W O — M V LCO Cfl - N- W O W o co • OW O r N ) N \ c, M NM ,- NNN M d N No c I• a) a) -a w L L O XUU N N 0000000000000000000 C M _0 S O O O O O O O O O O O O O O O O O O O C6 U O E 0 0 0 0 8 0 c) 8 0 0 0 0 O O O O O O 0 "O U) 7 O O O o O o o O O O O O O o O O O O O O -o O O Z W W W W W W N N N N N N N N N N N N N CV) a) Y - 888888000c, 0000000-7, 0 m a) - Q < :J MMMMMMMMMMMMMMMMMMM .0 sL X� N N N N N N N N N N N N N N N N N N N a) O ) CT ) CT CA CT O O CA O Cn C) M O O) O O O O -O N c COp N N N N N N N N N N N N N N N N N N N CO O oO O O O O O O O O O O O O O O O O O O O E C (C6 n ,.c O O O O O O O O O O O O O O O O O O OO O a) V U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) U) C) J C a) a) a. Q 3 oN N o C 4- E 7 qJ C Z N co c w z C v YN 0. 'O t 1,-', a) •Cn C co 73 J O- E O f n- C Q a) R) i O_ LL • d C z 1 0 O Q' N N - rn >, o 2 00 CO W W W W W W W W W W W W ico 0 o00000 1a) = WZZZZZZZZZZZZZZZZZ0QM ZZ 1 IQ L • • 02a 2__ Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 RECEIVED 3800 Centerpoint Drive Suite 100 FEB B 5M 1 7 Anchorage,AK 99503 Phone: 907/777-8300 AOGGC Fax:907/777-8301 2/14/17 Ms. Cathy Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7`' Avenue,Suite 100 Anchorage,AK 99501-3572 SCOW ..�.�N 3 02017 RE: Well Status Report of NS08 and NS18 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17,2010 attached are the 10-409s containing the NS08 and NS18 Kuparuk Formation well tests acquired for the period of October 1St, 2016 to December 31`h, 2016. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, �,r, Leanne Watkins Production Analyst,North Slope ' — 3 • _M L O n n LO V O M W M CO O M O CO M CVC) ON) m N N O U N n CVO O V W M V CVO W O Q) N n W V V COn O N O M C� o m O C) r c- 0 M CO ` N r 'Ct Cn N M O V Cil n 0? n CO f0 LL V V V V' V V t` V CO 0) O CA W V' V M COCO Cn M V V V V ce m m M m m M r O C0 m r W M M M M M MMMM LJ- 0 LU nN MON. 0 n O O 0 OCM O V M OoCNVu0) VO0N CnOOO • COnmCnVNNnCOnCCMr0) 0O0nCOCnO0OVCO N M CO CA n n C0 CO Cf) 0 0 Cn CC) Cn Cn O) CA CA CA CO CC) CO Cn Cl) CO Cn N MMMMMMMMMMM 0 '> 2 < < < < < < < < < < < < < < < « « « « < < 0 0E0 Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z CCT . C .c N o 0) M M 0) V' N n 0 CO Ln M m 0 0 O m M n O W n N 0 0 CO V ON M n O N m r v. C Cn Cf) CO V V V CO) N _ _ CO M Cn0 CO W O O O O O• O 5 7 O , .., C') C') C,') M C) C') n n n n n n n n n n n n n n n n n n n d ` O CO C0 CO CO (O Co O O O O O O O O O O O O O O O O O O O V V V V V C) Ln Cn Cn Cn Cn IC) Cn CC) Cn Cn CC) Cn CO Cn Cn Ur CO Cn Cn Cn COO Cn CO CCn Cn Cn CO 0 Cn Cn Cn Cn o )Cn CO C Cn CO Cn CO m Cl) N r Cn N N N O O r o (O O O r 0 00 O r e- N e- N 1. O N z m Co E W oo E I— J yN ` 0d) COMnOOrOOOOMMOOOOVVVV 0 0 Z ° E rnrn - rnrn . CO o) rrr . . rrrrnn O o C o W H Z cn Q o N ua_ .c oC 2 mo O —I °; 0 O c 0 O M A Cn N n CO Cn Nr. CnO nnN M CO N v Nv Cn V CO Cn Cn N 0 Q VMMV VVMMMMNMVVMVVVVVVVVVV '0 CC Z N. n . nnNNNnr. n ( N. N. N- NN. NN- NNc On c7. Lm v^ O LL IL- Q^ OaN O = N O a U) > V r - • m N L.1.- IY N O a) N N N N N N CO M O M C') r 0 0) CO CO N O 0) C) 0) CO N N O V M N .0.' LL • W Ln r 7 st st V V d O O M V Cn Cnv v v v v v v Q m a Z Z N ` w = F- C O 0 a Q 0 M y o V W0 Q N. M Cn N. V Cn Cn M N. 0 0 st V CO O CO r V — CA m — O C C (n O O O O) 0 0 0) 0 0 0 u) 0 Cn Cn V Cn Cn Cn N M CO o V o o 1- _ c co co n 00 0 Co n n n N. N- N. N. n CD CO Co n N. N. N. Cn Cn Cn C) ~ o 0 N a C' ° N 7 oO N y Z lU 0 E O o 0 0 0 0 v v v v v v v v v v v v v v v v v v v V Q ce t i:ia) Y a) m m m 0) CA 0) Cn Cn Cn Cn Cn Cn Cn Cn Cn to u) m Cn Cn Cn CC) n Cn Cn Cco N O N N ow ° Zmu) 0 Qm (0 m N 0 C O 0 O N O Q CO N▪ O a) N N Q ii z ' 0 3 CO (0 (O CO CO CO C0 (0 Co CO CO CO m CO CO CO CO CO CO CO (0 (o i0•Co CO 2 C ) J a) 0000000000000000000000000 m >, J H N N N N N N N N N N N N N N N N N N N N N N N N N E N- ,.- N M Cn O r M O N M N Cn r O N M V Cn O n W O O O ° 6 N ,_ N N N -6 r N N N N r N N N N N N N N N M U p .0. ,- 0 ,- r,—,.. N .- 00 NNNNNNNNNNN 0. N CO r r r r . . . . . . r r r r r N co 0 t• L xxX L O N 7C O O O O O O O O O O 0 O O O O O O O O O 0 0 0 0 0 8 M . >< 9999999999999999999999999 CC 00 0 E0 0 0 0 0 0 0 0 0 6 O O o O 0 O O O O O (7 0 0 0 0 v N La 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 01 Z co co co N W (0 N N N N N N N N N N N N N N N N N N N 0 CO Y • — uu o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 o O 0 m d < < M C') C'') m M C') m M m m C) m M M M M C,) C,) M C) M m C') C') M C " CO N N N N N N N N N N N N N N N N N N N N N N N C a) a) C co (nmmmm mmmmmmmmmmmmmmmmmmmm v C C E N N N N N N N N N N N N N N N N N N N N N N N N N CO O 999999999 ° 9999999999999 ° 9 E m CO M n .c o O O o O O O O 0 O 0 0 O O 0 0 O 0 O O O o O O 0O a) O Cn Cn CC) n Cn Cn CCn Cn Ln LC) LC) LC) Ln C) Ln Ln Cn Cn Cn Lf) Cn Cf) Ln (n C O m J C a) N Q 3 0 N d a U C E w 0 Z .'CO- Z c c m _ V c 6 �6 0 (n ,`- w C (a 0 .,.. c • n a) . ,Z, a E < N N a N a M c Z d o II O m Cn N — 0 T N 0 N 0 3N W OO W CO m O O CO (0 O O CO CO CO O m Cb O CO O A N O Cb M N 0 • Uo 000000 www0wwCn ( ( CCnC6UUU6Cn ( u a 0 L O2 < m ZZZZZZZZZZZZZZZZZZZZZZZZZ Q — • z2- o2_. I • Hilcorp Alaska, LLC HECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 MAY 16 Zi,`9" 3800 Centerpoint Drive Suite 100 ("� Anchorage,AK 99503 J� ,("'BOG G Q.�` Phone: 907/777-8300 Fax:907/777-8301 5/13/16 Ms. Cathy Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7`''Avenue, Suite 100 Anchorage,AK 99501-3572 %WED MAY 1 8 ZQ1b RE: Well Status Report of NS08 Kuparuk FormatAQncTesting Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached is the 10-409 containing the NS08 Kuparuk Formation well tests acquired for the period of January 1S`, 2016 to March 31`h, 2016. Should you have any questions, please contact Wyatt Rivard at (907) 777-8547. Sincerely, C01,i06‘-- Leanne Watkins Production Analyst, North Slope 7 COW m Co CO OO m O h M O) co ' C <Y LL M coNM coNM M M LL U O .-- O CO N LO CO CO Tr CO Cn CO CO CO C() CO CO r- O COco NNNN 10 U) (O C() Cn 1.0 M (9 5@ Q Q Q Q Q Q Q H (� (� ZZZZZZZ 0) C O N ("13 M (3) CO O) 0 _0 O O 0) COO0) O O ) C — 10 CD CD CD CO 10 to O O 0 C O d CO O V tt V V 4 V V O a) N vi C rCOQ zU) E oc000co N 0 tll (D C) U) a) E toE W 0 J m QM CO QC° OCV ao ‘11" C Z o 0 -C O. E r O O O O O O• C O a) a) m (n• 2 z U ~ aZi U) wp C c To- -5) vvvvvvv 0 U N , O —•I a) °; al 0 al U ¢ y Z i `o C Co (o n O /A 2 CT M 0 N In M cv 10 V p 7)V/ CO M 'I" 'I' V V V' V O 0 N 1J � Q a � � � tir` Nr` a YY a� �a o Q N — 0 CO > QW 0 in• 0 y 0) vvvvvvv CO Y LL (' Z N a 0 0 ~ O z O z Q U a U O v C Z I0 I"— N- CO 0 0 CO N CO 3 �� re co c 0 CO co co co Co co U CO O O N ) N O N D 0 a F- c Y Z W .9 CO Cn w (O (O Cn CO (n "0 .n Q _C a Y a) CO CD CO CD CO CO CO CO Z IL _ o — 0 0 a) (o L CO. o OV) azaoo L= 0 r C CI N a = a) CO < -O L O j L N a Q V) N O O O a) J ��^ Il Z ` Q CO CO CO CO CD CO CO y N a) 0 0 0 0 0 0 0 J I— N N N N N N N - CO N N M N LLI Q O N N CO 0. Ti; (6 O co _0 t L L O 3 tiC 0 • 0 0 0 0 0 0 0 0 cc) E C) 0 0 6 0 0 0 O) 7 0 0 0 0 0 0 0 c 0) Z co co co Co w 00 co COc0i Qa X co co 0 0 0 0 0 CO7 CO Q xx co co co co co co M �, ,r) N NN N a) CD 0) 0) o) d) 0) 0) 0) 0) 0 �' c o CO NCVNCVNLr) O O O O O O O E c ti o E CO N Q 00000010 3 a00)i J o CD .2 °) Y _i Ias T -1 > Z N Z C V a TS O a) Cl) E n 0 a < a) E a o (1 c Z a) c0i O cC N N — N T a) 0 O 5j 0 0 0 0 0 0 0 92 co co co co co co co 0) U -0 a 0_ -� a M U (nCONUMU — _C 0 2 Q M ZZZZZZZ Q — Im¡ e Project Well History File Cov( Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ¿;j 0 â- O~l Well History File Identifier 0 Two-Sided ¿e{' Rescan Needed 11111111111111111 Organizing (dOIl(~) RESCAN 1111111111111111111 DIGITAL DATA ~ Diskettes, No. I va" Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: 0 Other, NolType NOTES: BY: BEVERLY ROBIN VINCENT SHERY~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation ~ x 30 = J ~ D BY: BEVERLY ROBIN VINCENT SHERYL ~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: DATE: - YES - NO /s/ BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY Stage 2 ,,7 OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) / Logs of various kinds 0 Other I Yv1 . 1 111111111 DATE: + 1(3 = TOTAL PAGES I 33 DATE: 'yV¡ BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: Isl (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) _YES _NO DATE: I 111111111 ReScanned (im.liviäual p,JfjfJ 1.~,p()GÌ,JI MfC)f fíonj .~Gð/ nilt!] wmplo/od) RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY I 1111111111 DA TE: Isl General Notes or Comments about this file: Quality Checked (dOIl(;) I 11111111 I 12/1 OIO2Rev3NOTScanned. wpd by • • RECEIVED 0 Katrina Cooper PR 24 2013 Head of Base Management - Alaska BP Exploration (Alaska) Inc. PO East Benson Boulevard AOGCO P.O. . Box 196612 Phone: (907) 564 -4212 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email Katrina.Cooper @bp.com Web: www.bp.com PIOU Jul_ f f• P SCANNED J of . 0 2 13 April 23r 2013 Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of January 1, 2013 to March 31, 2013. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, Ctn Katrina Cooper cc: Mark Sauve Northstar Files N • Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mod) (scfistbo) (psi) NS08 312812013 4 1,065 1,065 0 27,290 25,624 2,818 NS08 3/28/2013 4 1,063 1,063 0 27,291 25,674 2,819 NS08 3/1/2013 4 1,128 1,123 5 27,743 24,704 2,775 NS08 3/1/2013 4 1,128 1,128 0 28,525 25,288 2,636 NS08 3/1/2013 4 1,460 1,460 0 32,994 22,599 2,444 NS08 2/28/2013 4 1,460 1,460 0 32,985 22,592 2,446 NS08 2/1712013 4 780 780 0 18,278 23,433 3,060 NS08 2/17/2013 4 816 816 0 18,762 22,993 3,054 NS08 2/212013 4 856 856 0 21,270 24,848 3,010 NS08 212/2013 4 852 852 0 21,271 24,966 3,010 NS08 1/28/2013 4 854 854 0 21,376 25,030 3,010 NS08 1/2/2013 4 859 859 0 21,431 24,949 3,017 NS08 1/1/2013 4 819 819 0 19,643 23,984 3,037 NSO8 1/1/2013 4 819 815 4 19,701 24,173 3,037 2 b • • p RECEIVED Katrina Cooper JAN 2 9 2013 Head of Base Management - Alaska BP Exploration (Alaska) Inc. ti 900 East Benson Boulevard O ( P.O. Box 196612 A Phone: (907) 564 -4212 Anchorage, Alaska 99519 -6612 Main 907 564 5111 Fax: (907) 564 -4440 Email Katrina.Cooper @bp.com Web: www.bp.com th Z January 18 2013 Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of October 1, 2012 to December 31, 2012. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, SCANNED APR 11 3 Katrina Cooper cc: Mark Sauve Northstar Files • • • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scflstbo) (psi) NS08 12/31/12 4 819 819 0 20,064 24,492 3,037 NS08 12/01/12 4 814 814 0 20,026 24,588 3,042 NS08 12/01/12 4 815 815 0 20,029 24,570 3,042 NS08 11/23/12 4 814 814 0 20,017 24,577 3,042 NS08 11/23/12 4 815 815 0 20,018 24,567 3,042 NS08 11/22/12 4 814 814 0 20,025 24,598 3,042 NS08 11/14/12 4 823 823 0 20,037 24,334 3,042 NS08 11/01/12 4 833 827 6 20,275 24,525 3,035 NS08 11/01/12 4 831 831 0 20,267 24,377 3,035 NS08 10/31/12 4 830 829 1 20,277 24,465 3,035 NS08 10/30/12 4 833 830 3 19,505 23,489 3,035 NS08 10/30/12 4 830 829 1 19,122 23,067 3,035 NS08 10/30/12 4 827 827 0 19,199 23,207 3,034 NS08 10/05/12 4 776 776 0 20,549 26,476 3,031 NS08 10/04/12 4 775 775 0 20,539 26,491 3,030 NS08 10/04/12 4 772 T72 0 20,550 26,613 3,029 NS08 10/01/12 4 958 952 5 23,078 24,232 2,964 2 by • • RECEIVED Katrina Cooper T 11 2012: Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard A0GC P.O. Box 196612 Phone: (907) 564 -4212 � C Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email Katrina.Cooper @bp.com Web: www.bp.com Oct 8 2012 Mr. John Norman APR 0 S 201 Alaska Oil and Gas Conservation Commission SHE 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the N508 Kuparuk Formation well tests aquired for the period of July 1, 2012 to September 30, 2012. Should you have any questions, please contact Mark Sauve at (907) 564-4660. Sincerely, a&k. Katrina Cooper cc: Mark Sauve Northstar Files • • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scflstbo) (psi) NS08 09/30/12 4 956 945 11 23,545 24,924 2,964 NS08 09/11/12 4 985 985 0 23,512 23,864 2,978 NS08 09/11/12 4 855 855 0 20,142 23,550 2,978 NS08 08/20/12 4 975 975 0 24,478 25,106 2,935 NS08 08/19/12 4 972 972 0 24,375 25,070 2,933 NS08 08/19/12 4 966 966 0 24,269 25,129 2,933 NS08 08/12/12 4 954 954 0 23,550 24,698 2,948 NS08 08/12/12 4 951 951 0 23,323 24,523 2,947 NS08 07/30/12 4 1,054 1,049 5 26,444 25,203 2,847 NS08 07/29/12 4 1,054 1,049 5 26,124 24,898 2,845 NS08 07/09/12 4 1,090 1,090 0 25,447 23,355 2,895 NS08 07/09/12 4 1,129 1,129 0 25,850 22,887 2,956 2 by • • Katrina Cooper Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Phone: (907) 564 -4212 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email Katrina.Cooper @bp.com TD Web: www.bpcom l / 'RECEIVED July 24 2012 JUL, 2 6 2012 Mr. John Norman AOGGO Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of April 1, 2012 to June 30, 2012. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, * Xetti.4.1.4, 4 , 1 RBDMS JUL 27 2012 Katrina Cooper cc: Mark Sauve Northstar Files • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Firs (bpd) (bpd) (bpd) (mscfd) (scflstbo) (psi) NS08 6/1112012 4 1,092 1,092 0 27,650 25,321 2,886 NS08 6/11/2012 4 1,089 1,084 6 27,624 25,493 2,886 NS08 5/1/2012 4 969 969 0 26,027 26,851 2,927 NS08 5/1/2012 4 968 968 0 26,010 26,869 2,927 NS08 4/29/2012 4 982 977 5 26,072 26,686 2,927 NS08 4/29/2012 4 980 975 5 26,057 26,737 2,928 NS08 4/28/2012 4 975 970 5 26,103 26,901 2,928 NS08 4/3/2012 4 1,037 1,037 0 27,323 26,347 2,909 NS08 4/2/2012 4 1,036 1,036 0 27,290 26,350 2,912 2 • • o p2 -02k per; -\ �� ° " SEAN PARNELL, GOVERNOR �r ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Emeka Emembolu Head of Bas Management - Alaska BP Exploration (Alaska) Inc., - lU P.O. Box 196612 Anchorage, AK 99519 -6612 RE: Northstar Unit Request for a Temporary Waiver of the Gas-Oil Ratio requirement of 20 AAC 25.240 for Kuparuk formation testing in the .NS08 well Dear Mr. Emembolu: By letter dated January 16, 2012, BP Exploration (Alaska) Inc. (BPXA) requested re- authorization of the temporary gas-oil ratio (GOR) waiver that the Alaska Oil and Gas Conservation Commission granted under 20 AAC 25.240(b)(3) to allow continued testing of the Kuparuk Reservoir within the Northstar Unit to help determine future reservoir development. BPXA's request is hereby approved Through June 30, 2012, the period of the tract operations authorized by the Department of Natural Resources, subject to the same conditions applied to the original March 17, 2010, waiver. The NS08 well began an extended test in the Kuparuk Reservoir in the Northstar Unit in November 2010. To date over 550 MBO and 11.5 BCF have been produced. The initial producing GOR for this well was approximately 20 MSCF /STB and has remained about the same for the duration of the ongoing test. The GOR peaked at 23.3 MSCF /STB in July 2011, but has since dropped slightly below the initial GOR. Given the production history to date, and the short period of the extension requested, it is unlikely that the NS08 well will exceed the GOR limitation imposed by 20 AAC 25.240(a) during the period of this tract operation. However in the unlikely event that the GOR behaves in an unanticipated fashion, a GOR waiver to allow for completion of the test production period is warranted. DONE at Anchorage, Alaska and dated April 17, 2012. Ay Cath P. oerster Daniel T. Seamount, Jr. Chair, Commissioner Commissioner • • James T. Rodgers Greater Kuparuk Area Development Manager ConocoPhillips Alaska, Inc. ConocoPh l l i s PO Box 100360 Anchorage, Alaska 99510 -0360 phone 907.263.4027 Conoco Phillips RECEIVED' Commissioner Alaska Oil and Gas Conservation Commission r ,�.' i 2 &' 2m2 333 W. 7 Avenue Anchorage, Alaska 99501 -3539 Alaska Oil & Gas Cons. Commission February 8, 2012 Anchorage Re: Request for Changes to the Well Testing Periods for Well Testing and Production Allocation for ConocoPhillips Alaska, Inc. Operated Pools. Dear Sir, ConocoPhillips Alaska, Inc. (CPAI) as operator of the Kuparuk River Unit (KRU) requests changes to the requirements of the following Conservation Orders: 1. Rule 7 (c), Conservation Order 406B; 2. Rule 7 (c), Conservation Order 430A; 3. Rule 7 (c), Conservation Order 435A; and 4. Rule 6 (d), Conservation Order 456 (collectively, the Rules). CPAI requests that the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) amend the abovementioned Rules to change the individual producing well testing frequency for measurement and allocation of production to one test per month. Currently, the Rules require tests twice per month and the Rules state "Each producing well must be tested a minimum of twice per month" ConocoPhillips requests that each of the Rules be amended to read "Each producing well must be tested at least once . montly." CPAI requests the testing requirement be reduced to one test monthly for the following reasons: • The proposed changes support consistency and enhance facility utilization between KRU, Kuparuk Oil Pool rules with KRU, Satellite Oil Pool rules, which require only one test per month. • The proposed changes will provide consistency with Conservation Order 432D, Rule 10 (a) Kuparuk River Field, Kuparuk River Unit, Milne Point Unit, Kuparuk River Oil Pool Production Well testing requirements, which allows for increased measurement capacity of production well testing facilities being used by most leveraging or uncharacteristic performing wells. • The requested changes will promote KRU participating area well production testing quality. Please note that CPAI will use existing drill sites to perform the testing and thus this change will require no increase in facility infrastructure. The requested changes will not compromise reservoir management or Commission oversight. We believe that these changes will lead to more efficient management of the • • reservoir. The requested changes will not promote waste, jeopardize correlative rights, and is based on sound engineering principles. We look forward to receiving the revised Conservation Orders soon. Please do not hesitate to contact me at (907) 263 -4027 if you have any questions or require clarification about this request. Sincerely, L ,Jdnaes T. Rodgers CC: BP Exploration (Alaska), Inc. ExxonMobil Alaska Production, Inc. Bret Chambers Mark Agnew 900 E. Benson Boulevard (Zip 99508) 3301 "C" Street, Suite 400 (Zip 99503) PO Box 196612 PO Box 196601 Anchorage, Alaska 99519 -6612 Anchorage, Alaska, 99519 -6601 Chevron USA, Inc. Glen Fredrick 3900 Centerpoint Drive, Suite 100 (Zip 99503) PO Box 196247 Anchorage, Alaska 99519 -6247 CPAI: Central Files CPAI: Patrick J. Wolfe CPAI: Alan J. Campbell CPAI: Jack R. Newell by • • Emeka Emembolu 0 Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Phone: (907) 564 -5536 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email emeka.emembolu @bp.com Web: www.bp.com '✓ _ O R REC EIVED April 9 2012 APR 1 2 2012 Mr. John Norman AOGCC Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the N508 Kuparuk Formation well tests aquired for the period of January 1, 2012 to March 31, 2012. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, :�i Tiv.v. ��'�\� o A AP .t c LU AL Emeka Emembolu cc: Katrina Cooper Mark Sauve Northstar Files • • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scflstbo) (psi) NS08 03128112 4 1,033 1,023 10 25,696 25,115 2,947 NS08 03128112 4 1,032 1,027 5 25,046 24,391 2,947 NS08 03102/12 4 1,052 1,052 0 26,741 25,426 2,943 NS08 03/01/12 4 1,076 1,076 0 26,910 25,019 2,941 NS08 02126112 4 1101 1097 5 27,493 25,072 2,913 NS08 02/26112 4 1,102 1,097 5 27 ,491 25,056 2,913 NS08 02/26/12 4 1,104 1,094 10 27,476 25,126 2,914 NS08 02/12/12 4 1,102 1,092 10 26,939 24,668 2,921 NS08 02/12/12 4 1,103 1,093 10 27 ,086 24 ,774 2,941 NS08 02/11/12 4 996 986 10 20,008 20,297 2,983 NS08 02/11/12 4 990 990 0 21,129 21,349 2 ,983 NS08 01/20112 4 1,037 1,031 5 25,517 24,741 2,960 NS08 01/20112 4 1,039 1,033 5 25,506 24,685 2,961 NS08 01/20112 4 1,036 1,036 0 25,500 24,610 2,961 NS08 01/05/12 4 1,031 1,031 0 25,856 25,068 2,959 NS08 01/05112 4 1,030 1,030 0 26,080 25,315 2,949 2 y bp • • Emeka Emembolu Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Phone: (907) 564 -5536 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email emeka.emembolu @bp.com Web: www.bp.com �2..- I RE CEIVED January 16 2012 JAN 8 ')01 Mr. John Norman Z!on ,a 0i( & Gar, Cans. iComnissino Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of October 1, 2011 to December 31, 2011. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, Emeka Emembolu cc: Katrina Cooper Mark Sauve Northstar Files • • Well Test Data Well Bore Run Date Hrs Total Oil Water Form GOR FTP Fluid Rate Rate Gas (scf /stbo) (psi) Rate (bpd) (bpd) Rate (bpd) (mscfd) NS08 12/15/2011 4 1,103 1,098 5 26,508 24,137 2,929 NS08 12/15/2011 4 1,057 1,052 5 24,343 23,138 2,950 NS08 12/15/2011 4 1,056 1,047 9 24,435 23,340 2,933 NS08 12/14/2011 4 1,191 1,186 5 29,676 25,027 2,863 NS08 11/27/2011 4 1032 1032 0 23,474 22,741 2,976 NS08 11/12/2011 4 987 987 0 23,622 23,941 2,975 NS08 11/11/2011 4 974 974 0 22,402 22,993 2,975 NS08 11/4/2011 3 959 959 0 24,261 25,293 2,975 NS08 11/4/2011 4 955 955 0 24,682 25,851 2,975 NS08 10/20/2011 4 1,105 1,102 2 26,251 23,815 2,899 NS08 10/19/2011 4 1,178 1,178 0 29,104 24,702 2,863 NS08 10/18/2011 4 1,177 1,177 0 29,699 25,234 2,863 NS08 10/18/2011 4 1,174 1,174 0 29,262 24,923 2,863 NS08 10/5/2011 4 1,118 1,118 0 27,614 24,710 2,866 NS08 10/5/2011 4 1,118 1,118 0 28,106 25,138 2,866 2 bp • c2tZ 0 Z Emeka Emembolu Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Phone: (907) 564 -5536 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 Main 907 564 5111 Email emeka.emembolu @bp.com Web: www.bp.com RECEIVE,D fi ,l OCT 2 8 ?On October 26 2011 kiagka L4i & tae Gans. Comolifsini. Al .0!10.0.111 Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well NS08 Kuparuk Formation Testing aoa 'I • Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of July 1, 2011 to September 30, 2011. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, 4 1r Emeka Emembolu cc: Katrina Cooper Mark Sauve Northstar Files • • • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scf /stbo) (psi) NS08 9/22/2011 4 1,086 1,084 2 25,736 23,734 2,866 NS08 9/21/2011 4 1,132 1,132 0 28,428 25,111 2,822 NS08 9/21/2011 4 1,126 1,126 0 29,124 25,865 2,821 NS08 9/3/2011 4 1,005 1,005 0 26,006 25,887 2,822 NS08 9/3/2011 4 987 981 6 26,147 26,657 2,818 NS08 8/20/2011 4 1,570 1,570 0 41,960 26,726 2,207 NS08 8/20/2011 4 1,572 1,572 0 41,510 26,412 2,208 NS08 8/14/2011 4 1,587 1,587 0 41,219 25,979 2,231 NS08 8/14/2011 4 1,571 1,571 0 41,247 26,261 2,253 NS08 8/1/2011 4 1,502 1,497 5 36,877 24,633 2,346 NS08 8/1/2011 4 1,502 1,497 5 36,931 24,674 2,346 NS08 7/30/2011 4 1,499 1,493 5 36,954 24,743 2,348 NS08 7/30/2011 4 1,496 1,486 10 36,936 24,849 2,349 NS08 7/9/2011 4 1,441 1,441 0 38,421 26,660 2,528 NS08 7/9/2011 4 1,446 1,446 0 38,536 26,655 2,539 NS08 7/8/2011 4 1,446 1,446 0 38,626 26,709 2,598 NS08 7/3/2011 4 1,285 1,285 0 29,596 23,026 2,786 NS08 7/2/2011 4 1,184 1,184 0 27,059 22,849 2,816 NS08 7/2/2011 4 1,239 1,231 8 28,816 23,416 2,781 2 bp • • Emeka Emembolu $) Head of Base Management - Alaska BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Phone: (907) 564 -5536 Anchorage, Alaska 99519 -6612 Fax: (907) 564 -4440 (907) 561 -5111 Email emeka.emembolu ©bp.com Web: www.bp.com 010.),-oal July 25 2011 Mr. John Norman Alaska Oil and Gas Conservation Commission - . r; KI 333 W. 7th Avenue, Suite 100 � o Anchorage, AK 99501 "w `'`'' RE: Summary Report of Well N508 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of April 1, 2011 to June 30, 2011. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, 1 rT y l� i Emeka Emembolu cc: John Garing Mark Sauve Northstar Files • • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scf /stbo) (psi) NS08 4/28/2011 4 1,338 1,338 0 33,360 24,933 2,738 NS08 4/29/2011 4 1,321 1,309 12 33,157 25,330 2,736 NS08 5/1/2011 4 1,314 1,308 7 33,459 25,580 2,717 NS08 5/8/2011 4 1,210 1,210 0 30,727 25,394 2,738 NS08 5/8/2011 4 1,200 1,200 0 30,813 25,678 2,645 NS08 5/9/2011 4 1,152 1,152 0 29,488 25,597 2,799 NS08 5/18/2011 4 1,173 1,173 0 30,270 25,806 2,821 NS08 5/18/2011 4 1,166 1,166 0 29,967 25,701 2,821 NS08 5/30/2011 4 1,224 1,224 0 29,795 24,342 2,832 NS08 5/30/2011 4 1,220 1,220 0 29,606 24,267 2,830 NS08 5/31/2011 4 1,225 1,225 0 29,624 24,183 2,832 NS08 6/1/2011 4 1,225 1,220 5 29,555 24,225 2,833 NS08 6/1/2011 4 1,224 1,219 5 29,587 24,272 2,833 NS08 6/1/2011 4 1,225 1,220 5 29,528 24,203 2,833 NS08 6/14/2011 4 1,233 1,233 0 29,507 23,931 2,857 NS08 6/15/2011 4 1,206 1,206 0 29,255 24,258 2,862 NS08 6/17/2011 4 1,138 1,133 5 29,062 25,650 2,855 NS08 6/17/2011 4 1,154 1,154 0 29,551 25,607 2,857 2 bp • • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 Dave Szabo 3 Head of Resource Management - Alaska y Phone: (907) 564 -4788 FEB 0 1 101 Fax: (907) 564 -4440 t1 Email david.szabo @bp.com Web: www.bp.com R % a? rims. C! r?`= 6S$1�0 WIMP January 27 2011 F.F. -? - Z �� Mr. John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Summary Report of Well N508 Kuparuk Formation Testing Gentlemen, As requested in the AOGCC's letter of March 17, 2010 attached is a report of the NS08 Kuparuk Formation well tests aquired for the period of October 1, 2010 to December 31, 2010. Should you have any questions, please contact Mark Sauve at (907) 564 -4660. Sincerely, Dave Szabo cc: John Garing Mark Sauve Northstar Files • Well Test Data Total Form Fluid Oil Water Gas Rate Rate Rate Rate GOR FTP Well Bore Run Date Hrs (bpd) (bpd) (bpd) (mscfd) (scf /stbo) (psi) NS08 12/31 /2010 4 1,493 1,493 0 39,230 26,276 2,453 NS08 12/31 /2010 4 1,497 1,492 5 39,157 26,245 2,454 NSO8 12t1 8/2010 4 1,554 - 1,554- - -- 0._ __39;965 - 25,71 -8 -- -2,549 NS08 12/16/2010 4 1,516 1,507 9 40,297 26,740 2,465 NS08 12/14/2010 4 1,522 1,520 2 40,339 26,539 2,470 NS08 12/14/2010 4 1,537 1,530 7 40,398 26,404 2,483 NS08 12/14/2010 4 1,546 1,543 2 40,326 26,135 2,636 NS08 12/11 /2010 4 1,293 1,282 11 32,843 25,619 2,768 NS08 12/10/2010 4 1,344 1,332 12 32,489 24,391 2,783 NS08 12/9/2010 4 955 955 0 22,220 23,267 3,066 NS08 12/6/2010 4 937 937 0 20,680 22,070 3,073 NS08 12/6/2010 4 990 977 13 20,509 20,992 3,088 NS08 11/27/2010 4 340 340 0 6,056 17,812 3,272 2 U BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~~~. jqj,~, , ,~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, by a~~- Ns~ 0~-1 o$ ~~~~~~~~ MAY ~ ~ 2010 ~li~C ~afa t~. C. tan~~n~sic~- ~ncltoraae Enclosed please find a spreadsheet with a list of welts 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 • i BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar 4/20/2010 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NSO6 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 NSOS 202021 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 5002923ttto00o 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. • • o ~ a a SEAN PARNELL, GOVERNOR ALASSA OIL A1~TD GA5 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOrT CO1~IIrIIS5IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 March 17, 2010 Mr. David J. Szabo Head of Resource Management Alaska Consolidated Team BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 RE: Request for Surface Commingling of Test Production and a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for well NS08 (PTD 242~d21~ Dear Mr. Szabo: By letter dated February 3, 2010, BP Exploration (Alaska) Inc. (BPXA) requested the Alaska Oil and Gas Conservation Commission (Commission) approve surface commingling of production from the Kuparuk Reservoir in well NS08 with production from the Northstar Oil Pool and a waiver in accordance with 20 AAC 25.240(b)(3) to allow testing of the NS08 well in the Kuparuk Reservoir to acquire reservoir performance data to help determine future reservoir development. BPXA's requests are hereby by granted under the conditions below. The NS08 well, in the Northstar Unit, was drilled and completed in the Northstar Oil Pool in early 2002. In late 2005 the well was recompleted to allow for testing and possible production from the Kuparuk Formation. A brief test indicated the Kuparuk Formation is a gas condensate reservoir that produces at a GOR of approximately 25,000 scf/stb. Under the Commission's regulations, NS08 is an oil well and therefore subject to the GOR limitations of 20 AAC 25.240. BPXA now proposes to conduct long term testing, up to one year, to acquire reservoir performance data to evaluate the Kuparuk Formation's potential for future development. As part of its evaluation, BPXA proposes surface commingling of production from the NS08 well with the Northstar Oil Pool and processing of the production in the existing Northstar facilities. BPXA proposes to allocate production in accordance with the Commission's regulations in 20 AAC 2.21 ~ and will test the well at least twice per month to determine the quantities from each pool. BPXA represents that its modeling .indicates that the NS08 well should not produce at more than twice the initial GOR during the testing phase but BPXA requests a waiver in case testing operations cause the GOR limit to be exceeded during the reservoir evaluation. • Mr. David J. Szabo March 17, 2010 Page 2 of 2 Because BPXA will comply with the surface commingling allocation metering requirements in 20 AAC 25.215 and 20 AAC 25.240(b)(3) allows waiver of the GOR requirements of 20 AAC 25.240(a) for the purpose of acquiring pool performance data necessary to determine an optimum reservoir management program, BPXA's requests are approved with the following conditions: 1) To determine the quantities from each pool, the NS08 well must be tested in accordance with 20 AAC 25.215 and tested at least twice per month while flowing. 2) The GOR waiver expires at the end of the month 12 months after testing begins (e.g. if testing begins at any time during March 2010 the GOR waiver will be valid through March 31, 2011.). 3) On a quarterly basis, the operator must submit copies of all well tests for the NS08 well showing the GOR at the time of the test. DONE at Anchorage, Alaska Daniel T. Seamount, Jr. dated March 17, 2010. Cathy Ij: Fo Chair Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), `[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p. m. on the next day that does not fal[ on a weekend or state holidav. by ~ David J. Szabo Head of Resource Management BP Exploration tAaaska) Inc. Alaska Consolidated Team (ACT) 900 East Benson Boulevard PO Box 196612 Androrage, AK 99519-6612. (9(171 564-5111 February 3, 2010 Pnone:(so7)5sa-a~as Mr Dan Seamount Chairman Fax: (907)5s4-4440 . , Email SzaboDJ'~bp.com Alaska Oil & Gas Conservation Commission Web: ww.v.bp.com 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Northstar Unit Request for Surface Commingling of Test Production and Request for a Temporary Waiver of the Gas-Oil Ratio requirement of 20 AAC 25.240 Dear Mr. Seamount, As operator of the Northstar Unit, BP has requested and received approval from the Alaska Department of Natural Resources for a Test of the Kuparuk Reservoir in well NS08. Currently the NS08 test production is planned to occur during 2010 under none-year tract operation granted by ADNR effective 1/7/2010. The plan is to insert a plug into well NSOS to isolate the existing Ivishak production and then to shift an existing sliding sleeve to start production from only the Kuparuk formation. The Kuparuk reservoir is not currently part of the existing PA or Pool at Northstar. During the test period(s-, in accordance with 20 AAC 25.215, BP requests permission to comingle the produced fluids from well NS08 Kuparuk formation at the surface with the production from the Northstar Ivishak pool where they will then be sold. During the test period(s) NS08 will be routed into the test separator to provide accurate measurements of the produced fluids and production will be allocated on a daily basis using the same methodology employed for all producing we11s in the Northstar field. Well test data for NS08 will be gathered at least 2 times per month during periods of testing. Produced gas from the Kuparuk Formation will be re-injected into the Ivishak formation. As operator, BP plans to operate NS08 at a variety of flow rates during the test period(s). While modelling based on a prior test (Jan. 2006) indicates that the gas-oil ratio may not exceed the requirements of 20 AAC 25.240 (the GOR may not exceed the original solution GOR of the crude by more than 100%), SP requests a temporary waiver of the GOR requirement for the period of the tract operation, since exceeding the requirement may be necessary to acquire pool performance data to determine the optimum reservoir management program. Should you have any questions, please contact me at (907) 564-478$. Sincerely, David J. Szabo • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 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 ab~= °~'' Re: Northstar Field, Undefined Pool, NS08 Sundry Number: 310-O1 l ~~rt~ ~ ~01G 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, Daniel T. Seamount ~ Chair n DATED this ? ~ay of January, 2010 Encl. STATE OF ALASKA ~^i~~~ ALAS~IL AND GAS CONSERVATION COMMISSI~ + 1- APPLICATION FOR SUNDRY APPROVALS RECE`VED-.~~ /-o?/-fa JAN 1 9 2010 ~n nnr. ~s ~Rn . ~ I•I>d AIASk~ ~ g QrAi C811E. Catimissiun 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change A'~~ram ^ Alter casing ^ Plug Perforations []" - Perforate [ ~ Pull Tubing ^ 'Time Extension ^ Operation Shutdown ^ Re-enter Susp Well ^ Stimulate^ Alter Casing ^ C N ~ ' . o Other: fo ](.. qr 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: a .L..s~'i BP Exploration (Alaska), Inc. Development ^ ~ Exploratory ^ 202-0210 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23068-00-00 - 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ NS08 ~ 9. Property Designation (Lease Number): 10. Field/Pool(s): (,(n ~ •ha Oa~-• ADLO-312799 ~ NORTHSTAR Field / /• 2~.~v 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): 12030 - 11266.74 11942 - 11179.58 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 165 20" 169# X-56 45 210 45 210 4260 2590 Surrace 3361 13-3/8" 68# L-80 44 3328 44 3220 4930 2270 Production 11710 9-5/8" 47# L-80 42 9919 42 9247 6870 4760 Liner 1864 7" 26# L-80 9741 11461 9084 10705 7240 5410 Liner 735 4-1/2" 12.6# 13CR80 11293 12029 10540 11266 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13CR VAM-ACE 40 11297 Packers and SSSV Tvpe: 4-1/2" BKR PKR Packers and SSSV MD and TVD (ft): 9554 8913 7" Top Packer 9741 9084 4-1/2" Baker S-3 Perm Packer 11249 10497 4-1/2" Top Packer 11293 10540 4-112" BKR Premier PKR 11170 10420 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/25/2010 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 Mark Sauve Printed Name Mark Sau Title production Engineer Signatur Phone Date 564-4660 1/15/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Commission so that a representative may witness Sundry Number: ~~+D '~l roval: Notif Conditions of a y pp Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: 1~ / w ~ w a.~ ~ S 1 eC ~ :p Es ~ ( {- . - ' S ~ ~ ,, , t rn. lr - S ~ ~ v ~ ~ r ~,,~~~ sue... R~,,a,~- £~~'oK ~.S~s Subsequent Form Required: 1o-yob APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: //Z ~ / s~ ' /, ~~~ l~D,~IAS JAN 2 2~ 2~~ ~ ~ zi. ~ o ~ /v ~'~ F 10-4 3 Revised 2/2009 ~ ~ ~ Submit in Duplicate NS08 202-021 ~cQ~ e~rreruen~N-r n U Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS08 3/19/02 PER 11,755. 11,895. 10,994.69 11,133.06 NS08 12/6/04 APF 11,891. 11,910. 11,129.1 11,147.9 NS08 8118/05 SQZ 1,954. 11,910. 1,951.86 11,147.9 NS08 8123/05 SQZ 11,755. 11,910. 10,994.69 11,147.9 NS08 12/16105 PER 9,628. 9,668. 8,980.49 9,017.16 NS08 12/23/05 STC 9,554. 11,170. 8,912.58 10,419.8 NS08 3/28/06 APF 11,886. 11,912. 11,124.16 11,149.88 NS08 6/1/06 APF 11,886. 11,912. 11,124.16 11,149.88 NS08 4/10/07 SQF 1,954. 11,910. 1,951.86 11,147.9 NS08 8/28/08 APF 11,886. 11,912. 11,124.16 11,149.88 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: Mark Sauve, Northstar PE • Date: January 15, 2010 (w: 564-4660 c: 748-2865 h: 336-6128) Subject: NS08 Conversion to Kuparuk Production IOR: 200 Please perform the requested well work on NS08 per the below procedure. 1 S Set 4.5" XXN lu in XN Ni le @ 11,220' MD 2 S Shift O en 4.5" XD Slidin Sleeve @ 9581' MD Well Detail Current Status: Producer Last Test: 12/1/09: 737 BOPD, 0 BWPD, 49471 GOR Max Inclination: 28° at 4,654' MD Max Dog Leg: 3.3 deg/100' at 1955' MD Minimum ID: 3.725" C«~ 11,220' MD, 4.5" XN Nipple Last TD tag: 2/23/09: Tag TD Cc~ 11,900' SLMD w/PDS tools and 3.2" Centralizer Last Downhole Op: 2/23/09: Memory SBHP survey Latest H2S value: Field Produced Gas 4 ppm -Taken from HP Separator 6/11/07 BHP: 5145 psi @ 11,100 TVDSS on 11 /24/09 Objective The objective of this program is to convert NS08 from Ivishak production to Kuparuk production. Well History NS08 was completed in early 2002 and for most of the wells producing life it has been near marginal GOR resulting in a high percentage of shut-in time. A production log run on December 7, 2004 showed all free gas being produced above 11,850'. In addition to the well's non-competitive GOR, NS08 also had tubing by inner annulus communication. Attempts to repair the communication with thru-tubing measures proved unsuccessful. Therefore, an August 2005 cement squeeze was completed followed by a December 2005 RWO. During the course of the RWO, the Kuparuk formation was shot and placed behind a straddle completion. The Kuparuk formation was tested through the sliding sleeves in January 2006. . . . • Following the Kuparuk test, the sliding sleeves were closed and the Ivishak re-perforated with E-line after a CTU cleanout. Post-squeeze production quickly returned to high GOR and subsequent production logs found the squeeze perfs to be leaking. Continued high GOR production from NS08 Ivishak has caused the well to endure a high percentage of shut-in time. As a result, NS08 has become an attractive potential Kuparuk production source. Procedure• 1. Hold PJSMs. Monitor and record all T/I/O pressures throughout all stages of the job. 2. RU slickline unit and PT equipment. 3. RIH. Drift and tag TD; document corrected tag depth in well log. Obtain sample if obstruction/fill encountered. 4. MU 4.5" XXN plug with sand extension and equalizing sub. RIH with plug and set in 4.5" XN nipple @ 11,220' MD. 5. Confirm plug was been successfully locked in place with acheck-set run. 6. MU shifting tool and RIH to upper 4.5" XD Sliding Sleeve @ 9,581' MD. Shift sleeve open and POOH. 7. RDMO slickline unit and leave well SI. Note: The POP and testing procedure for NS08 will be detailed in a future program. Please contact Mark Sauve 564-4660 (w); 748-2865 (c); 336-6128 (h) with any questions, comments, or concerns. 2of3 TREE< ABB.V l~ S-iM- SIfSI C31F4o~ ABB.Vt~ Y3S~9i'64Lt'IBDM4.5K9 . _.- . C11t4TfTRa_ _. - „ _ _. ..~»_... BAKf3t _. OPr 15?5'~ x Arx~E = 29' ~ 18~1'f _ ~ ~m6~~ _ '~~ ~~~ N3i0' ~t111iNllIl ~ ~ ~,~Sta ~~Z~~ 4-1t2" XN P~iPPLE FA5 LgT S la-tra-xcwnc~A ie~a~sr ~ ~~-- K~'pa,.~,/lc f! r torah`': vtip . 988' •stn-~Di.~os~csiv.>a=38z PEAI"CN uLliiR,dtY e[x:. S.4SUSR,.`Stsi(13'i3'421~iL[fi5~ ,ANi~EATT[3PP1 28-~928~ 1`~. i'QiF ~tfAF~L 'x'91]8 PEAVERIET, MC(, B ~[ _TR:AiY,.AL.2T, HCG0;34-, PHASE 80[7E6 z-?rii• a »?5s - i is~s s OSn3Cl5 z-aasr a iia9e.ii9lz o cian5ra5 2~?did 8 if~8 ~ f 19YZ O 08fii~d8 2-7r5 8 i1ffit - i 1910 8 09n3E15 ~ A 39~- ~ .oisz cQ~, u= a~g zeMk VSOemr-~ A~3ecf. n=ea?5- l.l~6i, 128iR, #3CR YAf1,AC1; 13029' hpt, D=3955" ORTE 1~V @Y DATE iidl BY Ot3ll4Y9Nls ~1t8152 NTtAd.GG01l~.ET101d' 03n8108 A~tliRIC ADDS i2n6g3! N-318S 1AlD 05n8fris8 D'faPJC 6Ll1ED~!1tiXNF~+~i1302' 01 A~AR18 PAC $41/ i in?itTT -MR~ -~! ~LOGTCEI QidC9Ki8 ~ i?Pl(MPllli; i121C1` t~I25g8 NIS3iW FET~FS 85129d8B 83/~9A08 iil~iiP.lC PJ~t R.A(G 2ii9A /'~ 9+RF£iY :.+.4.f12" T943Jti 2.1~T'•* X PfiDfB.i=. 4D: 3.St2 D~ 3.87lT xs-in- #BTA#Y WE11: t~08 i491iAQ Pio: ~fl2ftzt 0 At8 No: 50di2~23855-#q 5'~ it, T13N, RF9~ if t9' 1~3L 4k 842 44°1 Figptu~tin lAls+k a} 3 of 3 • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~,,, M~~' ~q~~ May 26, 2009 I~~~ ail ~ ~1~~ ~n'li~sion ~91ag! Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ ~- 333 West 7t" Avenue ~ ~ ~, Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or~r~ny~alternate, Anna Dube, at 659-5102. Sincerely, G2~ Andrea Hughes BPXA, Well Integrity Coordinator "~~~~~,s~~~ :_r~ ~~~ ,~ ~r 20G~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ "-~\ Date Northstar U 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 NS141~ 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 * na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 "Not measured due to rig proximity. L JUN 0 1 2009 ,~~~ ~,~ :- ~~~ ~ ~,., BI'XA WELL DATA TRATTSMITTAL Enclosed are the materials listed below. ,- ~~~~~ t'~ ~- ~' J'~; ,~~ ~~ a~ lye ~~~~~ Tf v~u have anv auesti~ns_ please contact Joe Lastufka at (9071564-4091 Date: 03-11-2009 Transmittal Number: 93048 Delive Contents SW Name Date Com an Run To De th Bottom De th Descri tion NS08 02-23-2009 PDS 1 11526 11926 CORRELATION LOG STATIC TEMPERATURE/ NS08 02-23-2008 PDS PRESSURE SURVEY CD-ROM -CORRELATION LOG AND TEMPERATURE/ NS08 02-23-2009 PDS PRESSURE SURVEY NS09 02-24-2009 PDS 1 12700 13349 CORRELATION LOG STATIC TEMPERATURE/ NS09 02-24-2009 PDS PRESSURE SURVEY CD-ROM -CORRELATION LOG AND TEMPERATURE/ NS09 02-24-2009 PDS PRESSURE SURVEY PL ADVISOR -PRODUCTION LOG INTERPRETATION NS16A 10-01-2008 SCH 14274 14339 WITH GHOST AND DEFT CD-ROM - PL ADVISOR PRODUCTION LOG INTERPRETATION WITH NS16A 10-01-2008 SCH GHOST AND DEFT n f I PI"ease`3'ign and Return one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center BPXA AOGCC DNR Murphy Exploration MMS _' .r .~ Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 n ,~ ')rill` ~ t , i 1 ti ,,..'J J _y „ ;;~~ ,; ,~-- ~.w_ _ _,-~~ David Fair Christine Mahnken Kristin Dirks Ignacio Herrera Doug Chromanski B.P. Exploration (Alaska). lnc. St°7t~C TE/77pE/'c~tU/'G' ~ P/'ESSU/'e SU/'VB j/ NS-OB North Star North Slope ~:~:.~4.6~~~~ MAR s ~ 2JU~ Surface -Before R/H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 32.85 3710.45 0.5 32.76 3710.90 1.0 32.90 3711.03 1.5 32.75 3711.04 2.0 32.56 3711.01 2.5 32.56 3710.98 3.0 32.64 3710.92 3.5 32.64 3710.86 4.0 32.58 3710.83 4.5 32.51 3710.79 5.0 32.55 3710.76 5.5 32.50 3710.72 6.0 32.41 3710.69 6.5 32.34 3710.64 7.0 32.32 3710.58 7.5 32.33 3710.52 8.0 32.30 3710.45 8.5 32.26 3710.38 9.0 32.40 3710.30 9.5 32.37 3710.20 10.0 32.11 3710.09 AVERAGE 32.51 3710.67 Current Wellhead Read in s Wellhead Pressure (psig) : 3700 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 Outer Annulus Pressure (si N/A ~;a -va ~ ~ ~~-o ~ Date: February 23, 2009 ob~EM We(( SAF a ~: Q ~~ -s ~ F~ .n P~oAcrivr Di~ynosric Srwviccs Start time: 17:47:00 Temperature Data 35 LL ~ ~ 25 20 - 0 1 2 3 4 5 6 7 8 9 10 Minutes 3720 3710 N 3700 d 36so 3680 0 Page 1 Pressure Data 1 2 3 4 Min~tes 6 7 8 9 10 B.P. Exploration (AlaskaJ. lna Static TB/7;r~7E!'c'it'U!r@~ P/'@SSU/'@ SU!'1/EJ/ NS-08 North Star North Slope 91,079' TVDss M.D. = 9 9,889' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 252.51 5107.89 1.0 252.61 5108.09 2.0 252.57 5108.34 3.0 252.56 5108.61 4.0 252.51 5108.88 5.0 252.47 5109.14 6.0 252.44 5109.38 7.0 252.43 5109.62 8.0 252.41 5109.85 9.0 252.41 5110.06 10.0 252.37 5110.26 11.0 252.39 5110.45 12.0 252.36 5110.63 13.0 252.36 5110.79 14.0 252.35 5110.95 15.0 252.36 5111.09 16.0 252.36 5111.23 17.0 252.34 5111.36 18.0 252.36 5111.49 19.0 252.34 5111.61 20.0 252.32 5111.71 21.0 252.31 5111.82 22.0 252.28 5111.91 23.0 252.33 5112.01 24.0 252.31 5112.09 25.0 252.31 5112.18 26.0 252.31 5112.26 27.0 252.31 5112.33 28.0 252.31 5112.40 29.0 252.31 5112.47 30.0 252.31 5112.24 AVERAGE 252.38 5110.75 Date: February 23, 2009 Temperature Data 260 240 220 - 200 180 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes Pressure Data 5200 5150 5100 - -- -- 5050 - ----- ------- N 5000 ----- ---- --- ------- ---- a 4950 ------- -- - - 4900 ------ -- - 48so - -- 4800 0 2 4 6 8 10 12 1411nutes 18 20 22 24 26 28 30 Page 2 Ob`EM We[[ SAf a ~i a ~~ W !~ i N PwoAcrivr Df~yMOSric S[wvic[s Start time: 19:09:00 B.P. Exploration (A/askaJ. lnc. Static rB/17~7E/'c~tU/'@~ P/'E.'SSU/'E sU/'VBJ/ NS-OB North Star North Slope 97,027' TVDss M.D. = 9 9,838' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 251.47 5105.32 0.5 251.49 5105.35 1.0 251.46 5105.39 1.5 251.45 5105.43 2.0 251.41 5105.47 2.5 251.39 5105.50 3.0 251.38 5105.53 3.5 251.36 5105.56 4.0 251.35 5105.59 4.5 251.35 5105.62 5.0 251.32 5105.64 5.5 251.31 5105.66 6.0 251.27 5105.68 6.5 251.31 5105.70 7.0 251.30 5105.72 7.5 251.27 5105.74 8.0 251.26 5105.76 8.5 251.28 5105.78 9.0 251.26 5105.79 9.5 251.25 5105.80 10.0 251.26 5105.82 10.5 251.27 5105.83 11.0 251.27 5105.85 11.5 251.26 5105.86 12.0 251.25 5105.87 12.5 251.25 5105.88 13.0 251.25 5105.89 13.5 251.27 5105.90 14.0 251.26 5105.91 14.5 251.23 5105.92 15.0 251.25 5105.92 AVERAGE 251.32 5105.70 Date: February 23, 2009 Temperature Data 260 240 ?~b`EM WE(( SA~ci Q ~~ s ~' F~ N P~oAcrivE Di~ynmric Suvkn Start time: 19:40:00 ~, 220 200 180 ~ I F I I I I F~ DTI I I I I I i I I F I I~ F-r-I I I ~ ~ 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 5200 5150 ---- 5100 5050 - - 5000 - -------- 4950 -- ~--------- --------- ~-- ----- 4900 ----------- - - -- 4sso ---- 4800 0 1 2 3 4 5 6 I~linutes 9 10 11 12 13 14 15 Page 3 ap Exp~orat/on Alaska>. l„~. Static Temperature/ Pressure Survey NS-08 North Star North Slope 70,970' 1'vDss M.D. = 9 9,787' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.97 5100.66 0.5 250.98 5100.66 1.0 250.98 5100.68 1.5 250.98 5100.70 2.0 250.98 5100.71 2.5 250.95 5100.73 3.0 250.99 5100.74 3.5 250.97 5100.74 4.0 250.97 5100.76 4.5 250.97 5100.77 5.0 250.97 5100.77 5.5 250.97 5100.78 6.0 250.97 5100.78 6.5 250.97 5100.79 7.0 250.97 5100.79 7.5 250.97 5100.80 8.0 250.96 5100.80 8.5 250.93 5100.80 9.0 250.92 5100.80 9.5 250.93 5100.81 10.0 250.92 5100.81 10.5 250.92 5100.81 11.0 250.95 5100.82 11.5 250.96 5100.82 12.0 250.95 5100.82 12.5 250.93 5100.82 13.0 250.95 5100.83 13.5 250.93 5100.83 14,0 250.90 5100.83 14.5 250.93 5100.35 15.0 250.93 5100.35 AVERAGE 250.95 5100.75 Date: February 23, 2009 Temperature Data 260 240 LL ~, 220 200 1so 0 5200 5150 5100 5050 ~~-, sooo a 4950 4soo 4s5o 4800 Ob`EM We[[ SAE a ~~• Q ~~ s F- ~ PROAcrive Diwywofric S[RVit Ff Start time: 19:56:00 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 0 Page 4 1 2 3 4 5 6 ajinutes 9 10 11 12 13 14 15 B.P. Exp/oration (A/askaJ. lnc. Static Temperature/ Pressure Survey NS-OB North Star North Slope X0,870' TYDss M.D. = 9 9,686' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 248.70 5090.48 0.5 248.67 5090.53 1.0 248.57 5090.60 1.5 248.50 5090.67 2.0 248.47 5090.73 2.5 248.40 5090.79 3.0 248.35 5090.83 3.5 248.30 5090.87 4.0 248.30 5090.89 4.5 248.29 5090.91 5.0 248.29 5090.92 5.5 248.27 5090.93 6.0 248.25 5090.93 6.5 248.24 5090.93 7.0 248.24 5090.92 7.5 248.20 5090.92 8.0 248.20 5090.91 8.5 248.22 5090.90 9.0 248.19 5090.89 9.5 248.15 5090.88 10.0 248.15 5090.87 10.5 248.19 5090.86 11.0 248.19 5090.85 11.5 248.19 5090.84 12.0 248.15 5090.83 12.5 248.14 5090.82 13.0 248.14 5090.81 13.5 248.14 5090.80 14.0 248.15 5090.79 14.5 248.14 5090.78 15.0 248.14 5090.78 AVERAGE 248.27 5090.82 Date: February 23, 2009 Temperature Data 260 240 LL 220 200 160 0 5200 5150 5100 5050 5000 4950 4900 4850 4800 ob~E,M WEi!( SAE a o,• 4 ~~ W N P~oAcrivE Di~yMOSric Sewvicrs Start time: 20:11:00 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 0 Page 5 1 2 3 4 5 6 A~linutes 9 10 11 12 13 14 15 B.P. Exp/oration (AlaskaJ. lnc. Stat~C rBlI7~VB/'c~tL//'@~ P/'@SSU!'@ SU/'1/EJ/ NS-OB North Star North Slope 90,972' TYDss M.D. = 9 9,789' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.56 5101.17 0.5 250.47 5101.14 1.0 250.47 5101.07 1.5 250.52 5101.00 2.0 250.57 5100.94 2.5 250.61 5100.88 3.0 250.62 5100.83 3.5 250.66 5100.79 4.0 250.66 5100.76 4.5 250.67 5100.74 5.0 250.68 5100.73 5.5 250.71 5100.71 6.0 250.72 5100.71 6.5 250.75 5100.70 7.0 250.74 5100.70 7.5 250.75 5100.70 8.0 250.76 5100.70 8.5 250.73 5100.70 9.0 250.77 5100.70 9.5 250.77 5100.71 10.0 250.77 5100.71 10.5 250.77 5100.72 11.0 250.81 5100.72 11.5 250.78 5100.73 12.0 250.82 5100.73 12.5 250.81 5100.74 13.0 250.78 5100.74 13.5 250.81 5100.75 14.0 250.82 5100.75 14.5 250.81 5100.76 15.0 250.82 5100.83 AVERAGE 250.71 5100.79 Date; February 23, 2009 ob`EM WEI( SAS a ~~ Q 9~ W ~ M PwaJkrive Di~ynmTic sewvien Start time: 20:27:00 Temperature Data 2so 240 220 -- -- --- ~, 200 -- 180 -- 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5200 5150 5100 5050 h 5000 a 4950 4900 4850 4aoo Pressure Data 0 Page 6 1 2 3 4 5 6 f~jinutes 9 10 11 12 13 14 15 ~r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~^^~ ~ ~ ~ ~ ~ ~ r ~ e.P Exp~orat/on ~a/aska>.1~~. Static Temperature/ Pressure Survey NS-08 North Star North Slope 90,370' TYDss M.D. = 9 9, 976' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 233.68 5039.40 0.5 233.61 5039.64 1.0 233.54 5039.88 1.5 233.44 5040.07 2.0 233.38 5040.20 2.5 233.28 5040.29 3.0 233.23 5040.33 3.5 233.23 5040.35 4.0 233.18 5040.34 4.5 233.12 5040.31 5.0 233.09 5040.26 5.5 233.03 5040.20 6.0 233.03 5040.14 6.5 233.00 5040.07 7,0 232.96 5040.00 7.5 232.95 5039.93 8.0 232.91 5039.86 8.5 232.95 5039.78 9.0 232.90 5039.71 9.5 232.90 5039.64 10.0 232.89 5039.57 10.5 232.89 5039.51 11.0 232.89 5039.45 11.5 232.85 5039.39 12.0 232.84 5039.33 12.5 232.85 5039.27 13.0 232.81 5039.22 13.5 232.85 5039.16 14.0 232.80 5039.11 14.5 232.81 5039.06 15.0 232.80 5039.02 AVERAGE 233.06 5039.76 Date: February 23, 2009 Ob~F,M WE[[.SAf a ~~ 4 ~~ W ~' M P~oAcrivr Diwyrosric SlRVK[S Start time: 20:59:00 Temperature Data 260 240 220 - -- ~, 200 ---- 180 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5200 5150 5100 5050 y 5000 a 4950 4900 4850 4soo Pressure Data 0 Page 7 1 2 3 4 5 6 Minutes 9 10 11 12 13 14 15 ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ w ~ B.P, Exploration (A/askaJ. lnc. Static Temperature/Pressure Survey NS-08 North Star North Slope 9,870' TVDss M.D. = 90,654' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 219.93 4985.54 0.5 219.86 4985.68 1.0 219.78 4985.80 1.5 219.71 4985.88 2.0 219.69 4985.92 2.5 219.66 4985.94 3.0 219.61 4985.93 3.5 219.59 4985.90 4.0 219.56 4985.86 4.5 219.51 4985.81 5.0 219.51 4985.75 5.5 219.49 4985.69 6.0 219.46 4985.62 6.5 219.46 4985.55 7.0 219.45 4985.49 7.5 219.41 4985.42 8.0 219.40 4985.35 8.5 219.39 4985.29 9.0 219.39 4985.22 9.5 219.35 4985.16 10.0 219.35 4985.10 10.5 219.35 4985.04 11.0 219.35 4984.98 11.5 219.31 4984.93 12.0 219.33 4984.88 12.5 219.30 4984.83 13.0 219.27 4984.78 13.5 219.30 4984.73 14.0 219.28 4984.69 14.5 219.26 4984.60 15.0 219.26 4984.60 AVERAGE 219.47 4985.35 Date: February 23, 2009 ob`EM WE[( SAF a ~y Q 9w F~ M P~oAcrivr Di~yaosric srwk[s Start time: 21:19:00 Temperature Data 2so 240 -- --- aL 220 - - - - 200 180 - 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5200 5150 5100 5050 H 5000 a 4950 4soo 4850 4aoo Pressure Data 0 Page 8 1 2 3 4 5 6 (winutes 9 10 11 12 13 14 15 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ a.P ~plo~at/o~ ~a/asks>.1~~. 5tatic Temperature/ Pressure Survey NS-OB North Star North Slope 9,369' TVDss M.O. = 70, 7 74' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psis) 0.0 207.71 4929.20 0.5 207.67 4929.29 1.0 207.62 4929.37 1.5 207.53 4929.42 2.0 207.49 4929.45 2.5 207.42 4929.47 3.0 207.38 4929.46 3.5 207.37 4929.45 4.0 207.31 4929.42 4.5 207.28 4929.39 5.0 207.22 4929.35 5.5 207.21 4929.31 6.0 207.17 4929.26 6.5 207.17 4929.21 7.0 207.12 4929.17 7.5 207.13 4929.12 8.0 207.09 4929.07 8.5 207.09 4929.02 9.0 207.07 4928.98 9.5 207.04 4928.93 10.0 207.00 4928.89 10.5 207.06 4928.85 11.0 206.99 4928.81 11.5 207.02 4928.77 12.0 206.98 4928.73 12.5 206.99 4928.69 13.0 207.01 4928.66 13.5 206.97 4928.62 14.0 206.96 4928.59 14.5 206.97 4928.56 15.0 206.96 4928.53 AVERAGE 207.19 4929.07 Date: February 23, 2009 Ob`EM WE« SAS 4P c~~ W u' i M P~oAcrivr Di~yumric Suvicrs Start time: 21:19:00 Temperature Data 2so 240 -- 220 - -- --- ----- ~, -- - -- 200 1so 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5200 5150 5100 5050 H 5000 a 4950 4900 4sso 4soo Pressure Data 0 Page 9 1 2 3 4 5 S M1~linutes 9 10 11 12 13 14 15 i a.P ~Flo~gt/o~ ~Aleska~ /~~. Static Temperature/ Pressure Survey NS-OB North Star North Slope 8,853' TVDss M.D. = 9,550' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 195.57 4869.70 1.0 195.53 4869.81 2.0 195.47 4869.90 3.0 195.34 4869.92 4.0 195.24 4869.90 5.0 195.19 4869.85 6.0 195.16 4869.79 7.0 195.09 4869.73 8.0 195.08 4869.66 9.0 195.06 4869.59 10.0 195.03 4869.52 11.0 195.01 4869.46 12.0 194.98 4869.40 13.0 194.97 4869.34 14.0 194.97 4869.28 15.0 194.93 4869.23 16.0 194.93 4869.19 17.0 194.89 4869.15 18.0 194.88 4869.10 19.0 194.89 4869.06 20.0 194.88 4869.03 21.0 194.88 4869.00 22.0 194.88 4868.97 23.0 194.86 4868.94 24.0 194.86 4868.91 25.0 194.84 4868.89 26.0 194.83 4868.87 27.0 194.84 4868.85 28.0 194.86 4868.83 29.0 194.83 4868.81 30.0 194.83 4868.80 AVERAGE 195.02 4869.31 Date: February 23, 2009 ob`EM WE(( SpF a ~~~ Q ~~ -s F~ N P~Mcriv[ Di~yr~osric s[svic[s Start time: 21:57:00 Temperature Data 260 240 - 220 - ~, 200 - -- 180 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes 5200 5150 5100 5050 ~-~, 5000 4950 4900 4850 4800 Pressure Data 0 Page 10 2 4 6 8 10 12 INinutes 18 20 22 24 26 28 30 B.P. Exploration (A/askaJ. lnc. Static TE/77f7E/'c'~itUlEB~ P!'ESSU/'B $U/'1/f'.~/ NS-08 North Star North S/ope 8,752' TVDss M.D. = 9,440' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 193.84 4857.25 0.5 193.88 4857.25 1.0 193.83 4857.25 1.5 193.82 4857.25 2.0 193.78 4857.26 2.5 193.75 4857.26 3.0 193.74 4857.26 3.5 193.77 4857.26 4.0 193.68 4857.26 4.5 193.68 4857.26 5.0 193.68 4857.26 5.5 193.68 4857.26 6.0 193.63 4857.25 6.5 193.63 4857.25 7.0 193.63 4857.25 7.5 193.60 4857.25 8.0 193.60 4857.24 8.5 193.62 4857.24 9.0 193.56 4857.24 9.5 193.57 4857.23 10.0 193.58 4857.23 10.5 193.55 4857.22 11.0 193.57 4857.22 11.5 193.55 4857.22 12.0 193.55 4857.22 12.5 193.57 4857.21 13.0 193.53 4857.21 13.5 193.54 4857.20 14.0 193.56 4857.20 14.5 193.53 4857.20 15.0 193.53 4857.20 AVERAGE 193.65 4857.24 Date: February 23, 2009 ob`EM WE(( SAf a ~: 4 v~ s ~' F~ .w PROAcrivE Di~ynoerie SERVICE! Start time: 22:30:00 Temperature Data 260 240 ---- - - LL 220 -- - - - 200 - -- - 180 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5200 5150 5100 5050 5000 4950 a9oo 48so a8oo Pressure Data 0 Page 11 1 2 3 4 5 6 Minutes 9 10 11 12 13 14 15 _J B.P. Exploration (A/askaJ /na Sta'1t/C Teml~e~'atU/'@~ P~'eSSU!'@ .SU/'VE'J/ NS-08 North Star North Slope Surface -After POI~H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 33.14 3704.64 0.5 32.95 3704.72 1.0 32.80 3704.83 1.5 32.61 3704.94 2.0 32.42 3705.06 2.5 32.20 3705.19 3.0 32.21 3705.32 3.5 32.11 3705.45 4.0 32.00 3705.58 4.5 31.90 3705.70 5.0 31.85 3705.82 5.5 31.75 3705.93 6.0 31.65 3706.02 6.5 31.55 3706.10 7.0 31.52 3706.16 7.5 31.42 3706.21 8.0 31.35 3706.24 8.5 31.05 3706.27 9.0 30.85 3706.27 9.5 30.75 3706.27 10.0 30.82 3706.26 AVERAGE 31.85 3705.67 Current Wellhead Read ings Wellhead Pressure (psig) : 3700 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 0 Outer Annulus Pressure (si ) : N/A Date: February 23, 2009 ob`EN1 WE(( SAE Qa c'~ s s f"' N PeoAcrivr Di~yNO~ric Srwiees Start time: 23:31:00 Temperature Data ao 35 --- LL 30 - Q+ 3 25 - - 20 ---- - 0 1 2 3 4 5 6 7 8 9 10 Minutes 3720 3710 H 3700 a 3690 3680 0 Page 12 Pressure Data 1 2 3 4 Minutes 6 7 8 9 10 J B.P. F-~rplonation (AlaskaJ. lnc. NS-08 North Star North Slope Downho% Temp/Press Date: February 23, 2009 Static Temperature/ Pressure Survey Start time: 17:47:00 End Time: 23:42:00 Ob`QM WE((SAf 4a c'~ r, s ~ M PIIOACtIVE DI~fjMOET~[ sl EtVICEf 2so Temperature Data 240 W 220 200 180 -200 200 600 1000 1400 1800 2200 2600 3000 Minutes Pressure Data 5200 5150 ---- 5100 - ---- -- 5050 -- _...-- -- --- - ------- N 5000 - ---- -- - ------ --- --- --- a 4950 ~ - ----- - -- -_-.- - ~ -- 4900 - - --- -- -- - - _.__ _______.------ _ __. 4850 -- - _-- -- _-- -_____--- - _---. -.- _--.-- --....----- -- 4800 - -- - -- 14no -200 200 600 1000 Mihtit-es 1800 2200 2600 3000 Page 13 STATE OF ALASKA V 9~~~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS °~ 0 $ 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ _~~~`~~~` CnS„ Ql's'?~" Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver ~ Time Extension ~id~, ~s,i'c~~8 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 202-0210 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number. `_ Anchorage, AK 99519-6612 50-029-23068-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 56 KB NS08 8. Property Designation: 10. Field/Pool(s): ADLO-312799 NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 12030 ~ feet Plugs (measured) None true vertical 11266.74 - feet Junk (measured) None Effective Depth measured 11942 feet true vertical 11179.58 feet Casing Length Size MD TVD Burst Collapse Conductor 165 20" 169# x-56 45 - 210 45 - 210 4260 2590 Surface 3361 13-3/8" 68# L-80 44 - 3328 44 - 3220 4930 2270 Production 11710 9-5/8" 47# L-80 42 - 9919 42 - 9247 6870 4760 Liner 1864 7" 26# L-80 9741 - 11461 9084 - 10705 7240 5410 Liner 735 4-1/2" 12.6# 13CR80 11293 - 12029 10540 - 11266 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR VAM-ACE 40 - 11297 0 0 - Packers and SSSV (type and measured depth) 5-1/2" HRO SSV 1992 7" Top Packer 9741 4-1/2" Baker S-3 Perm Packer 11249 4-1/2" Top Packer 11293 12. Stimulation or cement squeeze summary: Intervals treated (measured): >.~:~~~E~ 5~~~ ~~, ~~ 2008 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: 917 26711 0 766 Subsequent to operation: 983 33727 26 767 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 ~I GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-274 Contact Robert Younger Printed Name Robert Y nger Title Production Engineer Signature Phone 564-5392 Date 9/8/2008 Form 10-404 Revised 04/2006 fk~ ~ _ .. ~ ~j~~ ~ ~ ~~~8 Submit Original Onl~ ~, ~ i1 e.~l~~ ~.i`~~~1 1~ NS08 202-0210 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tod Tvd Depth Base NS08 3/19/02 PER 11,755. 11,895. 10,994.69 11,133.06 NS08 12/6/04 APF I 11,891. 11,910. 11,129.1 11,147.9 NS08 8/18/05 SQZ 1,954. 11,910. ________ 1,951.86 11,147.9 NS08 8/23/05 SQZ 11,755. 11,910. 10,994.69 11,147.9 NS08 12/16/05 PER 9,628. 9,668. 8,980.49 9,017.16 NS08 12/23/05 STC 9,554. 11,170. 8,912.58 10,419.8 NS08 3/28/06 APF 11,886. 11,912. 11,124.16 11,149.88 NS08 6/1/06 APF 11,886. 11,912. 11,124.16 11,149.88 NS08 4/10/07 SQF 1,954. _ 11,910. 1,951.86 11,147.9 NS08 8/28/08 APF 11,886. 11,912. 11,124.16 11,149.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT _ SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE _ • NS08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/27/2008 ""~W ELL FLOWING ON ARRIVAL~~~ RIG UP ELINE TO PERFORATE ONE INTERVAL WITH 26' OF 2.88" PJ 2906 ***JOB CONTINUED ON 28-AUG-2008*** 8/28/2008 ~**JOB CONTINUED FROM 27-AUG-2008*'`'` TIE INTO SLB JEWELRY LOG/USIT DATED 3/18/2002 PERFORATE INTERVAL 11886'-11912' WITH 26' OF 2.88" PJ 2906, EHD=0.38", TTP=25.3" JEWELRY LOG LOCATED UPPER X-NIP AT 11163', UPPER XN-NIP AT 11234', TAG TD AT 11927' ELMD. WELL TURNED BACK OVER TO OPERATIONS. WELL LEFT FLOWING, IA/OA-OPEN TO GAUGES, SWAB SHUT FINAL T/I/O = 775/33/100 PSI ***JOB COMPLETE, TURNED OVER TO DSO, OPERATIONS NOTIFIED*"" FLUIDS PUMPED BBLS 1.5 diesel 1.5 Total ALA5S-A OIL A1~TD GAS CO1~T5ERVATIOI~T COMl-II5SIOrIT Robert Younger Production Engineer BP Exploration Alaska Inc.,,. ~~ ~~ ~ ~ 20~g ~,- .-.. PO Box 196612 `~ ~' Anchorage AK 99519-6612 Re: Northstar Field, Northstar Oil Pool, NS08 Sundry Number: 308-274 Dear Mr. Younger: • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 a~ a~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. ~~ Chair DATED this ~ day of August, 2008 Encl. / ' u . STATE OF ALASKA ~ P ~e ,€~ ALASKA OIL AND GAS CONSERVATION COMMISSIOfiV`~'~ "~ ~ 2Q~& ~~'~'~ APPLICATION FOR SUNDRY A~P:~-1- 20 AAC 25.280 1. Type of Request: Abandon Suspend Operational shutdown Perforat ~ Waiver ^ Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulat~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni0 Exploratory ^ 202-0210 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23068-00-00 - 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: NS08 . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-312799 ~ 56 KB r 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): 12030 ~ 11266.74 ~ 11942 - 11179.58 - NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 165 20" 169# X-56 45 210 45 210 4260 2590 Surface 3361 13-3/8" 68# L-80 44 3328 44 3220 4930 2270 Production 11710 9-5/8" 47# L-80 42 9919 42 9247 6870 4760 Liner 1864 7"26# L-80 9741 11461 9084 10705 7240 5410 Liner 735 4-1/2" 12.6# 13CR80 11293 12029 10540 11266 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 13Cr80 12.6# 40 - 11297' Packers and SSSV Type: 4-1/2" BKR PREMIER PKR Packers and SSSV MD (ft): 11170' 4-1/2" BKR S-3 PKR 11249' 7" BKR ZXP PACKER 11293' 4-1/2" TRM-4E SCSSSV 992' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/12/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name obe Younger Title Production Engineer Signature Phone 564-5392 Date 7/29/2008 COMMISSION USE ONLY Number: ~ ~ ~~ Conditions of a roval: Notif Commission so that a re resentative ma witness Sund . ry pp y y p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form R fired: APPROVED BY ~~,,~ Y / Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 062 d Submit in Duplicate a..,°~~~. 3 S ~~., ~t~(i ~~ :~ 2006 NS08 202-0210 PERF ATTAC:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS08 3/19/02 PER 11,755. 11,895. 10,994.69 11,133.06 NS08 12/6/04 APF 11,891. 11,910. 11,129.1 11,147.9 NS08 8/18/05 SQZ 1,954. 11,910. 1,951.86 11,147.9 NS08 8/23/05 SQZ 11,755. 11,910. 10,994.69 11,147.9 NS08 10/24/05 AB 11,755. 11,910. 10,994.69 11,147.9 NS08 3/28/06 APF 11,886. 11,912. 11,124.16 11,149.88 NS08 6/1/06 APF 11,886. 11,912. 11,124.16 11,149.88 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • PERFORATING PROCEDURE Ver4ooslo'to, ~W rraoa~wa~t Well: NS08 API #: 50-029-23068-00 ................................................................. g ................................g............ Date: 07/25/08 Prod En r Robert Youn er Office Ph: 564-5392 H2S Level: Home Ph: 677-2599 0 ppm .......................................................... Cell Ph: 830-4920 .......................................................... CC or AFC: NSFLDWL08 Detail Code: Description: Re-Perforate ................................................................................................................................... WBL Entries IOR Type Work Description Well Objectives and Loaaing Notes: NS08 has been online since late 2001. In 2005, perforations were squeezed to shut off gas and secure the well for a RWO. The RWO resolved the existing TxIA communication and the squeezed perforations allowed for a more conservative perforation strategy. The objective of the slickline portion of this procedure is to evaluate the extent of any restrictions that might exist. The proposed reperforations are an attempt to increase the well's production. Please note that the final perforartion interval will depend on pre-perf drift. Attachment: Log Section, Tubing Summary 500 S Drift to TD w/ Dummy Gun 500 E Re -Perforate 26'. Please note actual) pert interval will de end on drift. USIT/GR/CCL ............................. 3/18/2002 from the tie-in log to be on depth with the reference log. Depths (from-to) Feet SPF Orient. 11886' - 11,912' 26' 6 Phasing Zone 60° 0 Ivishak 0 0 0 0 Gas Jetting Expected? No At what Depth? N/A Ad/Re/Iperf Re Requested Gun Size: 2-7/8" Charge: PowerJet_2906, HMX Desired Penetration: 25.3 Entry Hole Diam: 0.38 Is Drawdown Necessary/Desired/Unnecessary During Perforating No . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 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 C~ MD Tie in using: Minimum ID: _......-3:725.........in Min ID Type: ..............4.5" XN.Nipple,...,_,....... C~ 11,221 'MD .................... Tail Depth: 11,297 ft MD Casing Size: 4:5,,, .,, in 12.6# 13-CR Liner Est Res. Pres. ~ 11 :895 MD is ............. 5.1.1.0., psi Last Tag: .11:897 ft MD on slickline tag 02/16/07 Well: NS08 Perforation Summary Date: API #: 50-029-23068-00 On-Site Prod Engr: General Comments: Depths Balance Referenced to BHCS O/B/U - O/B/U ......................_......'....................... O/B/U - O/B/U ...............................-......................... O/B/U - Feet SPF Orient. Phasing PBTD Zone Aperf/Reperf DO ................................................................................ ~O ..........................................................-......................., -I /`/SDv lnoo U: ~ T /CG/=~ ~~ C ~ . 03 / ~ B ~,~ o~.Z, 11800 ~ `~ Z `J "' J w N W h J Re-Perforations 11886' - 11912' 11 ma nay lun) - ...~... __ ...__ ._... ------- (GAPI) 150 '0 (DEGF) 4 ~Ilar Locator (CCL) _Tension (TENS) _ ,,,,. - _ .. ~innnti~-~- (LBFI TREE _ WELLHEAD" ABB-VGI 13-5/8 MULTIBOWL 5 ACTUATOR - BAKER KB. ELEV _ 56' BF. ELEV = 40.1' (CB 15.9') KOP = 1575' Max Angle = 28° @ 4654' Datum MD = 11310' Datum TV D = 10500' SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" I~ 3328' Minimum ID = 3.725" @ 11220' 4-1 /2" XN NIPPLE NOTES: ***4-1l2" CHROME TBG &LNR*** 4-1/2" TRM-4E SCSSSV w/4-1/2" X PROFILE, ID = 3.812" 13-3/8" TAM PORT COLLAR GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DAl 4745 4488 27 SMOR DMY BK O 01/09 9466' 4-1/2" HES X NIP, ID = 3.813 9529' 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 9554' 9-5/8" X 4-1/2" BKR PKR, ID = 3.870" 9581' 4-1/2" XD DURO SLIDING SLV, ID = 3.812" I70P OF 7" LNR ~ 9741' 9-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681 " 9919' PERFORATION SUMMARY REF LOG: Sb~JS USff ON 03118!02 (NO LOGS @ PBOC 1123(06) ANGLE AT TOP PERF: 23 @ 9268' INITIAL PERF - CI-IARGE: 2906 POWERJET, HP~JC, 6 SPE PENETRATION: 27°: HOLE: 0.36", PHASE: 60 DEG. Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 4-1/2" 5 9628 - 9668 O 12/26/05 2-7/8" 6 11755 - 11895 S 08/23/05 2-7/8" 6 11886 - 11912 O 06/01/06 2-7/8" 6 11891 - 11910 S 08/23/05 4-1/2"TBG, 12.6#, 13CRVAM-ACE, I~ .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR ~-1 11293, 4-1/2" TBG, 12.6#, 13CRVAM-ACE, 11297 .0152 bpf, iD = 3.958" 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 11461 u-t , ~ y4s~ 4-1/2" LNR, 12.6#, 13CRVAM-ACE, 12029' .0152 bpf, ID = 3.958" 9689' I-I4-1/2" XD DURO SLIDING SLV, ID = 3.812" 11149' - ~4-1/2" HES X NIP, ID = 3.813" 11170' 7" X 4-1/2" BKR PREMIER PKR, ID = 3.875" 11199' 4-1/2" HES X NIP, ID = 3.813" 11220' 4-1/2" HES XN NIP, ID = 3.725" 11241' 4-1/2" X 7" UNIQUE OVERSHOT 11252' ELM TBG STUB (10/29/05) 11249' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 11273' 4-1/2" HES X NIP, ID = 3.813" 11284' 4-1/2" HES XN NIP, ID = 3.725" 11302 ELM 4-1/2" HES XN NIP, ID = 3.725" 11297' 4-1/2" WLEG, ID- 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 03/18/02 INITIAL COMPLETION 03/28/06 RMH/PJC ADPERFS WELL: NSOS 12/26/05 N-33ES RWO 05/28/06 DTR/PJC E-LINE DEPTH-XN NIP @ 11302' PERMff No: 2020210 01/02/06 KSB/PJC DRLG DRAFT CORRECTIONS 06/09/06 WRR/PA REPERF (06101/06) API No: 50-029-23068-00 01/09/06 GJB/PJC SSSV CORRECTIONS 11/27/07 WRRIPJC WELLHD/LOCATION CORRECTION S SEC 11, T13N, R13E, 1119' FSL & 642' FEL 01/09/06 GJB/PJC SET PXN PLUG @ 11220' 03128/O6 RMH/PJC PULL PXN PLUG (2/19/06) BP Exploration (Alaska) ABB-VGI5-1/8" 5 NS08 ~;; 992' 1582 e e bp Date 08-14-2007 Transmittal Number:92897 "'i -.C:. ....... \.1 Z007 Sf. Commission BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ;) Log Top SW Name Date Contractor Run Depth Bottom Depth Loq Type <.>):c.. -..; -/l1a NS10 07-21-2007 SCH 1 4800 7975 WATER FLOW INJECTION :tc. 0"3-,,,4< NS32 07 -20-2007 SCH 1 3760 8075 WATERFLOW INJECTION 9-;)6"7- NS19 07-08-2007 SCH 1 13650 1 3955 PERFORATION RECORD ~' ö3C.. NS11 07-06-2007 SCH 1 14450 14625 PERFORATION RECORD )1 - ()W_ NS13 07 -14-2007 SCH 1 11 534 11 790 MEMORY PPROF - (~ NS24 07 -15-2007 SCH 1 11774 12476 STATIC BOTTOM HOLE , ~ -~J3 NS22 07-09-2007 SCH 1 12600 12850 PERFORATION RECORD -b81 NS08 .12-23-2005 PDS 1 9006 11406 CORRELATION LOG bd --91t) NS21 07 -02-2005 PDS 1 21590 22249 DEPTH DETERMINATION 1:c:!. -/~c9 NS10 01-01-2006 PDS 1 4497 5497 CORRELATION LOG fJ¢o v 9 ~Ö ìö h. ~ ~o ¡cd () 7(JÖ c. lL--- Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center stANNED AUG 1 12007 Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp tRECEIVED . Date 05-04-2007 Transmittal Number:92888 MAY 0 8 Z007 Alaska Oil & Gas Cons. c;ommIssioo Anchorage BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~o;).- oa I #: IS(D~ Log Top SW Name Date Contractor Run Depth Bottom Depth Log Type STATIC TEMP / PRESSURE NS07 07 -23-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS12 07 -23-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS16 08-20-2006 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS12 02-17 -2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS09 02-19-2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS24 02-15-2007 PDS SURVEY REPORT STATIC TEMP / PRESSURE NS06 02-18-2007 PDS SURVEY REPORT DEPTH DETERMINATION NS07 07 -23-2006 PDS LOG DEPTH DETERMINATION NS12 07 -23-2006 PDS ::Nat "^V I\.{J ?nn7 LOG ....- .. .. . DEPTH DETERMINATION NS16 08-20-2006 PDS LOG NS12 02-17-2007 PDS JEWELRY LOG NS09 02-19-2007 PDS JEWELRY LOG NS24 02-15-2007 PDS JEWELRY LOG NS06 02-18-2007 PDS JEWELRY LOG NS24 04-10-2007 PDS PRODUCTION PROFILE NS08 04-10-2007 PDS PRODUCTION PROFILE NS13 04-07 -2007 PDS COIL FLAG NS07 07 -13-2006 PDS JEWELRY LOG / CD ROM NS12 07-23-2006 PDS JEWELRY LOG / CD ROM DEPTH CORRELATION NS16 08-20-2006 PDS STATIC SURVEY CD ROM Petrotechnical Data Center LR2-l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp . . Date 05-04-2007 Transmittal Number:92888 BPXA WELL DATA TRANSMITTAL JEWELRY LOG / STATIC NS12 02-17 -2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS09 02-19-2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS24 02-15-2007 PDS SURVEY CD ROM JEWELRY LOG / STATIC NS06 02-18-2007 PDS SURVEY CD ROM PRODUCTION PROFILE NS24 04-11-2007 PDS CD ROM PRODUCTION PROFILE NS08 04-10-2007 PDS CD ROM NS13 04-07-2007 PDS COIL FLAG CD ROM Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center Attn: Kristin Dirks Chistine Mahnken Ignacio Herrera Doug Chromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ons ('''- 1. Operations Performed: AnChoraitlt,erO ,v,"On AbandonO RepairWellD PluQ Perforation sO Stimulate 0 Alter casingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒI ExploratoryD 202-0210 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-23068-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.00 NS08 8. Property Designation: 10. Field/Pool(s): ADL-0312799 Northstar Filed / Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 12030 feet true vertical 11266.7 feet Plugs (measured) None Effective Depth measured 11942 feet Junk (measured) None true vertical 11179.6 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 20" 169# X-56 45 210 45.0 - 201.0 4260 2590 SURFACE 3361 13-3/8" 68# L-80 44 - 3328 44.0 - 3220.0 4930 2270 PRODUCTION 11710 9-5/8" 47# L-80 42 - 9919 42.0 - 9247.0 6870 4760 LINER 1864 7" 26# L-80 9741 - 11461 9084.0 - 10705.0 7240 5410 LINER 735 4-1/2" 12.6# 13Cr80 11293 . 12029 10540.0 - 11266.0 8430 7500 Perforation depth: Measured depth: 9628-9668,11755-11895, 11891-11910, 11886-11912 S(!ANNSfJ sr:p 2 h znnE ~ ,~. ~'" . ~., ~~.....!. /";t -..J ...... U ''>Ii True vertical depth: 8980-9017, 10995-11133, 11129-11148, 11124-11150 TubinQ ( size, Qrade, and measured depth): 4-1/2" 12.6# 13CrBO @ 40 - 11297 Packers & SSSV (type & measured depth): 9-5/8" BKR Packer @ 9554 7" BKR Premier Packer @ 11170 7" BKR S-3 Packer @ 11249 7" BKR ZXP Packer @ 11293 4-1/2" TRM-4E SCSSSV @ 992 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft SEP 2 5 2006 Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 449 114 97 -- 694 Subsequent to operation: 450 117 108 --- 711 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 306-164 Printed Name DeWayntt R. Schnorr ~ Title Petroleum Engineer Signature ~n4 M "/ ,)'..... 11 - Phone 564-5174 Date 9/18/06 v Form 10-404 Revised 4/2004 CRIGINAL h¿ ?/2.)/ob R . . ECE/VED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SfP 1 9 ZOO' REPORT OF SUNDRY WELL OPERAl'I0NSGasc ö . . NS08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/01/2006 RE-PERFORATE NS-08 WITH 2 7/8" HSD POWERJETS LOADED 6SPF FROM 11886- 11912'. CORRELATED TO SWS USIT/GR/CCL DATED 18-MARCH-2002. TAGGED TD @ 11942' ELMD. ALL SHOTS FIRED. POP WELL. *** JOB COMPLETE*** 05/28/2006 *** Well flowing on arrival *** Drift wI 27/8" dummy gun & sample bailer to 11,907' slm, ( very small sample) hard bottom, drift wI XN loc to XN nipple @ 11,200' slm 20' corr. to MD = TD of 11,927' slm (Bottom perf @ 11,912') Notify DSO of well status, can POP FLUIDS PUMPED BBLS 1 Diesel --- PT Surface Equipment 2 Neat Methanol 3 TOTAL Page 1 TREE = WELLHEAD = ACTUATOR = KB. 8...EV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVO = ABB-VGI5-1/8" 5K ABB-VGI13-5/8" MUL TIBOWL 5K51 NS08 5 NOTES: ***4-1/2" CHROME TBG & LNR*** 56' 40.1' (CB 15.9') @ 10500' S5 113-3/8" CSG, 68#, L-80 BTC, 10 = 12.415" H 3328' Minimum ID = 3.725" @ 11220' 4-1/2" XN NIPPLE I TOP OF 7" LNR 19-5/8- CSG, 47#, L-80 BTM-C, ID = 8.681" PERFORA TION SUMMARY REF LOG: SWS usrr ON 03/18/02 (NO LOGS @ PBOC 1/23106) ANGLE AT TOP PERF: 23 @ 9268' INITLl\L PERF - CHARGE: 2906 POWERJET. HMX, 6 SÆ ÆNETRA TION: 27", HOLE: 0.36", PHASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MO) Opn/Sqz DATE 4-1/2" 5 9628 - 9668 0 12/26/05 2-7/8" 6 11755-11895 5 08/23/05 2-718" 6 11886-11912 0 06/01/06 2-7/8" 6 11891 - 11910 S 08/23/05 4-1/2" TBG, 12.6#, 13CR VAM-ACE. .0152 bpt, ID = 3.958" TOPOF 4-1/2" LNR I 4-1/2" TBG, 12.6#, 13CRVAM·ACE .0152 bpf, ID = 3.958" 17" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" IPBTD H 11943' 4·1/2" LNR, 12.6#, 13CRVAM-ACE --i 12029' .0152 bpf, 10 = 3.958" . 992' 4-1/2" TRM-4E SCSSSV w /4-1/2" X PROFILE, 10 = 3.812" --i 13-3/8" TAM PORT COLLAR I 14-1/2" HES X NIP, 10 = 3.813" I --i 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" --i 9-5/8" X 4-1/2" BKR PKR, ID = 3.870" I 9581' -14-1/2" XO DURO SLIDING SLY, 10 = 3.812" 9689' -14-1/2" XO DURO SLIDING SLY, 10 = 3.812" I 11149' !-14-1/2"HESXNIP,ID=3.813" I DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/02 INITIAL COM PLETION 03/28/06 RMHlPJC ADPERFS 12/26/05 N-33ES RWO OS/28/06 DTRlPJC E-LlNE DEPTH-XN NIP @ 11302' 01/02/06 KSB/PJC ORLG DRAFT CORRECTIONS 06/09/06 WRRlPA REÆRF (06/01/06) 01/09/06 GJB/PJC SSSV CORRECTIONS 01/09/06 GJB/PJC SET PXN PLUG @ 11220' 03/28/06 RMHlPJC PULL PXN PLUG (2/19106) NORTHSTAR WELL: NS08 PERMrr No: "2020210 API No: 50-029-23068-00 SEC T N R E BP Exploration (Alaska) . . 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 at 564-4091. ;¡ SW Name Date Contractor Loq Run Top Depth Bottom Depth Loq Type NS08 03-28-2006 SCH PERF RECORD ()J.. -ú~l NS08 06-01-2006 SCH PERF RECORD NS14A 01-20-2006 SCH DEPTH CONTROL NS16 05-05-2006 SCH PRODUCTION PROFILE PERF RECORD WITH NS31 06-05-2005 SCH GAMMA RAY NS30 04-15-2006 SCH JEWELRY LOG NS30 04-02-2006 SCH JEWELRY LOG PERF RECORD WITH NS30 04-14-2006 SCH GAMMA RAY NS19 05-15-2006 SCH PERF RECORD aU 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 SCANNED AUG 3 ). 2005 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RE: Northsta}: NS08 Testing Status ; e e Subject: RE: Northstar: NS08 Testing Status From: "Younger, Robert 0" <Robert.Younger@bp.com> Date: Thu, 18 May 2006 13:28:32 -0800 To: Jane· Williamson <j cc: "Garing, " <John. Garing <jody_colo in. state. ak.us> bJ.. \ Jane, NS08 is currently the only well in need of a well test frequency extension. Thanks for the help! Bob From: Jane Williamson [mailto:jane_williamson@admin.state.ak.us] Sent: Thursday, May 18, 20069:52 AM To: Younger, Robert 0 Cc: Garing, John 0; cathy_foerster@admin,state.ak.us; Jody J Colombie Subject: Re: Northstar: NS08 Testing Status ¥j¡ Fy '\ Q 2GOB hth\i oJ- U OK. Use 120 days but please make your best efforts to get a test soon after equipment is available. Will you need a well test frequency extension for any other wells? If so, please pass on the list of those wells impacted with a similar summary of situation as you provided for NS-08. Younger, Robert 0 wrote: Jane, Thanks for the below. I plan to forward your e-mail and touch base with the MMS. In terms of the 90 days, assuming the TAPS shutdown occurs as planned on July 22 that will be 87 days since NS08's last test which was April 26th. It will likely take a few days to get the facilities back up and running and there is always risk that the TAPS shut-down could slip a few days. Therefore, would it be possible to get a longer extension? Please let me know. Thanks! Bob From: Jane Williamson [mailto:iane williamson@admin,state,ak,us] Sent: Wednesday, May 17, 2006 1:35 PM To: Younger, Robert 0 Cc: winton aubert@admin.state,ak.us; Garing, John 0; Cathy P Foerster Subject: Re: Northstar: NS08 Testing Status Bob, You have AOGCC approval to produce NS08 without well test for up to 90 days. Please let us know if it appears you will not be able to get a test within this time frame. The following is our understanding of the situation. Ion 5/18/20061:43 PM RE: Northstàr: NS08 Testing Status e e BP squeezed upper perforations earlier in the year in NS08 and perforated a lower sand in an attempt to decrease GOR. Only one test was available after this procedure and production rate was quite low (although GOR remained unchanged.) We approved reperforation of the same zone early this month. Pool rules for Northstar require a well test every month and if you proceed with production immediately after the reperf, you won't be able to meet the testing requirement. I understand that BP uses an IPR technique to allocate production between well tests using surface flowing pressure, and estimating GOR and water cut from earlier tests. Field allocation factors for 2005 were acceptable at 1.093. The well allocation can be revised if a future test indicates it would be necessary. MMS regulations require well tests every 2 months. Allocation is on a lease basis using a formula agreed by BP, DNR and MMS and doesn't rely on individual well allocation and there should be no issues with ownership/royalty. This is a State well so we are not sure if MMS must also approve. Regardless, you should give them a call and fill them in. Probably the best contact for this at a staff level would be Kyle Monkelien. He can be reached at 334-5307 or kvle.monkelien(,á¿mms.Qov. Thank you for keeping us informed. Jane Younger, Robert 0 wrote: Jane, Winton requested that I touch base with you regarding the testing status of NS08. Issue · Due to a malfunctioning divert valve, NS08 cannot be diverted to the test separator. · The scheduled repair of the divert valve will be during the July TAPS shutdown. · Cannot test NS08 until the divert valve is repaired. · There is currently a re-perforation procedure waiting to be executed (see below history and attached re-perforation interval). Question · Any issue associated with proceeding with the re-perforations in light of not being able to test any change in rate? I will follow up with a phone call in the morning. Thanks! Bob History Following a squeeze and rig workover, NS08 was perforated low in the reservoir section to maximize stand-off from gas. Rates from the well have been extremely low and the proposed re-perforations are an attempt to increase the rate. «NS08 Post RWO Ivishak Re-perf Log ApriI2006.ZIP» Robert Younger 2 of3 5/18/2006 1 :43 PM RE: Northstar: NS08 Testing Status J e e BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) vounç¡er2(,á¿bp.com 30f3 5/18/20061:43 PM [Fwd: Re: Northstar: NS08 Testing Status] e e , Subject: [Fwd: Re: Northstar: NS08 Testing Status] From: Jane Williamson <jane_williamson@admin.state.ak.us> Date: Weq, 17 May 2006 15:40:24 -0800 To: Jody J Colombie <jody_colombie@admin.state.ak.us> Q., 0 :).,- 0 d-- ¡ Could you make sure this gets in the well files for NS-08? -------- Original Message -------- Subject: Re: Northstar: NS08 Testing Status Date: Wed, 17 May 2006 13:34:59 -0800 From: Jane Williamson <jane williamson@admin.state.ak.us> Organization: State of Alaska To: Younger, Robert 0 <Robert.Younger@bp.com> CC: wi]1ton aubert@admin.state.ak.us, "Garing, John D" <John.Gar_inSL@bp.com>, Cathy P Foerster <cathy foerster@admin.state.ak.us> References: <C11D74A5F1DF194DB3A9ADF4DBC4EDE071CFCB@bplancex005.bp1.ad.bp.com> Bob, *You have AOGCC approval to produce NS08 without well test for up to 90 days.** *Please let us know if it appears you will not be able to get a test within this time frame. * *The following is our understanding of the situation. BP squeezed upper perforations earlier in the year in NS08 and perforated a lower sand in an attempt to decrease GOR. Only one test was available after this procedure and production rate was quite low (although GOR remained unchanged.) We approved reperforation of the same zone early this month. Pool rules for Northstar require a well test every month and if you proceed with production immediately after the reperf, you won't be able to meet the testing requirement. I understand that BP uses an IPR technique to allocate production between well tests using surface flowing pressure, and estimating GOR and water cut from earlier tests. Field allocation factors for 2005 were acceptable at 1.093. The well allocation can be revised if a future test indicates it would be necessary. MMS regulations require well tests every 2 months. Allocation is on a lease basis using a formula agreed by BP, DNR and MMS and doesn't rely on individual well allocation and there should be no issues with ownership/royalty. This is a State well so we are not sure if MMS must also approve. Regardless, you should give them a call and fill them in. Probably the best contact for this at a staff level would be Kyle Monkelien. He can be reached at 334-5307 or kyle.monkelien@mms.gov. ** Thank you for keeping us informed. Jane Younger, Robert 0 wrote: '''-Ie /11 iM¡i\!t;,.~, '..:;iY,¿ ..'" ,,- '..JW\~ Jane, Winton requested that I touch base with you regarding the testing status of NS08. *Issue* * Due to a malfunctioning divert valve, NS08 cannot be diverted to the test separator. * The scheduled repair of the divert valve will be during the July TAPS shutdown. * Cannot test NS08 until the divert valve is repaired. * There is currently a re-perforation procedure waiting to be executed (see below history and attached re-perforation interval). 10f2 5/17/2006 4 :20 PM [Fwd: Re: Northstar: NS08 Testing Status] , e e -.:*Question* , * Any issue associated with proceeding with the re-perforations in light of not being able to test any change in rate? I will follow up with a phone call in the morning. Thanks! Bob *History* Following a squeeze and rig workover, NS08 was perforated low in the reservoir section to maximize stand-off from gas. Rates from the well have been extremely low and the proposed re-perforations are an attempt to increase the rate. «NS08 Post RWO Ivishak Re-perf Log April 2006.ZIP» *Robert Younger* BP Exploration, Alaska Northstar/Badami Production Engineer 907-564-5392 (Work) 907-677-2599 (Home) 907-830-4920 (Cell) younger2@bp.com Jane Williamson, PE <iane williamson(ci¿admin.state.ak.us> Reservoir Engineer Alaska Oil and Gas Conservation Commission 20f2 5/17/20064:20 PM e e FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 J. D J. --0 a-. I Re: Northstar Field, Northstar Oil Pool, NS08 Sundry Number: 306-164 <,' i . fio.'¡..i!i:.f\ ()t,;^~~D'Ø¡;¡;,,;' o V 2005 Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~ay of May, 2006 Encl. bp e e -t"·" ,(t". .......- ---::;;",.-- ~ ~. ·I"_\~ BP Exploration (Alaska) Inc, 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 05, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS08 Reperforate (Ivishak) BP Exploration Alaska, Inc. proposes to reperforoate NS08. Following a squeeze and rig workover, NS08 was perforated low in the reservoir section to / maximize stand-off from gas. Rates from the well have been extremely low and the proposed reperforations are an attempt to increase the rate. The procedure includes the following major steps: T Work Descri tion Slickline Drift to TD wI Dummy Gun Electric Line Re erforate 11886'-11912' MD ./ Comments Same interval shot 03128/06 Please let me know if there are any questions, comments, or concerns. Sincerely, ~ Rob Younger Production Engineer BPXA, ACT, Northstar ø .' . W~'RÈ}Jfs,t)-~'2j"- ,.& OIL AND ~:t;~g~s'i,':;A~ON COMMii: S'/$ /6 .. '<;¡~".. ~ Vt: 0 APPLICATION FOR SUNDRY APPROVAL ,,{) 20 AAC 25.280 1, Type of Request: Abandon Alter casing 0 Change approved program 0 2, Operator Name: BP Exploration (Alaska), Inc, 3, Address: P.O, Box 196612 Anchorage, AK 99519-6612 7, KB Elevation (ft): Suspend Repair well 0 Pull Tubing 0 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4, Current Well Class: Developm ent Stratigraphic 0 9, Well Name and Number: NS08 .,/ 56 KB 8, Property Designation: ADL-312799 11, Total Depth MD (ft): 12030 / Waiver Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0210 ,/ ø / Exploratory 0 Service 0 6, API Number: 50-029-23068-00-00 /' 10, Field/Pools(s): NORTH STAR Field / NORTHSTAR OIL Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 11266,74 Effective Depth MD (ft): Effective Depth TVD (ft): 11943 11180,57 Plugs (measured): None Junk (measured): None Collapse 2270 4760 5410 7500 Casing Surface Production Liner Liner Length Size TVD Burst 3284 13-3/8" 68# L -80 44 3328 44 3220 4930 9873 9-5/8" 47# L-80 46 991946 9247 6870 1720 7" 26# L-80 9741 11461 9084,01 10705 7240 737 4-1/2" 12,6# 13Cr80 11293 12030 10539,84 11267 8430 Perforation Depth MD (ft): 9628 - 9668 11886-11912 Perforation Depth TVD (ft): 8980.49 - 9017.16 11124,16 -11149.88 Tubing Size: 4-1/2" 12,6# / Packers and SSSV Type: 4-1/2" TRM-4E SCSSSV 4-1/2" Baker Packer 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Packer 4-1/2" Top Packer 12, Attachments: Descriptive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14, Estimated Date for Tubing Grade: 13Cr80 Tubing MD (ft): 40 - 11297 Packers and SSSV MD (ft): // 13. Well Class after proposed work: Exploratory 0 Development ø 15. Well Status after proposed work: Oil ø Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Commencing Operations: 16, Verbal Approval: Commission Representative: 5/19/2006 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. Printed Name Title 992 9554 11170 11249 11293 Service 0 Abandoned 0 WDSPL 0 Contact Prepared by Sharmaine Vestal 564-4424 Robert Younger Signature Phone 564-5392 COMMISSION USE ONLY Production Engineer Date 5/5/2006 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Other: Subsequent Form Required: lO - Approved by: Form 10-403 Revised 7/2005 Sundry Number: Location Clearance 0 RBDMS 8Ft MAYO 8 2DD6 APPROVED BY THE COMMISSION Date: S ,f /Þ6 Submit in Duplicate · - TREE WELLHEAD ACTUA TOR = ----..-"-...-" KS. ELEV = SF. KOP NS08 SA _ NOTES: ***4-112" CHROME TBG & LNR*** ASB-VGI5-1/8" 5 ABB-VGI13-5/8" MUL TIBOWL 5K ,.~--".._-----~-~-~_."- 56' 40.1' 15.9') 10500' S8 113-3/8" CSG, 68#, L-80 BTC, 10 = 12.415" H 3328' Minimum ID = 3.725" @ 11220' /2" NIPPLE I TOP OF 7" LNR PERFORA TION SUMMARY REF LOG: 4-1/2" 2-7/8" 2" 2-7/8" DATE 03/18/02 12/26/05 01/02/06 01/09/06 REV BY RMH/PJC ADPERFS e> 992' 4-1/2" TRM-4E SCSSSV w /4-1 /2" X PROFilE, -113-318" TAM PORT COLLAR I -14-1/2" HES X NIP, ID = 3.813" I -14-1/2" FIBER OPTIC TRANSDUCER, 10 = 3.958" -19-5/8" X 4-1/2" BKR PKR, 10 = 3.870" I 9581' 9689' NORTHSTAR WELL: NS08 PERMIT No "'2020210 API No 50-029-23068-00 SEC T N R BP Exploration (Alaska) . . Date: 03-15-2006 Transmittal Number:92763 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 ?. ();. '- () 7-.1 SW Name Date Contractor Loa Run TaD Depth Bottom Depth Log Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE NS14 01-07 -2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD NS24 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 111 30 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11 300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD ~\)¡ ..DÀ I Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 r7 tt.::.I!( I) tA OÎv vDÀ· f q-, ~ . . BPXA WELL DATA TRANSMITTAL Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug chromanski Ignacio Herrera Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date: 03-15-2006 Transmittal Number:92763 SW Name Date Contractor '2(f!:; - NS25 02-19-2004 SCH I CR~. NS08 "'P2-·t7l-( ~ .rJ;ß 2-56/E101 09-01-2004 SCH 1'( e e Date: 03-30-2005 Transmittal Number: #91588 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtoiohnsoih@bp.com 18364 ULTRA SONIC IMAGING TOOL; Iß UBING PATCH RECORED; /-ó, RST SIGMA BORAX CARBON . OXYGEN LOG; ¿t1 ~., /3D5"'I~ ¿j) --f' 3./'¡·D~ 01-29-2005 SCH 5600 1 4650 1 16980 17695 Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK99519-6612 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA ùlL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission Anchorage 1 b. Well Class: II Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 202-021 305-350 13. API Number 50- 029-23068-00-00 14. Well Name and Number: - r - 1a. Well Status: II Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPl 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. location of Well (Governmental Section): Surface: 1119' FSl, 642' FEl, SEC. 11, T13N, R13E, UM Top of Productive Horizon: 3917' FSl, 3081' FEl, SEC. 11, T13N, R11E, UM Total Depth: 3964' FSl, 3106' FEl, SEC. 11, T13N, R11E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 659834 y- 6030892 Zone- ASP4 TPI: x- 657334 y- 6033636 Zone- ASP4 Total Depth: x- 657308 y- 6033684 Zone- ASP4 -----------..--..------- - .. ----- --- 18. Directional Survey 0 Yes II No No. of Completions One Other 5. Date Comp., Susp., or Aband. 12/25/2005 6. Date Spudded 2/13/2002 7. Date T.D. Reached 03/06/2002 8. KB Elevation (ft): 56' 9. Plug Back Depth (MD+TVD) 11942 + 11180 10. Total Depth (MD+TVD) 12030 + 11267 11. Depth where SSSV set (Nipple) 992 MD 19. Water depth, if offshore 39' MSL 21. Logs Run: GIR , DIR , RES, PWD , DEN, NEU, USIT , CCL CASING, LINER AND CEMENTING RECORD SElTING DEPTH MD SElTING DEPTH TVD HOLE . J OP troTTOM I OP I:SOTTOM SIZE Surface 2011 Surface 201' 20" 44' 3328' 44' 3220' 16" 46' 9919' 46' 9247' 12-1/4" 97411 11461' 9084' 10705' 8-1/2H 11293' 12029' 10540' 11266' 6-1/8" 22. CASING SIZE 20" 13-3/8" 9-5/8" 7" 4-1/2" WT. PER FT. 169# 68# 47# 26# 12.6# GRADE X-56 l-80 l-80 L-80 13Cr 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Gun Diameter, 6 SPF 4-1/2" Gun Diameter, 5 SPF MD TVD MD TVD 11755' - 11895' 10995' - 11133' 9628' - 9668' 8980' - 9017' 11891' - 11910' 11129' - 11148' Rt::l.;t:IVt:U FEB 0 9 2006 NS08 15. Field / Pool(s): Northstar Unit Ft Ft 16. Property Designation: ADL 312799 17. Land Use Permit: 20. Thickness of Permafrost 1545' (Approx.) CEMENTING RECORD AMOUNT PUllED Driven 590 sx PF 'l', 470 sx Class 'G' 553 sx Econolite, 517 sx Class 'G' 273 sx Class 'G' . 105 sx Class 'G' 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, 13Cr80 11231' 9554', 11170' 4-1/2u, 12.6#, 13CrSO 11252' - 11297' 11249' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 290 Bbls of Diesel containing 1 % Nalco CR0408 stANNElJ FED 1 4 2005 26. Date First Production: Not On Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl GAs-McF W ATER-BBl PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ...... Oll-BBl Press. 24-HoUR RATE""" GAs-McF W ATER-BBl CHOKE SIZE GAS-OIL RATIO Oil GRAVITy-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbrµ!~j'{~ ~hiPS;. if none, state 'none". RBDMS 8ft FEB 1 4 1006 None I ,¿~ ".~~o~; . f Form 10.4~;'~~~~~~~2003 0 RIG I N ~UEO ON REVERSE SlOE (:; ~. 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List Intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk A 9671' 9026' None Top of Sag River Sand 11474' 10718' Top of Shublik 11572' 11664' 10814' Top Sadlerochit Sands 10905' Top of Northstar Zone 'C2' 11782' 11021' Top of Northstar Zone 'C1' 118281 110671 Top of Northstar Zone 'B' Top of Northstar Zone 'A2' 11873' 11111' 11912' 11150' Top of Northstar Zone 'A1' Top of Kavik Shale 11958' 11195' 11990' 11227' Top of Lisburne 12063' 11299' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram and a Pre Rig Summary. 31. I hereby certify that the for going is true an9 correct to the best of my knowledge. Signed _ Title Technical Assistant DateC~- 04-0& NS08 Well Number Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564·4750 Paul Hanson, 564-4195 202-021 305-350 Permit No. I 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state In item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only - , I Well: Field: API: Permit: NS08 Northstar Unit 50-029-23068-00-00 202-021 PRE-RIG WORK 10/24/05 PRESSURE TEST CEMENT PLUG PRIOR TO RWO PREP T/I/O = 500/500/50 PUMPED 0.3 BBLS DIESEL DOWN TUBING. PRESSURED UP TO 1000PSI. GOOD TEST. BLEED TUBING TO O. FWHP'S = 0/500/50 10/25/05 WELL SHUT IN UPON ARRIVAL. PERFS CEMENTED 8/23/05. DRIFT FOR CHEM CUT WITH 3.70" CENTRALIZER AND 1.75" SAMPLE BAILER. TAG HARD BOTTOM AT 11704' WLM. BAILER EMPTY. RD. PREP FOR E-LlNE CHEM CUT. 10/28/05 RIH WITH 2.125" TUBING PUNCH, TIED INTO JEWERL Y AND TAG BOTTOM. TO AT 11927' ELMO TOOLS HANGING UP IN PERF AREA. TOOLS STICKING AND PULLING HEAVY THROUGHOUT PERF AREA. PUNCH HOLES JUST ABOVE UPPER X-NIPPLE 11244'-11246' ELMD. RUN STRING SHOT FROM 11242' - 11254' ELMO. 10/29/05 CUT TUBING AT 11252' ELMD 4' BELOW UPPER X-NIPPLE USING SCHLUMBERGER 3.625" CHEMICAL CUTTER. 11/15/05 PUMPED 11 BBLS 45* DIESEL TO PRESSURE OA UP TO 2500 PSI, OAP BROKE BACK TO 2150. INCREASE RATE TO 4.5 BPM, OAP INCREASED TO 2300 PSI THEN BEGAN TO FALL STEADILY TO 1650 PSI. FINAL INJECTIVITY = 4.5 BPM @ 1650 PSI. BLED OAP TO 100 PSI ALL FLUID (APPROX 3 BBLS) FINAL WHP'S=SSV/21 0/1 00 -, , . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Page lof13 Start: 11/12/2005 Rig Release: 12125/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 11/18/2005 00:00 - 00:00 24.00 MOB P PRE 11/19/2005 00:00 - 00:00 24.00 MOB P PRE 11/20/2005 00:00 - 00:00 24.00 MOB P PRE 11/21/2005 00:00 - 00:00 24.00 MOB P PRE Description of Operations - Four crew members arrived on Island. Northstar orientation for new members. - Placed Tioga heater on Mac air heater to pre heat prior to start up. - Hook up gas & water lines from pipe rack to rig. - Fire up air compressor & turn on block heaters for rig engines. - Open up gas valve on pipe rack - no gas - close valve. Work with OPS to troubleshoot problem - frozen valve upstream of pipe rack valve. OPS thawed out valve. - Open up gas valve on pipe rack - leaking regulator on rig - close valve. Repair regulator. * G & lOPS - Reviewed operational procedures, UO TIO requiremnts, & BP expectations for working on Island. - Maintenance work on hi-vac system. - Loaded grinding balls in conical mill. - Removed storage braces from vibrating ball mill. - Remove covers on all exhaust stacks. - Start up Mac air heater. - Assemble boilers. - Place heaters on rig water tank & water pump. - Chip ice in walkways on rig. - Tidy up work areas & put supplies received in proper storage area. *G& I - Reviewed procedures wI all crew members. - Assisted rig crew. - Button up boiler # 2. - Place heater on condensate tank & feed pumps. - Start up rig loader. - Charge batteries for 24V panel in motor room. - Isolate steam lines from service module to substructure. - R/U blow down hoses for blowing down water lines after filling boilers. - Hook up heat trace for water line. - Plug air gaps throughout rig. - Shovel snow on rig floor. * G & I - Reviewed procedures - Assisted rig crew - Additional Nabors labor to rig - orientation for new personnel. 10 Nabors hands working on rig which includes 1 Tool Pusher. - PJSM - Fill water tank, condensate tank, & start # 1 boiler & stage up. Boiler holding 115 psi. Start # 2 boiler & stage up - holding pressure. Turn on steam to service module and G & I. Installed traps & repair leaks. - Monitor boilers & clean up areas. * G & I Printed: 12/27/2005 8:35:40 AM .-, ~~ , . Page 2 of 13 Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 11/12/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2005 Rig Name: NABORS 33E Rig Number: 33E Description· of Operations 11/21/2005 00:00 - 00:00 24.00 MOB P PRE - Installed grating on pallet lift. - Installed shaker screens. - Removed hoses from vac system. - Monitor & repair leaks on steam system. 11/22/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks - Turn Steam To Sub Base And Install Steam Traps - Repair Leaks. Clean Up Melting Snow Area's Around Rig And Put Up Items Used During Job - Unwrap Equipment On The Rig Floor And Discard Wrapping Material - Thaw Out Rig Water Tank And Circulate Line - Maintain Watch On Boilers Verfiying That Automatic Systems Are Operating Correctly - 10 Nabors Employees Working On Rig Which Includes 1 Tool Pusher Hold PJSM For All Tasks Preformed By G& I Personal - Monitor And Repair Leaks On Steam System - Removed Hoses From Vacuum System - Inspect Bowls And Impellers On Slurry Pumps NO.1 & 2 - Inventoried Oil In Plant - 4 Employees Working On Grind And Injection Plant 11/23/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks - Clean Up Melting Snow Area's Around Rig - Replace Valve In Boiler Blow Down Line - Service PPE Cabinets Unpack Safety Harnesses And Store Same - Fill Up Eye Wash Stations - Set The Rest Of The 4 High Rig Mats Between The Well Row And Pipe Racks - Remove Draw Works Brake Bands For Replacement - Work On Rig Start Up To Do List - 11 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher Hold PJSM For All Tasks Preformed By G& I Personal - Continue To Rebuild The Vacuum System - Remove Snow From The Roof And Cleared Area For The Auger Shaft To Be Installed - 6 Employees Working On Grind And Injection Plant 11/24/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Start And Run All G-399 Prime Movers - Service Rig Loader - Organize And Inventory Rig Parts - Insulate Steam Lines As Needed - Clear Ice And Snow From Rig Stairs - Install Belts On Washing Machine - Cut Up 2 Pallets Of Plywood For Rig Move And Shiming Then Clean Up Welding Shop When Finished - Clean Out Sumps In Pump Room And Mop The Floor - Check Out Rig Move Drive Cabs For Power And Function Same - Power Up Koomey Unit And Check Bladders In Bottles - 12 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher Hold PJSM For All Tasks Preformed By G& I Personal - Change Air Filters On Hogh Vacuum - Work On Cleaning Grease Off Of The Triplex Injection Pump Parts - Start Maintenance And Inspection On The Bucket Elevator - Inspected And Test Ran The Rig Auger, Slop Tank Auger, Impactor Auger, Impactor, Hi-Vac, And The Platco Dump Valve - 6 Employees Working On Grind And Injection Plant 11/25/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Check Out Pulsation Dampners On Mud Pumps - Remove Brake Blocks From The Brake Bands That Were Previously Printed: 12/27/2005 8:35:40 AM -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Page 3 of 13 Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 11/25/2005 00:00 - 00:00 24.00 MOB P PRE 11/26/2005 00:00 - 00:00 24.00 MOB PRE P 11/27/2005 00:00 - 00:00 24.00 MOB PRE P Description· of Operations Removed From The Draw Works - Cut More Plywood Shim Stock For Placing Under Rig - Service Shale Shakers And Pit Agitiators - Replace Shock Absorber On Pipe Skate - Check Condition Of The BOP Bridge Crane Cables - 12 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher Hold PJSM For All Tasks Preformed By G& I Personal - Training New Personal - Finished Cleaning Injection Pump Expendables - Put Injection Pump NO.1 And NO.2 Back Together - Began Removing Suction Charge Dampner Off NO.2 Injection Pump For Inspection - Set Up Fan To Blow Warm Air Into Injection Pit NO.2 To Allow For Agitiator Oil To Be Changed - 6 Employees Working On Grind And Injection Plant Hold PJSM For All Tasks Preformed By Nabors Personal - Clean Up BOP Bolts And Nuts - Service Air Slips And Super Choke - Check Out The Rig Floor Tuggers And Man Riders - Cut" More Plywood Shim Stock For Rig Move - Disconnect The Flow Line, Mud Mix Line In The Putz - Inventory Oil - Clean Snow And Ice From Around Rig At Ground Level, Move Equipment And Items Stored Around And Near Rig - Check Out Casing Hydraulic Hoses And Air Lines - Service And Function Floor Safety Valves - 12 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher. Hold PJSM For All Tasks Preformed By G& I Personal - Chip Snow And Ice Away From Walkways - Firewatch For GBR Welder Working On Vacuum Lines - Remove Vacuum Line Going To Substructure And The Drag Chain Chute In Preparation For Rig Move - Finished Servicing Suction Dampners On Injection Pumps NO.1 And NO.2 - Checked Endgrat Bolts On VBM - Checked NO.1 And NO.2 Charge And Process Pumps - Checked Wear Plate Bolts On Conical Mill - Cleaned And Serviced Filter Pots - Training New Personal - 6 Employees Working On Grind And Injection Plant Hold PJSM For All Tasks Preformed By Nabors Personal - Disconnect Mud Line In Putz - Replace Cover On Outside Gas Regulator - Replace Boiler Feed Pump Coupling - Place Second Brake Band On Draw Works (Waiting On Parts To Complete Job) - Install Brushes In Traction Motors - Sort And Store Parts - Clean And Vac Out SCR Bays - Install Spinner Assembly On The Iron Ruffneck - Fill The Rig Water Tank- Clean Snow And Ice From Around Rig At Ground Level, Move Equipment And Items Stored Around And Near Rig - 13 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher. Hold PJSM For All Tasks Preformed By G& I Personal - Chip Snow And Ice Away From Walkways - Firewatch For GBR Welder Working On Vacuum Lines - Started VBM Lube Skid And Monitored Oil Lines And Hoses - Secured Injection Line For Upcoming Rig Move - Repaired Belt Guard For VBM - Printed: 12/27/2005 8:35:40 AM .,..--, Page 4 of 13 Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 11/12/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2005 Rig Name: NABORS 33E Rig Number: 33E Phase Description of Operations 11/27/2005 00:00 - 00:00 24.00 MOB P PRE Hook Up Drum Products Line And Fresh Water Line To Rig - Changed Gear Box Oil On Bucket Elevator - Serviced High Pressure Line Ball Valves And Bleed Off Valves On Injection Line - Training New Personal - 6 Employees Working On Grind And Injection Plant Including 1 GBR Welder 11/28/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Bring Scaffolding To Rig Floor And Help ASRC Erect Same - Scaffolding To Access Top Drive For Replacment Of Pressure Switiches (Oil & Temperature) Install Brushes In Top Drive - Test Blowers On Mud Pumps And Draw Works - Repair Lighting Circuit In Pipe Shed - Install Rotary Drive Chain - Majority Of Crews Attended The Rig Pass Provided By Nabors Management On The Beach - 13 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher. Hold PJSM For All Tasks Preformed By G& I Personal - Chip Snow And Ice Away From Walkways - Firewatch For GBR Welder Working On Vacuum Lines - Replaced Burnt Out Flourescent Lamps - Replaced Protective Covers On VBM Flexiable Oil Lines - Inspected Utility And Vac Hoses For Integrity - Install Sound Panels On VBM - Filled Eye Wash Stations - Inventoried Parts And Stored - Training New Personal - 6 Quadco Employees Working On Grind And Injection Plant With 1 GBR Welder. 11/29/2005 00:00 - 00:00 24.00 MOB P PRE Majority Of Nabors Employees Attended Rig Pass On The Beach - Hold PJSM For All Tasks Preformed By Nabors Personal - Dress Out The Oilwell PT-1700 Mud Pumps With Liners, Valves, Seats And Change Oil In Gear End - Complete Electrical Work On Top Drive - 15 Nabors Employees Working On Rig Which Includes 1 Tool Pusher And 1 Tour Pusher. Hold PJSM For All Tasks Preformed By G& I Personal - Chip Snow And Ice Away From Walkways - Firewatch For GBR Welder Working On 6" And 4" Vacuum Lines - Install The New Vacuum Sweeps - Replaced Cracked 6" Camlock Fitting On The Rig Sub Base Vacuum Line - Training New Personal - 6 Quadco Employees Working On Grind And Injection Plant With 1 GBR Welder. 11/30/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Function Moving And Hydraulics System - Continue To Dress Mud Pumps - Prepare Rig To Move Down Island To Gain Access To Cellar For Building BOP - Move Rig 19 Feet Down Pad - Build BOP And Related Equipment - Clear Snow From Mats In Rig Move Path Hold PJSM For All Tasks Preformed By G& I Personal - Checked Oil In All Augers And VBM - Up Date Maintenance Records And Complete Monthly HSE Plant Walk Thru - Replace Failed Lights Through Out Plant - Training New Personal 12/1/2005 00:00 - 00:00 24.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Function Moving And Hydraulics System - Continue To Dress Mud Pumps - Prepare Rig To Move Down Island To Gain Printed: 12/27/2005 8:35:40 AM ..-, Page 50t13 Legal Well Name: NS08 Common WelJ Name: NS08 Spud Date: 2/13/2002 Event Name: WORKOVER Start: 11/12/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/25/2005 Rig Name: NABORS 33E Rig Number: 33E Description of Operations 12/1/2005 00:00 - 00:00 24.00 MOB P PRE Access To Cellar For Building BOP - Move Rig 19 Feet Down Pad - Build BOP And Related Equipment - Clear Snow From Mats In Rig Move Path Hold PJSM For All Tasks Preformed By G& I Personal - Checked Oil In All Augers And VBM - Up Date Maintenance Records And Complete Monthly HSE Plant Walk Thru - Replace Failed Lights Through Out Plant - Training New Personal 12/2/2005 00:00 - 12:00 12.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Continue To Build 135/8" 5M BOP And Related Equipment And Secure In Rack - Place Shims Under Support Complex - Prepare Rig To Move Down Island Well Row. Inspect Fire Extenguishers In G&I Plant - Pick Up And Clean Plant- Serviced Mixers In No.2 Injection Tank 12:00 - 21 :00 9.00 MOB P PRE Place Shims Under Support Complex And Substructure - Rig On G399 Power At 18:00 Hours 21 :00 - 00:00 3.00 MOB P PRE Organize And Clean Up Rig, Pad, And Cellar Area's - Work On Mud Pumps While Waiting For Schlumberger E-Line Unit To Complete Perforation Job On NS-18 (Schlumberger Operation Was Shut Down After Guns Removed From Well Due To The BP 16 Hour Rule) 12/3/2005 00:00 - 16:00 16.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Work On Rig Equipment While Waiting On Schlumberger Equipment To Be Moved - Install Epoch PVT System - Modify Iron Ruffneck Controls - Dress Oilwell Mud Pumps - Weld In PitsAnd Install Hatches On "L" Pits Hold PJSM For All Tasks Preformed By G&I Personal - Rebuild Valves - Work On Barrel De-Header - Finish Installing Mixer In Process Tank NO.1- Service Mixers In Process Tank No.2 - Service Air Tugger - Greased Motors - Up Date Maintenance Log. 16:00 - 00:00 8.00 MOB P PRE Hold PJSM And Obtain Unit Work Permit - Coordinate With Production And Start Rig Move Out Of Hole On The North End Of Island To NS-08 12/4/2005 00:00 - 12:00 12.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Continue With Rig Move To NS-08 Lost Gas Pressure To G-399 Prime Movers Due To Production Issues - Run Cold Start For +/- 3 Hours Hold PJSM For All Tasks Preformed By G&I Personal - General Maintenance And Repair During Rig Move 12:00 - 16:00 4.00 MOB P PRE Wait While AIC Levels Pad For Move 16:00 - 00:00 8.00 MOB P PRE Spread Out HercuJite - Lay Matting Boards And Continue With Rig Move To NS-08 12/5/2005 00:00 - 12:00 12.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Continue With Rig Move Down Well Row And Spot Rig Over NS-08 - Berm Rig And Hook Up Utilities To Pipe Rack - Finish Installing Brake Bands - Hook Up Lines In Putz - Hook Up Communications To Office. Hold PJSM For All Tasks Preformed By G&I Personal - Install Printed: 12/27/2005 8:35:40 AM Page 6 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 Description of Operations 12/5/2005 00:00 - 12:00 12.00 MOB P PRE Vac System To Rig - Re-Install Guard On VBM Motor Enclosure - Mount Martin Decker PVT Components - Install Drag Chain Extension Hose - Vacuum Out Process Pit NO.1 - Change Oil Vac And Train New Employee 12:00 - 00:00 12.00 MOB P PRE Hold PJSM For All Tasks Preformed By Nabors Personal - Rig On Hi-Line Power At 16:30 Hours - InstallS 1/2" Liners In Mud Pumps - Seal Cellar Door Area's - Weld Anodes In Pits - Install Hatches On L-Pits - Thaw Out Water Line On Pipe Header- Clean BOP Ram Blocks - Repair Valves In Pits - Service Top Drive And Traveling Blocks 12/6/2005 00:00 - 12:00 12.00 MOB P PRE - Sevice top drive, swivel, & blocks. Function test top drive. - Install shaker screens. - Dress mud pumps. - Prepare pipeshed to UD tubing. - Service squeeze manifold in cellar. - Secure lines in derrick & perform full visual inspection of derrick. 12:00 - 00:00 12.00 MOB P PRE - Remove outside fresh water line for heat trace. Remove insulation & prepare for heat trace. - cia leaking steam heater. - Attempt to fill L pits wi sea water. Sea water line frozen. Hook up jumper line & fill L pits. 12/7/2005 00:00 - 12:00 12.00 MOB P PRE Conduct PJSM, plan task, discuss hazards & risks. Fill pits wi sea water, circ through mix pumps & piits. Flush pits & transfer sea water to G&I. Clean L pits and mud pits in preparation to mix salt batches. Remove collars & unnecessary equipment fl pipe shed. Function check casing Hyd unit. (ok) Take on sea water, mixing brine in pits @ G & I. 12:00 - 00:00 12.00 MOB P PRE Continue mixing brine in pits. Complete zonal derick inspections Areas #1,2,3,4. Ensure clear mud lines from pumps through top drive wi air. Install safety cables on top drive. Mud System - work on sea water outside line. Pressure test both mud pumps, mud lines & manifold to 4500 psi. Install mud cleaner cones, clean rust & debris from pits. Install secondary valve on wellhead "IA". 12/8/2005 00:00 - 05:00 5.00 RIGU P PRE Conduct PJSM, plan task, discuss hazards & risk Function test hole fill pump, finish cleaning mud pits Work on rig condition I environmental audit punch list Service drawworks, roughneck and tongs 05:00 - 12:00 7.00 RIGU P PRE Mix brine in pits (1075 bbls total @ 9.9 ppg) RU choke I kill lines & squeeze manifold Finish repairing steam heater in pits General housekeeping & maintenance 12:00 - 14:00 2.00 RIGU P PRE PU & clean cellar area, organize & clean rig floor area Rig accepted at 14:00 hrs. 14:00 - 15:30 1.50 RIGU P DECaMP RU valves & hoses to squeeze manifold 15:30 - 16:00 0.50 KILL P DECaMP PJSM, Pressure test trip tank return line to G&I Leaks in line 16:00 - 16:30 0.50 KILL P DECaMP Pressure test squeeze manifold & lines to 1500 psi 16:30 - 18:00 1.50 KILL N RREP DECOMP Repair leaks in trip tank return line, retest line (OK) Printed: 12/27/2005 8:35:40 AM -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 7 of 13 NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12125/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 12/8/2005 18:00 - 19:30 19:30 - 22:00 22:00 - 00:00 12/9/2005 00:00 - 01 :30 01 :30 - 02:30 02:30 - 06:30 06:30 - 12:00 12:00 - 13:00 13:00 - 16:30 16:30 - 18:30 18:30 - 20:30 20:30 - 00:00 12/10/2005 00:00 - 11 :00 11 :00 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 00:00 12/11/2005 00:00 - 07:00 07:00 - 12:00 1.50 KILL 2.50 KILL 2.00 KILL 1.50 KILL 1.00 KILL 4.00 KILL 5.50 KILL 1.00 KILL 3.50 DHB P 2.00 WHSUR P 2.00 WHSUR P 3.50 BOPSUP P 11.00 BOPSUR P 4.00 BOPSUP P 1.50 BOPSUPP 0.50 BOPSURP 7.00 BOPSUP N 7.00 BOPSUFN 5.00 BOPSUP N Description of Operations P N DECOMP Drain trip tank, fill gas buster, bleed IA from 20 psi to 0 psi SFAL DECOMP Operations repaired and tested injection line valve at header on pipe rack. DECOMP PJSM, Circulate diesel out of lA, Pump 45 bbls before returns Pump rate 1.3 bpm @ 0 psi tubing pressure DECOMP Circulate out freeze protection diesel from IA. Recovered 160 Bbls diesel from IA. DECOMP Circulate out freeze protection diesel from tubing. Recovered 90 Bbls diesel from tubing. DECOMP Mix 300 Bbls 9.9# brine. Clean pits of contaminated brine. DECOMP Circulate surface to surface x 2. Pump Pressure 870# @ 6 BPM. 9.9 PPG brine confirmed in & out. DECOMP Shut down pumps & monitor well. P P P P P P DECOMP Bleed off pressure, Install BPV. T est from below to 500 psi. Chart & hold test for 30 minutes. DECOMP Bleed down lines. ND tree and put on stand in cellar. DECOMP Operations Shut-in NS-07 & NS-09. Disconnect fiber optics cable from wellhead. Disconnected & plugged control lines. DECOMP NU BOPE, Install drilling spool, Set BOP stack on wellhead. Torque BOP bolts. Operations returned NS-07 & NS-09 to production. DECOMP - N/U BOPE, hook up new koomey lines, install 4 1/2" x 7" variable rams in upper & lower gates & blind rams in middle gate. Install choke & kill lines. DECOMP - Clean debris from under rotary table & off riser. - Install & adjust turnbuckles on stack & install riser. DECOMP - Function test & cycle rams & work air out of accumulator lines. DECOMP - Island muster drill including loading of ARKTOS. Rig personnel mustered on rig w/o evacuation. Discuss & critique drill. SFAL DECOMP - Fill stack with sea water & check for leaks. - Test BOPE per BP & AOGCC Regs. Test witnessed by AOGCC Rep Jeff Jones, Nabors Tool Pusher Robert Kennedy, & WSL Richard Watkins. * Tightened nuts between cross & double gate due to leak, tightened choke hose unibolt, & adjusted relief valve on test pump. SFAL DECOMP -Test BOPE, 250/5000 psi, Witnessed by Jeff Jones (AOGCC), WSLs - Mike Dinger, Richard Watkins & Tool Pushers - Chris Page, Robert Kennedy -Unable to obtain 5000 psi test on double gate pipe rams or choke line valves - Inspect & grease manual valves, HRC & Choke line valves -Unable to obtain 5000 psi test on double gate pipe rams or choke line valves SFAL DECOMP - Began to isolate source of leak, Remove kill line, Retest Printed: 12/27/2005 8:35:40 AM -- Page 8 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 Description of Operations 12/11/2005 07:00 - 12:00 5.00 BOPSUP N SFAL DECOMP double gate pipe rams, Test failed - Kill line valves did not leak -Change out two way check, close blinds, Repressure & Visually inspect BOPE, Inspect testing equipment -Unable to obtain successful test, Continue troubleshooting BOPE pressure losses - Inspect & replace test manifold valves & Test chart recorder, No success 12:00 - 16:30 4.50 BOPSUPP DECOMP -Test annular preventer on 4.5" test joint to 250/3500 psi - Test OK -Test accumulator - Test OK -Test double gate pipe rams (4.5x7.0) on 4.5" test joint - Test failed 16:30 - 21 :00 4.50 BOPSUPN SFAL DECOMP -Drained BOP Stack, Installed work platform on BOPs -Changed 4.5x7.0 pipe rams in double gate preventer with 3.5x6.0 pipe rams 21 :00 - 00:00 3.00 BOPSUP P DECOMP -Retest BOPE to 250 psi low/5000 psi high, annular preventer to 250/3500 psi wI 4.5" & 5.0" test joints -Test Partially Witnessed by AOGCC Rep. Jeff Jones -Complete test witnessed by Tool Pushers - Chris Page, Robert Kennedy & WSLs - Mike Dinger, Richard Watkins 12/12/2005 00:00 - 03:30 3.50 BOPSUF P DECOMP -Test BOPE per BP & AOGCC Regs -Test witnessed by Tool pushers Robert Kennedy, Chris Page & WSLs Mike Dinger, Richard Watkins -RD 4.5" test joint, RU 5.0" Test joint -Test pipe rams to 250/5000 psi on 5.0 test joint -Test annular preventer to 250/3500 psi on 5.0" test joint -Test upper and lower TD valves to 250/5000 psi 03:30 - 04:30 1.00 BOPSUPP DECOMP -RD BOP test equipment, Bleed test pump and test lines -PJSM to RU LD equipment & pull tubing 04:30 - 07:00 2.50 PULL P DECOMP -RU sheaves in derrick to pull fiber optic and control lines -RU tongs, bails & 5.5 YC elevators to pull 5.5" tubing -Clear rig floor of unnecessary equipment 07:00 - 08:00 1.00 PULL P DECOMP -Pull two way check, Monitor well bore - well static 08:00 - 09:00 1.00 PULL P DECOMP -PU landing joint, MU change overs, screw into tubing hanger -PJSM with rig personnel and contractors 09:00 - 10:30 1.50 PULL P DECOMP -MU TrrD & pull tubing hanger from wellhead w/330K, PU weight 225K -Pull tubing hanger above floor, Up weight 228K, monitor well, well static -Hookload weight w/ blocks & top drive equipment 72K 10:30 - 12:00 1.50 PULL P DECOMP -Close annular, circulate through choke and gas buster @ 6 BPM 150 psi. 12:00 - 14:30 2.50 PULL P DECOMP -Circulate surf/surf w/9.9 ppg brine, 8350 strokes & monitor well 14:30 - 17:00 2.50 PULL P DECOMP -Blow down lines, RU equipment to LD 5.5" tubing 17:00 - 18:00 1.00 PULL P DECOMP -Adjust drawworks brakes 18:00 - 00:00 6.00 PULL P DECOMP -PJSM, LD 68 joints of 5.5" 17# 13CR Vam -Ace tubing. 12/13/2005 00:00 - 15:30 15.50 PULL P DECOMP -Continue UD 5.5" 17# 13Cr-80 Vam Ace tubing and completion assy. Spooling fiteroptic cable. Splice damaged and parted cable @ jts. # 146, 163, 172, and 183. Proper fluid Printed: 12/27/2005 8:35:40 AM - Page 9 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 Description of Operations 12/13/2005 00:00 - 15:30 15.50 PULL P DECOMP volumes in hole during lay-down opns. 15:30 - 17:00 1.50 PULL P DECOMP Change out tbg handling tools to lay down 4.5" 12.6# V AM Ace tbg. 17:00 - 19:30 2.50 PULL P DECOMP LD 4.5" 12.6#, V AM Ace tbg. Total jts layed down: 235 jts 51/2" Vam Ace tubing,S 1/2" SSSV, GLM, 38 jts 41/2" Vam Ace tubing, Cidra mandrel, & X nipple. Cut was below X nipple pup jt. as planned. Cut pup jt recovered was 3.9' leaving 6.33' stub remaining in well. 19:30 - 20:30 1.00 PULL P DECOMP RD tbg handling tools. Change out bales. Prep to pick up 5" dp. 20:30 - 21 :00 0.50 PULL P DECOMP Clean and clear rig floor. Remove faulty fall arrest unit from derrick board. 21 :00 - 00:00 3.00 PULL P DECOMP Remove tubing and 4" dp from pipe shed in prep. to run 5" dp. 12/14/2005 00:00 - 07:00 7.00 CASE P DECOMP - C/O elevators, clean floor, hang fall arrest in derrick, repair leak on TD, & install bowl protector while removing 4" DP from pipe shed in preparation for picking up 5" DP. 07:00 - 07:30 0.50 CASE P DECOMP PSJM to PU Clean-out BHA and 5" DP. MU mill, csg scraper, &XO. 07:30 - 17:30 10.00 CASE P DECOMP Pick up 5" 19.5 #, S-135 DP and RIH. 17:30 - 19:30 2.00 CASE P DECOMP Work DP in pipe shed. Strap and tally. 19:30 - 00:00 4.50 CASE P DECOMP Cont. picking up 5" DP and RIH. Picked up 308 jts. Tagged 7" liner top at 9749' (20' in with 309th jt) 12/15/2005 00:00 - 00:30 0.50 CASE P DECOMP Rig up to reverse circulate. Fill kill line and close annular BOP. 00:30 - 04:00 3.50 CASE P DECOMP Pick up to 9729'. Reverse Circ. 20 bbl. high visco sweep at 4.25 bpm at 412 psi. Full returns throughout eirc. 04:00 - 04:30 0.50 CASE P DECOMP RD circ. equip. Blow down lines. Monitor well, OK. PU single and tag 7" liner top @ 9749'. Pick up one foot. 04:30 - 06:00 1.50 CASE P DECOMP Pump and spot 20 bbl high visco perf pill from 9748' to +/- 9350'. Pump at 7 bpm at 325 psi. Monitor well, OK. Blow down top drive. 06:00 - 14:30 8.50 CASE P DECOMP POH with 5" DP. SLM on trip out. No depth correction. LD BHA. 14:30 - 16:00 1.50 PERFOB P OTHCMP ND drilling nipple. 16:00 - 00:00 8.00 PERFOB P OTHCMP NU shooting flange, E-line riser, and wireline BOP. RU Schlumberger to perforate. 12/16/2005 00:00 - 06:00 6.00 PERFOB P OTHCMP RU Schlumberger perforating tools. Loading pipe shed with 4 1/2" Vam Top tbg. Service TD. Schlumberger re-headed to remove wireline nick. Had to rehead again due to short. Pro Tst. shooting lubricator to 500 psi. MU guns for first perf run. 06:00 - 11 :00 5.00 PERFOB P OTHCMP RIH with 41/2" PURE Gun PowerJet Omega 4505 HMX perf guns @ 5JSPF. Run GR/CCL from 9900' to 9500' for formation correlation and tie-in. Perforate from 9628' to 9648'. Good indication of guns firing. Monitor well, no gain or loss. POH. No indication of overpull. All shots fired. LD gun. (Logged liner top at 9755' WLM; DP measurement at 9749') 11 :00 - 15:00 4.00 PER FOB N DFAL OTHCMP PU second gun assembly and RIH. Tie-in for depth control and perforate from 9648' to 9668', 1/2 bblloss after shooting. POH. Gun would not come through shooting flange on top of Hydril. Had to pull 2800# to pull gun through shooting flange into lubricator. 15:00 - 16:00 1.00 PERFOB N DFAL OTHCMP LD guns. Partial miss-fire. Only top 3' of guns fired. Hollow carrier split and part of the carrier internal strip protruded from Printed: 12/27/2005 8:35:40 AM -. . .. Page 10 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 Phase Description of Operations 12/16/2005 15:00 - 16:00 1.00 PERFOB N DFAL OTHCMP split causing the hang-up while pulling gun. 16:00 - 20:00 4.00 PERFOB N DFAL OTHCMP NPT. Wait on Schlumberger to load replacement perf guns and transport to rig. Circ. across top of hole and monitor, OK. Finish loading tubing in pipe shed. 20:00 - 00:00 4.00 PER FOB P OTHCMP PU re-run gun assembly and RIH. Tie-in for depth control and perforate from 9648' to 9668'. Good indication of guns firing. POH with no indication of overpull. 2 bbl fluid loss after gun run. 12/17/2005 00:00 - 01 :00 1.00 PERFOB P OTHCMP POH with perf guns 01 :00 - 01 :30 0.50 PERFOB P OTHCMP PJSM. LD spent perf guns. All shots fired. 01 :30 - 02:00 0.50 PERFOB P OTHCMP PU 5.994" gage ring/junk basket and GR/CCL. 02:00 - 03:00 1.00 PERFOB P OTHCMP RIH to top of 4 1/2" tubing stub at 11,253' WLM. Run GR/CCL from top of stub up to 9500', correlating to fm and liner top at 9755' WLM (9749' SLM). Hole taking about 1 BPH but appears to be diminishing. 03:00 - 04:30 1.50 PERFOB P OTHCMP POH w/ Eline. Check junk basketnclean, no debris. 04:30 - 06:30 2.00 PERFOB P OTHCMP RD SWLS. 06:30 - 08:30 2.00 PERFOB P OTHCMP Clear rig floor. 08:30 - 09:00 0.50 PERFOB P OTHCMP PJSM to ND shooting flange and NU drilling riser. 09:00 - 10:00 1.00 PERFOB P OTHCMP ND shooting flange. 10:00 - 14:30 4.50 RUNCO~ RUNCMP NU drilling riser. 14:30 - 16:00 1.50 RUNCOf RUNCMP Jack and shim rig for better center over hole. 16:00 - 17:00 1.00 RUNCO RUNCMP Pull wear ring and make dummy run with tubing hanger. 17:00 - 18:30 1.50 RUNCOrvP RUNCMP Check RKB measurements. Change bales and elevators. RU power tongs. 18:30 - 22:30 4.00 RUNCOtvP RUNCMP RU running equipment for running CiDRA cable. Compl. RU to run tubing. 22:30 - 00:00 1.50 RUNCOtvP RUNCMP Running 41/2" 12.6 #/ft, Vam Top tubing and completion equipment. 12/18/2005 00:00 - 15:30 15.50 RUNCOM\J RREP RUNCMP Rig repair. Top drive struck end of stabbing board while running tubing. Bent adjustable floor portion. Remove adjustable floor for inspection and repair. Visually inspect all welds, attachment points, and winch systemnOK. Replace winch cable. Remove and inspect all rollers and bolts--OK. Installed adjustment stops to prevent over-extending floor section. Re-install stabbing board. Work on elec. winch controls for stabbing board. 15:30 - 16:30 1.00 RUNCOM\J SFAL RUNCMP Repair and adjust torque controls on tubing tongs. 16:30 - 18:00 1.50 RUNCO! RUNCMP Run 41/2",12.6 #, Vam Top completion string from 140' to 520' (10 jts) 18:00 - 18:30 0.50 RUNCO RREP RUNCMP Work on electrical controls for stabbing board. 18:30 - 00:00 5.50 RUNCOtvP RUNCMP Run 4 1/2", 12.6 #, Vam Top completion string from 520' to 1646' (26 jts). Ran 60' blast rings on joints # 35 & 36. 12/19/2005 00:00 - 00:30 0.50 RUNCOrvP RUNCMP Run 41/2" 12.6 #, Vam Top compl string. PJSM. Run remaining downhole jewelry, blast rings, and Baker 9 5/8" pkr. PJSM. Run CiDRA mandrel. Hook up fiber optic sensors and lines. All tubing torqued to Vam specs. with computer record of each connection. 00:30 - 02:00 1.50 RUNCOrvP RUNCMP PJSM. Run CiDRA mandrel. Hook up fiber optic sensors and lines. Pr Tst. to 500 psi for 5 min then to 7500 psi for 15 min. --OK. 02:00 - 03:00 1.00 RUNCOtvP RUNCMP Run tbg to 1910' installing Cannon clamps every collar. Pr. Tst. D-16 plug in X nipple 88' above 9 5/8" pkr to 4200 psi for 5 Printed: 12/27/2005 8:35:40 AM .-, ~. f. Page 11·of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 Description of Operations 12/19/2005 02:00 - 03:00 1.00 RUNCOrvP RUNCMP min.--OK. 03:00 - 12:00 9.00 RUNCOrvP RUNCMP Run 41/2" tubing with Cannon clamps every collar. Run to 4003'. 12:00 - 13:30 1.50 RUNCOM\l RREP RUNCMP Rig Repair. Repair leaking standpipe manifold and replace leaking Lo-torq valve. 13:30 - 17:00 3.50 RUNCOrvP RUNCMP RU to Pr. Tst. tbg. Press. up to 4200 psi. Slowly bleeding off. Repressure 3 times wI no improvement. Reverse CÎrc. 4 bbl to wash possible debris from D16 ball. Retest but bled off. Reverse circ. 10 bbls at 3 BPM and 130 psi. Retest to 4200 psi for 15 minutes--OK. Blow down lines. 17:00 - 23:30 6.50 RUNCOrvP RUNCMP Run 4 1/2" tubing to 6103'. PU 11 OK#; SO 11 OK# 23:30 - 00:00 0.50 RUNCOrvP RUNCMP RU and Pr. Tst. tubing to 4200 psi. Slowly leaking off. RU to reverse circ. 12/20/2005 00:00 - 00:30 0.50 RUNCOrvP RUNCMP Pr. tst. tubing. Pr. to 4200 psi with slow bleed off. 00:30 - 01 :00 0.50 RUNCOrvP RUNCMP Rev. circ. at 3 BPM and 130 psi to clear D16 plug seat. 01 :00 - 03:00 2.00 RUNCOfvP RUNCMP Pr. tst. tbg to 4200 psi. Made 3 attempts before D16 plug seated and test OK. Held for 15 minutes. 03:00 - 04:00 1.00 RUNCOrvP I RUNCMP RD test headpin and blow down lines. 04:00 - 08:00 4.00 RUNCOrvP RUNCMP Run 41/2" Yam Top completion tubing to 8224'. 08:00 - 09:00 1.00 RUNCOrvP RUNCMP Rev. circ. 10 bbls at 3 BPM and 110 psi. 09:00 - 10:30 1.50 RUNCOfvP RUNCMP Pr. tst. tbg to 4200 psi for 15 min.--OK. Blow down lines. 10:30 - 16:00 5.50 RUNCOrvP RUNCMP Run 41/2" Yam Top completion tubing to 10,249'. 16:00 - 17:30 1.50 RUNCOfvP RUNCMP PU SSSV mandrel and control line equipment. Test to 6000 psi for 15 min.--OK. 17:30 - 18:30 1.00 RUNCOrvP RUNCMP Pr. tst tbg. to 4200 psi for 15 min.--OK. PU wt == 188K & SO wt. == 160K. 18:30 - 21 :00 2.50 RUNCOrvP RUNCMP Run total of 260 jts of 41/2" Yam Top completion tubing to 11,201'. PU == 190K & SO == 172K. 21 :00 - 22:30 1.50 RUNCOfvP RUNCMP Pick up additional pipe to tag 4 1/2" tubing stub and check space out. Tag at 11,241'. No clear indication of overshot shear. 22:30 - 00:00 1.50 RUNCOrvP RUNCMP Work pipe and attempt to work down over stub. Attempt to rev. circ on bottom to wash out behind stub. Could not circ. PU off of stub and could rev. circ. Used total of 226 Canon clamps and 2 stainless bands. 12/21/2005 00:00 - 01 :00 1.00 RUNCOrvP RUNCMP Clear rig floor. Blow down lines. PJSM. 01 :00 - 03:00 2.00 RUNCOfvP RUNCMP RU SWS slick line and lubricator. 03:00 - 04:30 1.50 RUNCOr-.1N HMAN RUNCMP Locating lubricator cross-over on the island. Service and clean rig. 04:30 - 05:30 1.00 RUNCOrvP RUNCMP RU SWS slick line and lubricator. 05:30 - 09:00 3.50 RUNCOrvP RUNCMP RIH wI wireline pulling tools to X nipple at 9468'. Latch onto D16 plug. Tight. Sheared off. POH. Did not retrieve plug. 09:00 - 11 :30 2.50 RUNCOrvP RUNCMP RIH wI wireline equalizing prong. Push plug to sliding sleeve at 9587'. POH. 11 :30 - 14:30 3.00 RUNCOtvP RUNCMP RIH wI wireline pulling tools. Latch into D16 plug and pull same. OK. 14:30 - 16:00 1.50 RUNCOfvP RUNCMP RU to run GR/CCL memory log. 16:00 - 19:30 3.50 RUNCOM\l SFAL RUNCMP Run GR/CCL memory log from 11,243' to 9500'. 19:30 - 21 :30 2.00 RUNCOM\l SFAL RUNCMP Download memory log data. Experienced depth control problems and did not log all of intended interval. Logged from 11,730' (inside 7" below tubing stub). 21 :30 - 00:00 2.50 RUNCOtvP RUNCMP RIH with GR/CCL memory log. Rerun log from 11,349'. 12/22/2005 00:00 - 02:30 2.50 RUNCOrvP RUNCMP Rerun GR/CCL memory log from 11720' to 8900'. Continued Printed: 12/27/2005 8:35:40 AM < '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Page 12 of 13 Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 12/22/2005 00:00 - 02:30 2.50 RUNCOfvP RUNCMP 02:30 - 03:00 0.50 RUNCOfvP RUNCMP 03:00 - 04:00 1.00 RUNCOfvP RUNCMP 04:00 - 08:00 4.00 RUNCOfvP RUNCMP 08:00 - 09:00 1.00 RUNCOfvP RUNCMP 09:00 - 10:00 1.00 RUNCOfvP RUNCMP 10:00 - 12:00 2.00 RUNCOfvP RUNCMP 12:00 - 14:30 2.50 RUNCOfvP RUNCMP 14:30 - 15:30 1.00 RUNCOfvP RUNCMP 15:30 - 17:30 2.00 RUNCOfvP RUNCMP 17:30 - 19:00 1.50 RUNCOfvP RUNCMP 19:00 - 22:00 3.00 RUNCOfvP RUNCMP 22:00 - 00:00 2.00 RUNCOfvP RUNCMP 12/23/2005 00:00 - 02:30 2.50 RUNCOfvP RUNCMP 02:30 - 03:30 1.00 RUNCOfvP RUNCMP 03:30 - 05:00 1.50 RUNCOfvP RUNCMP 05:00 - 08:30 3.50 RUNCOfvP RUNCMP 08:30 - 14:00 5.50 RUNCO! RUNCMP 14:00 - 16:00 RUNCMP 2.00 RUNCOrw 16:00 - 17:30 1.50 RUNCOfvP RUNCMP 17:30 - 19:00 1.50 RUNCOfvP RUNCMP 19:00 - 20:00 1.00 RUNCOfvP RUNCMP 20:00 - 21 :00 1.00 RUNCOfvP RUNCMP 21 :00 - 23:00 2.00 RUNCOWN HMAN RUNCMP 23:00 - 00:00 1.00 RUNCOfvP RUNCMP 12/24/2005 00:00 - 06:00 6.00 BOPSUF P RUNCMP 06:00 - 07:00 1.00 BOPSUR P RUNCMP 07:00 - 07:30 0.50 BOPSUF. P RUNCMP 07:30 - 11 :00 3.50 BOPSUP P RUNCMP 11 :00 - 15:30 4.50 SIT N SFAL RUNCMP Description of Operations to have depth control problems therefore logged sufficient interval to assure coverage on all areas of interest. Evaluate logs. Proper spaceout indicated. RD SWS slick line tools. RU to reverse circ. Rev. circ. Picked up l' above top of tbg stub. Establish circ at 3 BPM & 160 psi. Rev. circ BU. Work back over stub in l' increments, rev. circ. each time. Circ. press increased +/- 100 psi each time until reaching 500 psi at 1 BPM at 4' over stub. Rev. circ. PU to top of stub and rev. circ. BU. RD circ head and prep. to space out. Space out for landing com pI. string. RU SWS slick line. RIH with D16 plug and set in SSSV at 947'. Pro tst. tubing above SSSV to 4200 psi for 15 min. OK. RIH with slick line and pull D16 plug. RD wireline. Pull hanger to RT. Hook up SSSV line to hanger. Make fiber optic line hook up. Rerun hanger and land tubing. Check hanger seals to 2000 psi. OK. RU slick line and run final GR/CCL memory log from 11,400' to 9400'. Complete GR/CCL memory logging. All spacing proper. LD logging tools. PU RHC plug seat and running tool. RIH w/RHC. Trash in tubing. Tools stopped at 5165'. Pulled tight. Free up and POH. RIH with 3.25" gage ring and brush on slick line through XN nipple at 11,220'. POH. PU and run RHC plug seat and set in XN nipple at 11,220'. POH and RD SWS slick line. Pick up tubing and hanger. Rev. circ. 295 bbls containing 25 gal/100 bbl EC1124A and 25 gal/100 bbl 01VD121 inhibitor chemical at 3 BPM and 220 psi. Displ. inhibited brine by reversing 255 bbls of 9.9 ppg neat brine at 3 BPM and 220 psi. clear rig floor while rev. circ. Re-Iand tubing hanger in wellhead. RD circ. lines. Run in ULDS and pr. tst hanger seals to 5000 psi for 10 min. OK. Drop rod and ball to set packers. Pro tbg to 4200 psi with annulus open. Set packers. Held pressure on tbg for 30 min. OK. Pr. IA to 1000 psi with tubing open. Held for 30 min. OK. Set BPV. Damaged Lding Jt. threads. Redress. Pull BPV. Run TWC. Pr. tst TWC to 500 psi. OK. RD lines. Prep. to ND BOPE. ND BOPE. Remove drilling nipple. Remove and secure Koomey lines. ND choke & kill lines. RD CiDRA running equip. Gave 2-hr notice to Prod of heavy lift. Prod. shutting in wells for heavy lift. PJSM to lift and rack BOP stack. Rack back BOP stack. Terminate fiber optic line and SSSV control line. Clean snow from well row. Work on pit #1. Clean pits for rig move. Load pipe shed with 4 1/2" TCII. Repair first fiber optic termination. Redo. Work on bottom of Printed: 12/27/2005 8:35:40 AM - . .... 1 .... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS08 NS08 WORKOVER NABORS ALASKA DRILLING I NABORS 33E Page 130113 Start: 11/12/2005 Rig Release: 12/25/2005 Rig Number: 33E Spud Date: 2/13/2002 End: 12/25/2005 12/24/2005 11 :00 - 15:30 4.50 SIT N SFAL RUNCMP 15:30 - 16:00 0.50 BOPSUP P RUNCMP 16:00 - 19:30 3.50 BOPSUPP RUNCMP 19:30 - 20:30 1.00 BOPSUPP RUNCMP 20:30 - 21 :00 0.50 BOPSUPP RUNCMP 21 :00 - 22:00 1.00 RUNCOrvP RUNCMP 22:00 - 00:00 2.00 SIT P RUNCMP 00:00 - 01 :30 1.50 ZONISO P OTHCMP 01 :30 - 02:30 1.00 SIT P OTHCMP 02:30 - 03:30 1.00 SIT P OTHCMP 12/25/2005 03:30 - 04:30 1.00 SIT P OTHCMP 04:30 - 10:30 6.00 SIT P OTHCMP 10:30 - 11 :30 1.00 SIT P OTHCMP 11 :30 - 12:00 0.50 WHSUR P POST Description of Operations pit #1 Clear cellar. PJSM. NU tree and adapter flange. Pro tst adapter to 5000 psi for 10 min. OK. Pro tst tree to 5000 psi for 10 min. OK. Pull TWC. RU lines to tubing, lA, and squeeze manifold. PJSM. Fill lines and pro tst. to 1000 psi. Pro tst. IA to 4200 psi for 30 min. OK. Shear DCK valve in GLM mandrel. Complete pro tst of IA and 9 5/8 X 4 1/2 packer to 4200 psi. Shear DCK valve at 2600 psi on annulus. Secure well. Drain and blowdown lines. Fix leak in kill line. Retest lines. OK Check that DCK valve sheared. Pmp dn IA 2 bbls at 2 BPM and 380 psi. Switch and pmp dn tbg 2 bbl at 2 BPM and 500 psi. Close SSSV. Pmp dn IA and hold 1000 psi against valve for 5 min. OK. PJSM. RU Hot Oil Services and test lines to 1500 psi. OK. Pmp 290 bbl freeze protection diesel containing 1 % Nalco CR0408 corrosion inhibitor. Pmped dn annulus. Prep for rig move. U-Tube balance freeze protection fluids. Bleed tubing and annulus to 0 psi. Set BPV. Secure well. Drain and blowdown all lines. Rig released at 1200 hrs., 12/25/05. Prep to move to NS10. Printed: 12/27/2005 8:35:40 AM BP Exploration (Alaska) NORTHSTAR WB...L: NS08 ÆRMIT No: 1"2020210 API No: 50-029-23068-00 SEe T N R E COMMENTS RBI BY ~ I r... Z I 11170' 1-i7" X 4-1/2" BKR PREMIER PKR, ID = 3.875" 11199' 1-i4-1/2"HESXNIP,ID=3.813" 1 11220' 1-i4-1/2" HES XN NIP, ID = 3.725" 1 I 11220' 1-i4-1/2" HES PXN R...UG I ~i 11241' 1-i4-1/2" X 7" UNIQUE OVERSHOT 1 Z~ 11252' ELM I-iTBG STUB (10/29/05) J "i 11249' l-i 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 ~ 11273' H4-1J2"HESXNIP.ID=3.813" I ~ 11284' 1-i4-1/2"HESXNNIP,ID=3.725" I J I 11297' 1-i4-1/2" WLEG, ID - 3.958" 1 ~ ~ l z 11149' 1-i4-1/2" HES X NIP, ID = 3.813" I I . ~ " 1-i4-1/2" XD DURO SLIDING SLY, ID = 3.812" 1 9689' D z ~ 9554' 1-i9-5/8" X 4-1/2" BKR PKR, ID = 3.870" 1 I 9581' 1-i4-1/2" XD DURO SLIDING SLY, ID = 3.812" x 9529' 1-i4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" ~ 9466' 1-i4-1/2" HES X NIP, ID = 3.813" 1 . . GAS LIFT MANDRELS I STI MD I ND I DE\! /1YÆ / VLV I LATCHI PORT I DATE I 1 4745 4488 27 SMOR DMY BK 0 01/09/06 l " 992' 1- 4-1/2" TRM-4E SCSSSV w/4-1/2" X PROFILE, 10 = 3.812" 1 1582' l-i 13-3/8" TAM PORT COLLAR I - .-, S rY NOTES: ***4-1/2" CHROMETBG& LNR*** NS08 DATE COMMENTS INITIAL COM PLErION RWO ORLG DRAFT CORRECTIONS SSSV CORRECTIONS SET PXN PLUG @ 11220' REV BY N-33ES KSB/PJC GJB/PJC GJB/PJC DATE 03/18/02 12/26/05 01/02/06 01/09/06 . 01/09/06 I PBID 1-1 11943' 4-1/2" LNR, 12.6#, 13CRVAM-ACE, -i 12029' .0152 bpf, 10 = 3.958" ~ 17" LNR, 26#, L-80 BTG-M, .0383 bpf, 10 = 6.276" l-i 11461' I TOP OF 4-1/2" LNR 1-1 11293' 4-1/2"TBG, 12.6#, 13CRVAM-ACE, -1 11297' .0152 bpf, 10 = 3.958" 4-112" TBG, 12.6#, 13CR VAM-ACE, -1 11231' .0152 bpf, 10 = 3.958" ANGLE AT TOP PERF: 23 @ 9268' NIT"IA L FERF - CHARGE: 2906 P()WERJET, HviX, PENETRA TION: 2T', HOLE: 0.36", P'riASE: 60 DEG. Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL (MO) Opn/Sqz DATE 4-1/2" 5 9628 - 9668 0 12/26/05 2-7/8" 6 11755 - 11895 S 08/23/05 2-7/8" 6 11891 - 11910 S 08/23/05 PERFORA TION SUMMARY REF LOG: SWS VSIT' ON 03/18/02 (NO LOGS @ PBOC 1/23/06) ~ 9919' I TOP OF 7" LNR 1-1 19-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" 1-1 9741' Minimum ID = 3.725" @ 11220' 4-1/2" XN NIPPLE lR~ ¡= !- ABB-VGI5-118" 5K~, WB...LHEAO = ABB-VGI13-5/8" MUL TIBOWL 51\ ACTUATOR = KB. B...EV = 56' .. ---------------..-......... BF. B...EV = 40.1' (CB 15.9') KOP= Max Angle = @ ...-.---------------,.._".............--. Datum MO = Datum NO = 10500' SS 113-3/8" CSG, 68#, L-80 BTC, 10 = 12.415" 1-1 3328' I~ - e . m ~'. ,', ',7',' ,r;\\ I , '/1 \ ¡i. ~ 11 ß . ", /11 ' . . AJ:/ASIiA. OIL AND GAS I CONSERVATION COMMISSION / Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 '~¥; Re: Northstar NS08 Sundry Number: 305-350 tL"(" ¡:'N\\.'~r·> nr(~ 1: ,., 200¡:::' ...-, JA"t.r'\'1ç¡ L,¡~,", ;¡¡ _ ",.1 Dear Mr. Archey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, K. Chai DATED thisiL day of November, 2005 Encl. tJ r 1/. f D' :.,5 e STATE OF ALASKA Ô/f./O/S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~.". ',\_,;¡3 i:'~ 20 AAC 25.280 ~.. (') I\:. ,~'~" ~'F< n ¡Iv( U(':) I.N· In\! L ¥ ')on, L...U...., 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Other o Alter Casing II Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program II Pull Tubing II pe~te New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: / 5. eermitToDriU Number BP Exploration (Alaska) Inc. a Development o Exploratory 2ö2~ vi-I \4Gt\- 13. Address: o Stratigraphic o Service 6. API Number: \ P.O. Box 196612, Anchorage. Alaska 99519-6612 50- 029-23068-00-00 r' 7. KB Elevation (ft): 56' 9. Well Name and Number: NS08 ./ 8. Property Designation: 10. Field / Pool(s): ADL 312799 Northstar Unit 11. PRESENT WELL CONDITION SUMMARY ...... <. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12030 11267 11942 11180 None None Casina Length Size MD /' TVD Burst CollaDse StrtJcttJr;:¡I 201' 20" 201' 201' 4260 2590 - " 3284' 13-3/8" 3328' 3220' 4930 2270 9873' 9-5/8" 9919' 9247' 6870 4760 I inE'!r 1720' 7" 9741' -11461' 9084' - 10705' 7240 5410 Liner 736' 4-1 /2" 11293' - 12029' 1 0540' - 11266' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 11755' - 11910' 10995' - 11148' 5·112",17# x 4·1/2",12.6# 13Cr80 11297' Packers and SSSV Type: 5-1/2" 'HRQ' SSV Packers and SSSV MD (ft): 1992' 4-1/2" Baker 'S-3' Perm packer 11249' 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal o BOP Sketch o Exploratory a Development o Service o Detailed Operations Program 14. Estimated Date for December6")005 15. Well Status after proposed work: 'r.: Commencing Operations: a Oil ~as v-'(¡I 0 Plugged o Abandoned 16. Verbal Approval: Date: - o WAG DGINJ DWINJ o WDSPL Commission ReDresentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Hanson, 564-4195 Printed Name Rat Archey Title Senior Drilling Engineer V3 /JJ "j)A?~ Prepared By Name/Number: Sianature Phone 564-4366 Date /tl/zø/¿;> Terrie Hubble, 564-4628 f Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: tf)Çj - 7f'-{) o Plug Integrity e'SOP Test o Mechanical Integrity Test o Location Clearance Other: D (:;. t-' p-,ofE +0 ç (J()O ;pC",' t . RBDMS 8Ft 1 4 2005 :::zz; c {o7. APPROVED BY //£,;/6 COMMISSIONER THE COMMISSION Date Form 1 0-403 ~e" n, """;5 '--..--- Su6mit tf, Duplicate ORIGINAL e e bp ... ,tlf.'iifl. _..~ ~~.- ~..- ~..~ ~~'\: -F...... ·'I't~I\· ". BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: October 31, 2005 From: Paul Hanson Northstar Drilling Engineer Subject: NS08 Application for Sundry Permit - Rig Workover (Replàce Tubing and complete Kuparuk C interval) API #50-029-23060-00-00 Reference: Sundry approval is requested to replace the leaking 5-1/2"x 4-112" tubing with a 4-112" stacker- __/ packer completion. Also, a single-select completion of the Kuparuk C will be added on Northstar producer NS08. The addition of 40' of perforations with blast joi~ts and sliding * sleeves will facilitate future gas production from the Kuparuk C interval../ Post-Rig re- perforation of the Ivishak interval will reduce GOR. Pre-workover preparation operations are expected to begin by late November, 2005; rig operations to begin by early December, 2005. Below is an outline of the current status of the well and proposed workover operations. NS08 SUMMARY OPERATIONS NS08 was completed in March, 2002 with 5-112",17# x 4-112",12.6# 13Cr VAM ACE tubing. Production commenced shortly thereafter, and in December '04 pressure communication (a slow leak at 5500') between the tubing was identified and patched, but leakage continued. A cement squeeze on the remaining Ivishak perforations was performed on 8/25/2005 to provide zonal ./ isolation and the tubing patch was pulled on 9/22/2005 in preparation for the workover proposed in this document. Proposed Pre-IDI! Operations: 1. Load well with Brine 2. Rig-up slickline unit and pull the wireline retrievable SSSV 3. Drift the tubing for chern cut run. 4. Chemical cut tubing at -11,232'. (2 - 4' below X Nipple @ 11,228' in the first joint above the packer) 5. Circulate 9.7 ppg KWF and diesel FP (approximately 300' TVD of diesel FP) / 6. Remove flow lines, well house. 7. ND wellhead drilling sweeps e e Proposed Ri2 Operations: 1. MIRU. Pull BPV. Circulate well to 9.7# KWF thru chern cut, displacing diesel FP. 2. Set TWC. ND tree. NU test BOPE to 4SOO psi. S";:;(')CWGIt 3. Pull and LD 5-1/2" x 4-1/2" tubing string to the cut. 4. Slickline drift 9-5/8" casing prior to running perf guns. 5. Run CCUGR to top of stub for primary depth control. 6. Perforate Kuparuk C interval (9628' - 9668') ~ 7. Drift 7" casing to insure access to stub. 8. Run 4-1/2" 13 Cr VamTop (12.6#) with Unique Overshot, T~ 4-1/2" Premier, 60' of Carbide blast joints with sliding sleeves above and below, .~,and a 9-5/8"x 4-1/2" ,/ Premier packer above the uppermost sliding sleeve in hole to top of tubing stub. Record PU and SO weights. 9. SO past top of tubing stub watching for shearing of pins in overshot. Tag overshot no-go and SO 15k lbs. 10. PU slack out of pipe and Space out overshot no-go 2' above tubing stub 11. Run a memory caliper/CCL log to ensure proper space-out before setting packers. 12. Drop Ball, Set Packers / 13. Pull ball/rod with slickline. Pull RHC ball seat with slickline ? 14, Pressure test lower packer to 3500 psi against squeezed perforations, pressure test upper / packer to 3500 psi via IA. 15. Shear RP Valve. Freeze Protect to 3000' w/diesel (Tubing and IA) 16. Set TWC, ND BOPE, NU/PT tree to 5000 psi. 17. RDMO Nabors 33E. Post-Ri2 Work: 1. Re-perforate Ivishak interval below squeezed perforation interval to resume production at reduced GOR. TREE: ABB-VGI 5 1/8" 5ksi A .WELLHEAD: ABB-VGI 13-5/8" .. Multibowl 5ksi c.t.c..CTE't'Tt" NS08 13 3/8" TAM Port Collar at +1-1582'MD 133/8", 68#/ft, L-80, BTC @ 3328'MD Min.ID = 2.992" @ 5496' 5-1/2" WFD PATCH 5.5", 17#/ft, 13-Cr, Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813" ID 4.5" X NIPPLE, @ 11273' MD 3.813" 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WLEG, @ 11297' MD 3.958" ID 7", 26#/ft L-80, BTC-M @ 11461'MD PERFORATION SUMMARY REF LOG: SWS usrr (3/18/02) A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2906 Power Jet, HMX; Pen: 27"; Hole: .36"; Phase: 60 deg SIZE SPF INTERVAL Opn/Sqz DATE 2.88 6 11755 -11895 MD S 08/23/05 (10998 - 111361VD) 2.88 6 11891 -11910 MD S 08/23/05 (11133 - 111511VD) PBTD @ 11943' MD TD @ 12029'MD AKB. ELEV = 56' WB-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 51/2 SSSV @ 1992' MD, wI HRQ/ SVLN nipple - 4.562" ID 5.5" GLM @ 4746' MD, 4489' TVD wI 4.62" ID I SAFETYNOTES: WAIVEREDWEll?? 51/2" x 41/2" XO @ 9603'MD, 8959' TVD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') - 7" PACKER,13 Cr@ 11249' MD, .......- 10500'TVD 4.5" LINER TOP @ 11293'MD 4.5",12.6#, 13CrVam Ace DATE RBI BY COMMENTS DATE REV BY COMMENTS NORTHSTAR UNrr 01/16/02 BMH NS08 PROPOSED 03/05/05 JAF/TLH PATCH SET (01/29/05) WELL: NS08 03/13/02 EMF UPDA TED DEPTHS 05/11/05 RMH/TU" PATCH 10 CORRECTION ÆRMrr No: 03/27/02 EMF UPDA TED ÆRFS 08/25/05 SRBITLH CMT SQZ & PATCH PULLED Apt No: 50-029-23068-00 12/20/02 EMF UPDA TED KB INFO SEC T N R E 02/08/05 MDClTU- ADD PERFS (12/06/04) BP Exploration (Alaska) TREE: ABB-VGI 5 1/8" 5ksi . WEllHEAD: ABB-VGI 13-5/8" e Multibowl 5ksi 133/8", 68#/ft, l-80, BTC @ 3209' MD 4 1/2", 12.6#/ft, 13-Cr, Yam-TOP TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT 13 Cr DURASLEEVE @9608' MD CARBIDE BLAST JOINTS 9618' - 9678' MD 13 Cr DURASLEEVE @9688' MD 9-5/S" 47# l-SO BTM-C @ 9919' MD 4.5" XN NIPPLE, @ 11209' MD 3.725" ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WlEG, @11297'MD 3.958" ID 7", 26#/ft l-80, BTC-M @11461'MD PBTD @ 11943' MD TD @ 12029' MD DATE 9/21/05 REV. BY PMH Selective Single 0 0 111'\( 0 / 0 0 llqlO .RIGINAl KB. ElEV = 56' B-BF. ElEV = 40.1' CB. ElEV = 15.9' 41/2" SSSV @ 1000' TMD/TVD 6.8PPG DIESEL FREEZE PROTECTION AT +1- 3000' TVD (3000'MD) 4 1/2" GlM @ 4500' TVD (4747' MD) wI 4.62" ID 4.5" Fiber Optic Transducer 3.958" ID @ 9560' MD 4.5" X NIPPLE, @ 9574' MD 3.813" ID 9-5/8"x 4-112" PACKER @ 9594' MD o o o o Kuparuk C Perforations -9628' - 9668' - 7" LINER TOP @ 9741' MD 4.5" X NIPPLE, @ 11158' MD 3.813" ID - 7" Premier PACKER, 13 Cr @ 11178' MD 4.5" X NIPPLE, @ 11198' MD 3.813" ID _ 7"PACKER,13Cr@11249'MD 10500'TVD 4.5" LINER TOP @ 11293' MD 4.5",12.6#, 13Cr Yam Ace Northstar WELL: NS08 API NO: BP Exploration (Alaska) ) biJ:~ Date: 10/31/2005 Transmi~ ~~t···bf1~~1~ llE·.·'~::: J" I .. ,; ',' ~', :._ .~ ¡ J 1\ ;~1"""" . ,,,,fJJ,,,,.,¡,. ,j \¡,. '''' 'J ,1 Bi íCt1 ~ BPXA WELL DATA TRANSMITTAL j~¡rnl~~~Q1)~f;m\~® Enclosed are the materials listed below. 'If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS27 06/08/2004 SCH 1 10730 11316 PERFORATING RECORD ~ Ok.. o~ NS08 01/29/2005 SCH 1 4650 5600 TUBING PATCH RECORD J,Od..--O~1 Ws - O?J l (AL( Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center SCANNED NOV 2 1 2005 Attn: Howard Okland AOGCC Jason Smith Murphy Exploration Kristin Dirks DNR Doug Chromanski MMS Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMI......J1oN REPORT OF SUNDRY WELL OPERATIONS RECEIVED SEP 262005 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing D Pull Tubing 0 Change Approved Program 0 Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations 0 Perforate New Pool 0 Perforate D 4. Current Well Class: Development M Stratigraphic Stimulate D AI Ot~!" ~ch . . Waiver D Time ~~~~s'tØ~ as-tiIfiS. ¡.;ø.....r: Re-enter Suspended Well 5. Permit to Drill Number: 202-0210 6. API Number: 50-029-23068-00-00 9. Well Name and Number: Exploratory Service 56 KB NS08 8. Property Designation: ADL-312799 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool Total Depth measured 12030 true vertical 11266.74 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 11942 true vertical 11179.58 feet feet Casing Surface Production Liner Liner Length Size MD TVD Burst Collapse 3284 13-3/8" 68# L-80 44 - 3328 44 - 3220.12 4930 2270 9873 9-5/8" 47# L-80 46 - 9919 46 - 9246.74 6870 4760 1720 7" 26# L -80 9741 - 11461 9084.01 - 10704.78 7240 5410 737 4-1/2" 12.6# 13Cr80 11293 - 12030 10539.84 - 11266.74 8430 7500 Perforation depth: Measured depth: True Vertical depth: SCANNEO NO" 0 S 2005 Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# 13Cr80 13Cr80 40 - 9603 9603 - 11297 Packers and SSSV (type and measured depth) 5-1/2" HRQ SSV 7" Top Packer 4-1/2" Baker S-3 Perm Packer 1992 9741 11249 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11755'-11895'; 11891 '-1191 0' Treatment descriptions including volumes used and final pressure: see attached fluid summary T/I/O= 13. RBDMS BFl SEP 2 8 2005 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 000 15. Well Class after Droposed work: Exploratory C Development ,GZ 16. Well Status after proposed work: Oil r;¡ Gas r W AGr Tubing pressure o o Service r x GINJ r W INJ [' 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: 305-042 Contact Sharmaine Vestal Printed Name Sharmaine Vestal, / Signat~ 7j~ Title Data Mgmt Engr Phone 564-4424 Date 9/22/2005 Form 10-404 Revised 04/2004 o F\ I G ¡ lVA L Submit Original Only ) ) NS08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/12/2005 T/I/0=3500/1680/35 Assist SLS Pump Crew (Acidize/Pre-Squeeze)- Pumped 97 bbls 80*F diesel following pickle. Pumped 97 bbls 80*F diesel following acid treatment. Turn well over to production control for 4 hr soak. Final WHP's=600/1620/40 8/12/2005 ****Well Shut In Upon Arrival**** Acid treatment; pickle wellbore with 2 bbls meth spear followed by 18 bbls 12% HCL, displace with 133 bbls 80 deg fsw & 97 bbls 80 deg diesel. Produce pickle back to test separator and well clean up tank, flow back vol=250 bbls. Pump 2 bbls meth spear followed by 25 bbls 12% HCL, displace HCL with 67 bbls 2 % KCL - 157 bbls 80 deg fsw - 97 bbls 80 deg diesel. Shut well in and let soak 4 hrs. Produce well to test separator and clean up tank (347 bbls). Test well post clean~up. 8/15/2005 ****Well Shut In Upon Arrival**** Spot slickline equipment. Thaw tree cap and swab valve. RU to pull 5.5" WRDP SSSV and drift for upcoming CTU Cement Squeeze. Could not stay latched up to SSSV. POOH and check GS. Small pieces of metal on GS keys. Made decision to get new keys out here in the morning to prevent damaging SSSV fishing neck. Lay down equipment for the night. 8/16/2005 ****Well Shut In Upon Arrival**** RU slickline equipment and Little Red. PT lines and lub. Pump 60 bbls 180 deg diesel. RIH with 5.5" GS with new keys. Latch 5.5 WRDP with 5.5" RQ lock. GS continued to pull out of fishing neck at 1200# jar licks. Spang licks pull right out. Have tool room set up 5.5" releasable spear and continue in AM. Move equipment out of well row to spot CTU equipment on NS-24 for upcoming squeeze. Leave well shut in. 8/16/2005 T/I/O= Assist S-Line Pull SSSV (Pre-Cement Squeeze) - Pump as directed 60 bbls 180*F diesel down tubing. Final WHP's=3000/1500/40 8/18/2005 *****Well Shut In Upon Arrival***** T/I/0=3050/1500/0 RIH with 5.5" releasable spear to 1954' wlm. Latch and pull 5.5" WRDP with RQ lock. Fishing neck flaired out. RIH with Weatherford "PS" patch pulling tool on 4.5" GS. Latch patch at 5443' wlm. Jar on patch to release. Pull patch to 4708' wlm, patch hanging up at collars. Could not move patch above 4708' wlm. Work patch down to 5443' wlm. Shear off patch and POOH. Check out tool string, repin GS and add 4" cent above GS. RIH and latch patch at 5443' wlm. Pull up hole to 4708' wlm. Patch continues to hang up in same spot. Run patch up and down hole in an attempt to wear down element. Pulled past tight spot, continue to surface. At surface with upper portion of Weatherford patch, rubber emement intact, missing packing. RIH and latch lower portion of patch and pull up to 4708' wlm, patch fell off. Decision made to lay down equipment for night, cut wire and resume in AM. 8/19/2005 *****Well Shut In Upon Arrival***** T/I/0=3050/1530/30 PI. RIH to pull lower section of 5.5" Weatherford tubing patch. Latch patch @ 9558' and pull up to 4708' wlm, work up to 4690' wlm, stuck patch shear off, POOH. BBLS 21.5 87 51 107 5 1111 1382.5 ) ') Check tools and repin GS. RIH and latch patch @ 4815' wlm, pull up to 4701' wlm, lost spangs and jars, RU Little Red and pump 28 bbls diesel and free up tools. Pull patch to surface. Small chunks of rubber ripped off of packing element. RIH with 4.5" wire grab and 3.5" centralizer. Sat down@ 11708' wlm, tight spot, work wire grab through tight spot and tag hard bottom @ 11867' wlm,11892' MDBKB. POOH. At surface recover one piece of v-packing. RD. Leave well shut in. 8/19/2005 T/l/0=3100/1550/30 Assist Slickline (Pre-Squeeze) - Pump as directed. Pumped 28 bbls ambient diesel down tubing. Final WHP's=2850/1525/30 8/21/2005 CTU #5. RU, Stand by on logistic support personal to be able to move equipment. Continued on 8/22/05 WSR. 8/21/2005 *** Job Prep/Stage Equipment/Stand by for Support Equipment*** 8/22/2005 T/I/O=750/150010 Assist CTU #5 Squeeze/MIT-IA 3000 psi (Wavier Compliance) - CTU#5 pumping well kill, LRS pumped 28 bbls diesel to load & pressue up IA. ***Job in Progress*** 8/22/2005 CTU #5, Cement Squeeze I MITIA; Continued from WSR 8/21/05... Stand by on logistic support personal to be able to move equipment. MIRU. Pumping down backside wi filtered seawater for well kill ops. LRS doing MIT-IA test. Continue wi MIT-IA test. Continued on 8/23/05 WSR ... 8/23/2005 CTU #5, Cmt Sqz; Continued from 8/22/05 WSR... Continue wi MIT-IA test. Talked wi town eng & confirmed that we can carryon wi cmt sqz after MIT-IA failing test. RIH & continue well kill down backside. RIH for dry tag. Tag soft fill @ 11909' ctm. Pump @ 1 BPM & RIH for tag. Tag hard bottom @ 11911' & could not get deeper. Get CT weight back @ 11904'. Flag CT @ 11894'. Hold 450 psi @ choke manifold & taking returns to tank to check for gas. Good fluid returns wi no gas. CT @ 11730' & close in at choke manifold while pumping down CT @ 0.5 BPM to keep well fluid packed. Prep to cement. SIWHP = 285 psig. Pump 21.5 bbls of Class G LARC cement. Lay in across perfs and attain initial squeeze pressure of 1500 psig. Lay in remaining cement and pull to safe. Work squeeze pressure in 500 psi increments up 3700 psig WHP. Hold squeeze for 45 min. Estimate 2.5 to 3.0 bbls cement behind pipe. RIH and contaminate to TD. Lay in 5 bbls of TEA across perfs. POOH circulating out contaminant maintaining 1000 psig WHP. Freeze protect well from 3000' with 70 bbls of diesel. Trap 1500 psig WHP. Secure well. RD CTU #5. *** Job Complete *** 8/23/2005 ***Continued from previous days WSR*** Assist CTU#5 MIT-IA 3000 psi ***FAILED*** Pumped 28 bbls diesel to load & pressure up IA to 3000 psi. IA lost 140 psi in 1 st 15 min. IA lost 130 psi in 2nd 15 min. Bump up lAP w/2 bbls diesel Start 2nd test. IA lost 110 psi in 1 st 15 min. IA lost 95 psi in 2nd 15 min. Failed. Bleed lAP through choke skid to open top. CTU continue wlsqueeze FLUIDS PUMPED Cement Diesel 60/40 MeOH Biozan TEA SW,FW,XS SW TOTAL bp Date: 07-20-2005 Transmittal Number: #91588NS 10,08,32 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohflsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type rNS19 05-16-2005 PDS 1 13700 14080 PRESSURE BUILDUP; ).. - ¡ ìJ'7 NS19 05-16-2005 PDS NS10 05-12-2005 PDS t~-\8,l .,.~, NS-08 05-12-2005 PDS f.~ :,} -I yg NS- 05-14-2005 PDS ;2/VVD-02 1 13700 14080 PRODUCTION PROFILE 0 8007 MEMORY MULTI-FINGER CALIPER 0 11374 MEMORY MUL TI-FINGER CALIPER 0 8105 MEMORY MULTI-FINGER CALIPER 5 2 /'/'1 / l ........, ,f/1 t' / if / YI: ,,) f / /:,.J:t~/ /);Jj~ I' ~V1 ..,~ ~ Pl'ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center "-"0 Þ f ~¡\"'M'-'" ¡., r"'ì)¡ ";\ C'\ r;nrì~- ,,~~,.,.·",'~,11\~,~'\l1!r.:;J._' .) [J-' li:1 (,0 t..J c),J Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) ~ ~ Petro technical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage. AK 995 19-6612 -> ~(1)c~ -~~t ~ (~ ') STATE OF ALASKA ) ALA.....lA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56 KB 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Total Depth measured 12030 true vertical 11266.74 Effective Depth measured 11942 true vertical 11179.58 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development p): Stratigraphic L' rVED ,AUG 2 4 200S Stimulate D Other D Waiver D Ti~ª:Ë·*tedS'idtil [§jSf; C[m~. Commiss~m~ Re-enter Suspended WelljWr.:~Wn~~tæ 5. Permit to Drill Number: Exploratory C 202-0210 Service [J' 6. API Number: 50-029-23068-00-00 9. Well Name and Number: NS08 10. Field/Pool(s): NORTHST AR Field/ NORTHST AR 01 L Pool feet feet Plugs (measured) Junk (measured) None None feet feet Surface Production Liner Liner Length Size MD TVD Burst Collapse 3284 13-3/8" 68# L-80 44 - 3328 44 - 3220.12 4930 2270 9873 9-5/8" 47# L-80 46 - 9919 46 - 9246.74 6870 4760 1720 7" 26# L-80 9741 - 11461 9084.01 - 10704.78 7240 5410 737 4-1/2" 12.6# 13Cr80 11293 - 12030 10539.84 - 11266.74 8430 7500 Casing Perforation depth: Measured depth: 11755 - 11895 True Vertical depth: 10994.69 -11133.06 11129.1 -11147.9 11891 - 11910 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5-1/2" 17# 4-1/2" 12.6# 5-1/2" HRQ SSV 7" Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer 13Cr80 13Cr80 40 - 9603 9603 - 11297 1992 9741 11249 11293 Treatment descriptions including volumes used and final pressure: .' ..,¡c::,.,. f\UG C'j¡ n: 'ìOOS S(;,ANNG:.~) J'1 . ~ì ti... '"' 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 3821 2590 x Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 44229 26 0 33733 0 0 15. Well Class after Droposed work: Exploratory r Development P' 16. Well Status after proposed work: Oil P Gas r WAG r Tubing pressure 2892 3145 Service r WDSPL r GINJ r WINJ 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: 304-488 Contact Sharmaine Vestal Printed Name Shar~aine Vestal _ / Signa~ 6L,A(} Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 8/18/2005 o RIG! N A L ~LJf7š M~~onIY ) ') NS08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 1/29/2005 Set WFD PB 5 1/2" tubing patch. Come off weather standby. MU and RIH wI WFD 13 Cr PB lower packer. Log down from 4600'. Tie into GLM at 4746' using SLB leak detection log dated 12-07-2004. Set lower packer (COE) at 5506' ELM. (Collar at 5501' ELM). POOH. MU and RIH wI 13 Cr snap latch assy, spacer and upper packer. Latch and pull 800# over. Set upper packer at 5496' ELM. POOH. RDMO E-Line equip. Note: Bled IA from 2350 to 750 psi during operation. Shut bleed in after patch set and IA pressured back up to 2350 psi in less than 10 minutes. Notify Control room of well status. Put heater on well to thaw alllA surface lines to verify accurate IA pressure. Request to POP well and monitor IA. FLUIDS PUMPED BBLS o TOTAL (ffù~, ,í 1['. :. ,~!.r'/A,I.' l. ¡ rr'.' \: ~: 'n ~¡ ¡? íæ.. :: f,' '.\ U 11 ) :ø~-CJ,21 AI..ASK.& OIL Al\ID GAS CONSERVATION COMMISSION I ,) .f 1 ! ¡ .1 / J FRANK H. MURKOWSK', GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS08 Sundry Number: 305-042 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's 'petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a liday or weekend. A person may not appeal a Commission decision to Superior 0 unless rehearing has been requested. /'" Enc!. SCA~~~En MAR 0 2 2005 bp ) ') ... ,\lr.,", ......."~. ~...~ ~~- ~...- ...~ ~...... .'i'~§\. .,. BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 16, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 FEB 1 8 Z005 Dear Winton: Oii Re: Sundry Notice for NS08 to do a Gas Shut-off Squeeze (Ivishak) BP Exploration Alaska, Inc. proposes to perform a gas shut-off squeeze in the NS08 well. This well has experienced a steady increase in GOR. At its current GOR of 14,500 SCF/STB, this well is shut-in a majority of the time due to facility gas handling limitations. Production logging indicates a majority of the gas production is coming from the upper two-thirds of the perforations. The proposed procedure would isolate these perforations to reduce the GOR in this well so it can become a full-time producer again. The procedure includes the following major steps: . RU Coiled Tubing . Isolate the lower one third of the perforations with a sand plug . Squeeze the upper two thirds of the perforations using gel and cement / . Clean out the well bore using coiled tubing . Retu rn the well to production Sincerely, ~~~I :::¡; - Ù; Mictael J. ~ a~,PE: Senior Petr leum Engineer BPXA, ACT, Northstar rì();(:!f\\ lJ 61\- ~ I ¿.l.-! ~"S () 7:S <j "<. k ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV*ö 1 !~J, 20 AAC 25.280 Perforate D W~,i,~~d] .Annular Disposal D StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0210 /" 6. API Number /' 50-029-23068-00-00 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend D RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations Œ] Perforate New Pool D 4. Current Well Class: / //' (" Development [!] Exploratory D Stratigraphic D Service D 9. Well Name and Number: NS08 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11942 11127.0 MD TVD BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12030 Casing Total Depth TVD (ft): 11270.3 Length Size Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 9741 11461 9085.7 10708.1 7240 5410 11293 12029 10543.1 11269.3 8430 7500 40 9919 40.0 9248.6 6870 4760 40 3328 40.0 3220.1 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 9603 11297 5.5" 17# 13Cr80 40 9603 Liner 1720 Lln~ 736 Production 9879 Surface 3288 Perforation Depth MD (ft): 11755 - 11785 11785 - 11815 11815 - 11845 11845 - 11875 11875 - 11895 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 5-1/2" HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ) 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10998.1 11027.7 11027.7 11 05r.4 11057.4 11087.1 11 087.1 11116.7 11116.7 11136.5 Packers and SSSV MD (ft): 11249 11293 1992 9741 Detailed Operations Program D BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentŒ) // Service D 15. Well Status after proposed work: Oil Œ:I GasO PluggedO AbandonedO WAG D GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: April 1, 2005 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Michael Francis ~cJwJ 1:þA~/~J P.iE. ~ Commission Use Only Title Phone Michael Francis Petroleum Engineer 564-4240 2/8/05 BOP TestO Mechanciallntegrity Test D Location Clearance 0 Other: RBDMS 8FL ',~AR 0 :¡ 2005 BY ORDER OF THE COMMISSION Appro l)¡-\¡v¡r~)4L. Sundry Number: 30::;- ..ð '1";;- Date: 1~ oŠ SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksi WE~LHEAD: ABB-VGI13-5/8" ," ' Multibowl 5ksi ') NS08 133/8" TAM Port Collar at +/-1582'MD 13 3/8", 68#/ft, L-80, BTC @ 3328'MD ~ 5.5", 17#/ft, 13-Cr, Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBUFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBUFT ~ H 6 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813" ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID - 4.5" WLEG, @ 11297' MD 3.958''' ID - J B 7", 26#/ft L-80, BTC-M @ 11461'MD J. FGR:RATK.)\ SlMv'AR( ÆFLCG 9I\SLSIT(3'18'02) AN3..EAT"RFHW N:Xe: Fè'er to Ftcxidion æ fa" l'istcrical perf dëia hitia Rrf - O'a'ge: 2ro3 RMterJet, HvÞ<; RJ1etratia1: 2]"; !-tie: .2ß'; Ræe: 00 dad SZE s:F NJm/AL rvo NJm/AL lVD Q:d&¡z 2.88 6 11755' -11898 1cm8 -1112ß Q:n D\lE 3fl2f2fJJ2. PBTD @ 11943' MD TD @ 12029'MD j DATE 1/16/02 3/13/02 3/27/02 12/20/02 REV. BY BMH EMF EMF I::MI- COMMENTS ~t)08 ~roposed Updated Depths Updated Perfs Updated KB Information .. )KB. ELEV = 56' KB-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1992' MD, 1989' TVD w/ HRQ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD w/4.62" ID ~ ... / 51/2" X 41/2" XO @ 9603'MD, 8959' TVD ~ - 7" LINER TOP @ 9741'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460'TVD(SensorELM TVD = 10480') -;- - 7" PACKER, 13 Cr @ 11249' MD, , - 10500' TVD E 4.5" LINER TOP @ 11293'MD V I ~ ~ 4.5". 12.6#, 13Cr Vam Ace Northstar WFJ J : N~08 API NO: 50-029-23068-00 BP Exploration (Alaska) STATE OF ALASKA. ) ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: 3. Address: Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate ŒJ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development ŒJ Stratigraphic 0 9. Well Name and Number: NS08 10. Field/Poo/(s): Northstar Field / Northstar Oil Pool Stimulate D OtherD WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 202-0210 6. API Number Service D 50-029-23068-00-00 56.00 8. Property Designation: ADL-312799 11. Present Well Condition Summary: IVED 0 3 2009 Total Depth measured 12030 feet Effective Depth measured 11942 feet true vertical 11183.0 feet Plugs (measured) Junk (measured) Alaska Oil G~~~~R¡¡s. Commission Am:i'¡om«ie None~ true vertical 11270.3 feet Casing Length Size MD TVD Burst Collapse LINER 1720 7" 26# L-80 9741 - 11461 9085.7 - 10708.1 7240 5410 LINER 737 4-1/2" 12.6# 13Cr80 11293 - 12030 10543.1 - 11270.3 8430 7500 PRODUCTION 9873 9-5/8" 47# L-80 46 - 9919 46.0 - 9248.6 6870 4760 SURFACE 3284 13-3/8" 68# L-80 44 - 3328 44.0 - 3220.1 4930 2270 Perforation Depth: Measured depth: 11755 -11785,11785 -11815,11815 -11845,11845 -11875,11875 -11891,11891 -11895,11895 -11910 True vertical depth: 10998.09 -11027.74,11027.74 -11057.39,11057.39 -11087.05,11087.05 -11116.72,11116.72 -11132.55 11132.55 -11136.51,11136.51 -11151.35 TubinQ ( size, Qrade, and measured depth): 5-1/2" 17# 13Cr80 @ 40 SCANNED FE. B 0, 7 ?005 9603-". . <= Packers & SSSV (type & measured depth): 5-1/2" HRQ SSV 7" Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer @ 1992 @ 9741 @ 11249 @ 11293 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 25.5 19 2300 66.7 39 2200 13 Prior to well operation: Subsequent to operation: Oil-Bbl 3187 5910 Tubing Pressure 2871 2345 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil[!] GasD DevelopmentŒ] Service 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-458 Title Production Technical Assistant Signature jJ ~ C"Ø::¡~ Phone 564-4657 Date 1/26/05 RBDMS BFl FE8 0 4 2005 Form 10-404 Revised 4/2004 ) NS08 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/06/04 11891'-11910' 6 SPF BBLS 5 Methenal 5 TOTAL FLUIDS PUMPED Page 1 ) REC IVE FEB 0 :3 2005 Alaska. Oil & Cons. Commission .. , TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) NS08 13 3/8" TAM Port Collar at +1-1582'MD 13 3/8", 68#/ft, L-80, BTC @ 3328'MD ..4 5.5", 17#/ft, 13-Cr, Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT ~ ¿. 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813"ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WLEG, @ 11297' MD 3.958" ID - B B 7", 26#/ft L-80, BTC-M @ 11461 'MD iI FfH{RA.l'(]\J~ ÆFLCG 9I\6lS1T (~18'02) MGEATlCPr:tW N:te: Rafe- to Fhrlx::tia1 œ fcr I1sta-ica pErl d:ta ntia R3rf - ~ 2ro) FONe- J:t, I-fIh(; Fe1etraIia1: 'lJ"; -Ije; .'æ'; Fhase: 00 dEg SZE s:F NTm/AL rvÐ NTm/AL 1VD Qn'S:1z 2ffi 6 117fB -11895' 1Œm -111'æ Q11 rnlE 3I72f2ffJ2. PBTD @ 11943' MD TD @ 12029'MD ~ DATE 1/16/02 3/13/02 3/27/02 12/20/02 REV. BY BMH EMF EMF EMF COMMENTS ""NS08 proposed Updated Depths Updated Perfs Updated KB Information .. ~ )KB. ELEV = 56' .-KB-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1992' MD, 1989' TVD wI HRQ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD wI 4.62" ID .. ) 5 1/2" x 4 1/2" XO @ 9603'MD, 8959' TVD ~ - 7" LINER TOP @ 9741'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') IÇ;'" - 7" PACKER, 13 Cr @ 11249' MD, .- 10500' TVD 'E V . 4.5" LINER TOP @ 11293'MD ~ RE FEB 0 3 2005 A1atka Oi~ ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WFJ J : NS08 API NO: 50-029-23068-00 BP ExploråtíòÍ1(AI~ska) ) )....J Date: 01-11-2005 Transmittal Number: #91588NS21 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com VC6 Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS21 04-17-2004 SCH 7 201 22261 VISION DENSITY NEUTRON; (MD) J ('1 r¡; NS21 04-17 -2004 SCH 7 201 22261 VISION DENSITY NEUTRON; (TVD) NS21 04-17 -2004 SCH 7 201 22261 VISION RESISTIVITY; (MD) NS21 04-17-2004 SCH 7 201 22261 VISION RESISTIVITY; (TVD) NS21 11-16-2002 SCH 200 22200 LDWG EDIT OF LWD GR,ARC,CDR / 12-06-2004 AND IN TIFF FORMAT ON CD ROM; NS08 SCH 11150 11898 PERFORATING RECORD; ~OZ-()l1 J J 12-'11-2004 NS09 SCH 12950 13340 PRODUCTiON PROFILE; /)02.·-RO /'" NS08 12-07-2004 SCH 11650 11928 PRODUCTION PROFILE; 2£/<- - \ NS08 Ii I 12-07-2004 SCH 1500 11400 LEAK DETECTION LOG; Ð~\ , '"' ...........J/. Il ,,-,-..,..' I )C£ /// ' ,.. /..1' / &;;' '/1 -? "7' O';~ .' , ~0UA--- Please Sign a d Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center . t" ,.., .; ('". ') L\ m:: '. . f ' fi. &~ ~ \\i ¡¡:: r' j~") ~-~ .'i.. Ö L ,U ,] l~v,M~¥,~Ç.. ,~. Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ,,~r~~! :} ~~!Æ~~!Æ ) AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27&7542 ~....(),~~()~ I Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS08 Sundry Number: 304-458 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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. Cð~ Daniel T. Seamount, Jr. Commissioner Zq. ^Jov, - DATED this-=¡.. day of ñ€èC1llber, 2004 Encl. S{;ANNED DEC 0 1 2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: bp November 19, 2004 ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519.6612 (907) 561.5111 NOV 1 2004 Re: Sundry Notice for NS08 to Add Perforations (Ivishak) BP Exploration Alaska, Inc. proposes to add 15' of perforations below the existing perforations in the NS08 well. These perforations are expected to increase oil production from this well. The procedure includes the following major steps: Type Slickline Electric Line Slickline Sincerely, Work Description Pull SSSV, DrifVtag wI dummy gun Add 151 of Ivishak Perforations from: /' 11,895' - 11,910' MDrkb (11,136' - 11,151' TVDrbk) Run SSSV ~/ "~~ /'Aùlla.J ~ .'1 Mic1ael J. is, P.E. Senior Petr leum Engineer BPXA, ACT, Northstar ORIGINAL .,. ,\I,.,,,. -.....~ ~#..- ~..- ~...~ ~~ ~...... .'I'~I\- ". BP Exploration {Alaska}, Inc. 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: II--.lGÃ- U[22.{ ¿Oo4 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV A~OV 1 q 2004 20 AAC 25.280 Suspend D RepairWell 0 Pull Tubing 0 -~ ~;~J .::~I ~: Perforate Ii] W~iY:ffi~~;~llPular DisposalD StimulateD Time ExtensionO OtherD Re-enter Suspended Well 0 5. Permit to Drill ~umber: 202-0210 / Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development Œ] Exploratory D ( 6. API Number / 50-029-23068-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12030 Casing Length StratigraphicD Service D 9. Well Name and Number: NS08 ..,/ 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11942 11127.0 MD TVD Plugs (md): Junk (md): None None Burst Collapse Total Depth TVD (ft): 11270.3 Liner 1720 Liner 736 Production 9879 Surface 3288 Perforation Depth MD (ft): 11755 - 11785 11785 - 11815 11815 - 11845 11845 -11875 11875 - 11895 Packers and SSSV Type: 4-1/2" Baker $-3 Perm Packer 4-1/2" Liner Top Packer 5-112" HRQ SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ] Detailed Operations Program D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Size 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10998.1 11027.7 11027.7 11057.4 11057.4 11087.1 11087.1 11116.7 11116.7 11136.5 top bottom top bottom 9741 11461 9085.7 10708.1 7240 5410 11293 12029 10543.1 11269.3 8430 7500 40 9919 40.0 9248.6 6870 4760 40 3328 40.0 3220.1 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 9603 11297 5.5" 17# 13Cr80 40 9603 Packers and SSSV MD (ft): 11249 11293 1992 9741 BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentŒ] Service D December 2, 2004 15. Well Status after proposed work: Oil Œ] / GasD PluggedD AbandonedD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis Michael Francis ~g!fi~~ ) ?'F- 11/18/04 Title Phone Petroleum Engineer 564-4240 Commission Use Only Sundry Number: 3jJ If ~L ~t' Plug Integrity 0 Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 BOP TestD Mechancial I ntegrity Test D RBDMS BFL NOV 302004 Other: Subsequent Form ReqUired:. ~ð - D 4 ' Approved by: 0~ r Form 10-403 Revised 06/2004 Date: II/Zr/<{-- BY ORDER OF THE COMMISSION i L} t'.\ L SUBMIT IN DUPLICATE ~ '.\..,.,,,,,,,--: ~ ~ .. -) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS08 133/8" TAM Port Collar at +1-1582'MD r>"'~ 13 3/8", 68#/ft, L-80, BTC @ 3328'MD ~ 5.5", 17#/ft, 13-Cr, Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBLlFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT ~ 9-5/8" 47# L-80 BTM-C @ 9919'MD M Jj- 4.5" X NIPPLE, @ 11228' MD' 3.813" ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WLEG, @ 11297' MD 3.958" ID - J , E 7", 26#/ft L-80, BTC-M @ 11461 'MD J. Æff'ŒA1X)\ SJvM'.R{ ÆFLffi 9A6 LSIT (3'18102) AN3..EATKPFBT: N::te: R:ter to R'cxiJ:;tic:n œ fer listaica perl dci:a htia Rrl- Oa"ge: 2m Rmer.k:t, ~ Fa1etraIicn 21"; f-\je; .?ß'; R'1ase: 00 deJ SZE 3=F NTERJAL fv1) NTERJAL lVD Qn'~ 288 6 117fß -11895 1ŒŒ -111?ß QJ1 O\lE 3fl2f2ID2 PBTD @ 11943' MD TD @ 12029'MD 1 DATE 1/16/02 3/13/02 3/27/02 12/20/02 REV. BY BMH EMF EMF EMF COMMENTS ""NS08 -1roposed Updated Depths Updated Perfs Updated KB Information .. ~ )KB. ELEV = 56' KB-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 5 1/2" SSSV @ 1992' MD, 1989' TVD wI HRQ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD wI 4.62" ID ~ } 5 1/2" x 4 1/2" XO @ 9603'MD, 8959' TVD l\. - 7" LINER TOP @ 9741'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') -;; - 7" PACKER,13 Cr @ 11249' MD, .- 10500' TVD 'E ~ I 4.5" LINER TOP @ 11293'MD ... ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WFI I : NS08 API NO: 50-029-23068-00 BP Exploration (Alaska) -' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimulate 00 Abandon 0 OtherD Alter CasingD Pull TubingO Perforate New Pool D WaiverD Time ExtensionO Change Approved Program D Operation ShutdownO Perforate D Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 202-0210 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-23068-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.00 N508 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar Field / Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 12030 feet true vertical 11270.3 feet Plugs (measured) None Effective Depth measured 11942 feet Junk (measured) None true vertical 11183.0 feet Casing Length Size MD TVD Burst Collapse Liner 1720 7" 26# L-80 9741 - 11461 9085.7 - 10708.1 7240 5410 Liner 736 4-112" 12.6# 13Cr80 11293 - 12029 10543.1 - 11269.3 8430 7500 Production 9879 9-5/8" 47# L-BO 40 - 9919 40.0 - 9248.6 6870 4760 Surface 3288 13-3/8" 68# L-BO 40 - 3328 40.0 - 3220.1 4930 2270 Perforation depth: Measured depth: 11755 -11785,11785 -11815,11815 -11845,11845 -11875,11875 -11895 True vertical depth: 10998.09 -11027.74,11027.74 -11057.39,11057.39 -11087.05,11087.05 -11116.72,11116.72 -11136.51 Tubing ( size, grade, and measured depth): 5-112" 17# 13Cr80 @ 40 - ~~~:RECEIVED 4-1/2" 12.6# 13Cr80 @ 9603 - Packers & SSSV (type & measured depth): 4-112" Baker 5-3 Perm Packer @ 11249 SEP 2 1 2004 4-112" Liner Top Packer @ 11293 5-112" HRQ 55V @ 1992 Alaska Oil & Gas Cona. Commission 7" Liner Top Packer @ 9741 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11755-11895 Treatment descriptions including volumes used and final pressure: 33 Bbls 12% DAD Acid @ 3012 psig 13 Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 9485 67.5 8 1761 Subsequent to operation: 8698 70.2 11 1767 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations, X OilŒJ GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-265 Printed Name Garry Catron Title Production Technical Assistant Signature Mr.- ,~ C~ Phone 564-4657 Date 9/16/04 I - R\G\NAL L 'SEPil_~ Form 10 404 Revised 4/2004 0. R8DMS BF NSO8 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/28/04 ACID TREATMENT:. PICKLE TBG WI 18 BBLS 12% DAD ACID, 133 BBLS SEAWATER, AND 97 BBLS DIESEL. FLOWBACK TO WELL CLEANUP TANK.. MAIN TREATMENT: 33 BBLS 12% DAD ACID WI NALCO SI, 253 BBLS SW DISPL TO PERFS (SOAK 30 MINS). OVERFLUSH & UB WI 186 BBLS SW & 97 BBLS DIESEL.. TURN BACK TO OPERATIONS FOR 4 HOUR SOAK FOR SCALE INHIBITOR PRECIPITATION.. «JOB IS COMPLETE--NSTAR ACID SEASON COMPLETED». BBLS 51 12% DAD Acid 386 Sea Water 194 Diesel 631 TOTAL FLUIDS PUMPED Page 1 bp .'. ""~.'I.I. ....:~ :I~.. .~; ~:'. .;l~~~\\- '" BP Exploration (Alaska) Inc. 900 East B,=nson Boulevard P. O. Bo:( 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 d-.-6 [)-. -6 ?- July 7,2004 1". , I . . ' - Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 ,~ !.J i- I ::: )004 I, Dear Winton: Re: Sundry Notice for NS08 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS08 well. This well has exhibited decline and analysis of formation water indicates the formation of CaC03 scale is likely. Last summer's acidizing campaign at Northstar was very successful. The procedure includes the following major steps: . Pickle the tubing Bullhead HCI based acid treatment (which includes scale inhibitor) Flowback . . Sincerely, .ô ~ M:::::J~~~ Senior Petroleum Engineer BPXA, ACT. Northstar nDrh'~,f^' i¡,,-&/~ . 7 tl41 zc c4 t STATE OF ALASKA \ D/5 7/11--/ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 Repair Well 0 Pull Tubing D -' >flf14 Operation Shutdown 0 PerforateD WaiverD Annular DisposalD Plug Perforations D StimulateŒ] Time ExtensionD OtherD Perforate New Pool D Re-enter Suspended WellD 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ1 Exploratory 0 Stratigraphic 0 Service 0 9. Well Name and Numb~r: NS08 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11270.3 11942 11127.0 Size MD TVD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 12030 Casing Liner Liner Production Surface Length 5. Permit to Drill Number: 202-0210 / 6. API Number / 50-029-23068-00-00 Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 9741 11461 9085.7 10708.1 7240 5410 11293 12029 10543.1 11269.3 8430 7500 40 9919 40.0 9248.6 6870 4760 40 3328 40.0 3220.1 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 9603 11297 5.5" 17# 13Cr80 40.1 9603 1720 736 9879 3288 7" 26# L-80 4-112" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (It): 10998.1 11027.7 11027.7 11057.4 11057.4 11087.1 11 087.1 11116.7 11116.7 11136.5 Perforation Depth MD (It): 11755 - 11785 11785 - 11815 11815 - 11845 11845 - 11875 11875 - 11895 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 5-1/2" HRO SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ] Detailed Operations Program 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Packers and SSSV MD (ft): 11249 11293 1992 9741 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD August 1, 2004 15. Well Status after proposed work: Oil ŒJ GasD WAG D GINJD Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis L /L- :/ - Title ~~ C ,1'1""'..4) . £- Phone Commission Use Only Petroleum Engineer 564-4240 7/8/04 Conditions of approval: Notify Commission so that a representative may witness Other: Subsequent Approved by: BOP TestD Mechanciallntegrily Test D Location Clearance D PluggedD AbandonedD WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Number: 30f-C)6,s- .-afi. 1Ul í.\ I\\\\~ BY ORDER OF 't--i¡r W ./ 0 RI G ¡ ~, , '¡ , THE COMMISSION Date: 1/11¡ VI SUBMIT IN DUPLICATE Form 10-403 Revised 06/2004 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8' ';, Multibowl 5ksi NS08 133/8" TAM Port Collar at +1-1582'MO 13 3/8", 68#/ft, L-80, BTC @ 3328'MO ~ 5.5". 17#/ft, 13-Cr, Vam Ace TUBING 10: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" CAPACITY' 0.01522 BBL/FT ~ ~ 6" 9-5/S" 47# L-SO BTM-C @ 9919'MD 45" X NIPPLE, @ 11228' MO' 3.813" 10 4.5" X NIPPLE, @ 11273' MO 3.813"10 4.5" XN NIPPLE, @ 11284' MO 3.725" 10 4.5" WLEG, @ 11297' MO 3 958" 10 - J 81 7", 26#/ft L-80. BTC-M @ 11461'MO J, FEfRPAllCN SJ\.Tl.f\R1' ÆFLffi 9/l.6L8T13'1B'02 AI\I1EA TKPFm=: l\!1e' FèfEf [0 Ra:lLCIion œ fa- histcriCc31 p;rf data h1JaI Fbi - 01arg:-: ~ FbNerJet. H\,K Fènetra1JCY1: 'Z1"; I-öe: æ: R'Iæ.e: EO cIeJ SZE g:¡:: NTIR.I AL ~D NTIR.I AI.. 1VD Q:nI& z 288 6 11755' - 11895' 1COO8' - 11133' QJ1 D\lE 3JZ2J 2fJJ2 PBTO @ 11943' MO TO @ 12029'MO 1 DATE 1/16/02 3/13/02 3/27/02 12/20/02 REV. BY BMH EMF EMF I::MI- COMMENTS ~S08 proposed Updated Depths Updated Perfs Updated KB Information . f KB. ELEV = 56' r<B-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 5 1/2" SSSV @ 1992' MO, 1989' TVO wI HRQ SVLN nipple - 4 562" 10 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4037' TVO (4238'MO) 5.5" GLM @ 4746' MD. 4489' TVO wI 4.62" 10 ~ .. ¡ 51/2" x 4 1/2" XO @ 9603'MD, 8959' TVD ~ - 7" LINER TOP @ 9741'MD 4,5" Fiber Optic Transducer 3.958" 10 @ 11208' MD, 10460' TVO (Sensor ELM TVO = 10480') ~ - 7" PACKER.13 Cr @ 11249' MD. , - 10500. TVO E 4.5" LINER TOP @ 11293'MO II I .. ~ 4.5". 12.6#. 13Cr Vam Ace Northstar WFI I : NS08 API NO: 50-029-23068-00 BP Exploration (Alaska) bp ~~~ :~ '.~ ...,."'.. Da[~: OG-15-2004 Transl1liUal NUl1lb~r: #92654 BPXA "YELL DATA TRANSMITTAL Please replace the previously issued materials with the data listed below. This data has been depth corrected to the primary depth control gamma ray acquired 10-31-2003. I'm sorry for any inconvenient. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com SW Name Date NS~9 i/ 04-13-2001 '1.-, .1 -O.{f 1/""'- '-' NS29 - ,.' 04-13-2001 NS29 (..... 04-13-2001 NS29 L/ 04-13-2001 NS~9 V 06-05-2001 NS19 ~ 06-05-2001 NS29 1//06-05-2001 V NS29 04-13-2001 L-"'/ tJ. c: I,.. ¿ i 9 N S 09, ~') /- ()'K~, NS 13, ,- ..>") O;¡. -()¿ I NSOS,'; - /Jrd NSI5 ...?cJ 2 -f,,'.J T 05-25-2004 Top Depth Bottom Depth Log Type 165 13469 CDR* MEASURED DEPTH LOG: FINAL DATA: I\IEASURED DEPTH: 13469 CDR* I\IEASURED DEPTH LOG: FINAL DATA: TRUE VERTICAL DEPTH: 13469 ADN* I\IEASURED DEPTH LOG: FINAL DATA: I\'IEASURED DEPTH: 13469 ADN* I\IEASURED DEPTH LOG: FINAL DATA: TRUE VERTICAL DEPTH: 13666 PLATFORI\I EXPRESS NEUTRON POROSITY LOG: 13666 DIPOLE SHEAR SONIC 1C\IAGER: Log Contractor Run SCH 8 SCH 165 8 SCH 165 8 SCH 165 x SCH 4800 SCH 4800 SCH 4745 SCH 161 SCH 13680 CASED HOLE ALFS EDIT FOR # / ú /70 COI\-tPENSA TED NEUTRON AND DIPOLE SONIC DATA ON CD RO~1 IE:\: OPEN HOLE ALFS EDIT FOR -1l:l:-/ ~ C\IEASUREC\IENT \VHILE DR[LLlNtr D 16 ""'- DATA ON CD ROM I L\: BP ALASKA NORTHSTAR PVT STUDY: FLUID STUDY: HARDCOPY: .. .. .-. --.......-.--....--. f~ ~ [1 ~ ~ ú ~ "' 0 ~ I 13527 ----------.....-....- .. Pc[ro[cdmil'al Daw Ccmcr LR2-1 900 E. Benson BinI. PO Box 196612 Anchorage, AK 99519-6612 bp ~~.~~ .' " , ... ".. '. ",1;.',-- BPXA WELL DATA TRANSMITTAL ~j) û1l~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) PClrotcchnical Data Center LR2-1 900 E. Benson BI\'<.I. PO Box 1l)66J:~ Anchorage. A K 99519-6() I::! Date: 06-15-2004 Transmittal Number: #92654 ?,( y&v? ÀG[}~'{ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 5pVl ¿ I j Fe& lJY~) Permit to Drill 2020210 Well Name/No. NORTHSTAR UNIT NS-O8 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23068-00-00 MD 12030 ..--- ìVD 11270 .'- Completion Date 3/22/2002/-- Completion Status 1-01L Current Status 1-01L UIC N ------------- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes -------------- ---- --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~-- Logl Data Digital Type Med/Frmt ¡'COg ¡..t'og , ì - ¿(Log I . ~D Electr Dataset Number Name Log Log Run Interval OHI Scale Media No Start Stop CH Received 2 Blu ; fIJ/'11 201 12030 Open 12/5/2002 5 Blu ðU~( 1 201 12030 Open 12/5/2002 2 BIUtHi11 201 12030 Open 12/5/2002 5 202 12030 Open 4/4/2002 Comments C -------------- ':.-r0671 -- -- - -- - - J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y/N Chips Received? Y/N Analysis Y/N Received? Daily History Received? Y/N ---~- Formation Tops '(þN Comments: ¿Vl.b of W{¡l! (:O) () y . ~ C /~v~LLI> J ~ t/}l ~l J i,,:'; ) - ------------ ---- ---- --- u- --,.- !U ~ J Vi u- A"-'Úw.---'C, ,tb; Compliance Reviewed By: Date: ----- - -- -- -- ---. -- - - - /- c¡ ¥JJji_Y- ___-d- FW: N* ,AOGCC tests '( I: "~ Subject: FW: N* AOGCC tests ( ~ V~ (éc,ls) Date: Wed, 10 Sep 2003 11 :32:54 -0500 From: "Wood, Ken R" <W oodK.R@BP.com> To: Jim - Regg@admin.state.ak.us, AOGCC _Prudhoe - Bay@admin.state.akus ~11 11nlù3 -----Original Message----- From: Wood, Ken R Sent: Thursday, September 04, 2003 2:49 PM To: NSU, ADW Well Operations Supervisor¡ NSU, ADW Well Integrity Engineer; Francis, Michael J¡ NSU, ADW WL & Completion Supervisor¡ 'scheve@admin.state.ak.us' Subject: N* AOGCC tests All, Northstar has completed the semi-annual test of the well safety systems. All equipment passed with the exception of the surface safety valve on NS-08. This SSV then passed a subsequent test after it was exercised several times. A copy of the test results is attached, we are in the process of forwarding the necessary documents to the appropriate agencies. Thanks, Ken Wood «9-1-03 SCSSSV State Test.xls» C ::::,:::: ~ ::: :;~::;: :::::: '~:~:~::' ::' ~::: ::'::::~::;' ~:::;::: :'" :::: ~ ::::,,' :~'::: ~::: :'::' ~':: ::::'::::~::::'::::;::: :..:~:' :~::::::::::..~~ :::: ::::':: ::' ::::' ~::~,,:'~::,,::,,':" ::':::: :,,' ::':' ::::::,,: :::..::'~ :'::::': ..~::: ,,':::':::: :..:': ~':':' ~:' :::::::'::::,,~: ':..:~' ::':::~'::::: :::'::' ::':": '; ~:::: ":',::;.. ::~:' :::' ::' ': '; ::': ':::::::::: :::: :..~ ':: '" ::.. ':"::,,':" , ~"~::...."".. "".. =="m...............'... ...................................,................................ .....J~?~?di~<~:1J~s~(j1..... ......................... ..."<T... TT..................................'......'.."""",......,v,....~! 1 of 1 9/12/2003 8:19 AM Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: bp Exploration Operator Rep: See Remarks '<Iù~ AOGCC Rep: Waived by C.C. ":'Y q\C!-\1V Date: 9/2/2003 Submitted By: Boots/Kulhavy Field/Unit/Pad: Northstar Separator psi: LPS 685 Date: 9/2/2003 HPS WellcI1Íl(4~ n- ~ r:.. c X--~-~; n~~~-.~1!!lfJtl.t- Well Permit Separ Set LIP Number Number PSI PSI Trip NS-06 2021010 685 550 P NS-07 2020770 685 550 P NS-08 2020210 685 550 P NS-09 2012190 685 550 P NS-12 2021100 685 550 P NS-13 2010860 685 550 P NS-14 2011180 685 550 P NS-15 2020540 685 550 P NS-16 2021270 685 550 P NS-17 2021690 685 3500 P NS-18 2021410 685 550 P NS-19 2022070 685 550 P NS-20 2021880 685 550 P NS-22 2022230 685 550 P NS-23 203-050 685 3500 P NS-24 2021640 685 550 P NS-27 2010270 685 3500 P NS-29 2000410 685 3500 P NS-31 2010600 685 3500 P _:,~~ iL~~ ~8ÎPA 7}~stl!J.~tß.št/~f/JJtlt~I:Well' Type; Test Test Test Date Tested and or Code Code Code Passed Retest or SI P P P 9/3/2003 P P P 9/2/2003 P 43 P 9/2/2003 P P P 9/2/2003 P P P 9/3/2003 P P P 9/3/2003 P P P 9/2/2003 P P P 9/2/2003 P P P 9/1/2003 P P P 9/3/2003 P P P 9/2/2003 P P P 9/3/2003 P P P 9/3/2003 P P P 9/3/2003 P P P 9/3/2003 P P P 9/2/2003 P P P Wl/20œ P P P 9/3/2003 P P P 9/3/2003 Oil, WAG, GINJ, GAS, CYCLE, SI OIL OIL OIL OIL OIL OIL OIL OIL OIL GINJ OIL OIL OIL OIL GINJ OIL GINJ GINJ GINJ Wells: 19 Components: n- 57 Failures: 1 Failure Rate: 1.75% 090 Day NS-8 SSV failed, increased 110 psi over 10 minutes, cycled SSV & retested 9/4/03 passed te Remarks: b 685 MMS/AOGCC MMS AOGCC AOGCC MMS MMS AOGCC AOGCC AOGCC AOGCC AOGCC AOGCC AOGCC AOGCC MMS AOGCC AOGCC AOGCC AOGCC AOGCC - ---'- Operations reps were: Darrell Donaldson, Jackson Meyer, Claire Donahue RJF 09/19/02 Page 1 of 1 2003-0902 SVS Northstar.xls - - bp (: ( tX ó~ - 6d-/ .,. ,"t.'~I. ........~ ~..~ ~.- ~.._-- *~ ~.... . I'.'J\" ". BP Exploration (Alaska) Inc, 900 East Benson Boulevard P, 0, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 7, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NSO8 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS08 well. This well has exhibited a high rate of decline and analysis of formation water indicates the formation of CaCO3 scale is likely. Additionally, CaCO3 scale was recovered from the offset NS13 wellbore using slickline. The procedure includes the following major steps: . Pickle the tubing . Bullhead HCI based acid treatment (which includes scale inhibitor) . Flowback Sincerely, tfJ?í c.-lv~ þ Mi~~~el J. Fraifcis:--P.E. Senior Petroleum Engineer BPXA, ACT, Northstar !q IG Jl', t"'ìnn'ì H~.J'l ~ iJ) (¡)I,J , ' , ". ORIGINAL \J-IGIt 1. /l-d { 2. 0 0 "3 Lif ~ /16:7 ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Alter CasinQ 0 ChanQe Approved ProQram 0 2. Operator Name: Suspend D Repair Well 0 Pull TubinQ 0 BP Exploration (Alaska), Inc. P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): RKB 56.00 8. Property Designation: ADL-312799 3. Address: Operation Shutdown D PerforateD VarianceD PluQ Perforations 0 StimulatelX! Time ExtensionO Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: Development 00 Exploratory 0 Stratigraphic 0 Service 0 9. Well Name and Number: NS08/' 10. Field/Pool(s): Annuar Disposal 0 OtherD 5. Permit to Drill Number: 202-0210 /' 6. API Number /' 50-029-23068-00-00 Northstar I Northstar 11. Total Depth MD (ft): 12030 Casing PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11270.28 11942 11071.03 Length Size MD TVD Conductor Surface 3284 13-3/8" 68# L-80 Intermediate 9873 9-5/8" 47# L-80 Liner 1720 7" 26# L-80 Production Liner 736 4-112" 12.6# 13CR80 Perforation Depth MD (ft): Perforation Depth TVD (ft): 117551 -118951 10998.11 -11136.51 Packers and SSSV Type: 7" Baker Liner Top Packer /7" Baker Permanent Packer 4-112" Baker Liner Top Packer /5-1/2" WRDP-2 SSV 12. Attachments: Description Summary of Proposal 00 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for 8/20/2003 /1 Commencing Operation: 16. Verbal Approval: Commission Representative: Date: top bottomltoD bottom 44 46 9741 11293 - 3328 - 9919 - 11461 - 12029 44 - 3220.1 46 - 9248.6 9085.7 - 10708.1 11543.1 -11069.3 Plugs (measured): IJunk (measured): Burst Collapse 5020 6870 7240 8430 2270 4760 5410 7500 Tubing MD (ft): 40 - 9603 9603 - 11297 Tubing Size: 5-1/2" 4-1/2" Tubing Grade: 17# 13CR80 12.6# 13CR80 Packers and SSSV MD (ft): 9741 /11249 /11293 /1992 13. Well Class after proposed work: Exploratory 0 Development~ 15. Well Status after proposed work: Oil[!] GasD PluggedD AbandonedD WAGD GINJD WINJD WDSPLD Perpared by S. Copeland 564-4424 Printed Name 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact ServiceD Mike Francis Signature Michael Francis Title Production Engineer ~ lL~o<VY'e.1. Phone 564-4240 Date 8/14/03 ~ -J Commission Use Only Plug Integrity D BOP TestD Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity TestD Other: I.ÒJ!C,l)lI'ìil'VI./1Il"".,:.'. [..::I.~, ".". lNI.!J)~v\Q, LL"l /1-, Subsequent Form Required: to--4oL/ Approved by: lto.- ~ II --~ Form 10-403 Revised 2/2003 Sundry Numb3~,3-  1-  Location Clearance 01'"';: "_"".' C', ',.,," ,.\ !)"Z.. """." ,I , /..:1.t J C.'. oj,' IQ " t:.¡ . [1 " I ~ " A" IG 1 r: 'ÌO(") U ,JJ J!. ~,Ð / ,.,} J ", I' ,.. '.., "', ,II, BY ORDER OF THE COMMISSION Date: ry/g/Ò3 SUBMIT IN DUPLICATE bp .,~ ,\It.'~I. ........ ~ ~.. ~ ~4!:- --:.~ ...~ ~..... .;~,.~~\. ". ( ( To: Gary McBride/John Smart - Well Operations Supervisor August 8, 2003 From: Mike Francis and Patty Hill - Northstar Subject: N508 DAD Acid/51 Treatments AFE N5Z832018 Est. Cost: $60 M lOR: Est 500 BOPD Please perform an acid stimulation/SIT with 12% DAD acid on the NS08: Type lOR PR N DSWL AFE Job Description Priority Comments/Other 0 500 NS08 NSZ832018 Pump Acid and SIT NS08 has suffered significant decline since start-up. The water chemistry indicates CaCO3 scale formation is likely and the presence of scale has been confirmed in the offset NS 13 well. This treatment will dissolve the scale and place scale inhibitor in the formation. The treatments are being combined to simplify logistics. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. AU 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 7. Pump the following fluids to pickle the production tubing at 3 bpm, 3500 psi max pressure. a) 18 Bbls 12% DAD acid b) 133 Bbls seawater c) 97 Bbls diesel 8. Produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 248 Bbls. I 1 '\ ," ,{ 9. Pump the following treatment at maximum rate or 3500 psi max pressure. a) 33 bbls 12% DAD Acid b) 253 bbls Seawater (To displace acid to perfs) c) Shut down for 30 minutes and allow acid to soak d) 186 bbls Seawater (for over flush and displacement) e) 97 bbls Diesel (for displacement and under-balance) 10. Shut well in for 4 hours to allow scale inhibitor to precipitate. 11. AD Schlumberger. 12. Flow back Procedure: For flow back, line up into the test separator and well cleanup tank. Produce clean-up volume of 570 bbls. After clean-up, divert back to the plant and get 2 6-hour tests. 13. Two days after well is cleaned up and stabilized, perform a closure test on the SSSV. Fluid descriptions: 12% DAD Acid to contain: 10% Nalco Scale Inhibitor + 0.6% A261 + 4 ppt A 179 + 8 ppt A 153 + 0.2% F103 + 20 ppt L58 + 1 .5% U74 + 100/0 Xylene Note: Acid strength to be verified and documented via titration before leavin~"J Schlumberger. Results will be available on location. Procedure Contacts: Mike Francis WK: 564-4240 HM: 644-0534 Cell: 529-8678 Patty Hill WK: 564-4346 HM: 248-6262 Cell: 350-0742 TREE: ABB-VGI 5 1/8" 5ksi ".. WELL~HEAD: ABB-VGI 13-5/8" ( Multibowl 5ksi 13 3/8" TAM Port Collar at +1-1582'MD 13 3/8", 68#/ft, L-80, BTC @ 3328'MD 5.5", 17#/ft, 13-Cr, Vam Ace TUBING 10: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813" 10 4.5" X NIPPLE, @ 11273' MD 3.813" 10 4.5" XN NIPPLE, @ 11284' MD 3.725" 10 4.5" WLEG, @ 11297' MD 3.958" 10 7", 26#/ft L-80, BTC-M @ 11461'MD FEH\H\ 1m Sl.I\IfIh\R( ÆFLæ Sl\6USIT(2{1ß102) AN3..E AT llF FER=: N::te: Rier to R"cx:Itdicn æ for historical perf data hitial Fài - Olarge: 2OCB RMter Ja:,1-M(; Fènetratiort: 'lJ"; I-I:)e: .æ"; A1ase: 00 ~ NTEW AL M) I NTEW AL lW ~ 2.88 6 117f8-1189B 1Œ93'-11135' Q:n PBTD @ 11943' MD TO @ 12029'MD NSO8 a\lE 2{'l2fðJJ2 DATE 1i16i02 3/13/02 3/27/02 12/20/02 REV. BY I (' ',KB. ELEV = 56' '<B-BF. ELEV = 40.1' BASE FLANGE ELEV = 15.9' 51/2" SSSV @ 1992' MD, 1989' TVD wI HRQ SVLN nipple - 4.562" 10 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD wI 4.62" ID 51/2" x 4 1/2" XO @ 9603'MD, 8959' TVD - 7" LINER TOP @ 9741'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') - 7" PACKER,13 Cr @ 11249' MD, 10500' TVD 4.5" LINER TOP @ 11293'MD 4.5",12.6#, 13Cr Vam Ace Northstar WELL: NS08 API NO: 50-029-23068-00 BP Exploration (Alaska) ( ~C bp ,~~:~~~. .. .. ' ".. .. ,... .... "... 6ø;.tit('-- Date: 12-5-2002 Transmittal Number:92602 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Lo Run De th 100,101, 201 200,300, 400 100,101,\ 201 200,300, 400,401 100,101,1 201 200,300, 400,401 100,200.1 201 300,400, 500 100,200.1 201 300,400, 500 100,200.1 0 300,400, 500 1,2,3,4 I 201 SW Name Date Contractor NS06 06-07 -2002 SPERRY --I SUN () ""ìINS06 '1J 1NSO6 l06-07 -200~ SPERRY SUN MUDLOG-2"-TVDLOG 13396.9 lO6-03-20~ I SPERRY SUN MUD LOG - 2" - MD LOG 13396.9 .¡ l05-15-2002 SPERRY SUN MUD LOG - 5" - MD LOG NS07 13529 v ';:INS07 0 ( I 0NS07 -~., .NS08 - ~INS08 ~NSO8 I ,NS12 C .;: NS12 ~INS12 ro , NS14 MUD LOG - 2" - TVD LOG 05-15-20021 SPERRY SUN 13529 ( 105-15-20021 SPERRY SUN MUD LOG - 2" - MD LOG 13529 Ii -l03-10-20021 SPERRY SUN 03-10-20021 SPERRY 11,2,3,4 I 201 SUN 03-10-2002\ SPERRY 11,2,3,4 I 201 SUN 06-27 -2002 SPERRY v' SUN 06-27 -2002 SPERRY /1 SUN / 06-27-2002 SPERRY v SUN , " -""" ," ,..M ','.' , ~ q~-Ð9~20Ð2, / ,$ c ,~RRY II'" SUN ÒC NS14 02-09-2002 ,'SP'ERRY 11,2,3,4 I 201 ::::. .¡ 'SUN \ Õ NS14F~'}':I~ 02~09~2002: ¡)S'PEHFtY ::'11,2,3,4 I 201 ".i>."""'Õ" ,'/' SUN \ .,/' "; ,.... I" NS15 04-13-2002 SPERRY 100,200,1 201 -:::r SUN' 300,400, 8 -/ 500 I NS15 04-13-2002 SPERRY 100,200,1 201 ~ I SUN 300,400, ~ MUD LOG - 5" - MD LOG 12030 MUD LOG - 2" - TVD LOG 12030 MUD LOG - 2" - MD LOG 12030 100,200,1 201 300 100,200,1 201 300 100,200,f201 300 1,2,3,4 I 201 MUD LOG - 5" - MD LOG 13135 MUD LOG-2"-TVD LOG 13135 MUD LOG - 2" - MD LOG 13135 MUD LOG - 5" - MD LOG 13020 MUDLOG-2"-TVDLOG 13020 13020 MUD LOG - 2" - MD LOG 15370 MUD LOG - 5" - MD LOG MUD LOG - 2" - TVD LOG 15370 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp 'D"á,~ ~'~"'l",'tJ{ -..'/ -' ,,'Iff .'-" ~" '-.. , ' ... . "" .,,- (' { Date: 12-5-2002 Transmittal Number:92602 \ 500 NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - MD LOG SUN 300,400, / 500 NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 5" - MD LOG \' ./ SUN' ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - TVD LOG ( / SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - MD LOG ~ I SUN NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 5" - MD LOG SUN 200,201, 300,301, v 400,401 -- NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 2" - TVD LOG ~ SUN 200,201, -... . 300,301, í(J / 400,401 0 NS18 08-06-2002 SPERRY 100,101, 201 1 6550.4 MUD LOG - 2" - MD LOG ra SUN 200,201, " / ,~ 300,301, 400,401 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 5" - MD LOG -::,-. v SUN 300 -9> NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - TVD LOG -- ~ V' SUN 300 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - MD LOG CO (' SUN 300 B PXA WELL D A T A TRANS MITT AL ~~g~n one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ayherd (DNA) Attn: Doug Choromanski (MMS) RECEIVED DEe 05 2002 AI.. Oü & Gaa Cona. Comrniau8on ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ( t Date: 04-012-2002 :Transmittal Number:9245 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. NS-08 02-12-20021 SPERRY - - - SW Name Date Contractor ¿p \ NS-08 03-18-2002 SCH # 'K»-..D5~ INS-15 04-08-20021 ANADRILL 15370 - 0 ~ ~d R f h' . I ease Ign an eturn one copy 0 t IS transmltta . Thank You, James H. Johnson Petrotechnical Data Center .- Attn: Howard Okland (AOGCC) t-./SA Ultl"~¡;/~ Attn: Buford Bates (Murphy Exploration (Alaska), mc Attn: Doug Choromanski END OF WELL REPORT; MUD LOGS & DISKETTE INCLUDED; DIRECTIONAL SURVEY; HARDCOPY/DISKETTE; RECEIVED f,PR 2 Z 2002 Alaska Oil & Gas COns. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 y bp ~1.., ~\i~":'~""::(' ..::.')~' *"1: ,,', ~, f Date: 04-012-2002 Transmittal Number:92451 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor LoQ Run Depth Bottom Depth LoQ T vpe NS-08 03-18-2002 SCH 1 55 11910 JEWELRY LOG; ULTRASONIC IMAGING TOOL; NS-08 03-19-2002 SCH 1 11400 11919 PERFORATING RECORD; dOd -ad) é2{y~ ' ~ -- Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED t.Pr< 1 Z 2002 Alaska Oil & Gas Cons. commision Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 1. Status of Well Ø!a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1119' NSL, 642' WEL, SEC. 11, T13N, R13E, UM , ... . At top of productive interval ' ..3~2i .-oz-, 3909' NSL, 3075' WEL, SEC. 11, T13N, R13E, UM; ~'[~';i~'-¡~11-- ; ;> ,~ At t~tal depth, : .----.ßl?---...--. .: ~ '." - " I- 3957 NSL,3098 WEL, SEC. 11, T13N, R13E, UM """""'-"""" "-""""'" 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 55.7' ADL312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 2-13-2002 3-6-2002 3,:~2002 ß 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12030 11270 FT 11942 11183 FT Ø!a Yes 0 No 22. Type Electric or Other Logs Run GR, DIR, RES, PWD, DEN, NEU, USIT, CCL 23. CASING SIZE 20" 13-3/8" 9-5/8" l' 7" WT. PER FT. 169# 68# 47# - 26# 12.6# 4-1/2" { STATE OF ALASKA \ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( Classification of Service Well 7. Permit Number 202-021 8. API Number 50- 029-23068-00 9. Unit or Lease Name Northstar Unit 10. Well Number NSO8 11. Field and Pool Northstar Unit 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1992' MD 1545' (Approx.) GRADE X-56 L-80 L-80 - L-80 13Cr CASING. LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 201' 20" Driven 44' 3328' 16" 590 sx PF 'L', 470 sx Class 'G' 46' 9919' 12-1/4" 553 sx Econolite 517 sx Class 'G' 9741' 11461' 8-1/2" 273 sx Class 'G' 11293' 12029' 6-1/8" 105 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD 11755' - 11895' 10998' - 11137' 27. - Date First Production March 22, 2002 Date of Test Hours Tested 3/22/2002 4 Flow Tubing Casing Pressure Press. 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2, 17#, 13Cr 9603' 4-1/2", 12.6#, 13Cr I 9603' - 11297' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED Freeze Protected with 284 Bbls of Diesel. PACKER SET (MD) 11249' PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL -BBL TEST PERIOD 3546 CALCULATED 24-HoUR RATE GAs-McF 7303 GAs-McF OIL GRAVITY-API (CORR) CHOKE SIZE WATER-BBL 0 WATER-BBL GAS-OIL RATIO 2060 OIL-BBL 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, ga No core samples were taken. Form 10-407 Rev. 07-01-80 APR 11 2002 AIaIka Oil & GIs Cona. COInmisiOn Anchorage .- 2~bmit In Duplicate u ,-- RBOMS 8FL f { 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Kuparuk A 9671' 9021' Top of Sag River Sand 11474' 10721' Top of Shublik 11572' 1081T Top Sadlerochit Sands 11664' 10908' Top of Northstar Zone 'C2' 11782' 11025' Top of Northstar Zone 'C1' 11828' 11070' Top of Northstar Zone 'B' 11873' 11115\ Top of Northstar Zone 'A2' 11912' 11153' Top of Northstar Zone 'A l' 11958' 11199' RECEIVED Top of Kavik Shale 11990' 11230' Top of Lisburne 12063' 11303' APR 1 1 2002 Alaska 011 & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak Off Test Summary and a Post Rig Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~! Signed Sandra ~a!2J.t=~)V~f.JS'v---- Title Technical Assistant Date ()~- IO..()L NS08 Well Number 202-021 Permit No. / Approval No. Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/12/2002 2/13/2002 2/14/2002 2/15/2002 (: {" Page 1 of 13 BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E 08:00 - 10:00 From - To I Hours IActivity! Code I NPT P PRE 10:00 - 10:30 10:30 - 18:00 18:00 - 20:00 00:00 - 02:00 02:00 - 05:00 05:00 - 10:00 10:00 - 14:30 14:30 - 16:30 16:30 - 18:00 18:00 - 20:30 20:30 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 02:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08:30 08:30 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 -13:00 13:00 -17:00 17:00 - 18:00 18:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 03:00 2.00 I MOB 0.50 I MOB 7.50 MOB 2.00 I MOB 2.00 I RIGU 3.00 RIGU 5.00 I RIGU 4.50 I RIGU 2.00 I RIGU 1.50 DRILL 2.50 DRILL 2.00 DRILL 0.50 DRILL 0.50 I DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 4.00 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 1.50 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 4.00 DRILL 1.00 DRILL 4.00 DRILL 1.00 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL Phase P P PRE PRE P PRE N N HMAN IPRE HMAN PRE P PRE P PRE P P PRE SURF P P P SURF SURF SURF P SURF P P P P N SURF SURF SURF SURF HMAN ISURF P P P P P P P P P P P P P P P P SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Description of Operations RID Pipe rack lines & bulid berms. Clean up cellar & steps on back of rig. PJSM before rig move. Move off NS-14 toward NS-08. Quit moving. Warm up moving system. Turn up pressure. At 1400 hrs, moving rig again. Rig is spotted over NS-08 @ 1800 hrs. RU lines and continue to berm around rig. Clean up herculite from NS-14. Set Geronimo line, set all steps and handrails. Work on thawing frozen injection line. Bring riser into cellar. Continue working on frozen injection line. Thawed out. MU 4" again. Continue RU. Button up all pipe rack lines & clean-up area on NS-14. Turn over NS-14 to operations @ 9:00 am. Cover NS-9 and NS-10 wellhouse with herculite. NU Surface riser, mouse hole, roughneck track. RU turn buckles. Run musd through lines and check for leaks. Perform D7 drill. RU tools for BHA#1 MU. MU BHA #1- (16" T69 Bit, jetted 1 x12 and 3x20 I Motor! Orient Subl Mon. stabl Mon LCI X-over). Tag ice. Drill ahead through ice and out 20" drive shoe to 228'. PJSM. RU Schlumberger WIL for gyro. Run in hole wI gyro. Initial survey@ 157' md: Incl 0.65 degl Azi 3.40 deg. Turn TF to 100 deg and slide 40'. Rotate down stand. Deviation survey. Good. Drill ahead. Drilling ahead 16" hole from 318' to 406' md. Survey & Pooh. PJSM. MU BHA#2. Floorman cut little finger when wiping off collar with gloved hand. He was trying to mark a line on pipe. Sent to Medic where he received 4 sutures. Returned to work. Gathered entire rig team and discussed accident and how to prevent another hand injury. Team decided that absorbant or rags to be used to wipe down tools--not gloves. Pictures taken of tong burrs on collar. Continue MU of BHA#2. CBU. Gyro survey and orient TF. Drill ahead 16" from 406' to 580' md. Blow down lines & Gyro. Drill ahead 16" from 580' to 760' md. Blow down lines & Gyro. Change shaker screens & clean pump screens. Drill ahead f/760'- 947' md. Blow down lines & Gyro. Drill ahead f/947'-1291' md. Blow down lines & Gyro. Drill ahead f/1291' to 1576' md. Pump sweep. Blow down lines & Gyro. Drill ahead f/1576' to 1674' md. Drill ahead 16" hole from 1674'-1862' md. Blow down lines and Gyro survey. Printed: 3/18/2002 1:48:05 PM BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/15/2002 03:00 - 09:00 6.00 DRILL P SURF Drill ahead from 1862'- 2432 md. 09:00 - 10:30 1.50 DRILL P SURF BID lines and Gyro survey. 10:30 - 20:00 9.50 DRILL P SURF RD Schlumberger and Gyrodata. Drill ahead from 2432' to TD @ 3344' md. Final TVD 3234.18', Incl = 26.56 deg, and az = 318.26 deg. 20:00 - 21 :30 1.50 DRILL P SURF Pump 75 bbls high vis Barofibre sweep. Sweep carried -30% excess cuttings. Circulate a total of 17352 strokes (2+ total surf to surf vols.). Returns clean. 21 :30 - 00:00 2.50 DRILL P SURF POOH to 1600' md. Note: Clean PUW off btm 175k. Check flow. Pump dry job. Blow down lines. TOH. Hole in good condition. Max drag 10k. 2/16/2002 00:00 - 01 :00 1.00 DRILL P SURF POOH with Drill Pipe to 1600' md. Note: Hole in great shape with no significant overpulls. 01 :00 - 05:30 4.50 DRILL P SURF Continue to POOH, stand back HWDP and LD BHA#2. Note: Flush MWD and Motor with Fresh H2O. Some clany on stabilizers but overall pretty clean. 05:30 - 06:00 0.50 DRILL P SURF Clean rig floor. 06:00 - 08:00 2.00 CASE P SURF PJSM-- RU casing running equipment. 08:00 - 08:30 0.50 CASE P SURF RU Franks Circ Tool and Mu mandrel hanger on lower portion of landing joint and set back on short side of pipe shed. 08:30 - 09:00 0.50 CASE P SURF PJSM for running 13-3/8" surface casing. 09:00 - 12:00 3.00 CASE P SURF MU 13-3/8" float track, engage Franks Fill Up Tool and circulate float track volume. Continue RIH with 13-3/8" casing to Joint 19. Note: Bakerlocked thru pin end of joint 3 into Float Collar. 12:00 - 16:30 4.50 CASE P SURF Change crews and continue to Rlh with remaining 62 joints of 13-3/8" casing. Note: Total of 81 joints 13-3/8" 68# L80 BTRC Casing RIH. 16:30 - 18:00 1.50 CASE P SURF MU lower portion of landing joint with mandrel hanger, break out lift sub, remove rotary table and lower hanger into riser. Replace rotarty table, MU upper portion of landing joint and land mandrel hanger. MU cement head. Note: PU was 330K, SO was 185K -- landed hanger in tension with 185K which includes 75K for traveling equipment. 18:00 - 20:00 2.00 CEMT P SURF Break Circulation and gradually increase rate to 12 bpm with no sign of losses. 20:00 - 20:30 0.50 CEMT P SURF Pump 5 bbls of Sea Water and Test Lines to 3500 psig. Pump 75 bbls of Alpha Spacer and pump drop bottom Plug. 20:30 - 22:30 2.00 CEMT P SURF Pump Surface Cement Job as follows: 439 bbls 10.7 ppg Lead Slurry (Permafrost L), and 100 bbls 15.8 ppg Tail Slurry (Premium G wI 2% CaCI2) @ 5-6 bpm. 22:30 - 00:00 1.50 CEMT P SURF Release top plug and flush wI 25 bbls SW from HAco. Switch to rig pumps for displacement wI 9.0 ppg mud @ 10 bpm. Slow rat to 5 bpm @ 4400 strokes. Bump plugs @ 4640 strokes (464 bbls on Halliburton meter). Pressure up to 1445 psig. Hold pressure for 3 mins. Bleed off pressure to 0 psig to check floats. Begin RD cement equipment. Note: Estimated returns: 50 bbls cement contaminated mud and 50 bbls of clean cement (approximately 100 bbls excess). Caught cement sample. ( ( ( Printed: 3/18/2002 1 :48: 05 PM ~r <' " BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/17/2002 00:00 - 05:00 5.00 CEMT P SURF Finish post cement cleanup and rig down. Clear floor of cement head, landing jt, casing tools, etc. Wash out rotary table. Clean pits (L-pit in particular). 05:00 - 08:30 3.50 CEMT P SURF Pull riser & mousehole and LD in pipe shed. Take lower sections of riser through cellar. 08:30 - 12:00 3.50 CEMT P SURF NU VETCO multibowl WH spool and test to 5000 psig. NU single gate and mud cross. 12:00 - 14:30 2.50 CEMT N RREP SURF Repair bridge crane. Spool bridge crane lines. 14:30 - 20:30 6.00 CEMT P SURF Nipple up BOPE stack. 20:30 - 00:00 3.50 CEMT P SURF Pressure Test BOPE stack. Note: AOGCC Rep "Lou Grimaldi" waived right to witness test. 2/18/2002 00:00 - 02:30 2.50 CEMT P SURF Finish Testing BOPE -- Blowdown lines. Note: Failed Valve in choke manifold -- redressed and tested. 02:30 - 03:00 0.50 CEMT P SURF Pull Test Plug, Run Wear Ring & LD Test Joint. 03:00 - 06:00 3.00 CEMT P SURF PJSM -- MU, pump thru and visually check the Rotary Steerable Tools. 06:00 - 08:00 2.00 CEMT P SURF Finish MU BHA. Note: Change out stabilizer blades. The rotary motor is being worked on -- affects BHA MU time. 08:00 - 10:00 2.00 CEMT P SURF RiH with HWDP and shallow test MWD. Blowdown lines. 10:00 -12:00 2.00 CEMT P SURF RiH and tag cement at 3210' md. Drill cement to 3220' md. 12:00 - 13:00 1.00 CEMT P SURF Drill Cement fl 3220' - 3242' md -- tag plugs on top of float collar. 13:00 - 14:00 1.00 CEMT P SURF Test casing to 3500 psi for 30 minutes -- chart. Notes: Racked back stand of dp, blewdown top drive, MU TIW Valve and King pin, rig up cement hose to standpipe manifold, shut in on top pipe rams variable bores, open HCR and pump down both drill pipe and kill line. Bleed pressure and RD TIW valve and king pin, MU top drive. 14:00 - 17:00 3.00 CEMT P SURF Drill Float track, rathole and 20' of new formation to 3364' md. Note: Pumped 600 to 700 gpm while rotating 40 to 60 rpm while drilling cement with 10 to 14 WeB. 17:00 - 19:00 2.00 CEMT P SURF Displace well to new mud 8.8 ppg. 19:00 - 20:00 1.00 CEMT P SURF Perform FIT to 12.6 ppg emw -- chart. Note: Pull up into shoe with rotary steerable and bit while racking back on stand of dp. Shut in on annular preventer, open HCR and pump down dp and kill line. Bleed off pressure thru bleed line, blow down kill line and surface lines and open annular preventer. 20:00 - 23:00 3.00 DRILL P INT1 Slip and Cut drill line and service top drive. 23:00 - 00:00 1.00 DRILL N FLUD INT1 Calibrate tools. Check Pump #1- hammering. SO clean suction screens and dicover fish eyes. Fish eyes also coming back on shaker screens. Prematurely changed screens on shakers 2 and 3 to 35. Re-evaluated and decided to change screens back. Shakers 1-4 are 100, 80, 80, and 100 mesh respectively. 2/19/2002 00:00 - 02:00 2.00 DRILL N FLUD INT1 Condition mud & circulate fish eyes. Plugged off suction screens. 02:00 - 04:00 2.00 DRILL P INT1 Drill from 3364' to 3676'. 04:00 - 05:30 1.50 DRILL P INT1 Downlink RSS Power Drive Unit. Note: Shut down and check for flow so necessary to perform downlink 2x. 05:30 - 08:30 3.00 DRILL P INT1 Drill from 3676' to 4144'. Printed: 3/18/2002 1 :48:05 PM (' .( \ BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/19/2002 08:30 - 09:00 0.50 DRILL P INT1 Downlink RSS Power Drive Unit. 09:00 - 12:00 3.00 DRILL P INT1 Drill from 4144' to 4557'. Note: No indication that RSS is responding to downlinks. 12:00 - 12:30 0.50 DRILL P INT1 Downlink RSS Power Drive Unit. 12:30 -14:00 1.50 DRILL P INT1 Drill from 4557' to 4713'. Note: No indication that RSS is responding to downlinks. Decision to pull based on directional and close approach. 14:00 - 15:00 1.00 DRILL P INT1 PJSM - Circulate sweep & clean hole. 15:00 -15:30 0.50 DRILL P INT1 Shut down & observe well. Pull 2 stands slowly & check for swabbing. Pump dry job and blow down lines. 15:30 - 22:00 6.50 DRILL P INT1 POOH to 13-3/8" shoe. Note: POOH 8 stands with no problem. POOH an addtional 5 stands -- hole swabbing but able to wipe off. Attempt to pull stand 14 while swabbing -- unable to wipe off ball. RIH with stand 13 and wipe off ball -- rerack stand 13. Attempt to pull stand 14 while swabbing -- unable to wipe of ball. MU Top Drive and and back ream stand 14 -- rack back. Attempt to pull stand 15 while swabbing -- pump out of hole with stand 15. Pump out of hole with stand 16 and while pulling RSS and bit into the shoe. Circulate dry job out of casing while pumping another dry job. 22:00 - 23:30 1.50 DRILL P INT1 POOH while LD BHA #3. Notes: 1. BHA was very clean with no sign of clay. 2. Bit and stabilizers in gauge. 3. Pumped thru RSS and Bias Tool was flowing thru all 3 pads which indicates that there was a problem -- no steering capability. 4. Broke out Bias Tool and looked like the lower torquer shaft was broken. 23:30 - 00:00 0.50 DRILL P INT1 Service Rig. 2/20/2002 00:00 - 01 :30 1.50 DRILL P INT1 M/U bit, motor, LC, Stab, LWD & MWD. Unable to pull bit back through wellhead to orient tool face. 01 :30 - 03:30 2.00 DRILL N DPRB INT1 Orient BHA 90,180,270, & 360 degrees & attempt to pull BHA through stack unsuccessfully. 03:30 - 04:30 1.00 DRILL N DPRB INT1 Discussed problem with rig team & compare wellhead & BOP measurements with BHA to determine location of problem. The initial prognosis is that the top of the bit is hanging up at the transition area between the 13 3/8" hangar and the casing spool. 04:30 - 05:00 0.50 DRILL N DPRB INT1 Rotate at low RPM while attempting to pull past problem area. Gained .4' but still not able to pull free. Prognosis is top of bit is hanging up at base of bowl protector. 05:00 - 05:30 0.50 DRILL N DPRB INT1 Lower bit & pump 50 SPM while atempting to POH. Still hanging up. Motor stalled indicating bit was locked up. 05:30 - 07:00 1.50 DRILL P INT1 Finish M/U BHA. 07:00 - 08:00 1.00 DRILL N DPRB INT1 Waiting on decision while rig team discusses options with Anchorage team. 08:00 - 09:30 1.50 DRILL N DPRB INT1 Waiting on x-over to pull bowl protector. Repair accumulator hose on top drive while waiting. 09:30 - 11 :30 2.00 DRILL N DPRB INT1 Pull & inspect bowl protector. Scrapes from stabs. & bit evident. 11 :30 - 12:00 0.50 DRILL N DPRB INT1 Re-run bowl protector. Printed: 3/18/2002 1 :48: 05 PM ( ( BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/20/2002 12:00 - 14:00 2.00 DRILL N DPRB INT1 Pull bowl protector, inspect, & re-run. 14:00 - 15:30 1.50 DRILL N DPRB INT1 POH to tight spot & RIU to pull. Pulled free. This was accomplished by pulling the string over to one side opposite the kick pad on the motor while picking up. Final prognosis was that the kick pad on the motor was hanging up at the interface between the ram cavity & the mud cross. 15:30 -17:30 2.00 DRILL N WAIT INT1 Clean rig while waiting on rotary steerable motor. 17:30 - 21 :00 3.50 DRILL P INT1 Change out BHA. RIU steerable assy & service top drive. 21 :00 - 22:00 1.00 DRILL P INT1 RIH & test steerable assy. Okay 22:00 - 23:00 1.00 DRILL P INT1 Program MWD. 23:00 - 00:00 1.00 DRILL P INT1 RIH to bottom of HWDP & test MWD. Okay. 2/21/2002 00:00 - 03:30 3.50 DRILL P INT1 RIH from 3320' to 4334'. Wash & ream from 4334' to 4713'. 03:30 - 07:00 3.50 DRILL P INT1 Drill from 4713' to 5127'. 07:00 - 07:30 0.50 DRILL P INT1 Downlink. 07:30 - 09:30 2.00 DRILL P INT1 Drill from 5127' to 5476'. 09:30 - 10:00 0.50 DRILL P INT1 Downlink. 10:00 - 15:00 5.00 DRILL P INT1 Drill from 5476' to 5856'. 15:00 - 15:30 0.50 DRILL P INT1 Downlink. 15:30 - 19:30 4.00 DRILL P INT1 Drill from 5856' to 6235'. 19:30 - 20:00 0.50 DRILL P INT1 Downlink. 20:00 - 00:00 4.00 DRILL P INT1 Drill from 6235' to 6440'. 2/22/2002 00:00 - 08:30 8.50 DRILL P INT1 Drill from 6440' to 6899' MD. Pumped hi vis sweep @ 03:30. 08:30 - 09:00 0.50 DRILL P INT1 Pump hi vis sweep (3400 stks) 09:00 - 10:00 1.00 DRILL N RREP INT1 Repair drag chain in shaker room. 10:00 - 14:00 4.00 DRILL P INT1 Montior well, check for swab, pump dry job, blow down lines & POOH. Notes: 1. First 15 stands pulled fine. 2. Next 10 stands showed signs of swabbing -- able to wipe off. 3. After pulling bha thru previous bit depth at 4713' swabbing was minimal and hole was in good shape. 4. Hole fill was good and after pulling thru Ugnu there was signs of seepage losses where 5 stands took between 5 and 7 bbls versus the previous 3.5 bbls. 14:00 - 16:00 2.00 DRILL P INT1 Handle BHA # 5. 16:00 -16:30 0.50 DRILL P INT1 Clear floor of tools. 16:30 -18:00 1.50 DRILL P INT1 M/U BHA # 6. 18:00 - 21 :00 3.00 DRILL N DPRB INT1 Bit would not go through bowl protector. Pull bowl protector & smooth top wI grinder. Miter motor kick pad wI grinder. Re-install bowl protector. Note: Necessary to turn bit so junk slot was oriented high side, orient BHA so high side was pointing to DS tugger, Rig up cable from ODS Break Out Cathead and suck pipe up against SE side of hole while lowering bha into hole. 21 :00 - 22:30 1.50 DRILL P INT1 Continue RIH wI BHA #6 & HWDP. Note: Met with control room after pooh and analyzed the load swings on turbine. Obvious from data that it will be necessary to go to 2 turbines while tripping pipe after surface caisng is set. D5 alarm was set off several times and company rep was present on the rig floor to ensure that throttle was applied gradually throughout trip. Printed: 3/18/2002 1 :48:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/22/2002 2/23/2002 2/24/2002 2/25/2002 (' (' Page 6 of 13 BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E 22:30 - 23:00 From - To I Hours I Activity I Code I NPT P 23:00 - 00:00 00:00 - 03:30 03:30 - 12:00 12:00 - 00:00 00:00 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 00:00 00:00 - 03:00 03:00 - 05:00 05:00 - 09:30 09:30 - 13:30 13:30 - 17:00 17:00 - 17:30 17:30 -18:00 18:00 - 21 :00 21:00-21:30 21 :30 - 22:00 0.50 I DRILL 1.001 DRILL 3.50 I DRILL 8.50 I DRILL 12.00 I DRILL 7.00 I DRILL 1.00 DRILL 0.50 I DRILL 3.50 I DRILL 2.00 I DRILL 0.50 I DRILL 9.50 DRILL 3.00 DRILL 2.00 DRILL 4.50 DRILL 4.00 DRILL 3.50 DRILL 0.50 DRILL 0.50 DRILL 3.00 DRILL 0.50 I DRILL 0.50 DRILL P P P P P P P P P P P P P P P P P P P P P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Phase Description of Operations Test MWD (okay) Note: Move pipe while testing MWD to minimize any possible damage due to rotating PDC bit in casing while on BH motor. Lubricate rig & service top drive. Note: Called control room and notified them of 2nd turbine requirement. RIH to 6899' filling pipe. Hit tight spots @ 5080',5800', & 6100'. Worked through without pumping. Ream last stand to bottom. Pump nut plug sweep while breaking in new bit. Rotate & slide from 6899' to 7590'. Pumped hi vis sweep at 7500'. Drill & slide from 7590' to 8580'. Note: ART: 10.88 hrs. AST: 3.6 hrs. Drilled f/8580' to 9013' md. Circ Hi-Vis Sweep, Shut down pumps and monitor well. Note: Shakers cleaned up pretty well. Pull one stand -- no swab, pump dry job, blow down top drive, mud pump and bleeder line. Short trip to 6700' (2 stands above last bit trip). Notes: 1. Hole in good shape -- 30 to 40K overpull and swabbing across the Schrader Bluff fm. 2. Displace mud and add baranex in preparation for weight up. Drill f/9013' to 9111' md. Notes: Weighting up from 9.1 ppg to 9.6 ppg by the top of the HRZ, 9.8 ppg by the top of the Kuparuk and 10.0 ppg by TD. Lubricate rig & service top drive. Drill from 9111' to 9730'. Note: 1. Saw 4100 units of gas in the Kuparuk C. Monitored well for 15 minutes. 2. Schlumberger due on location to run RFT's in Kuparuk. Drill from 9730' to 9945'. Casing point for 95/8". Condition mud & pump hi vis weighted sweep. Pull 1 stand & pump dry job, blow down mud lines & POH to shoe @ 3328' from 9945' Hole in good shape. Dry wiped 5 spots after pulling 40,000 to 55,000 over at 7485',6820',6153',6058', & 5108'. RIH to 9945' filling pipe every 25 stands. Blow down after filling. Condition mud & circulate @ 900 GPM & 100 RPM. Pull 2 stands & monitor well. Okay Pump dry job & blow down all lines. POH to shoe, hole in good shape. Notes: SIO weights as follws: 220K @ 8245' 205K @ 7202' 190K @ 5299' 165K @ 4346' 155K @ 3392' Pull rubber, monitor well at shoe, replace rubber & air slips. PJSM on cut & slip drilling line. Printed: 3/18/2002 1 :48: 05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/25/2002 2/26/2002 2/27/2002 2/28/2002 ( ,( BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours IActivity! Code I NPT 22:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 06:30 06:30 - 07:30 07:30 - 12:30 12:30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 00:00 00:00 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 12:00 12:00 - 13:00 13:00 - 16:30 16:30 - 17:30 17:30 - 00:00 00:00 - 01 :00 01 :00 - 05:30 05:30 - 07:00 07:00 - 08:30 2.00 DRILL 1.50 DRILL 1.00 DRILL 4.00 DRILL 1.001 DRILL 5.00 DRILL 1.001 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 8.00 DRILL 7.501 DRILL 1.50 DRILL 0.50 CASE 2.50 CASE 1.00 CASE 3.50 CASE 1.00 CASE 6.50 CASE 1.001 CASE 4.501 CEMT 1.501 CEMT 1.501 CEMT P P P P P P P P P P P P P P P P P P P P P P P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 7 of 13 Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Phase Description of Operations Hang blocks & cut off drilling line. Slip & cut drilling line. Clean up POH to jars. UD BHA. Pump fresh water through Anadrill tools to clean & flush. Blow down mud lines. Clear & clean rig floor. P/U test jt, pull bowl protector, set test plug, & test BOP's. Blow down all mud lines & choke manifold. Note: Great job -- Best in Class Performance is 5 hours. Lessons learned captured to make this task more efficient: Install 2 pressure recorders (one on rig floor and one at test pump), install remote test pump controls on rig floor, and revise procedure for clear and consistent instructions for testing valves. Recall that choke manifold was tested while POOH. Pull test plug & install bowl protector. Lubricate rig & service top drive while waiting on additional logging tools. (RFT-formation sample chambers and liquid extraction equipment) PJSM on RIU E-line. R/U Schlumberger E-line. Running RFT's as per Nstar G&G. Notes: Results will be sent to town via email -- see remarks for details. 1. 20 good tests including samples, one super charge, set. 2. 7 slow to build sets and one SAM. 3. One 2-314 gallon sample filled to 700 psi @ 9676.5' loggers depth. 4. One 1 gallon sample filled to 4000 psi @ same depth. 5. 23 lost seal sets and 10 dry test sets. Complete E-line logging run- Details on previous DIMs report. Loggers TD @ 9,916 ft. POOH. Rig Down Schlumberger wireline. Pull Wear Ring. PJSM- Rig up to run 9.5/8" Casing. Install Franks TooL, Bails and Tongs. M/U 9.5/8" shoetrack. Bakerlock and check floats- good. Run 9.5/8" casing to 13.3/8" shoe @ 3190 ft. Circulate Casing contents @ 10 BPMI 600 psi. No Losses. Continue to run 9.518", L-80, 47 Iblft casing. No Losses. Running speed @ 18.4 joints per hour. Steadyl Safe progress. Run and land 9.5/8" casing. No Hole problems. Precautionary wash down last joint. 240 joints of L-80, 47 Iblft casing. Overall average @ 18.4 jtsl hr. Hole in good shape and mud properties in excellent shape permitting smooth running. Stage up pumps slowly to 10 BPM I 600 psi- no losses. 1.2 bottoms up. Maximum gas @ 1100 units. Mix and pump 50 bbls of 11 ppg Spacer, 319 bbls Lead Slurry @ 11.2 ppg tailed by 106 bbls 15.9 ppg slurry @ 5 BPM/1 000 psi. Drop Top Plug. Pump 25 bbls water followed by 695 bbls Mud with rig pumps @ 10 BPM/1 000 psi. Pressure increasing as cement lifted. Slow to 5 BPM. Final strokes 8300= 95%, No bump. Full Printed: 3/18/2002 1:48:05 PM ( ( BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/28/2002 07:00 - 08:30 1.50 CEMT P INT1 Returns. 08:30 - 10:30 2.00 WHSUR P INT1 Install 9.5/8" Pack-off and test same to 5000 psi. 10:30 -12:00 1.50 CASE P INT1 Clear rigfloor of all casing handling equipment. Change bails. Change control lines on Rams to 5" and function test same. 12:00 - 13:00 1.00 CASE P INT1 R/U to inject into annulus. Install wear ring. Change out sweep on wellhead. 13:00 - 16:30 3.50 CASE P INT1 Inject 220 bbls. of 10.0 ppg mud down 13 3/8" x 9 5/8" annulus while M/U BHA # 7. 16:30 -17:00 0.50 CASE P INT1 Test MWD @ 1000'. Okay - BID mud lines & kill line. 17:00 - 22:00 5.00 CASE P INT1 RIH to 9017' & tag cement. (816' above float collar) 22:00 - 00:00 2.00 CASE N FLUD INT1 Drill cement from 9017' to 9470'. Pump Efficiency equates to 87%. 3/1/2002 00:00 - 01 :00 1.00 CASE N FLUD INT1 Continue to drill cement down to Float collar @ 9,833 ft. Cement drilling at 220 ftlhr with 10 klbs WOB. 01 :00 - 02:00 1.00 CASE P INT1 Circulate Bottoms up. 02:00 - 03:30 1.50 CASE P INT1 Test Casing to 4230 psi 130 minutes with 10.2 ppg MW. 10.6 bbls pump/return. Discuss Well Control while conducting Test. 03:30 - 05:00 1.50 CASE P INT1 Drill remainder of Shoetrack and clean out rathole. 05:00 - 08:30 3.50 CASE P INT1 Displace well to 11.8 ppg system with 17.8 ppg spike fluid transported to island on vac trucks. 08:30 - 09:30 1.00 CASE P INT1 Drill 20 ft of new formation to 9965 ft. 09:30 - 10:30 1.00 CASE P INT1 Conduct FIT to 13.6 ppg EMW. 850 psi surface pressure. Bit inside shoe. 1.8 bbls pump/return. Observed 10ft fill when going to bottom- probably from pressuring up on FIT. 10:30 - 12:00 1.50 DRILL P LNR1 Clean out fill & drill fromm 9965' to 9980'. 12:00 - 00:00 12.00 DRILL P LNR1 Drill from 9980' to 10991'. 3/2/2002 00:00 - 09:00 9.00 DRILL P LNR1 Drill ahead 8.1/2" Hole to 11,385 ft monitoring all drilling trends and cuttings returns. No drag, No losses. 520 GPM/2500 psi. ECD steady. Some balling at 11,257 ft and @ 11,385 ft. 09:00 - 11 :30 2.50 DRILL N DPRB LNR1 Pump two 40 ppb walnut med, 6 ppb sap, 25 bbls. Seemed to help. Bit balling possibly due to low Lubricant concentration ( 0.5%) and new bit design? 11 :30 - 13:00 1.50 DRILL P LNR1 Drill ahead 8.1/2" Hole to TO. BHA dropping 0.5-0.9 deg/1 00'. Top of Sag @ 11,447'. Drill to 11,470 ft for a 23 ft rathole. 13:00 - 14:00 1.00 DRILL P LNR1 Circulate botoms up @ 520 GPMI 2500 psi. Up weight 360 klbs, Down weight 245 klbs. Rotating weight 285klbs.. Normal cuttings returns. 14:00 - 15:30 1.50 DRILL P LNR1 Make Wiper trip to 9.5/8" Shoe @ 9,919 ft. Hole in good shape. Minor "tugs" at 11,194', 10,680' and 10,450'. ( 25 klbs o/pull) 15:30 - 16:30 1.00 DRILL P LNR1 Lubricate rig & service top drive. 16:30 - 17:00 0.50 DRILL N RREP LNR1 Replace blower motor fuse on drawworks. 17:00 - 17:30 0.50 DRILL P LNR1 RIH back to bottom from 9 5/8" shoe @ no more than 100 ftlmin. 7' of fill. Hole slick. 17:30 -19:00 1.50 DRILL P LNR1 Condition mud & circulate high vis sweep. Circulated hole clean with no signs of splintered shales. 19:00 -19:30 0.50 DRILL P LNR1 Drop ESS & monitor well. 19:30 - 21:00 1.50 DRILL P LNR1 POH to shoe keeping block speed less than 50' per minute. Hole slick. 21 :00 - 21 :30 0.50 DRILL P LNR1 Momitor well, pump dry job, drop 2 3/8" rabbit, & blow down top drive. 21 :30 - 00:00 2.50 DRILL P LNR1 POH in preparation for running 7" liner. Kept block speed less than 50' per minute until 2,000' above 9 5/8" shoe. 3/3/2002 00:00 - 01 :30 1.50 DRILL P LNR1 POOH to 5" HWDP. Printed: 3/18/2002 1 :48: 05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( (' BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours I Activity I Code I NPT Phase 3/3/2002 01 :30 - 02:30 02:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 11 :00 11 :00 - 12:30 12:30 - 19:30 19:30 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 23:30 3/4/2002 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 06:00 06:00 - 09:00 09:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 14:30 14:30 -15:00 15:00 -19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 23:30 1.00 DRILL 3.00 DRILL 0.50 DRILL 1.00 CASE 4.00 CASE 1.501 CASE 7.00 I CASE 1.00 CASE 1.00 CASE 0.50 CASE 0.50 CASE 1.001 CASE 0.50 I CEMT 0.50 CEMT 1.001 CEMT 0.501 CASE 1.001 CEMT 1.00 CASE 0.50 CASE 1.50 CASE 3.00 CASE 1.00 CASE 1.00 CASE 1.00 CASE 2.50 CASE 0.50 CASE 4.50 CASE 0.50 CASE 0.50 CASE 3.00 CASE P P P P P LNR1 LNR1 LNR1 LNR1 LNR1 P LNR1 P P LNR1 LNR1 P P P LNR1 LNR1 LNR1 P LNR1 P P LNR1 LNR1 P LNR1 P LNR1 P LNR1 P P P P P P P P P P P P P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 Page 9 of 13 Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Description of Operations Laydown 24 joints 5" HWDP Pull BHA and laydown same. Bit in Very Good shape. Clear rigfloor. PJSM. RIU to run 7" Liner. Make up Shoetrack. Check Floats. Run 42 joints of L-80, 26 Ib/ft, Hydril 521 Flush 7" Liner. Dog collar each joint. Make up FlexLock Hanger and ZXP Packer. Circulate string volume @ 8 BPMI 200 psi. Up=Down weight = 105 klbs. Rotate pipe @ 20 RPM= 1500 ftlbs. Blow down lines. RIH wI liner on 5" DP filling every 10 stands. Circulate pipe volume @ shoe & blow down lines. Up weight 275K, down weight 220K, rotate pipe @ 20 RPM = 9500 ftlbs. While circulating & rotating @ 20 RPM - up weight 255K, down weight 240K. Torque 9500 to 10,000 ftlbs. Final circulating pressure 760 psi @ 8 BPM. Continue RIH wI liner to 11,435'. Open hole in good condition. MIU single & cement head. Wash down liner from 11435' to 11466'. Final setting depth of liner is 11461'. (4ftfill) Circulate pipe volume & PJSM for cement job. Stage pumps up in 1 bbl increments from 2-8 bbls. Final pressure @ 8 BPM was 760 psi. Pump 5 bbls of 12.8 spacer & test cement lines to 4,000 psi. Mix and pump 73 bbls ( 273 sacks) of G Slurry @ 15.9 ppg 5 BPM. Wash up Lines. Drop Dart and displace cement @ 8 BPM slowing down to 3 BPM to Latch wiper plug and for bump. Full Returns. Good pressure indications of cement lifting. Observe latch. Bump plug to 3200 psi. Pump Efficiency = 97%/231 bblsl 2717 strokes. Flowmeter was indicating 229 bbls and pit strap confirmed volumes Check hanger set. Pressure up to 4000 psi twice to release from liner. Circulate from top of 7" liner @ 9741 ft. Approximately 8 bbls cement seen @ surface. Rig down cement head and hoses. Clear rigfloor. Pull 15 stands. Flowcheck well. Slip and Cut Drilline. POH and lay down running tool- all in order Pull Wear Ring Test choke manifold. Clean L pits. Install test plug Work on pipe rack drain. Change top rams to 5 1/2". PJSM for testing BOP's Test BOP's Pull test plug & install bowl protector. PJSM for freeze protecting 13 3/8" x 9 5/8" annulus. Freeze protect 13 3/8" x 9 5/8" annulus wI 120 bbls. of diesel. Final pressure 840 psi @ 1 BPM. Printed: 3/18/2002 1:48:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/4/2002 3/5/2002 3/6/2002 3/7/2002 Date (" '" Page 10 of 13 BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours I Activity I Code I NPT Phase 20:30 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 12:00 12:00 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 -18:00 18:00 - 21 :00 21 :00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 11 :30 11 :30 - 18:00 3.00 CASE 0.50 CASE 2.00 CASE 1.00 CASE 3.00 CASE 1.00 CASE 1.00 CASE 4.00 CASE 1.00 CASE 1.50 CASE 0.50 CASE 3.00 CASE 3.00 CASE 1.501 CASE 1.001 CASE 0.50 I DRILL 17.50 DRILL 2.00 I DRILL 0.50 DRILL 4.00 DRILL 2.50 DRILL 1.00 DRILL 1.50 DRILL 0.50 DRILL 1.50 CASE 2.00 CASE 0.50 I CASE 1.00 CASE 0.501 CASE 0.50 CASE 6.501 CASE P P N P P P P P P P P P P P P P P P P P P P P P P P P P P P P LNR1 LNR1 RREP I LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Description of Operations Pull rotary table & replace rotary motor while freeze protecting. Blow down freeze protect lines to bleed trailer. Install Rotary Table Motor while Freeze Protecting well. Test Casing to 3460 psil 30 mins over 11.8 ppg mud. 9 bbls pump/return. M/U 6.118" BHA with LWD/MWD. PJSM for loading sources. RIH making up HWDP Surface test MWDI LWD- OK. RIH. Lubricate rig. Service top drive. Continue RIH to 11296' md. Wash down from 11296' md to 11380' md. Drill out shoe tracke and rat hole to 11470' md. Condition mud & swap mud over to 9.1 ppg. Clean screens twice each on both mud pumps (fish eye). Drill 20' of new formation from 11470' md to 11490' md. Circulate MWin= MWout = 9.1 ppg. FIT test to 11.3 EMW -1300 psig and 48 strokes. Held pressure for 30 mins while holding well control (pay-zone lost circulation matrix) safety briefing with rig team. Bleed down and blow down kill line. Drill f/11490' to 11493' md. Drill ahead 6-1/8" production hole from 11493' md to TO at 12030' md (11270' TVD) with no losses. Drilling parameters: Total ROP= 33.6 fph. TF= 340 gpm with max pump pressure of 2000 psig. Torque on bit was 9k ft-Ibs with 80 rpm. Final inclination and azimuth out 7.08 and 340.7 degs, respectively. Top of Shublick 10,801' TVD/11557 I MD, Top Ivishack 10,893' TVD/11 ,643' MD, Top Kavik 11,183' TVD/11 ,943' MD Pump sweep and CBU. Flowcheck. POOH wI BHA #8 to 7" shoe. PUW 290 k off bottom. Hole in good condition. Monitor well at shoe for 15 mins - hole is stable. Pump dry-job and drop 2.3/8" steel rabbit. Blow down mud lines. Continue POOH wI BHA #8. Continue to POOH. Lay down HWDP. Lay down BHA, PJSM. Pull source. Bit in good shape 2-3 and in gage. Clear rigfloor. R/U to run 4.1/2" Chrome Liner.PJSM. Make up shoetrack and check floats- OK. Run 17 joints of 4.1/2", VAM ace, L-80 Liner. M/U Baker Liner Hanger and Packer. RID Liner Equipment and Circulate Liner contents @ 7 BPMI 200 psi. Up weight 80 KLbs, Down weight 75 klbs. RIH with drillpipe. Minor gas leak traced to connection fitting at back of rig. Investigate same and take rig of gas power and place pan Hi-line to resolve same. RIH 5" drillpipe to 7" shoe @ 11,461 ft. Hole taking correct Printed: 3/18/2002 1 :48:05 PM ( ( BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: NS08 Common Well Name: NS08 Spud Date: 2/13/2002 Event Name: DRILL +COMPLETE Start: 2/10/2002 End: 3/12/2002 Contractor Name: NABORS Rig Release: 3/12/2002 Rig Name: NABORS 33E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 3/712002 11 :30 - 18:00 6.50 CASE P PROD1 displacement. 18:00 -19:30 1.50 CASE P PROD1 Circulate string contents @ shoe @ 7 BPM/600 psi. Up weight 285 klbs, Down Weight 250 klbs. 19:30 - 20:00 0.50 CASE P PROD1 Run 4.1/2" Liner to bottom. Hole slick. Tag on Depth. Hook up Cement linesl Cement Head. 20:00 - 22:00 2.00 CASE P PROD1 Circulate bottoms up @ 12,030 ft staging pumps up to 7 BPMI 1030 psi. Full returns. No reciprocation. Minor packing off 50% through circulating. No gas on bottoms up. PJSM while circulating to discuss modified procedure. 22:00 - 23:00 1.00 CEMT P PROD1 Flush Surface lines and system through both pumps to rig floor with seawater( 40 bbls). Charge both pumps with 9.3 ppg Brine. 23:00 - 00:00 1.00 CEMT P PROD1 Mix and pump 5 bbls Spacer, Test lines to 4000 psi, Pump 25 bbls Spacer and 28bbls of 15.9 ppg Slurry @ 5 BPM/500 psi. Close head, Flush cement lines. Drop Dart and prepare to displace cement with 9.3 ppg Clean KCL and mud. 3/8/2002 00:00 - 01 :00 1.00 CEMT P PROD1 Displace cement with 193 bbls. 15 bbls 9.3 ppg KCL Brine and rest with Mud @ 7 BPM. Observe plug latch and bump plug @ 98% efficiency. No Losses. Up weight 285 klbs, down 250 klbs. ( No reciprocation) 01 :00 - 01 :30 0.50 CASE P PROD1 Bleed Floats. Unable to set hanger. Successful at third attempt at pressuring up. Release from hanger. P/U with 1000 psi and circulate @ 10 BPM for 40 bbls. Slow to 3 BPM and set liner top packer withl without rotation. Shear observed @ 25 klbs . 01 :30 - 02:30 1.00 CEMT P PROD1 Continue to circulate bottoms up @ 10 BPM. Observe 8 bbls cement @ surface. 02:30 - 03:00 0.50 CEMT P PROD1 Test Liner top packer to 1500 psi/15 minutes.( 11.8 ppg EMW) RID Cement Head. 03:00 - 04:00 1.00 CLEAN P COMP Prepare Pits for displacement of clean seawater. Hold PJSM with all personnel. 04:00 - 07:00 3.00 CLEAN P COMP With 500 bbls of Filtered seawater in G & I displace well to clean seawater @ 13 BPM taking seawater direct from pipe rack as well preceeded by 50 bbls caustic washl 50 bbls Baraklean/50 bbls Hi Vis sweep. Achieved NTU of 60-70 after two complete circulations. 07:00 - 07:30 0.50 CLEAN P COMP Conduct negative flowcheck on Liner Top for 30 minutes-good. 07:30 - 13:00 5.50 CLEAN P COMP POOH. 13:00 - 13:30 0.50 CLEAN P CaMP Lay down 4.1/2" Liner running tool. Inspect same- fine. 13:30 -14:30 1.00 CLEAN P CaMP PJSM. RU Schlumberger slickline for liner drift and sample. 14:30 - 15:30 1.00 CLEAN P CaMP RIH wI 6" drift and tag Top of 4-1/2" liner @ 11310' slm. POOH. (17 ft deeper to dillers depth) 15:30 - 16:30 1.00 CLEAN P COMP RIH wI 3.813" drift wI sample bailer. Tag inside 4.5" liner @ 11823' slm, which is approximately 100' higher than landing collar @ 11941' md. Spang down several times and find it a bit sticky. POOH. Cement in sample bailer. 16:30 - 18:00 1.50 CLEAN P COMP Start in hole wI dummy perf gun, but decide not to make run after confering wI town. POOH and RD slickline. 18:00 -19:30 1.50 CLEAN P COMP Slip and cut 102' of drilling line. 19:30 - 20:00 0.50 CLEAN P COMP PJSM on BHA #9 (Tapered cleanout string wI mill and motor---no casing scrappers). 20:00 - 00:00 4.00 CLEAN P COMP MU BHA#9 (3-3/4" miIl/2-7/8" PDMI Circ-subl XO/22 jts of 2-318" DPI XOI 51 jts 4" DP). At 5" DP @ midnight. Continue to RIH. Printed: 3/18/2002 1:48:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/9/2002 3/10/2002 3/11/2002 ( ( ( Page 12 of 13 BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours I Activity I Code I NPT 00:00 - 02:00 02:00 - 02:30 02:30 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 11 :00 11 :00 - 12:00 12:00 - 13:00 13:00 -15:00 15:00 -16:00 16:00 - 21 :00 21:00 - 21:30 21 :30 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 07:00 07:00 - 09:00 09:00 - 22:30 22:30 - 00:00 00:00 - 12:00 12:00 - 14:00 14:00 - 17:00 17:00 - 21:00 21 :00 - 22:30 2.001 CLEAN Ip 0.50 CLEAN P 3.501 CLEAN IP 2.001 CLEAN IP 1.001 CLEAN IP 2.001 CLEAN IP 1.00 CLEAN P 1.00 CLEAN P 2.00 CLEAN P 1.00 CLEAN N 5.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.00 RUNCO 1.50 RUNCO 0.50 I RUNCO 1.00 RUNCO 1.00 RUNCO 3.00 RUNCO 2.00 RUNCO 13.50 I RUNCO 1.501 RUNCOt 12.00 1 RUNCO~ 2.00 I RUNCOt 3.001 RUNCO~ 4.00 I RUNCOf 1.50 1 RUNCO~ Phase CaMP CaMP CaMP COMP CaMP CaMP COMP CaMP CaMP CaMP COMP COMP CaMP CaMP CaMP CaMP SFAL ICOMP CaMP CaMP CaMP COMP CaMP CaMP CaMP CaMP CaMP CaMP Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Spud Date: 2/13/2002 End: 3/12/2002 Description of Operations Continue to RIH with cleanout string. Spikes from rig power affetcing island power. Switch to Rig Generators. Continue to RIH. Had to circulatel rotate into 7" Liner. No problems in 4.112" Liner. wash down inside 4.1/2" liner @ 11,736 ft to landing collar @ 11,943 ft @ 800 psi/30 SPM.Rotate @ 20 RPM/5 klftlbs. Observe stringers at 11,800', 11,805', 11,840', 11,854' and 11,881'. Circulate 850 strokes. PJSM. Drop circ ball and open @ 1600 strokes. Pump 50 bbls caustic wash, 50 bbls BARAKLEAN wash, and follow w/1 00 bbls high vis sweep. Chase with seawater. At 12500 strokes-- 60 NTU's. Monitor well. POOH to 11250' md. RU and PT casing to 4200 psig for 30 mins on chart. Pump pill. POOH. Find kink in drill line. Slip and cut 34'. POOH wI 5" DP. Change over to 4" equipment. POOH wI 4" DP. Change over to 2-3/8" equipment. LD 2-3/8" DP. LD BHA #9. Pull wear ring and flush stack. PJSM. Rig up to run production string and fiber optic cable. R/U to run 4.1/2" x 5.1/2 Chrome completion. Hold PJSM for running. M/U Tailpipe Assembly. Bad M/U on Cidra Mandrel Lay down Cidra Mandrel and P/U spare- galled pin end. Replace box on X-nipple assembly. Test Back Up Cidra Mandrel Run 38 joints of 4.1/2", VAM Ace, 12.6 Iblft Chrome tubing. MIU Crossover module and change handling equipment to 5.1/2". Run 120 jts of 5.1/2", Vam Ace, 17 Iblft Chrome tubing. M/U 5.1/2" OTIS LB mandrel wI RP shear valve installed. Set to shear at 3000 psig. Run 5.1/2", Vam Ace, chrome tubing from Jt# 121 to Jt# 135. Shift change. Continue to run 5.1/2" VAM ACE Chrome tubing. Tag Tieback sleeve on 4.1/2" On depth @ 11,293' with 5 klbs. Repeat tag-Good. Note: Had to rotate 1/2 turn to get WLEG inbto 7" liner @ 9,741 ft. Spaceout and P/U Pups- drifting same. M/U Hanger and landing joint. Connect! Test SSSV control lines and CIDRA cable to hanger and land Tubing. Up weight 235 klbs, Down 205 Klbs. Block weight is 75 klbs. 235 joints of 5.1/2" VAM ACE, 4 x Pup Joints of 5.1/2" VAM CE, 38 joints of 4.1/2" VAM ACE. Test Tubing hanger- Good. RIU to reverse circulate Sea water, corrosion inhibitor pill, and diesel. PT lines-- good. Working on chart recorder. Reverse cirulate 2000 strokes of clean SW. Returns clean - NTU of 65. SI and PT lines again to check chart recorder- good. Conduct pre-job safety meeting on using newly Printed: 3/18/2002 1 :48:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/11/2002 3/12/2002 (' (' I" BP EXPLORATION Operations Summary Report NS08 NS08 DRILL +COMPLETE NABORS NABORS 33E From - To I Hours IActivity Code NPT Phase 21 :00 - 22:30 1.50 RUNCO CaMP 22:30 - 23:00 0.50 RUNCO WAIT CaMP 23:00 - 23:30 0.50 RUNCO CaMP 23:30 - 00:00 0.50 RUNCO COMP 00:00 - 03:30 3.50 RUNCONP I ¡CaMP 03:30 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 -11:45 11:45 -12:45 12:45 -17:00 17:00 - 20:00 20:00 - 23:00 23:00 - 00:00 0.50 I RUNCO COMP 2.00 I RUNCO CaMP 2.00 I RUNCO CaMP 1.00 RUNCO 1.00 RUNCO 1.75 RUNCO 1.00 RUNCO 4.25 RUNCO 3.00 RUNCO 3.00 RUNCO COMP COMP CaMP CaMP CaMP COMP CaMP COMP Start: 2/10/2002 Rig Release: 3/12/2002 Rig Number: Page 13 of 13 Spud Date: 2/13/2002 End: 3/12/2002 Description of Operations commisioned diesel warm up tank wI operations, ACS, and rig crew. High line power went out. Production troubleshooting problem. Fire up rig generators. Line up to backfeed G & I power. Reverse circulate 25 bbls of corrosion inhibited sea water pill. Switch to pumping diesel from warm-up tank. Best rate @ 17 spm or starve pump. Get initial strap from G & I for returns. Pump 284 bbls diesel for FP down IA and take returns off tubing. Warm diesel skid pump able to supply 1.4 bpm max rate (Temperature on diesel 54 deg F). Back out landing joint x-over and drop 1-718" ball and rod assembly wI 1.375" fishing neck (2" SB pulling tool required). Let it fall for 1/2 hr down to RHC plug body in "XN" nipple below the packer. Pressure up to 4200 psig and set the Baker permanent pkr. Record tubing test for 30 mins on chart recorder and Cidra data-- Good. Bleed tubing to 2600 psig and test IA to 4160 psig for 30 mins-- good. Bleed off pressure on tubing and shear(2700 psig) RP valve in GLM. Communicate IA and tubing at surface and allow to U-tube diesel. Blow down and rig down U-tube circ lines. Back out and lay down landing jt. Install 2-way check. Nipple down BOPE stack. Island wide safety stand down-- both rig crews participate. Continue NO BOPE stack. Terminate control and Fiber optic lines. Nipple up and test tree to 5K psig. Test void to 5000 psig. G & I started flush and well kill on NS-10 for rig move at 10:30 hrs. Operations have lowered level in grey-water and produced water tanks. PJSM. Rig down. Printed: 3/18/2002 1 :48: 05 PM i( ( Well: NS08 Rig Accept: 02-13-02 Field: Northstar Unit Rig Spud: 02-13-02 API: 50-029-23068-00 Rig Release: 03-12-02 Permit: 202-021 Drilling.B!g: Nabors 33E --- -- - --- - - ---- ---- - -- -------- ---- - -------------- ---- ---.. --- ---- - --_..- - -- - - - - -- -- -...-..--- - -- -- ..-- -- - - _...- -- --- .. -- -- --- -.._-- ------ .. - -- ---- --- -- --_...---- - --..- --- --- ..-- --- -- - -- ....-- - --- - - - - - - --- -- -- -- - ---- -- POST RIG WORK 03/1 8/02 - 03/22/02 RIH with Schlumberger USIT. Started logging gamma, CCL log from surface to 11,850' ELMO. Sent log to town for evaluation. Unable to get the USIT sub to function down hole, POOH. Change out the USIT sub. RIH with the USIT sub powered up from surface. Log down pass from 9000' to 11,910', up repeat pass to 11,215' ELMO. RIH to 11,910', log gamma, CCL from 11,910' to surface. RIH with Gamma/CCL, 2.875" HSO, 2906 PJ, HMX charge, 6 spf, 60* phasing perforating gun. Shot 20' interval from (11,875' to 11,895') ELMO. Saw 200 psig at surface, log off, POOH. (250 psig at rig down). RIH with perforating gun #2, 2.875" x 30'. Perforate (11,845' to 11,875'). POOH. RIH with perforating gun #3, 2.875 x 30'. Perforate (11,845' to 11,815). POOH. Rehead cable. Rope socket hung up on the lubricator when picking up the gun and pulled out of the weak point on surface. RIH with perforating gun #4, 2.875 x 30'. Perforate (11,785' to 11,815'). POOH. Sat down at 3200' ELMO while running in the hole with 5th and final gun run, (hydrates forming). RIH with perforating gun #5, 2.875 x 30'. Perforate (11,755 to 11,785'). RIH and set 51/2" BBE SSSV @ 1971' WLMO. Perform 300-psi closure test on valve. 2/18/2002 1/3/2002 3/5/2002 FIT FIT FIT 3,326.0 (ft) 9,919.0 (ft) 11,490.0 (ft) 3,218.0 (ft) 9,248.0 (ft) 10,737.0 (ft) 8.80 (ppg) 11.80 (ppg) 9.10 (ppg) Surface Pressure 640 (psi) 850 (psi) 1,300 (psi) Leak Off Pressure (BHP) 2,111 (psi) 6,519 (psi) 6,376 (psi) Page 1 of 1 EMW 12.63 (ppg) 13.57 (ppg) 11.43 (ppg) "--, ---, Printed: 3/18/2002 1 :47:57 PM ANADRILL SCHLUMBERGER Survey report Client....... ...... ......: BP Exploration (Alaska) Inc. Field....................: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS08 API number........... ....: 50-029-23068-00 Engineer.................: Rathert COUNTY:... ........ .......: Nabors 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DLS........ ...: Mason & Taylor ----- Depth reference ----------------------- Permanent datum...... ....: Mean Sea Level Depth reference....... ...: Drill Floor GL above permanent. ......: 15.67 ft KB above permanent.......: 0.00 ft DF above permanent.......: 55.69 ft ----- vertical section origin---------------- Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-).... ....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-)... ......: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 318.56 degrees (c)2002 Anadrill IDEAL ID6_1C_10] 6-Mar-200221:47:22 Spud date. .... .... .......: Last survey date.........: Total accepted surveys. ..: MD of first survey. .... ..: MD of last survey........: Page 1 of 6 13-Feb-02 06-Mar-02 130 0.00 ft 12030.00 ft -~, ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2001 Magnetic date...... ......: 12-Feb-2002 Magnetic field strength..: 1150.26 HCNT Magnetic dec (+E/W-) .....: 26.54 degrees Magnetic dip.. ... ..... ...: 80.93 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip............: of G...........: of H...........: of Dip.........: Criteria --------- 1002.69 rnGal 1150.26 HCNT 80.93 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ~-. ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 26.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.54 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 ------ ------ Incl angle (deg) ------ ------ 0.00 0.28 0.38 0.55 0.42 0.75 0.94 1.27 1.03 1.07 1.17 1.13 1.12 1.01 1.15 1.12 1.16 0.89 0.67 0.29 1.40 3.36 5.12 6.93 10.06 12.05 14.97 17.17 19.42 21.02 ------- ------- Azimuth angle (deg) ------- ------- 0.00 67.68 75.70 13.24 55.14 141.70 142.89 136.93 125.78 108.60 90.22 88.05 83.07 76.12 76.03 70.57 65.12 69.03 66.71 34.94 286.08 293.52 300.45 303.80 306.35 308.62 310.62 313.80 318.85 319.44 ------ ------ Course length (ft) ------ ------ 0.00 50.00 50.00 50.00 50.00 73.00 30.00 62.00 115.00 90.00 92.00 98.00 89.00 96.00 95.00 95.00 58.00 97.00 95.00 93.00 97.00 95.00 93.00 97.00 95.00 95.00 95.00 101.00 86.00 29.68 [(c)2002 Anadrill IDEAL ID6_1C_10] 6 7 8 9 10 273.00 303.00 365.00 480.00 570.00 11 12 13 14 15 662.00 760.00 849.00 945.00 1040.00 16 17 18 19 20 1135.00 1193.00 1290.00 1385.00 1478.00 21 22 23 24 25 1575.00 1670.00 1763.00 1860.00 1955.00 26 27 28 29 30 2050.00 2145.00 2246.00 2332.00 2361.68 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 150.00 200.00 272.99 302.99 364.98 479.96 569.94 661.92 759.90 848.89 944.87 1039.85 1134.83 1192.82 1289.81 1384.80 1477.79 1574.79 1669.70 1762.44 1858.90 1952.85 2046.08 2138.44 2235.49 2317.14 2344.99 6-Mar-200221:47:22 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.04 -0.16 -0.09 0.03 -0.48 -0.92 -2.12 -4.40 -5.92 -7.29 -8.56 -9.62 -10.54 -11.37 -12.15 -12.53 -13.08 -13.51 -13.62 -12.56 -9.06 -2.65 7.12 20.78 38.66 60.58 88.36 115.32 125.57 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.05 0.13 0.41 0.75 0.52 0.17 -0.73 -2.27 -3.01 -3.29 -3.26 -3.12 -2.81 -2.38 -1.84 -1.40 -0.72 -0.24 0.17 0.70 2.13 5.33 10.78 18.88 29.99 44.17 62.99 82.54 90.30 0.00 0.11 0.39 0.60 0.81 1.32 1.59 2.37 4.08 5.53 7.28 9.25 10.99 12.74 14.48 16.28 17.35 18.94 20.14 20.78 19.78 16.11 10.03 1.44 -10.01 -24.44 -41.51 -62.17 -80.74 -87.45 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.12 0.41 0.73 1.10 1.42 1.60 2.48 4.67 6.30 7.99 9.81 11.43 13.05 14.68 16.39 17.41 18.96 20.14 20.78 19.79 16.25 11.36 10.87 21.37 38.69 60.61 88.50 115.47 125.71 0.00 67.68 70.92 55.87 47.25 68.37 83.76 107.19 119.08 118.55 114.29 109.40 105.86 102.42 99.32 96.44 94.62 92.17 90.67 89.52 87.97 82.45 62.04 7.61 332.08 320.82 316.78 315.37 315.63 315.92 2 of 6 ----- ----- DLS (degl 100f) ----- ----- 0.00 0.56 0.22 1.01 0.73 1.15 0.64 0.56 0.28 0.35 0.40 0.06 0.11 0.18 0.15 0.12 0.20 0.29 0.23 0.48 1.57 2.08 1.97 1.90 3.32 2.14 3.11 2.35 3.20 5.43 ----- ----- Srvy tool type ----- ----- TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR MWD ------ ------ Tool qual type ------ ------ -"~ -""'"~~~ ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 31 32 33 34 35 2457.40 2554.38 2649.58 2744.75 2840.19 ------ ------ Incl angle (deg) ------ ------ 23.01 24.05 24.66 24.11 25.48 25.83 26.47 26.90 26.46 26.19 25.47 25.71 26.06 26.25 26.27 26.24 26.22 26.19 26.55 26.53 26.74 27.16 27.44 27.58 27.32 25.77 24.30 22.85 21.84 21.59 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 319.74 321.48 320.57 321.49 320.00 320.82 316.76 317.42 318.30 317.77 318.24 317.06 316.33 316.31 315.73 315.78 316.12 316.23 316.06 315.16 314.27 313.74 312.63 311.46 312.69 313.81 315.67 316.70 318.41 319.84 ------ ------ 95.72 96.98 95.20 95.17 95.44 96.58 95.24 93.02 97.67 52.78 137.01 96.07 95.21 93.02 96.69 95.91 96.05 95.20 96.35 94.64 95.51 94.00 94.21 98.30 91.91 94.09 96.15 95.50 96.52 94.12 [(c)2002 Anadrill IDEAL ID6_1C_I0J 36 37 38 39 40 2936.77 3032.01 3125.03 3222.70 3275.48 41 42 43 44 45 3412.49 3508.56 3603.77 3696.79 3793.48 46 47 48 49 50 3889.39 3985.44 4080.64 4176.99 4271.63 51 52 53 54 55 4367.14 4461.14 4555.35 4653.65 4745.56 56 57 58 59 60 4839.65 4935.80 5031.30 5127.82 5221.94 -------- -------- TVD depth (ft) -------- -------- 2433.73 2522.65 2609.37 2696.05 2782.70 2869.75 2955.25 3038.36 3125.64 3172.94 3296.26 3382.91 3468.57 3552.06 3638.77 3724.79 3810.95 3896.36 3982.69 4067.36 4152.73 4236.52 4320.24 4407.43 4488.99 4573.16 4660.27 4747.80 4837.07 4924.52 6-Mar-200221:47:22 -------- -------- Vertical section (ft) -------- -------- 161.45 200.13 239.36 278.61 318.60 360.39 402.35 444.10 487.95 511.36 571.05 612.54 654.08 695.05 737.79 780.17 822.58 864.58 907.34 949.57 992.29 1034.75 1077.77 1122.88 1164.97 1206.84 1247.43 1285.59 1322.27 1357.09 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 117.62 147.55 178.07 208.61 239.59 271.82 303.37 333.96 366.48 383.88 428.25 458.91 489.16 518.81 549.59 579.99 610.50 640.83 671.69 701.90 732.03 761.62 791.19 821.60 849.99 878.79 907.41 934.96 962.03 988.36 -110.71 -135.26 -159.96 -184.67 -210.01 -236.65 -264.31 -292.74 -322.17 -337.82 -377.76 -405.72 -434.23 -462.54 -492.25 -521.85 -551.37 -580.48 -610.13 -639.71 -670.14 -700.78 -732.29 -766.00 -797.45 -828.09 -857.00 -883.44 -908.22 -931.00 Page --------------- --------------- Total displ (ft) At Az irn (deg) --------------- --------------- 161.53 200.17 239.36 278.61 318.60 360.40 402.35 444.11 487.96 511.36 571.05 612.54 654.08 695.06 737.81 780.20 822.63 864.65 907.43 949.68 992.45 1034.97 1078.07 1123.29 1165.51 1207.47 1248.13 1286.32 1323.01 1357.80 316.73 317.49 318.07 318.48 318.76 318.96 318.94 318.76 318.68 318.65 318.58 318.52 318.40 318.28 318.15 318.02 317.91 317.83 317.75 317.65 317.53 317.38 317.21 317.01 316.83 316.70 316.64 316.62 316.65 316.71 3 of 6 ----- ----- DLS (degl 100f) ----- ----- 2.08 1.29 0.75 0.70 1.58 0.52 1.99 0.56 0.61 0.68 0.55 0.59 0.50 0.20 0.27 0.04 0.16 0.06 0.38 0.43 0.47 0.51 0.62 0.57 0.68 1.73 1.73 1.58 1.24 0.62 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ -~o ,~~~ ANADRILL SCHLUMBERGER Survey Report -------- -------- Seg Measured # depth (ft) --- -------- -------- 61 62 63 64 65 5317.16 5411.51 5507.53 5603.23 5697.07 ------ ------ Inc1 angle (deg) ------ ------ 21.52 21.53 21.43 21.03 21.09 20.95 21.26 21.76 22.40 23.14 23.44 23.47 23.44 23.38 23.19 23.11 23.33 23.03 23.56 23.67 23.77 23.15 23.32 23.61 23.88 23.46 23.00 23.22 23.51 23.21 ------- ------- Azimuth angle (deg) ------- ------- 320.61 322.01 321.88 322.93 323.37 323.24 322.88 322.88 322.39 322.37 322.23 320.90 319.85 318.09 316.31 314.43 313.90 314.13 316.58 318.33 319.34 320.35 321.11 320.50 320.53 320.49 320.16 320.04 319.87 319.83 ------ ------ Course length ( it) ------ ------ 95.22 94.35 96.02 95.70 93.84 95.54 92.98 92.63 97.95 95.59 94.18 94.75 97.05 95.30 90.67 98.86 94.04 94.86 94.90 95.02 95.31 94.13 95.26 95.19 92.53 96.41 94.89 96.25 93.38 94.16 [(c)2002 Anadrill IDEAL ID6_1C_I0J 66 67 68 69 70 5792.61 5885.59 5978.22 6076.17 6171.76 71 72 73 74 75 6265.94 6360.69 6457.74 6553.04 6643.71 76 77 78 79 80 6742.57 6836.61 6931.47 7026.37 7121.39 81 82 83 84 85 7216.70 7310.83 7406.09 7501.28 7593.81 86 87 88 89 90 7690.22 7785.11 7881.36 7974.74 8068.90 -------- -------- TVD depth (ft) -------- -------- 5013.08 5100.85 5190.20 5279.40 5366.97 5456.16 5542.90 5629.08 5719.84 5807.98 5894.49 5981.41 6070.44 6157.90 6241.19 6332.09 6418.51 6505.71 6592.88 6679.94 6767.20 6853.55 6941.08 7028.40 7113.10 7201.40 7288.5.9 7377.12 7462.84 7549.28 6-Mar-200221:47:22 -------- -------- Vertical section (ft) -------- -------- 1392.06 1426.64 1461.74 1496.31 1529.92 1564.07 1597.45 1631.32 1668.05 1704.96 1742.12 1779.78 1818.38 1856.24 1892.07 1930.87 1967.84 2005.06 2042.52 2080.58 2118.92 2156.38 2193.93 2231.80 2269.04 2307.73 2345.13 2382.90 2419.92 2457.25 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 1015.24 1042.26 1069.95 1097.40 1124.39 1151.87 1178.62 1205.71 1234.97 1264.27 1293.73 1323.27 1353.03 1381.59 1407.88 1435.54 1461.37 1487.32 1514.02 1542.06 1570.92 1599.56 1628.65 1658.03 1686.78 1716.65 1745.46 1774.44 1802.79 1831.33 -953.39 -975.02 -996.70 -1017.84 -1038.06 -1058.54 -1078.66 -1099.16 -1121.51 -1144.09 -1166.86 -1190.30 -1214.94 -1239.79 -1264.14 -1291.44 -1318.04 -1344.89 -1371.25 -1396.98 -1422.22 -1446.39 -1470.17 -1494.13 -1517.82 -1542.43 -1566.33 -1590.56 -1614.39 -1638.46 Page --------------- --------------- Total displ (ft) At Az irn (deg) --------------- --------------- 1392.72 1427.23 1462.26 1496.76 1530.30 1564.39 1597.71 1631.53 1668.21 1705.09 1742.22 1779.85 1818.45 1856.30 1892.14 1930.96 1967.95 2005.20 2042.69 2080.75 2119.08 2156.53 2194.06 2231.92 2269.14 2307.81 2345.21 2382.97 2419.98 2457.30 316.80 316.91 317.03 317.15 317.29 317.42 317.54 317.65 317.76 317.86 317.95 318.03 318.08 318.10 318.08 318.02 317.95 317.88 317.83 317.83 317.84 317.88 317.93 317.98 318.02 318.06 318.10 318.13 318.16 318.18 4 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 0.31 0.54 0.12 0.58 0.18 0.15 0.36 0.54 0.68 0.77 0.32 0.56 0.43 0.74 0.80 0.75 0.32 0.33 1.16 0.75 0.44 0.79 0.36 0.40 0.29 0.44 0.50 0.23 0.32 0.32 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ ~~ .->= ~, ANADRILL SCHLUMBERGER Survey Report 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 --- -------- -------- ------ ------ Incl angle (deg) ------ ------ 22.96 23.11 23.29 23.58 23.36 22.99 23.08 23.13 23.33 23.51 23.15 23.15 23.26 23.08 23.15 23.31 23.55 23.68 23.89 24.06 23.29 22.63 21.81 21.25 20.82 19.63 18.76 17.74 16.41 15.02 ------- ------- Azimuth angle (deg) ------- ------- 319.06 319.35 319.08 319.56 319.21 318.93 318.47 318.15 318.38 318.89 319.08 318.65 318.28 318.32 318.30 318.78 318.60 318.58 319.40 319.64 320.55 321.17 321.02 321.06 321.06 321.82 321.96 321.11 321.60 323.69 ------ ------ Course length (ft) ------ ------ 95.36 95.91 95.38 94.07 98.47 94.99 95.17 90.48 95.99 95.98 95.57 97.19 95.12 93.89 94.79 95.51 96.94 96.03 71.66 208.40 95.03 95.30 95.37 93.39 94.96 94.85 95.04 95.08 95.14 92.48 [(c)2002 Anadrill IDEAL ID6_1C_I0J Seq Measured # depth (ft) -------- -------- 91 92 93 94 95 8164.26 8260.17 8355.55 8449.62 8548.09 96 97 98 99 100 8643.08 8738.25 8828.73 8924.72 9020.70 101 102 103 104 105 9116.27 9213.46 9308.58 9402.47 9497.26 9592.77 9689.71 9785.74 9857.40 10065.80 10160.83 10256.13 10351.50 10444.89 10539.85 10634.70 10729.74 10824.82 10919.96 11012.44 -------- -------- TVD depth (ft) -------- -------- 7637.01 7725.27 7812.94 7899.25 7989.57 8076.90 8164.48 8247.70 8335.91 8423.98 8511.74 8601.10 8688.53 8774.84 8862.02 8949.79 9038.74 9126.72 9192.30 9382.72 9469.75 9557.50 9645.79 9732.66 9821.29 9910.29 10000.05 10090.35 10181.29 10270.31 6-Mar-200221;47:22 -------- -------- Vertical section (ft) -------- -------- 2494.63 2532.16 2569.73 2607.14 2646.35 2683.73 2720.97 2756.48 2794.34 2832.48 2870.33 2908.54 2946.02 2982.96 3020.17 3057.84 3096.39 3134.86 3163.76 3248.43 3286.57 3323.72 3359.75 3393.99 3428.04 3460.79 3491.98 3521.71 3549.62 3574.60 Page ---------------- ---------------- --------------- --------------- Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) ---------------- ---------------- --------------- --------------- 1859.74 1888.15 1916.60 1944.97 1974.74 2002.99 2030.96 2057.48 2085.73 2114.36 2142.92 2171.70 2199.75 2227.33 2255.12 2283.35 2312.31 2341.16 2362.97 2427.38 2456.65 2485.48 2513.54 2540.19 2566.70 2592.34 2616.93 2640.24 2662.06 2681.95 -1662.77 -1687.29 -1711.83 -1736.22 -1761.75 -1786.24 -1810.82 -1834.43 -1859.63 -1884.84 -1909.68 -1934.82 -1959.67 -1984.24 -2008.99 -2033.94 -2059.38 -2084.83 -2103.79 -2158.76 -2183.24 -2206.71 -2229.36 -2250.91 -2272.33 -2292.78 -2312.06 -2330.58 -2348.03 -2363.24 2494.68 2532.20 2569.77 2607.18 2646.39 2683.77 2721.00 2756.51 2794.37 2832.52 2870.36 2908.57 2946.05 2982.99 3020.20 3057.87 3096.42 3134.89 3163.79 3248.45 3286.59 3323.73 3359.75 3393.99 3428.04 3460.79 3491.98 3521.71 3549.62 3574.60 318.20 318.22 318.23 318.25 318.26 318.27 318.28 318.28 318.28 318.28 318.29 318.30 318.30 318.30 318.30 318.31 318.31 318.31 318.32 318.35 318.37 318.40 318.43 318.46 318.48 318.51 318.54 318.56 318.59 318.61 5 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 0.41 0.20 0.22 0.37 0.26 0.41 0.21 0.15 0.23 0.28 0.38 0.17 0.19 0.19 0.07 0.26 0.26 0.14 0.55 0.09 0.90 0.74 0.86 0.60 0.45 1.28 0.92 1.11 1.41 1.62 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type . ------ ------ ~- ---, þ ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 121 122 123 124 125 11108.64 11200.86 11296.06 11399.24 11594.98 ------ ------ Incl angle (deg) ------ ------ 14.13 12.90 11.54 10.58 9.81 8.60 8.75 8.47 7.86 ------- ------- Azimuth angle (deg) ------- ------- 325.76 325.02 325.75 327.50 328.41 331.04 332.43 333.57 336.50 ------ ------ Course length (ft) ------ ------ 96.20 92.22 95.20 103.18 195.74 95.79 95.34 95.34 65.28 Survey Projected to Total Depth: 130 12030.00 7.08 340.70 83.27 126 127 128 129 11690.77 11786.11 11881.45 11946.73 [(c)2002 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth (ft) -------- -------- 10363.42 10453.08 10546.12 10647.38 10840.03 10934.59 11028.84 11123.10 11187.72 11270.28 6-Mar-200221:47:22 -------- -------- vertical section (ft) -------- -------- 3598.66 3620.06 3640.07 3659.67 3693.85 3708.88 3722.88 3736.70 3745.59 3755.76 ---------------- ---------------- Disp1 +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 2701.70 2719.45 2736.02 2752.54 2781.91 -2377.23 -2389.46 -2400.91 -2411.81 -2430.20 2795.12 -2437.95 2807.79 -2444.75 2820.50 -2451.24 2828.90 -2455.16 2838.97 -2459.12 Page --------------- --------------- Total displ (ft) At Az irn (deg) --------------- --------------- 3598.67 3620.07 3640.08 3659.69 3693.90 3708.95 3722.97 3736.82 3745.73 3755.93 318.66 318.70 318.73 318.77 318.86 318.90 318.95 319.01 319.05 319.10 6 of 6 ----- ----- DLS (deg/ 100f) ----- ----- 1.07 1.35 1.44 0.99 0.40 1.34 0.27 0.34 1.13 1.14 ----- ----- Srvy tool type ----- ----- MWD MWD MWD MWD MWD MWD MWD MWD MWD Pro] .. ------ ------ Tool qual type . ------ ------ ~~.- - I: lß -- W r6 J 0 u c( I '<~ ~ In - ~ I- ::. en ~ ~~ II: <C 0 :). ...I 0. I W <C W en z ~ z UI O ...J ~ l - ...J <C I- ~ W I- I!J ~ en l J: 2 0 u. t- ...J 0 ~ OJ - 0.. 0 J c >< z D. J w Z 0.. W - 0: m ---=/ In [] ,~ c--~ .- - - - - -- -- - - ~ - - - - - - -- ~ I,~ ;1 I I I I I I I ( I I I I I I I I I TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Daily Operations 4. Show Reports 5. Morni ng Reports 6. BHA's 7. Bit Record 8. Mud Reports 9. Survey Record 10. Formation Tops 11. Formation Evaluation Logs sparr'v- sun I::J RI '-'-I N tj 51Ef:1! R\J 1 c: e!ã It I ., I I I I I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS08 Northstar North Slope Alaska United States 50-029-23068-00 AK-AM-22026 February 12, 2002 March 06, 2002 True 26.532 deg 80.930 deg 57513.397 nT February 12, 2002 North 70 deg 29 min 27.39 see East 148 deg 41 min 35.81 see 318.56 deg Doug Wi Ison Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Joe Polya Mike Dinger Ken Lemley Northstar 107 Alaska North Slope SpE!r'I-'Y- sun 1:1 AI LLI N œ SE FHII c: e s I i 1 BP Exploration - Northstar NS08 Daily Well Summary ,Î 1-/12-02 Rigged Down Pipe rack lines & built benns. Cleaned up the cellar & steps on the back of the rig.Held )JSM before rig move. Moved offNS-14 toward NS-08. Quit moving. Warmed up moving system and turned up pressure. At 1400 hrs, the rig began to move again. Rig was spotted over NS-08 at 1800 hrs. Rigged up lines and 1 ntinued to berm around the rig. Cleaned up herculite ITom NS-14 and set Geronimo line, all steps and handrails. 02/13/02 Worked on thawing the frozen injection line. Brought riser into the cellar while continuing to work on the t )zen injection line. Got it thawed out and made up 4" again. Continued rig up. Buttoned up all pipe rack lines & t~aned-up area on NS-14. Turned over NS-14 to operations @ 9:00 am. Covered NS-9 and NS-10 well houses with herculite. Nippled up surface riser, mouse hole, roughneck track. and rigged up turn buckles. Ran mud through lies and checked for leaks. Perfonned D7 drill. Rigged up tools for BHA#l. Made up BHA #1- (16" T69 Bit, jetted _..;]2 and 3x20 I Motorl Orient Sub/Mon. stabl Mon LCI X-over). Tagged ice. Drilled ahead through the ice and out 20" drive shoe to 228'. PJSM. Rigged up Schlumberger W/L for gyro. Ran in hole wi gyro. Initial survey@ 157' md: l cl 0.65 degl Azi 3.40 deg, turned tool face to 100 deg and slid 40'. Rotated down the stand. Perfonned Deviation Jrvey. Good. Drilled ahead to 318' rvID. I U14/02 Drilled ahead 16" hole from 318' to 406' md, surveyed & Pooh. Held a PJSM. Made up BHA#2. At 0130 . M Floonnan cut his little finger when he wiped off the collar with his gloved hand. He was trying to mark a line on (ipe. Sent to Medic where he received 4 sutures. Returned to work. Gathered entire rig. team and discussed accident Id how to prevent another hand injury. Team decided that absorbant or rags to be used to wipe down tools--not loves. Pictures taken of tong burrs on collar. Circulated bottoms up. Perfonned a Gyro survey and oriented Tool Face. Drilled ahead 16" from 406' to 580' md. Blowed down lines Performed a gyro surveyed, Continued to Drill llead 16" from 580' to 760' md. Blew down lines and perfonned a Gyro. Changed shaker screens & cleaned pump '~reens. Drilled ahead fl 760'- 947' md. Blew down lines and perfonned Gyro survey. Drilled ahead f/947'-1291' md. (Blew down lines and performed a Gyro survey. Drilled ahead f/1291' to 1576' md, pumped a sweep. ,lew down lines and perfonned a Gyro. Drilled ahead f/1576' to 1674' md. 1°.2115102 Continued to Drill ahead 16" hole from 1674'-1862' md. Blew down lines and performed a Gyro survey. Þrilled ahead from 1862'- 2432 md. Blew down lines and perfonned a Gyro survey. Rigged Down Schlumberger and \lyro data. Continued to drill ahead from 2432' to TD at 3344' md. Final TVD 3234.18', Incl = 26.56 deg, and az = 118.26 deg. Pumped 75 bbls high vis Barofibre sweep. Sweep carried ",,30% excess cuttings. Circulated a total of I 7352 strokes (2+ total surf to surfvols.) until retW1ls clean. POOH to 1600' rod. Note: Clean pick up weight offbtm 175k. Checked flow, then pumped dry job and blew down lines. TOH. Hole in good condition. Max drag 10k. [ 12116/02 POOH with Drill Pipe to 1600' md. Note: Hole in great shape with no significant overpulls. Continued to .POOH, stood back HWDP and LD BHA#2. Note: Flushed MWD and Motor with Fresh H2O. Some clay on [ "tabilizers but overall pretty clean. Cleaned rig floor. Rigged up casing running equipment. Rigged up Franks Circ Lool and made up mandrel hanger on lower portion of landing joint and set it back on short side of pipe shed. Performed a PJSM for running 13-3/8" surface casing. track volume. Continued Rill with 13 3/8" casing to Joint 19. I Vote: Baker locked thru pin end of joint 3 into Float Collar. Changed crews and continued to Rill with remaining 62 Dints of 13-3/8" casing. Made up lower portion of landing joint with mandrel hanger, broke out lift sub, removed rotary table and lower hanger into riser. Replaced rotarty table, Made up upper portion of landing joint and landed r -nandrel hanger. Made up cement head. Note: PUwas 330K, SO was 185K --landed hanger in tension with 185K ~hich includes 75Kfor traveling equipment. Broke circulation and gradually increased rate to 12 bpm with no sign of losses. Pumped 5 bbls of Sea Water and tested lines to 3500 psig. Pumped 75 bbls of Alpha Spacer and pumped I irop bottom Plug. Pumped Surface Cement Job as follows: 439 bbls 10.7 ppg Lead Slurry (Permafrost L), and 100 )bls 15.8 ppg Tail Slurry (premium G wi 2% CaCI2) @ 5-6 bpm. Released top plug and flushed wi 25 bbls SW from HALCO. Switched to rig pumps for displacement wi 9. o ppg mud @ 1O bpm. Slowed rate to 5 bpm @ 4400 strokes. I l ¡ I, ~ BP Exploration -Northstar NS08 \: Daily Well Summary t ,mped plugs @ 4640 strokes (464 bbls on Halliburton meter). Pressure up to 1445 psig. Held pressure for 3 mins. Bled off pressure to 0 psig to check floats. Began to Rig Down cement equipment. \hte: Estimated returns: 50 bbls cement contaminated mud and 50 bbls of clean cement (approximately 100 bbls 4 ':ess). Caught cement sample. r'\ /17/02 Finished post cement cleanup and rigged down. Cleared floor of cement head, landing jt, casing tools, etc. 1 ashed out rotary table. Cleaned pits (L-pit in particular). Pulled riser & mousehole and laid it down in the pipe shed. Took lower sections of riser out through the cellar. Nippled up VETCO multi bowl WH spool and tested to 5000 psig. IT'~,PPled up single gate and mud cross. Repaired bridge crane then spooled bridge crane lines. Nippled up BOPE stack d pressure tested BOPE stack. Note: AOGCC Rep "Lou Grimaldi" waived right to witness test. {"!/18/02 Finished testing BOPE and blew down lines. Valve failed in choke manifold, re-dressed and tested. Pulled st plug, ran wear ring and laid down test joint. Pickup BRA #3 with 12 V4," Hycalog RS-163HDNS bit and rotary steerable assembly and Trip in hole. Shallow test MWD tools-passed test. Continue trip in hole. Drill out shoe track, r )at equipment and 20' of new formation to 3364' MD. Displace hole with new 8.6 ppg Seawater Polymer mud. Cut ld slip drilling line. 1- !/19/02 Drilling 12 V4' hole from 3364' to 4713' MD. Trip out of hole due to rotary steering not responding. Pick up HA#4. 1- U20/02 Pickup BHA #4 with 12 V4," Hycalog DS69HFGLNPUV and mud motor. While pulling BRA #3 through , OP's, bit caught on wear ring. Unable to get through stack. Pull wear ring. Work BRA through BOP stack. Lay down Mud motor and BRA #3. Pickup new rotary steerable assembly and test same. Trip in hole with BRA # 4. 1.2121/02 Trip in hole to 4713' MD. Drill with rotary steerable assembly ITom 4713' to 6437' MD. In this interval a drilling break was encountered at 5900' to 5935' MD that had a maximum ROP of310 fph and maximum gas of 1735 I nits. Lithology consisted of30% clay, 40% sand and 30% siltstone. No sample fluorescence or cut fluorescence was noted. 12/22/02 Drilled ahead to 6899' MD. Circulated bottoms up and Tripped out of hole for new bit and BRA. Maximum ¿;as in this interval was 229 units at 6850' Md , with a 8.9 ppg mud weight. Lay down BRA #5 and pickup BRA #6 with 12 V4," Hycalog DS69HFGLNPUV.. Could not get bit through wear ring. Pulled wear ring. Grind wear ring. I ceinstall wear ring. Trip in hole. Service top drive. Continue trip in hole with aHA #6. 02/23/02 Trip in hole with BRA #6. Drill ahead from 6899' to 8578' MD. Maximum trip gas was 3650 units from I 'ottoms up on trip in hole at 6899' MD. Maximum gas encountered while drilling ITom 6899' to 8578' MD was 536 units at 7172' MD with a 9.1 ppg mud weight. Top of the Schrader Bluff formation was 6782' MD' 6382' TYD. Top of the Colville formation was 7435' Md, 6967' TYD. I ,)2/24/02 Drill and Slide !Tom 8578' to 9013' MD. Short ttip to 6830' MD. Trip to bottom-hole acted good. Maximum short trip gas was 1569 units. Drill ahead from 90133' to 9733' MD while increasing mud weight to 10 ppg. While lrilling this interval drilling breaks and maximum gases were observed as follows: (9615'-9657' MD, Maximum gas 4000 units, Maximum ROP 140 fph, Lithology-40% sandstone, 30% shale, 30% siltstone.), (9690'-9705' MD, Maximum gas 4987 units, Maximum ROP 160 fph, Lithology-30% sandstone, 30% shale, 40% siltstone.), ( 9720'- I )732' MD, Maximum ~as 5915 units, Maximum Rap 150 fph, Lithology- 40% ~andstone, 20% shale, 40% siltstone.) fop of the HRZ formation was 9265' MD, 8648' TYD. Base of the HRZ formatIon was 9365' MD, 8739' TYD. Top Il)fthe Kuparuk formation was 9397' MD, 8769' TYD. Top of the Kuparuk "c" was 9610' MD, 8965' TYD. Top of :he Miluveach formation was 9890' MD, 9221' TYD. 1 I l BP Exploration - Northstar NSO8 Daily Well Summary "l' " I )2/25/02 Drilled from 9733' to 9945' J\1D Total depth for the 9 5/8" casing point. Circulated and conditioned mud 1,- j pumped a hi viscosity sweep. Short trip to 13 3/8" casing shoe at 3328' MD. Trip back to bottom and circulate , ttoms up for a maximum short trip gas of 4603 units. Trip out of hole to run e-Iogs. Observed some drag on the first ~wo stands off bottom, good after that. ! /26/02 Trip out of hole for e-Iogs. Cut drilling line. Continue Trip out of hole. Lay down BHA #6. Test BOP's. Rig up wireline. Run wireline logs. ¡ ./27/02 Continue running wireline logs. Run RFT log. Rig up to run 9 5/8" casing. Run 9 5/8" casing. I î./28/02 Finish running 9 5/8" casing. Circulate and condition hole clean. Pump cement and bump plug as per :menting plan. Pickup BHA #7 8 1f2" Hycalog DS70FNPV rotary assembly without mud motor and trip in hole. Tagged cement at 9017' MD ( 900' cement in casing). Drill out cement in casing. ( ;/01/02 Drill out cement to float at 9833' MD. Pressure test casing-good. Drill cement to shoe at 9919' MDI drill out cement t09945' MD. Displace mud system to seawater KCL/Polymer and weight up mud system to 11.8 ppg. Drill (, )' of new formation to 9965' MD and perform Formation Integrity Test to 13.5 ppg equivalent mud weight. Drill , lead from 9965' to 10984' MD. Maximum gas was 350 units at 10092' MD. Top of Kingak formation was 10430' MD. 9717' TVD. L/02/02 Drill from 10984' to 11470' MD for Total depth of 7" casing point. Pumped sweep, circulated and conditioned mud and monitored well. tripped out of hole to 9 5/8" casing shoe. Service top drive and repair [ rawworks. Trip in hole to bottom with 7' of fill observed. Circulate bottoms up with short trip gas of 126 units. ... ump walnut sweep and circulate hole clean with very little sloughing Kingak shale observed. Trip out of hole to run 7" Liner. Top of the Sag River formation was 11447' MD, 10694' TVD. L /0 3/02 Trip out of hole to run T' Liner. Laydown BRA # 7. Rig up to run 7" liller. Run T' liner. (3/04/02 Finish running 7" Liner, Circulated down last joint with 4" offill observed on bottom to 11470' MD. .I. umped cement as per cement plan. Bump plug and set liner packer. Circulated out excess cement from liner top. Trip out of hole. Slip and cut drilling line. Continue trip out of hole. Lay down liner setting tool. Pull wear ring. Test choke (lanifold. Clean rig pits. Service rotary table. Begin testing BOP's. 10,3/05/02 Test BOP's. Freeze protect 9 5/8' X 13 3/8" annular. Install rotary motor. Service drwwworks.Test7"liner. I ¡fake up BHA #8 6 1/8" STX30CD and Trip in hole with same. Service top drive. Continue trip in hole to 11296' lvID. Wash down from 11296' to 11470' MD. Displace old KCL/Polymer mud with 9.1 ppg CaCO# BARADRIL-N I mud. Drill 20' of new foonati on. Perform Formation Integrity Test to 11.3 ppg equivalent mud weight. Drill ahead. 03/06/02 Drill from 11490 to 12030' J\1D, 11269' TVD Total depth ofNS08 well. Top of the Shublik formation was 1.1554' MD, 10799' TVD. Top of the Ivishak formation was 11643' MD, 10887' TVD. Estimated top of the Kavik I ormation was 11943' MD, 11183' TVD. No mud losses were encountered while drilling this interval. Pumped a sweep and circulated bottoms up. No short trip was done. Tripped out of hole to run 41f2" liner. Maximum gas of726 I 11nits was observed at 11512' MD. Drilling breaks encountered in this interval were as follows: ( 11500'11554' MD, vlaximum gas 726 units, maximum ROP 113 fph, Lithology- 60% sandstone, 40% siltstone.), ( 11650-11900' MD, Maximum gas 570 units, maximum ROP 148 fph, Lithology- 40% sandstone, 50% conglomerate, 10% siltstone.). I )3/07/02 Finish trip out of hole. Rig up to run 4 1f2" production liner. Run Liner to bottom and cement same. I \~~ :,1, II I, I ¡ " BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) I I I I I I I I I I I I I I I I I Time (hrs) Elapsed Code Time Operations Breakdown 02/12/02 08:00-10:00 2.00 10:00-10:30 0.50 10:30-18:00 7.50 18:00-24:00 6.00 02/13/02 00:00-02:00 2.00 02:00-05:00 3.00 05:00-10:00 5.00 10:00-14:30 4.00 14:30-16:30 2.00 16:30-18:00 1.50 18:00-20:30 2.00 20:30-22:30 2.00 22:30-23:00 0.50 23:00-23:30 0.50 23:30-00:00 0.50 02/14/02 00:00-00:30 0.50 00:30-01 :00 0.50 01:00-01 :30 0.50 01:30-02:00 0.50 02:00-06:00 4.50 06:30-08:00 1.50 08:00-08:30 0.50 08:30-10:00 1.50 10:00-10:30 0.50 10:30-11:00 0.50 RID Pipe rack lines & build berms. Clean up cellar & steps on back of rig. P JSM before rig move. Move offNS-14 toward NS-08. Quit moving. Warm up moving system. Turn up pressure. At 1400 hrs, moving rig again. Rig is spotted over NS-08 @ 1800 hrs. RU lines and continue to berm around rig. Clean up herculite from NS-14. Set Geronimo line, set all steps and handrails. Work on thawing frozen injection line. Bring riser into cellar. Continue working on frozen inj ection line. Thawed out. MU 4" again. Continue RU. Button up all pipe rack lines & clean-up area on NS-14. Turn over NS-14 to operations @ 9:00 am. Cover NS-9 and NS-IO wellhouse with herculite. Surface riser, mouse hole, roughneck track. RU turn buckles. Run musd through lines and check for leaks. Perform D7 drill. RU tools for BHA#l MU. MU BHA #1- (16" T69 Bit, jetted 1x12 and 3x20 I Motorl Orient Subl Mon. stabl Mon LCI X-over). Tag ice. Drill ahead through ice and out 20" drive shoe to 228'. PJSM. RU Schlumberger W IL for gyro. Run in hole wi gyro. Initial survey@ 157' md: Incl 0.65 deg/ Azi 3.40 deg. Turn TF to 100 deg and slide 40'. Rotate down stand. Deviation survey. Good. Drill ahead. Drilling ahead 16" hole from ~ 18' to 406' md. Survey & Pooh. PJSM. MU BHA#2. Floorman cut little finger when wiping off collar with gloved hand. He was trying to mark a line on pipe. Sent to Medic where he received 4 s1,ltures. Returned to work. Gathered entire rig team and discussed accident and how to prevent another hand injury. Team decided that absorbant or rags to be used to wipe down tools--not gloves. Pictures taken of tong burrs on collar. CBU. Gyro survey and orient TF. Drill ahead 16" from 406' to 580' md. Blow down lines & Gyro. Drill ahead 16" from 580' to 760' md. Blow down lines & Gyro. Change shaker screens & clean pump screens. ~ i ,I I I I I I I I I ' I I I I I I I I l{ BP Exploration -N orthstar NSO8 Daily Operations (I.A.D.C) Time Elapsed Code (hrs) Time 11:00-12:00 1.00 12:00-13:00 1.00 13:00-17:00 4.00 17:00-18:00 1.00 18:00-22:00 4.00 22:00-23:00 1.00 23:00-00:00 1.00 Operations Breakdown Drill ahead f/ 760'- 947' md. Blow down lines & Gyro. Drill ahead f/ 947'-1291' md. Blow down lines & Gyro. Drill ahead f/ 1291' to 1576' md. Pump sweep. Blow down lines & Gyro. Drill ahead f/ 1576' to 1674' md. 02/15/02 00:00-02:00 2.00 02:00-03:00 1.00 03:00-09:00 6.00 09:00-10:30 1.50 10:30-20:00 9.50 20:00-21 :30 1.50 Drill ahead 16" hole from 1674'-1862' md. Blow down lines and Gyro survey. Drill ahead from 1862'- 2432 md. BID lines and Gyro survey. RD Schlumberger and Gyro data. Drill ahead from 2432' to TD @ 3344' md. Final TVD 3234.18', Incl = 26.56 deg, and az = 318.26 deg. Pump 75 bbls high vis Barofibre sweep. Sweep carried -30% excess cuttings. Circulate a total of 17352 strokes (2+ total surf to surf vols.). Returns clean. POOH to 1600' md. Note: Clean PUW offbtm 175k. Check flow. Pump dry job. Blow down lines. TOH. Hole in good condition. Max drag 1 Ok. 21:30-00:00 2.50 02/16/02 00:00-01 :00 1.00 POOH with Drill Pipe to 1600' md. Note: Hole in great shape with no significant overpulls. Continue to POOH, stand back HWDP and LD BHA#2. Note: Flush MWD and Motor with Fresh H2O. Some clany on stabilizers but overall pretty clean. Clean rig floor. RU casing running equipment. RU Franks Circ Tool and Mu mandrel hanger on lower portion of landing joint and set back on short side of pipe shed. PJSM for running 13-3/8" surface casing. track volume. Continue RIH with 13 3/8" casing to Joint 19. Note: Bakerlocked thru pin end of joint 3 into Float Collar. Change crews and continue to RIH with remaining 62 joints of 13-3/8" 01:00-05:30 4.50 05:30-06:00 0.50 06:00-08:00 2.00 08:00-08:30 0.50 08:30-09:00 0.50 12:00-16:30 4.50 casing. 16:30-18:00 1.50 Note: Total of81 joints 13-3/8" 68# L80 BTRC Casing RIH. MU lower portion of landing joint with mandrel hanger, break out lift sub, remove rotary table and lower hanger into riser. Replace rotary table, MU upper portion of landing joint and land mandrel hanger. MU cement head. Note: PU was 330K, SO was 185K --landed hanger in tension with 185K which includes 75K for traveling equipment. Break Circulation and gradually increase rate to 12 bpm with no sign of losses. 18:00-20:00 2.00 I ij .~ .r ( ~ ~ BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) I I I I I I I I I I I I I I I I I Time Elapsed Code (hrs) Time 20:00-20:30 0.50 Operations Breakdown 22:30-00:00 1.50 Pump 5 bbls of Sea Water and Test Lines to 3500 psig. Pump 75 bbls of Alpha Spacer and pump drop bottom Plug. Pump Surface Cement Job as follows: 439 bbls 10.7 ppg Lead Slurry (permafrost L), and 100 bbls 15.8 ppg Tail Slurry (Premium G wI 2% CaCI2) @ 5-6 bpm. Release top plug and flush wI 25 bbls SW fTom HAco. Switch to rig pumps for displacement wI 9.0 ppg mud @ 10 bpm. Slow rat to 5 bpm @ 4400 strokes. Bump plugs @ 4640 strokes (464 bbls on Halliburton meter). Pressure up to 1445 psig. Hold pressure for 3 mins. Bleed off pressure to 0 psig to check floats. Begin RD cement equipment. Note: Estimated returns: 50 bbls cement contaminated mud and 50 bbls of clean cement (approximately 100 bbls excess). Caught cement sample. 20:30-22:30 2.00 02/17/02 00:00-05:00 5.00 08:30-12:00 3.50 Finish post cement cleanup and rig down. Clear floor of cement head, landing jt, casing tools, etc. Wash out rotary table. Clean pits (L-pit in particular). Pull riser & mousehole and LD in pipe shed. Take lower sections of riser through cellar. NU VETCO multi bowl WH spool and test to 5000 psig. NU single gate and mud cross. Repair bridge crane. Spool bridge crane lines. Nipple up BOPE stack. Pressure Test BOPE stack. Note: AOGCC Rep "Lou Grimaldi" waived right to witness test. 05:00-08:30 3.50 12:00-14:30 2.50 14:30-20:30 6.00 20:30-00:00 3.50 02/18/02 00:00-02:30 2.50 14:00-17:00 3.00 Finish Testing BOPE - Blowdown lines. Note: Failed Valve in choke manifold - redressed and tested. Pull Test Plug, Run Wear Ring & LD Test joint. PJSM - MU pump thru and visually check the Rotary Steerable Tools. Finish MU BHA. Note: Change out stabilizer blades. The rotary motor is being worked on- Affects BHA MU time. RIH with HWDP and shallow test MWD. Blowdown lines. RIH and tag cement at 3210' md. Drill cement to 3220' md. Drill Cement fl 3220' - 3242'md - tag plugs on top of float collar. Test casing to 3500 psi for 30 minutes - chart. Notes: Racked back stand of dp, blewdown top drive, MU TIW Valve and King pin, rig up cement hose to standpipe manifold, shut in on top pipe rams variable bores, open HCR and pump down both drill pipe and kill line. Bleed pressure and RD Tiw valve and king pin, MU top drive. Drill Float track, rathole and 20' of new formation to 3364' md. 02:30-03:00 0.50 03:00-06:00 3.00 06:00-08:00 2.00 08:00-10:00 2.00 10:00-12:00 2.00 12:00-13:00 1.00 13:00-14:00 1.00 ~ I' ,I J I ( I, I I I I I I I I I I I I I I \\ BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 17:00-19:00 2.00 19:00-20:00 1.00 20:00-23:00 3.00 23:00-24:00 1:00 02/19/01 00:00-02:00 2.00 02:00-04:00 2.00 04:00-05:30 1.50 05:30-08:30 3.00 08:30-09:00 0.50 09:00-12:00 3.00 12:00-12:30 0.50 12:30-14:00 1.50 14:00-15:00 1.00 15:00-15:30 0.50 15:30-22:00 6.50 Note: Pumped 600 to 700 gpm while rotating 40 to 60 rpm while drilling cement with 10 to 14 WOB. Diplace well to new mud 8.8 ppg. Perform FIT to 12.6 ppg emw - chart. Note: Pull up into shoe with rotary steerable and bit while racking back on stand of dp. Shut in on annular preventer, open HCR and pump down dp and kill line. Bleed off pressure thru bleed line, blow down kill line and surface lines and open annular preventer. Slip and Cut drill line and service top drive. Calibrate tools. Check Pump # 1- hammering. SD clean suction screens and dicover fish eyes. Fish eyes also coming back on shaker screens. Prematurely changed screens on shakers 2 and 3 to 35. Re-evaluated and decided to change screens back. Shakers 1-4 are 100, 80, 80, and 100 mesh respectively. Condition mud & circulate fish eyes. Plugged off suction screens. Drill from 3364' to 3676'. Downlink RSS Power Drive Unit. Note: Shut down and check for flow so necessary to perform downlink 2x. Drill from 3676' to 4144'. Downlink RSS Power Drive Unit. Drill from 4144' to 4557'. Note: No indication that RSS is responding to downlinks. Downlink RSS Power Drive Unit. Drill from 4557' to 4713'. Note: No indication that RSS is responding to downlinks. Decision to pull based on directional and close approach. PJSM. Circulate sweep and clean hole. Shut down & observe well. Pull 2 stands slowly & check for swabbing. Pump dry job and blow down lines. POOH to 13-3/8" shoe. Note: POOH 8 stands with no problem. POOH an addtional5 stands -- hole swabbing but able to wipe off. Attempt to pull stand 14 while swabbing -- unable to wipe off ball. RIH with stand 13 and wipe off ball -- rerack stand 13. Attempt to pull stand 14 while swabbing -- unable to wipe of ball. MU Top Drive and and back ream stand 14-- rack back. Attempt to pull stand 15 while swabbing -- pump out of hole with stand 15. Pump out of hole with stand 16 and while pulling RSS and bit into the shoe. Circulate dry job out of casing while pumping another dry job. ~ I I I I I I I I I I I I I I I I I I BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) Time Elapsed Code ehrs) Time 22:00-23 :30 050 Operations Breakdown 23 :30-00:00 0.50 POOR while LD BRA #3. Notes: 1. BRA was very clean with no sign of clay. 2. Bit and stabilizers in gauge. 3. Pumped thru RSS and Bias Tool was flowing thru all 3 pads which indicates that there was a problem -- no steering capability. 4. Broke out Bias Tool and looked like the lower torquer shaft was broken. Service Rig. 02/20/02 00:00-01:30 1.50 08: 00-09: 3 0 1.50 M/U bit, motor, LC, Stab, LWD & MWD. Unable to pull bit back through wellhead to orient tool face. Orient BRA 90,180,270, & 360 degrees & attempt to pull BRA through stack unsuccessfully. Discussed problem with rig team & compare wellhead & BOP measurements with BRA to determine location of problem. The initial prognosis is that the top of the bit is hanging up at the transition area between the 13 3/8" hangar and the casing spool. Rotate at low RPM while attempting to ppll past problem area. Gained .4' but still not able to pull free. Prognosis is top of bit is hanging up at base of bowl protector. Lower bit & pump 50 SPM while atempting to POR. Still hanging up. Motor stalled indicating bit was locked up. Finish M/U BRA. Waiting on decision while rig team. discusses options with Anchorage team. Waiting on x-over to pull bowl protector. Repair accumulator hose on top drive while waiting. Pull & inspect bowl protector. Scrapes from stabs. & bit evident. Re-run bowl protector. Pull bowl protector, inspect, & re-run. POR to tight spot & R/U to pull. Pulled fÌ"ee. This was accomplished by pulling the string over to one side opposite the kick pad on the motor while picking up. Final prognosis was that the kick pad on the motor was hanging up at the interface between the ram cavity & the mud cross. Clean rig while waiting on rotary steerable motor. Change out BRA. R/U steerable assy & service top drive. RIH & test steerable assy. Okay Program MWD. RIR to bottom ofRWDP & test MWD. Okay. 01:30-03:30 2:00 03 :30-04:30 1.00 04:30-05:00 0.50 05:00-05:30 0.50 05:30-07:00 07:00-08:00 1.50 1.00 09:30-11:30 2.00 11:30-12:00 0.50 12:00-14:00 2.00 14:00-15:30 1.50 15:30-17:30 2.00 17:30-21:00 3.50 21 :00-22:00 1.00 22:00-23:00 1.00 23:00-00:00 1.00 '~I I Ii ! ." J '; \ BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) I 'I I I I I I I I I I I I I I I I Time (hrs) 02/21/02 00:00-03:30 3.50 03:30-07:00 3.50 07:00-07:30 0.50 07:30-09:30 2.00 09:30-10:00 0.50 10:00-15:00 5.00 15:00-15:30 0.50 15:30-19:30 4.00 19:30-20:00 0.50 20:00-00:00 4.00 Elapsed Code Time 02/22/02 00:00-08:30 8.50 08:30-09:00 0.50 09:00-10:00 1.00 10:00-14:00 4.00 14:00-16:00 2.00 16:00-16:30 0.50 16: 3 0-18 : 00 1. 50 18:00-21:00 3.00 21:00-22:30 1.50 22:30-23:00 0.50 Operations Breakdown Rill from 3320' to 4334'. Wash & ream from 4334' to 4713'. Drill from 4713' to 5127'. Downlink. Drill from 5127' to 5476'. Downlink. Drill from 5476' to 5856'. Downlink. Drill from 5856' to 6235'. Downlink. Drill from 6235' to 6440'. Drill from 6440' to 6899' MD. Pumped hi vis sweep @ 03:30. Pump hi vis sweep (3400 stks) Repair drag chain in shaker room. Montior well, check for swab, pump dry job, blow down lines & POOH. Notes: 1. First 15 stands pulled fine. 2. Next 10 stands showed signs of swabbing -- able to wipe off. 3. After pulling bha thru previous bit depth at 4713' swabbing was minimal and hole was in good shape. 4. Hole fill was good and after pulling thru U gnu there was signs of seepage losses where 5 stands took between 5 and 7 bbls versus the previous 3.5 bbls. Handle BHA # 5. Clear floor of tools. MJUBHA# 6. Bit would not go through bowl protector. Pull bowl protector & smooth top w/ grinder. Miter motor kick pad w/ grinder. Re-install bowl protector. Note: Necessary to turn bit so junk slot was oriented high side, orient BHA so high side was pointing to DS tugger, Rig up cable fròm ODS Break Out Cathead and suck pipe up against SE side of hole while lowering bha into hole. Continue RIH w/ BHA #6 & HWDP. Note: Met with control room after pooh and analyzed the load swings on turbine. Obvious from data that it will be necessary to go to 2 turbines while tripping pipe after surface caisng is set. D5 alarm was set off several times and company rep was present on the rig floor to ensure that throttle was applied gradually throughout trip. Test MWD (okay) Note: Move pipe while testing MWD to minilnize any possible damage I i I I I I I I I I I I I I I I I I ( { BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 23:00-00:00 1.00 02/23/02 00:00-03:30 3.50 03:30-12:00 8.50 12:00-00:00 12.00 02/24/02 00:00-07:00 7.00 07:00-08:00 1.00 08:00-08:30 0.50 08:30-12:00 3.50 12:00-14:00 2.00 14:00-14:30 0.50 14:30-00:00 9.50 02/25/02 00:00-03:00 3.00 03:00-05:00 2.00 05:00-09:30 4.50 09:30-13:30 4.00 due to rotating PDC bit in casing while on BH motor. Lubricate rig & service top drive. Note: Called control room and notified them of 2nd turbine requirement. RIH to 6899' filling pipe. Hit tight spots @ 5080', 5800', & 6100'. Worked through without pumping. Ream last stand to bottom. Pump nut plug sweep while breaking in new bit. Rotate & slide ITom 6899' to 7590'. Pumped hi vis sweep at 7500'. Drill & slide ITom 7590' to 8580'. Note: ART: 10.88 hrs. AST: 3.6 hrs. Drilled fJ 8580' to 9013' md. Circ Hi-Vis Sweep, Shut down pumps and monitor well. Note: Shakers cleaned up pretty well. Pull one stand -- no swab, pump dry job, blow down top drive, mud pump and bleeder line. Short trip to 6700' (2 stands above last bit trip). Notes: 1. Hole in good shape -- 30 to 40K overpull and swabbing across the Schrader Bluff fm. 2. Displace mud and add baranex in preparation for weight up. Drill f/9013' to 9111' md. Notes: Weighting up ITom 9.1 ppg to 9.6 ppg by the top of the HRZ, 9.8 ppg by the top of the Kuparuk and 10.0 ppg by rD. Lubricate rig & service top drive. Drill from 9111' to 9730'. Note: 1. Saw 4100 units of gas in the Kuparuk C. Monitored well for 15 minutes. 2. Schlumberger due on location to run RFT's in Kuparuk. Drill ITom 9730' to 9945'. Casing point for 95/8". Condition mud & pump hi vis weighted sweep. Pull 1 stand & pump dry job, blow down mud lines & POR to shoe @ 3328' from 9945' Hole in good shape. Dry wiped 5 spots after pulling 40,000 to 55,000 over at 7485',6820',6153',6058', & 5108'. RIH to 9945' filling pipe every 25 stands. Blow down after filling. I I I I I I I I I I I ( I I I I I I I BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) Time Elapsed Code (ms) Time 13:30-17:00 3.50 17:00-17:30 0.50 17:30-18:00 0.50 18: 00- 21 : 00 3 .00 Operations Breakdown 21:00-21:30 0.50 21:30-22:00 0.50 22:00-00:00 2.00 Condition mud & circulate @ 900 GPM & 100 RPM. Pull 2 stands & monitor well. Okay Pump dry job & blow down all lines. POH to shoe, hole in good shape. Notes: SIO weights as follws: 220K @ 8245' 205K @ 7202' 190K @ 5299' 165K @ 4346' 155K @ 3392' Pull rubber, monitor well at shoe, replace rubber & air slips. PJSM on cut & slip drilling line. Hang blocks & cut off drilling line. 02/26/02 00:00-01 ~30 1.50 01 :30-02:30 1.00 02:30-06:30 4.00 12:30-13:30 13:30-14:30 1.00 1.00 Slip & cut drilling line. Clean up POH to jars. LID BRA. Pump fresh water through Anadrill tools to clean & flush. Blow down mud lines. Clear & clean rig floor. P/U test jt, pull bowl protector, set test plug, & test BOP's. Blow down all mud lines & choke manifold. Note: Great job -- Best in Class Performance is 5 hours. Lessons learned captured to make this task more efficient: Install. 2 pressure recorders (one on rig floor and one at test pump), install remote test pump controls on rig floor, and revise procedure for clear and consistent instructions for testing valves. Recall that choke manifold was tested while POOH. Pull test plug & install bowl protector. Lubricate rig & service top drive while waiting on additional logging tools. (RFT -formation sample chambers and liquid extraction equipment) P PJSM on R/U E-line. R/U Schlumberger E-line. Running RFT's as per Nstar G&G. Notes: Results will be sent to town via email-- see remarks for details. 1. 20 good tests including samples, one super charge, set. 2. 7 slow to build sets and one SAM. 3. One 2-3/4 gallon sample filled to 700 psi @ 9676.5' loggers depth. 4. One 1 gallon sample filled to 4000 psi @ same depth. S. 23 lost seal sets and 10 dry test sets. 06:30-07:30 1.00 07:30-12:30 5.00 14:30-15:00 0.50 15:00-16:00 1.00 16:00-00:00 8.00 I I: \1, BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) I I I I I I I I I I I I I I I I I I Time Elapsed Code (hrs) Time 02/27/02 00:00-07:30 7.50 Operations Breakdown 07:30-09:00 1.50 09:00-09:30 0.50 09:30-12:00 2.50 12:00-13:00 1.00 13:00-16:30 3.50 16:30-17:30 1.00 17:30-00:00 6.50 Complete E-line logging run- Details on previous DIMs report. Loggers TD @ 9,916 ft. POOH. Rig Down Schlumberger wireline. Pull Wear Ring. PJSM- Rig up to run 9.5/8" Casing. Install Franks Tool,Bails and Tongs MIU 9.5/8" shoetrack. Bakerlock and check floats- good. Run 9.5/8" casing to 13.3/8" shoe @ 3190 ft. Circulate Ca~ing contents @ 10 BPM/ 600 psi. No Losses. Continue to run 9.518", L-80, 47 lb/ft casing. No Losses. Running speed @ 18.4 joints per hour. Steadyl Safe progress. 02/28/02 00:00-01 :00 12:00-13:00 1.00 Run and land 9.5/8" casing. No Hole problems. Precautionary wash down last joint. 240 joints ofL-80, 47lb/ft casing. Overall average @ 18.4 jtsl hr. Hole in good shape and mud properties in excellent shape permitting smooth running. Stage up pumps slowly to 10 BPM / 600 psi- no losses. 1.2 bottoms up. Maximum gas @ 1100 units. Mix and pump 50 bbls of 11 ppg Spacer, 319 bbls Lead Slurry @ 11.2 ppg tailed by 106 bbls 15.9 ppg slurry @ 5 BPM/ 1000 psi. Drop Top Plug. Pump 25 bbls water followed by 695 bbls Mud with rig pumps @ 10 BPM! 1000 psi. Pressure increasing as cement lifted. Slow to 5 BPM. Final strokes 8300= 95%, No bump. Full Returns. Install 9.5/8" Pack-off and test same to 5000 psi. Clear rigfloor of all casing handling equipment. Change bails. Change control lines on Rams to 5" and function test same. R/U to inject into annulus. Install wear ring. Change out sweep on wellhead. Inject 220 bbls. of 10.0 ppg mud down 13 3/8" x 9 5/8" annulus while MlUBHA#7. Test MWD @ 1000'. Okay - BID mud lines & kill line. RIH to 9017' & tag cement. (816' above float collar) Drill cement trom 9017' to 9470'. Pump Efficiency equates to 87%. 1.00 01 :00-05:30 4.50 05:30-07:00 1.50 07:00-08:30 1.50 08:30-10:30 2.00 10:30-12:00 1.50 13:00-16:30 3.50 16:30-17:00 0.50 17:00-22:00 5.00 22:00-00:00 2.00 03/01/02 00:00-01 :00 01: 00-02: 00 02:00-03:30 1.00 1.50 Continue to drill cement down to Float collar @ 9,833 ft. Cement drilling at 220 ft/hr with 10 klbs WOB. Circulate Bottoms up. Test Casing to 4230 psi I 30 minutes with 10.2 ppg MW. 10.6 bbls pump/return. Discuss Well Control while conducting Test. Drill remainder of Shoetrack and clean out rathole. Displace well to 11.8 ppg system with 17.8 ppg spike fluid 1.00 03:30-05:00 1.50 05:00-08:30 3.50 I I I I I I I I I I I I I I I I I I I t \ BP Exploration - N orthstar NSO8 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 08:30-09:30 09:30-10:30 10:30-12:00 12:00-00:00 1.00 1.00 1.50 12.00 03/02/02 00:00-09:00 9.00 09:00-11:30 2.50 11 : 3 0-13 : 00 13:00-14:00 14:00-15:30 1.50 1.00 1.50 15:30-16:30 1.00 16:30-17:00 0.50 17:00-17:30 0.50 17:30-19:00 1.50 19:00-19:30 0.50 19: 3 0- 21 : 00 1. 50 21:00-21:30 0.50 21:30-00:00 2.50 03/03/02 00:00-01 :30 1.50 01 :30-02:30 1.00 02:30-05:30 3.00 05:30-06:00 0.50 06:00-07:00 1.00 07:00-11 :00 4.00 11 :00-12:30 1.50 transported to island on vac trucks. Drill 20 ft of new formation to 9965 ft. Conduct FIT to 13.6 ppg EMW. 850 psi surface pressure. Bit inside shoe. 1.8 bbls pump/return. Observed 10ft fill when going to bottom- probably from pressuring up on FIT. Clean out fill & drill fromm 9965' to 9980'. Drill trom 9980' to 10991'. Drill ahead 8.1/2" Hole to 11,385 ft monitoring all drilling trends and cuttings returns. No drag, No losses. 520 GPM/ 2500 psi. ECD steady. Some balling at 11,257 ft and @ 11,385 ft. Pump two 40 ppb walnut med, 6 ppb sap, 25 bbls. Seemed to help. Bit balling possibly due to low Lubricant concentration ( 0.5%) and new bit design? Drill ahead 8.1/2" Hole to TD. BRA dropping 0.5-0.9 deg/l00'. Top of Sag @ 11,457'. Drill to 11,470 ft for a 23 ft rathole. Circulate bottoms up @ 520 GPM/ 2500 psi. Up weight 360 klbs, Down weight 245 klbs. Rotating weight 285klbs.. Normal cuttings returns. Make Wiper trip to 9.5/8" Shoe @ 9,919 ft. Hole in good shape. Minor "tugs" at 11,194', 10,680' and 10,450'. (25 klbs o/pull) Lubricate rig & service top drive. Replace blower motor fuse on drawworks. RIH back to bottom from 9 5/8" shoe @ no more than 100 ft/min. 7' of fill. Hole slick. Condition mud & circulate high vis sweep. Circulated hole clean with no signs of splintered shales. Drop ESS & monitor well. POH to shoe keeping block speed less than 50' per minute. Hole slick. Momitor well, pump dry job, drop 2 3/8" rabbit, & blow down top drive. POH in preparation for running 7" liner. Kept block speed less than 50' per minute until 2,000' above 9 5/8" shoe. POOH to 5" HWDP. Laydown 24 joints 5" HWDP Pull BHA and laydown same. Bit in Very Good shape. Clear rigfloor. RIU to run 7" Liner. Make up Shoetrack. Check Floats. Run 42 joints ofL-80, 26Ib/ft, Hydril 521 Flush 7" Liner. Dog collar each joint. Make up FlexLock Hanger and ZXP Packer. Circulate string volume @ 8 BPM/ 200 psi. Up Down weight = 105 klbs. Rotate pipe @ 20 RPM= I I I ( I I I I I I I I I r I I I I I ~. BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 12:30-19:30 7.00 19:30-20:30 1.00 20:30-21 :30 1.00 21:30-22:00 0.50 22:00-22:30 0.50 22:30-23:30 1.00 23:30-00:00 0.50 03/04/02 01:30-02:00 0.50 02:00-03:00 1.00 03:00-04:00 1.00 04:00-04:30 0.50 04:30-06:00 1.50 06:00-09:00 3.00 09:00-10:00 1.00 10:00-11:00 1.00 11:00-12:00 1.00 12:00-14:30 2.50 14:30-15:00 0.50 15:00-19:30 4.50 19:30-20:00 0.50 20:00-20:30 0.50 20:30-23:30 3.00 23:30-00:00 0.50 03/05/02 00:00-02:00 2.00 02:00-03:00 1.00 03:00-06:00 3.00 06:00-07:00 1.00 07:00-08:00 1.00 1500 ftlbs.Blow down lines. RIH w/ liner on 5" DP filling every 10 stands. Circulate pipe volume @ shoe & blow down lines.Up weight 275K, down weight 220K, rotate pipe @ 20 RPM = 9500 ftlbs. While circulating & rotating @ 20 RPM - up weight 255K, down weight 240K. Torque 9500 to 10,000 ftlbs. Final circulating pressure 760 psi @ 8 BPM. Continue RIH wI liner to 11,435'. Open hole in good condition. MIU single & cement head. Wash down liner from 11435' to 11466'. Final setting depth of liner is 11461 '. ( 4 ft fill) Circulate pipe volume & PJSM for cement job. Stage pumps up in 1 bbl increments from 2-8 bbls. Final pressure @8 BPM was 760 psi. Pump 5 bbls of 12.8 spacer & test cement lines to 4,000 psi. Set liner. Circulate from top of 7" liner @ 9741 ft. Approximately 8 bbls cement seen @ surface. Rig down cement head and hoses. Clear rigfloor. Pull 15 stands. Flowcheck well. Slip and Cut Drilline. POH and lay down running tool- all in order Pull Wear Ring Test choke manifold. Clean L pits. Install test plug Work on pipe rack drain. Change top rams to 5 1/2". PJSM for testing BOP's Test BOP's Pull test plug & install bowl protector. PJSM for freeze protecting 13 3/8" x 9 5/8" annulus. Freeze protect 13 3/8" x 9 5/8" annulus wI 120 bbls. of diesel. Final pressure 840 psi @ 1 BPM. Pull rotary table & replace rotary motor while freeze protecting. Blow down freeze protect lines to bleed trailer. Install Rotary Table Motor while Freeze Protecting well. Test Casing to 3460 psil 30 mins over 11.8 ppg mud. 9 bbls pump/return. MIU 6.1/8" BHA with L WD/MWD. PJSM for loading sources. RIH making up HWDP Surface test MWDI L WD- OK. I:¡' I' t BP Exploration - Northstar NSO8 Daily Operations (I.A.D.C) ;1.11 i I I I I I I I I I I I I I I I I I Time Elapsed Code (hrs) Time 08:00-12:00 4.00 12:00-13:00 1.00 13 :00-14:30 1.50 14:30-15:00 0.50 15:00-18:00 3.00 18:00-21 :00 3.00 Operations Breakdown 21 :00-22:30 1.50 Rlli. Lubricate rig. Service top drive. Continue RIH to 11296' md. Wash down ITom 11296' md to 11380' md. Drill out shoe tracke and rat hole to 11470' md. Condition mud & swap mud over to 9.1 ppg. Clean screens twice each on both mud pumps (fish eye). Drill 20' of new formation ITom 11470' md to 11490' md. Circulate MWin= MWout = 9.1 ppg. FIT test to 11.3 EMW -1300 psig and 48 strokes. Held pressure for 30 mins while holding well control (pay-zone lost circulation matrix) safety briefing with rig team. Bleed down and blow down kill line. Drill f/ 11490' to 11493' md. 22:30-23:30 1.00 23:30-00:00 0.50 03/06/02 00:00-17:30 17.50 Drill ahead 6-1/8" production hole ITom 11493' md to TD at 12030' md (11270' TVD) with no losses. Drilling parameters: Total ROP= 33.6 fph. TF= 340 gpm with max pump pressure of2000 psig. Torque on bit was 9k ft-Ibs with 80 rpm. Final inclination and azimuth out 7.08 and 340.7 degs, respectively. Top ofShublick 10,801' TVDI 11557' MD, Top Ivishack 10,893' TVDI 11,643' MD, Top Kavik 11,183' TVD/ 11,943' MD Pump sweep and CB U. Flowcheck. POOH wi BHA #8 to 7" shoe. PUW 290 k off bottom. Hole in good condition. Monitor well at shoe for 15 mins ~ hole is stable. Pump dry-job and drop 2.3/8" steel rabbit. Blow down mud lines. Continue POOH wi BHA #8. 17:30-19:30 2.00 19:30-20:00 0.50 20:00-00:00 4.00 03/07/02 00:00-02:30 2.50 02:30-03 :30 1.00 03:30-05:00 1.50 10:30-11:00 0.50 11: 00-11 : 3 0 0.50 Continue to POOH. Lay down HWDP. Lay down BH~ PJSM. Pull source. Bit in good shape 2-3 and in gage. Clear rigfloor. RIU to run 4.1/2" Chrome Liner.PJSM. Make up shoetrack and check floats- OK. Run 17 joints of 4.1/2", V AM ace, L-80 Liner. M/U Baker Liner Hanger and Packer. RID Liner Equipment and Circulate Liner contents @ 7 BPMJ 200 psi. Up weight 80 KLbs, Down weight 75 klbs. RIH with drillpipe. Minor gas leak traced to connection fitting at back of rig. Investigate same and take rig of gas power and place pon Hi-line to resolve 05:00-05:30 0.50 05:30-07:00 1.50 07:00-09:00 2.00 09:00-09:30 0.50 09:30-10:30 1.00 I ! I r r I r r r r I r r I r r r t I ii' { ~ BP Exploration - North star NSO8 Daily Operations (I.A.D.C) Time (hrs) Elapsed Code Time Operations Breakdown 11:30-18:00 6.50 18:00-19:30 1.50 19:30-20:00 0.50 20:00-22:00 2.00 22:00-23:00 23: 00-00: 00 1.00 1.00 same. RIH 5" drill pipe to 7" shoe @ 11,461 ft. Hole taking correct displacement. Circulate string contents @ shoe @ 7 BPMI 600 psi. Up weight 285 klbs, Down Weight 250 klbs. Run 4 Vl" liner to bottom. Hole slick. Tag on depth. Hook up cement. Circulate bottoms up @ 12,030 ft staging pumps up to 7 BPMlI030 psi. Full returns. No reciprocation. Minor packing off 50% through circulating. No gas on bottoms up. PJSM while circulating to discuss modified procedure. Flush Surface lines and system through both pumps to rig floor with seawater( 40 bbls). Charge both pumps with 9.3 ppg Brine. Mix and pump 5 bbls Spacer, Test lines to 4000 psi, Pump 25 bbls Spacer and 28bbls of 15.9 ppg Slurry @ 5 BPMI 500 psi. Close head, Flush cement lines. Drop Dart and prepare to displace cement with 9.3 ppg Clean KCL and mud. ".1. i. I' , I.. I. 'I I ,I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: TOM MANSFIELD Report Delivered To: KEN LEMLEY I Depth (M D) (1VD) 7168 to 7175 ft 6722 to 6728 ft Show Report No. .-:! Date: 02/27/02 I Interpretation: Negative slope between C1/C2 & C1/C3 indicates zone is water wet. Readings may be erroneous due to possible contamination from recirculated trip gas. Pale green sample fluorescence with slow milky white cut fluorescence reported through interval. I o,(¡ Depth 7180 ft Gas U Units 536 Mud Chlorides (ppm) = ---Fiõ~iíñë-------s-ucti{)ñ-------siiõvv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 24.1 - = 24.1 C2 0.7 - = 0.74 C3 0.080 - = 0.080 C4 0.319 - = 0.319 C5 0.241 - = 0.241 --Prõd-uëtiõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 2 o,(¡ Depth ft Gas Units Mud Chlorides (ppm) = ---Fiõ~iíñë-------s-ucti{)ñ-------Sh{)vv-~---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) I Hydrocarbon Ratios C1/C2 = 32.4 C1/C3 = 301.3 C1/C4 = 75.6 C1/C5 = 100.0 I I I = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = = I = = = I o,(¡ Depth ft Gas UUnits Mud Chlorides (ppm) = ---Fiõ~ifiîë-------s-ucti{)ñ-------Sh()~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = C2 - = C3 - = C4 - = C5 - = --Fïrõd-uëtiõñ---------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 o,(¡ Depth ft Gas x Units Mud Chlorides (ppm) = ---Fiõ~niië-------s-ucti{)ñ-------Sh()~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) I Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = I I I Hydrocarbon Ratios C1/C2 =##### C1/C3 =##### C 1/C4 = f#I#II:# C1/C5 =f#I#II:# I C1 - = C2 - = C3 - = C4 - = C5 - = --Prõd-ûëtiõñ---------------------------------------------------------------------------- Analysis I 1000.0 1000.0 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH I::::::- I- I-- - = - - / " - ---_/-- --S .-.--.-'- '7 - .- .--Y / d - ------ ------ --- - - - --- --- - - - - - - - ~ 1 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH 100.0 - - - - - - -1-.-,----- ~-~ --:I~- ~-~ - - - - -- ... Gas -- - ------.¡.--- 10.0 - - - - - - - - - - -,- - - - - - - - - - -1- - - - - - - - - - - Oil --- NPH 1.0 i I sperry-sun DRILLING SERV1CES Show Report Well Name: NORTHSTAR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: TOM MANSFIELD Report Delivered To: KEN LEMLEY I Depth (M D) (1VD) 9140 to 9193 ft 8533 to 8581 ft Show Report No. --L Date: 02/27/02 I Interpretation: Steam still evaluation shows light, high gravity oil bearing zone. Cuttings evaluation indicates numerous thin sand stringers in a Siltstone with traces of dull yellow/green and yellow fluoresence. No cut fluoresence when wet. Light milky white cut fluoresence when dry. I % Depth - ft Gas 0 Units Mud Chlorides (ppm) = ---Fiõ\MTíñë-------S-üctl()ñ-------Sh()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 49.7 - 0.000 = 49.7 C2 6.5 - 0.000 = 6.48 C3 5.466 - 0.000 = 5.466 C4 3.915 - 0.000 = 3.915 C5 2.697 - 0.000 = 2.697 --Prõ(füë6õñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 2 % Depth ft Gas Units Mud Chlorides (ppm) = ---Fiõ\Mniië-------S-üctl()ñ-------Sh()vv-~---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 40.5 - 0.000 = 40.5 - C2 5.27 - 0.000 = 5.27 C3 4.50 - 0.000 = 4.50 - C4 3.191 - 0.000 = 3.191 C5 2.024 - 0.000 = 2.024 --Prõdliëfiõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 % Depth ft Gas Units Mud Chlorides (ppm) = ---Fiõ~irñë-------Š-üctl()ñ-------Sh()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) I Hydrocarbon Ratios C1/C2 = 7.7 C1/C3 = 9.1 C1/C4 = 12.7 C1/C5 = 18.4 I I I Hydrocarbon Ratios C1/C2 = 7.7 - C1/C3 = 9.0 C1/C4 = 12.7 C1/C5 = 20.0 I I I Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = I C1 - = C2 - = C3 - = C4 - = C5 - = I --Firõdlictiõñ'"--------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (ppm) = ---Fiõ~n¡;ë-------sijcti()ñ-------Sh()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) I I C1 - = C2 - = C3 - = C4 - = C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = I --PrCid-ûêITõñ---------------------------------------------------------------------------- Analysis I 1000.0 1000.0 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH - - - - - ~----- - ---- - - - - - - - -----:::" - - ----- - - ~ '-- ~ - - ------ ------ --- ---------- - ------ - - - - ---- - - - - L- - - - - -' 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 NPH 100.0 - - - - -1--...---- ~_":' --=1.:'"'- :-_~ - - - - -- - Gas - - -- ------ --- 10.0 - - - - - - - - - - -1- - - - - - - - - - -1- - - - - - - - - - - Oil NPH 1.0 I I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: TOM MANSFIELD Report Delivered To: KEN LEMLEY I Depth (MD) 9610 to 9785 ft (NO) 8965 to 9125 ft Show Report No. 3 Dateffime: 2/26/2002 I Interpretation: Steam still chromatograph ratios, lack of cuttings fluorescence, and a white crush cut fluorescence when dried indicate presence of light, high gravity oil, probably associated with some gas condensate. The slightly steeper slope of the plots in relation to the dashed line indicate somewhat low permeability. Sample analysis revealed somewhat low porosity due to presence of a silj:y clay matrix in sandstone intervals. I % Depth 9630 ft Gas G] Units 3750 Mud Chlorides (ppm) = 17K ---FÎõvviñ1ë-------S-uctlè)ñ-------Šh()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 99.33 - 0.76 = 98571 - C2 10.04 - 0.21 = 9835 - C3 6.17 - 0.41 = 5754 - C4 3.96 - 0.61 = 3356 - C5 2.73 - 0.67 = 2060 --PrõdLJ¿tlõñ--------------------~------------------------------------------------- Analysis x Gas x Oil Water Non-Producible Hydrocarbons 2 % Depth 9700 ft Gas x Units 4985 Mud Chlorides (ppm) = 17K ---FÎõvvniië-------siU¡:tl()iñ-------Šh()~~---------------------------'------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 81.34 - 0.76 = 80.59 C2 8.84 - 0.21 = 8.63 C3 5.27 - 0.41 = 4.86 C4 3.57 - 0.61 = 2.96 - C5 2.64 - 0.67 = 1.97 --Prõd-ü¿tlõñ---------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 3 % Depth # 9725 ft Gas x Units 5915 Mud Chlorides (ppm) = 17K ---FÎõvviñ1ë-------S-uctlè)ñ-------Šh()vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 70.01 - 0.76 = 69.25 C2 8.83 - 0.21 = 8.62 C3 5.83 - 0.41 = 5.42 C4 4.11 - 0.61 = 3.50 C5 3.18 - 0.67 = 2.51 --Prõ(fu¿tlõñ---------------------------------------------------------------------------- Analysis Gas x Oil Water Non-Producible Hydrocarbons 4 % Depth 9750 ft Gas x Units 1850 Mud Chlorides (ppm) = 17K ---Flõvvniië-------S-uctlè)ñ-------Šhè)vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 39.12 - 0.76 = 38.36 C2 5.23 - 0.21 = 5.02 C3 3.38 - 0.41 = 2.97 C4 2.38 - 0.61 = 1.77 C5 1.91 - 0.67 = 1.24 --PrõdLJ¿tlõñ-------------------- Analysis I Hydrocarbon Ratios C1/C2 = 10.0 C1/C3 = 17.1 C1/C4 = 29.4 C1/C5 = 47.9 I [ I Hydrocarbon Ratios C1/C2 = 9.3 C1/C3 = 16.6 C1/C4 = 27.2 C1/C5 = 40.9 [ I I Hydrocarbon Ratios C1/C2 = 8.0 C1/C3 = 12.8 C1/C4 = 19.8 C1/C5 = 27.6 I I I Hydrocarbon Ratios C1/C2 = 7.6 C1/C3 = 12.9 C1/C4 = 21.7 C1/C5 = 31.0 I I ----------------------------------------------- I C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 1000.0 - - - - =.--------------- ..................", - ---. ------ --- ~ I....-- - I--- -::J - -- - --------- - ~- - - - - - - - - - - - - - - - ~ - - - - -'- -' NPH 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 1000.0 NPH 100.0 - - - - -,- ----""'- ~-~ -"':1.:"'- ~-~ - - - - -- ... Gas ------..1:..;.-- 1QO ~--~---- -----~----------- Oil NPH 1.0 C1 C5 ¡.~.' " II ilil I ¡ ! sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY ~í i Depth (MD) (TV D) 11447 to 11553 ft 10694 to 10798 ft Show Report No. ¿ Date: 03/08/02 I Interpretation: Sample examination and steam still chromatograph analysis, a fair dull yellow/orange fluoresence with a slow milky white cut would produce oil. Gas trap gas-in-air ratios show good overall gas readings from steam still and gas trap indicates lower section of formation tight. I % Depth 11510 ft Gas UUnits 722 Mud Chlorides (ppm) = 11000 ---Fiõ;Vríñë-------š-uëtië)ñ-------Shë)~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 41.3 - 0.395 = 40.9 C2 7.1 - 0.376 = 6.75 C3 5.389 - 1.052 = 4.337 - C4 2.102 - 0.121 = 1.981 C5 1.924 - 0.033 = 1.891 --~õd-u¿flõñ---------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 2 % Depth 11530 ft Gas Units 272 Mud Chlorides (ppm) = 11000 ---Fiõ;Viíñë-------š-uëtië)ñ-------Shë)vv------------------------------------==----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 16.2 - 0.395 = 15.8 C2 2.94 - 0.376 = 2.57 C3 2.50 - 1.052 = 1.45 - C4 2.102 - 0.121 = 1.981 - C5 0.086 - 0.033 = 0.053 --F>rõd-u¿flõñ---------------------------------------------------------------------------- Analysis nGas mail nWater nNon-Producible Hydrocarbons 3 I Hydrocarbon Ratios C1/C2 = 6.1 C1/C3 = 9.4 C1/C4 = 20.6 C1/C5 = 21.6 I I I Hydrocarbon Ratios C1/C2 = 6.2 C1/C3 = 10.9 C1/C4 = 8.0 C1/C5 = 298.8 I I I Depth ft Gas U Units Mud Chlorides (ppm) = ---Flõ;Viíñë-------šijëfíCiñ-------shë)vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 - 0.000 = 0.0 C2 - 0.000 = 0.00 C3 - 0.000 = C4 - 0.000 = C5 - 0.000 = --Prõ(fu¿flõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (ppm) = ---Fiõvvniïë-------š-uëtië)ñ-------Shë)~------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 - 0.000 = 0.0 C2 - 0.000 = 0.00 C3 - 0.000 = 0.000 C4 - 0.000 = 0.000 C5 - 0.000 = 0.000 --Prõd-u¿flõñ---------------------------------------------------------------------------- Analysis nGas nail nWater nNon-Producible Hydrocarbons Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = [ I I Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = I I I 1000.0 1000.0 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH -=----- -....-=). - -~....---~- ~ - ~ ' - /' - - - - - - - - - - -' -¡ - ----. 1--- ~ -- - == - - - - ~ 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 NPH 100.0 ------- - - - -,- ------- ~-~ --=1.:-"'- ~-~ - - - - -- - Gas -- - ------+--- 10.0 -----------~---------~----------- Oil NPH 1.0 I!, 'I: I, , I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MARK LlNDLOFF Report Delivered To: KEN LEMLEY I Depth (MD) (1VD) 11643 to 11800 ft 1 0887 to 11042 ft Show Report No. ..2 Date: 03/08/02 I Interpretation: Upper Ivishak Zone - Sample examination and cut F/11642'MD T/12760"MD Dull yellow/green fluorescence with a slow milky white cut to a very poor dull orange cut was observed. Steam Still analysis predicts this Ivishak Interval would produce oil. I % Depth 11670 ft Gas D Units 549 Mud Chlorides (ppm) = 11000 ---~õ\Mni1ë-------Š-üctlë>ñ-------Šhë>vv------------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 30.6 - 0.395 = 30.2 C2 5.7 - 0.376 = 5.36 C3 4.946 - 1.052 = 3.894 C4 4.394 - 0.121 = 4.273 C5 2.001 - 0.033 = 1.968 --Prõd-üëtiõñ---------------------------------------------------------------------------- Analysis Gas x Oil Water Non-Producible Hydrocarbons 2 % Depth 11690 ft Gas Units 382 Mud Chlorides (ppm) = 11000 ---F1õ\Miíñë-------Š-üctlë>ñ-------Šhc>vv-----------------------------------_::----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 19.8 - 0.395 = 19.4 - C2 3.68 - 0.376 = 3.31 C3 3.27 - 1.052 = 2.21 C4 3.106 - 0.121 = 2.985 C5 1.545 - 0.033 = 1.512 --Prõdijëtiõñ---------------------------------------------------------------------------- Analysis Gas x Oil Water Non-Producible Hydrocarbons 3 % Depth 11710 ft Gas Units 414 Mud Chlorides (ppm) = 11000 ---Fïõ\Miín4;-------Š-üctlë>ñ-------Šhë>vv------------------------------------::_---------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 23.9 - 0.395 = 23.5 C2 4.15 - 0.376 = 3.77 C3 3.94 - 1.052 = 2.88 C4 3.686 - 0.121 = 3.57 C5 1.878 - 0.033 = 1.85 --Prõd-üëtiõñ---------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 % Depth 11770 ft Gas x Units 447 Mud Chlorides (ppm) = 11000 ---~õ\Mifi1ë-------Š-üctlë>ñ-------Šhë>vv-----------------------------------_::_---------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 25.1 - 0.395 =-1!Z. C2 4.12 - 0.376 = 3.74 C3 3.752 - 1.052 = 2.700 C4 2.567 - 0.121 = 2.446 C5 0.470 - 0.033 = 0.437 --Prõd-üëfiõñ---------------------------------------------------------------------------- Analysis nGas IXlOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 5.6 C1/C3 = 7.8 C1/C4 = 7.1 C1/C5 = 15.3 I I I Hydrocarbon Ratios C1/C2 = 5.9 C1/C3 = 8.8 C1/C4 = 6.5 C1/C5 = 12.9 I I I Hydrocarbon Ratios C1/C2 = 6.2 C1/C3 = 8.1 C1/C4 = 6.6 G1/C5 = 12.7 I I I Hydrocarbon Ratios C1/C2 = 6.6 C1/C3 = 9.1 C1/C4 = 10.1 C1/C5 = 56.5 I I 1000.0 1000.0 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH L '- ~------- ._--~ ----- - - - - - ~ - - ------- -----" --- ---- . -...J ~I 'F ----~----- == - - - - J - ~ 100.0 Gas 10.0 Oil NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 NPH ~ L = I-- ~---------------~_':"_-:.:-_:-_~- - - 7"'~ -;r- ------. ---- _./- I/' -- ---------- ---- I/'____~. -:...:: - - - - - - I - ---' 100.0 Gas 10.0 Oil NPH 1.0 1~ ~ if II' I: sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS08 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: MAR K LI N DLOFF Report Delivered To: KEN LEMLEY I I \, Depth (MD) (lVD) 11810 to 11950 ft 11052 to 11191 ft Show Report No. -Ê Date: 03/08/02 Interpretation: Lower Ivishak Zone - Sample examination and cut F/11810'MD T/11950"MD Dull yellow/green fluorescence with very_poor dull orange cut was observed. Steam Still analysis predicts this Ivishak Interval would produce oil. I I % Depth 11810 ftGas UUnits 430 Mud Chlorides (ppm) = 11000 ---Fiõvviínië-------š-uéti(;ñ-------Šhe>¥i------------------------------------------------ ppm ppm ppm (Steam Still PPM's in 1000's) C1 33.1 - 0.395 = 32.7 C2 5.2 - 0.376 = 4.84 C3 4.716 - 1.052 = 3.664 C4 4.136 - 0.121 = 4.015 C5 1.824 - 0.033 = 1.791 --Prõdliëtiõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 2 % Depth 11890 ft Gas Units 477 Mud Chlorides (ppm) = 11000 ---Fiõvvifiîë-------Š-uétl(;ñ-------Šhe>vv------------------------------------==----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 25.4 - 0.395 = 25.0 C2 4.50 - 0.376 = 4.12 C3 4.09 - 1.052 = 3.04 C4 4.201 - 0.121 = 4.080 C5 2.562 - 0.033 = 2.529 --Prõ(fuëtiõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 % Depth 11910 ft Gas Units 127 Mud Chlorides (ppm) = 11000 ---Fiõvvniië-------Š-uétl(;ñ-------Šhe>vv------------------------------------==----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 12.0 - 0.395 = 11.7 C2 2.41 - 0.376 = 2.03 - C3 2.65 - 1.052 = 1.60 C4 3.179 - 0.121 = 3.06 C5 2.345 - 0.033 = 2.31 --Prõ(fuëtiõñ---------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 4 % Depth 11930 ft Gas x Units 162 Mud Chlorides (ppm) = 11000 ---Fiõvvniië-------š-uéü(;ñ-------Šhe>vv------------------------------------==----------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 11.3 - 0.395 = 10.9 C2 1.90 - 0.376 = 1.53 - C3 1.963 - 1.052 = 0.911 C4 2.293 - 0.121 = 2.172 C5 1.780 - 0.033 = 1.747 --Prõdliëtiõñ---------------------------------------------------------------------------- Analysis nGas mOil nWater nNon-Producible Hydrocarbons I Hydrocarbon Ratios C1/C2 = 6.8 C1/C3 = 8.9 C1/C4 = 8.1 C1/C5 = 18.2 I I I Hydrocarbon Ratios C1/C2 = 6.1 C1/C3 = 8.2 C1/C4 = 6.1 C1/C5 = 9.9 I I I Hydrocarbon Ratios C1/C2 = 5.7 C1/C3 = 7.3 C1/C4 = 3.8 - C1/C5 = 5.0 I I I Hydrocarbon Ratios C1/C2 = 7.2 - C1/C3 = 12.0 C1/C4 = 5.0 C1/C5 = 6.3 I I I 1000.0 100.0 1000.0 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 NPH ~ L :::j - ----- - - - ---- - - - --- ~ ':" - ---- - - ------ ~------ ~~: -------- - - - ---- - r= - - IJ I I Gas 10.0 Oil NPH 1.0 C1 C2 Hyd rocarboh Ratios C1 C1 - - C3 C4 NPH 100.0 - - - - - - - - -1- ------- ~-~ --=1.:"'- :-_~ - - - - -- - Gas -- - -----_.a.--- 1 0.0 ~ - - - - - ~P'- - - - - - - - -1- - - - - - - - - - - Oil --.... -, - NPH 1.0 I 5 pel'""""'" V - 5U n i ~ I 0 R I L..L.. I N G SE!RVICeS ':ustomer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 !eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1 211212002 a a Moved Rig Gavin Kidd I Mudlogger's Morning Report -,} I ;:-i R. 0 . P - Current na 24 hr Avg ftJhr ftJhr ( units unm ( Deg F ( 24 hr Max ftJhr @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC 0 0 0 :~:JGas* ";~1Temp Out na I .~- ( I I I I I I I I I Logging Engineer: Doug Wilson I Mark lindloff * 10000 units = 100% Gas In Air I I Customer: BP Alaska ~ ~eport No.: 2 Well: NorthStar NS 08 Date: 2/1312002 Sper"r'V- sun Area: North Slope Depth 350 '1 CRILL I N G SERVIc:es Lease: NorthStar NS 08 Footage Last 24 hrs: 350 :{: Rig: Nabors 33E Rig Activity: Drilling Mudlogger's Morning Report I Job No.: AK AM 22026 Report For: Joe Polya Shows: I I I I Current 24 hr Avg 24 hr Max Pump and Flow Data JR.O.P. 404 ftIh r 275 ftlhr ( 478 ftlhr @ 273 ) Pump 1 82 spm DH flow JGas* 6 units 6 unm( 8 units @ 201 ) Pump 2 78 spm Total flow ,\ Temp Out 43 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 620 psi A V @ DC I I I I ( I ( I I I I I Logging Engineer: D~LJg Wilson I Mark lindloff * 1 0000 units = 1 00% Gas I n Air I I 5per-t....,V- sun I i ,'~;, ':~ .'i~ a R I L..L I N Ci SERVices Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 3 - 2/1412002 1671 1,321 Drilling Joe Polya I Mudlogger's Morning Report ~,,~; I Current ":1R.OoPo 210 : Gas. 8 ;;~, Temp Out 43 24 hr Avg 24 hr Max Pump and Flow Data ftIhr 201 ftIhr ( 808 ftIhr @ 409 ) Pump 1 102 spm DH flow units 5 un~( 16 units @ 1644 ) Pump 2 102 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres _1450- psi AV @ DC I I I I I I I I I I 1 'I Logging Engineer: Doug Wilson I Mark Lindloff , ~ ;;"y~:t!id!;:~it(f[Ó~~;:\~:\'~:bifl;c:~}::i~\~~fi¡~~~~~ßf~~~JI I I I I I I I I I I ! I I I ! I I (' Customer: BP Alaska ( Report No.: 4 Well: NorthStar NS 08 Date: 2/15/2002 SpE!r'r'V- sun Area: North Slope Depth 3,344 C R I L...L.I N Ci SERVices Lease: NorthStar NS 08 Footage Last 24 hrs: 1,673 Rig: Nabors 33E Rig Activity: POOH Mudlogger.s Morning Report I Job No.: AK AM 22026 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data AR.O.P. 0 ftIhr 202 ftlhr ( 704 ftIhr @ 2093 ) Pump 1 0 spm DH flow 0 units 9 un~( 22 units @ 2308 ) Pump 2 0 spm Total flow 45 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 0 psi AV @ DC Drillina ahead F/1371 T/3344 , Circulate hole clean. at present POOH for casino to run 133/8" casin..... Logging Engineer: Reg Wilson I Mark Lindloff * 10000 units = 100% Gas In Air t\ . ..".~: """.':';j~~\1:1 I sper""V- sun ; ~ I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 5 - 2/16/2002 3,344 0 Cementing Joe Polya I 0 A I LL.. I N G !5 e A v I c: e s " ':'o~;~-;¡ .'ði~"S~t':¡;A~,,"""O' ,.."øJ¡ I Current "¡IRo,Po a :;\ Gas. a ~;(' Temp Out 44 24 hr Avg ftlhr a ftJhr ( units a unit'¿ ( Deg F ( a 0 24 hr Max ftJhr @ units @ deg F @ a 0 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data L spm DH flow a spm Total flow spm AV @ DP a psi A V @ DC a a a I I Mud Wt In Mud Wt Out Vise 45 sees API tilt 10.4 ml HTHP ml Mud Wt at Max Gas - -- PV 9 cP YI 12 Ibs/100ft2 Gels 5 I 9 I a Ibs/100ft2 pH 8.6 Sd I Type: 0.00 RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ \ \ TF A: ------ Total Revs on Bit: Footage for Bit Run 3328 ft ft Trip Gas: Short Trip Gas: to 14 Mud Cut: Mud Cut: to ppg Trip CI: 17000 ppg Short Trip CI: Feet of Fiji on Bottom: I I I I I I I I I I I I I I I I I I I I I I I I Customer: BP Alaska ( Report No.: 6 Well: NorthStar NS 08 Date: 2/1712002 Sper--r'V- sun Area: North Slope Depth 3,344 DR I L..L I N G seRVices Lease: NorthStar NS 08 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Testing BOP's Mudlogger's Morning Report I Job No.: AK AM 22026 Report For: Joe Polya Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ftIh r 0 ftlhr ( 0 ftIhr @ 0 ) Pump 1 0 spm DH flow 0 units 0 unm( 0 units @ 0 ) Pump 2 0 spm Total flow 40 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres JL- psi AV @ DC Logging Engineer: BE!g Wilson I Mark Lindloff ¡ I I I I I I I I I I I I I I I ,."."", :~~! 5p~""'V- sun J:J A I L-L. I N G 5 f!! A V I c: e 5 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 teport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 7 2/1812002 3,364 20 Cutting & Slip Joe Polya ì,~"c{'::l{~,~'d¡;,~.. ,', Current 24 hr Avg 24 hr Max Pump and Flow Data ","'.'.,:'J,;, R.O.P. 0 ftJ~r 300 ftJ~r ( 300 ftJ~r @3355)Pump1 0 spm DH flow <,! Gas. 1 units 3 Unit: ( 4 units @ 3362 ) Pump 2 0 spm Total flow ..,. :::: Temp Out 45 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 0 psi A V @ DC I I I I I I I I I I 5p~"'V- sun I I CRI L..L-I N Gi SEAVlc:es Customer: Well : Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 2120/2002 4,713 0 TIH Joe Polya Mudlogger's Morning Report I '>""""~'\\~~;;,:I':<'~;;:~~~:¡¡ I Current 0 0 50 24 hr Avg ftlhr 0 ftlhr ( units 0 unite.. ( Deg F ( 0 0 24 hr Max ftlhr @ units @ deg F @ 0 0 ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data ~ spm DH flow 0 spm Total flow spm AV @ DP psi A V @ DC I Drilled F/3364 T/4713", POOH do to rota Logging Engineer: Reg Wilson I Mark Lindloff I ~ i I C A 11-1-1 N Ci sper--...,v- sun seRVICES I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 ~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ~'ó!~i,~'¡¡.;~'~-:.:.'!:; ,-,- 9 2/20/2002 4,713 0 TIH Joe Polya I Current 24 hr Avg 24 hr Max Pump and Flow Data 0 ftIhr 0 ftIhr ( 0 ftIhr @ 0 ) Pump 1 0 spm DH flow 0 units 0 unm( 0 units @ 0 ) Pump 2 0 spm Total flow 0 - 50 Deg F ( deg F @ ) Pump 3 spm AV @ DP 0 --- - Pump Pres ~ psi AV@DC 0 I I Mud Wt In Mud Wt Out I I I I I I Depth I I I I before to to Connection Gas and Mud Cut ft untts ppg ft untts ppg ft untts ppg Drill Rate during I ~.i¡K '- Logging Engineer: R.~g Wilson I Mark Lindloff Drilling Breaks after before Gas during after Cgl % Lithology Sst Sh Sitst ---- ---- ---- ---- I Customer: BP Alaska ( ~eport No.: 10 Well: NorthStar NS 08 Date: 2121/2002 Sper"r"'V- sun Area: North Slope Depth 6,437 (~I CAI LLI N G SEAVIc:es Lease: NorthStar NS 08 Footage Last 24 hrs: 1 ,724 (. Rig: Nabors 33E Rig Activity: Drilling ahead ," I Job No.: AK AM 22026 Report For: Joe Polya Mudlogger's Morning Report Shows: I I II I ( I I I I I I I I I I I I Current _,tRO.P. 65 "I Gas. 74 } Temp Out 52 24 hr Avg 24 hr Max Pump and Flow Data fUhr 82 fUhr ( 608 ftIhr @ 5097 ) Pump 1 105 spm DH flow units 138 un~( 1735 units @ 5910 ) Pump 2 105 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 1~~ psi AV @ DC Vise 47 sees API filt 6.4 ml HTHP - -- PV 8 eP YI 20 Ibs/100ft2 Gels 5 I 7 I --- Drill with rotarv steerable tool from 4713' to 6437'. Drillina ahead Logging Engineer: Reg Wilson I Tom Mansfield . 10000 units = 100% Gas In Air I~$! I I I Customer: BP Alaska ( Report No.: 11 Well: NorthStar NS 08 Date: 2/2212002 ::~~~~:~~~ I Area: North Slope Depth 6,899 Lease: NorthStar NS 08 Footage Last 24 hrs: 462 Rig: Nabors 33E Rig Activity: RIH Mudlogger's Morning Report I Job No.: AK AM 22026 Report For: Joe Polya Shows: I', ,I ! 'c- Current 24 hr Avg 24 hr Max Pump and Flow Data ftlhr 93 ftlhr ( 381 ftlhr @ 6661 ) Pump 1 spm DH flow units 115 unite.. ( 229 units @ 6850 ) Pump 2 spm Total flow Deg F ( ---- deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC I ":"~R.O.P. ,.'~ ~": Gas. !;¡) Temp Out 45 I I Vise 45 sees API filt 6.8 ml HTHP ml Mud Wt at Max Gas - -- PV 8 eP YI 19 Ibs/100ft2 Gels 5 I 7 I 8 Ibs/100ft2 pH 8.6 Sd I I I r Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Cly Sd Sltst I Depth to to ---- ---- I ---- ---- I I Drilled to 6899'. Circ. & POOH for new bit and BHA. UD BHA #5 & P/U BHA #6. Could get bit throuah wear ring. Pulled wear ring. Grind wear ring. Re-installed wear ring. RIH, service too drive. Continue in hole with BHA#6. I I Logging Engineer: Reg Wilson I Tom Mansfield I [ Customer: BP Alaska ( ~eport No.: 12 Well: NorthStar NS 08 Date: 2/23/2002 5pE!r""'V- sun Area: North Slope Depth 8,578 CRILL I N G SE5RVI c: e 5 Lease: NorthStar NS 08 Footage Last 24 hrs: 1,679 Rig: Nabors 33E Rig Activity: Drill Ahead I Job No.: AK AM 22026 Report For: Joe Polya Mudlogger's Morning Report Shows: I I ,~IR.o.p. Current 24 hr Avg 24 hr Max Pump and Flow Data 35 Slide ftIhr 105 ftIhr ( 276 ftIhr @ 6972 ) Pump 1 102 spm DH flow ~Gas* 110 units 128 unite.. ( 536 units @ 7172 ) Pump 2 103 spm Total flow ..'ÆI Temp Out 75 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 2650 psi A V @ DC --- I I VISC 44 sees API tilt 8.2 ml PV 12 eP YI 24 Ibs/100ft2 Gels I I I I Connection Gas and Mud Cut ft unns ppg ft unäs ppg ft unns ppg I Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Cly Sd Sitst I Depth to to ---- ---- I ---- ---- I I I Schrader Bluff 6782' MD, 6382' TVD CoMlle 7435' MD, 6967' TVD Logging Engineer: R§!g Wilson I Tom Mansfield I I I I r I I I I I I I I I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 ,~eport No.: Date: Depth Footage last 24 hrs: Rig Activity: Report For: Shows: 13 2/24/2002 9,733 1,155 Drill Ahead Joe Polya .~ (~., ., ,I"~': :~~ sp~""v- sun DR! L-L I N G 5 e R v I c= B 5 ,,".1M."'~,""~'" Current ':"IR.O,P. 110 '" .'< Gas" 4987 :d Temp Out 105 24 hr Avg 24 hr Max Pump and Flow Data ftIh r 95 ftIhr ( 171 ftIhr @ 9307 ) Pump 1 104 spm DH flow units 776 unite... ( 4987 units @ 9698 ) Pump 2 102 spm Total flow Deg F ( ----- deg F @ ) Pump 3 spm AV @ DP Pump Pres 2980 psi A V @ DC HTHP 9.1 ml Mud Wt at Max Gas - - ~ I ~I -2Z..lbs/100ft2 pH 8.3 9615 - 9690 - 9720 to to to 9657 - 9705 - 9732 Connection Gas and Mud Cut ft units ppg ft ft units ppg ft ft units ppg ft Drilling Breaks Drill Rate Gas before during after before during after 100 140 60 500 4000 1500 90 160 115 750 4987 3125 80 150 110 3125 5915 1800 % Lithology Sst Sh Sitst 40 30 30 ---- 30 30 40 ---- 40 20 40 Depth ---- ---- Logging Engineer: Reg Wilson I Tom Mansfield .. 10000 units = 100% Gas In Air "'i"\;¡¡~~~.~~~~;~~~'i~;~~"lW~~Ji¡'~' ~~~¡,i¡ir&m1¡1!!'-i~;;r1rl¡"."\,',.\,~..!\.;~\"":\,,,,,II..' I I I I r r r r I r r r I I I I I I I I SpE!r""'V- sun 0 A I L..L.. I N G 5 IE! A V I c: IE! 5 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 14 212512002 9,945 212 POOH Joe Polya l.~-" Current na .;~1' R.O.P. :,<; .,' Gas. f~; Temp Out na 70 24 hr Avg 24 hr Max Pump and Flow Data ftIh r 98 ftlhr ( 135 ftJhr @ 9778 ) Pump 1 105 spm DH flow units 775 unm( 5915 units @ 9725 ) Pump 2 104 spm Total flow 884 Deg F ( 106 deg F @ 9945 ) Pump 3 spm AV@ DP ~ ----- ---- Pump Pres 2990 psi A V @ DC 252 I I I I I I I I I I I I I I I I I I Customer: BP Alaska If Report No.: 15 Well: NorthStar NS 08 Date: 2/2612002 Sper"-'V- sun Area: North Slope Depth 9,945 C A I L-.L-. I N G seRVices Lease: NorthStar NS 08 Footage Last 24 hrs: Rig: Nabors 33E Rig Activity: wire line logs I Job No.: AK AM 22026 Report For: Joe Polya Mudlogger's Morning Report Shows: '-"'1' Current 24 hr Avg ftlhr ftlhr ( units unite.. ( Deg F ( 24 hr Max ftlhr @ units @ deg F @ Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV@ DC ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate during Sst % Lithology Sh Sltst Gas during before after before after to to to ---- ---- ---- ---- line. Continue POOH. Lav down BHA #6. Test BOPs. Ria UP wire line. 'Logging Engineer: Reg Wilson I Tom Mansfield . 1 0000 units = 1 00% Gas I n Air 'I I Customer: BP Alaska ( Report No.: 16 Well: NorthStar NS 08 Date: 2127/2002 SpE!r'rv- sun Area: North Slope Depth 9,945 CRIL'-I N G ' .. Lease: NorthStar NS 08 Footage last 24 hrs: seRVices Rig: Nabors 33E Rig Activity: Run 9 5/8" Csng I Job No.: AK AM 22026 Report For: Joe Polya Mudlogger's Morning Report Shows: I Current 24 hr Avg ftlhr ftlhr ( units unit'¿ ( Deg F ( 24 hr Max ftlhr @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC I "fl' R. O. P. F ", Gas. ;~~ Temp Out I VISe 43 sees PV 1 0 eP YI 21 I I Bit Size: Hrs. On Bit: I ft ft I I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I Drilling Breaks I before Drill Rate during after before Gas during after Sst % Lithology Sh Sltst Depth I to to to ---- ---- ---- ---- I Logging Engineer: Beg Wilson I Tom Mansfield . 10000 units = 100% Gas In Air I sper..,v- sun '~ i. ~ 0 R I L..L. I N Gi seRVices Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 ~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 17 2/2812002 9,945 I Mudlogger's Morning Report Drill Cement Joe Polya ~~~",~.:J(~:I' Current 24 hr Avg ftlhr ftlhr ( units un~ ( Deg F ( 24 hr Max ftlhr @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV@ DP psi AV @ DC I ¡IRa.p. I I I I I I I I I I I I 5per"'r"V- sun C A 1 '-'- I N G !5 E! R V I 1:: e 5 I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 ,~eport No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 18 3/112002 10,984 1,039 Drilling Gavin Kidd I '-r:-.."""-',, "1;¡~"'¡i!)~, , .:, N':~'.""." . ,:' I Current 24 hr Avg 24 hr Max Pump and Flow Data ~R.O.P' 170 ftIh r 108 ftlhr ( 218 ftlhr @ 10525 ) Pump 1 73 spm DH flow 'i: : Gas* 185 units 150 un~( 350 units @ 10092 ) Pump 2 72 spm Total flow t~ Temp Out 94 Deg F ( 94 deg F @ 10984 ) Pump 3 spm AV @ DP Pump Pres 2700 psi AV @ DC I I I I I I I I I I KINGAK @ 10430' MD, 9717' TVD Logging Engineer: Reg Wilson I Tom Mansfield I I Customer: BP Alaska ~' Report No.: 19 Well: NorthStar NS 08 Date: 31212002 ~~~~Ye:~~~ I Area: North Slope Depth 11 ,470 Lease: NorthStar NS 08 Footage Last 24 hrs: 486 Rig: Nabors 33E Rig Activity: POOH I Job No.: AK AM 22026 Report For: Gavin Kidd Mudlogger.s Morning Report Shows: I I Current 24 hr Avg 24 hr Max Pump and Flow Data na ftlhr 108 ftlhr ( 218 ftIhr @ 10525 ) Pump 1 spm DH flow na units 150 un~( 350 units @ 10092 ) Pump 2 spm Total flow - 94 Deg F ( 94 deg F @ 10984 ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC I r Vise 52 sees API filt 5.8 ml HTHP 13.8 ml Mud Wt at Max Gas - -- PV 25 eP YI 22 Ibs/1 00ft2 Gel~ 7 I 27 I 38 Ibs/100ft2 pH 9.0 Sd I I I I Connection Gas and Mud Cut ft units ppg ft unrns ppg ft units ppg I Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Sh Sltst I Depth I to to to ---- ---- ---- ---- I 24 hr Rec; Drill from 10984' to 11470', TO. Pump sweep, circ & cond., monitor well. POOH to shoe. Service to drive and repair draw works. RIH to bottom, 7' of fill. Short trip gas of 126 units. Pump walnut sweep & circ hole clean wI very little sloughing Kingak. POOH to run 7" liner. KINGAK @ 10430' MD, 9717' TVO SAG @ 11447' MO, 10694' TVO Logging Engineer: Reg Wilson I Tom Mansfield I I I Customer: BP Alaska { teport No.: 20 Well: NorthStar NS 08 Date: 3/3/2002 Sper"-'V- sun Area: North Slope Depth 11,470 C A I LL. I N 13 SERVICES Lease: NorthStar NS 08 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Run 7" liner I Job No.: AK AM 22026 Report For: Gavin Kidd Mudlogger's Morning Report Shows: I I Current 24 hr Avg 24 hr Max Pump and Flow Data na ftlhr ftJhr ( ftlhr @ ) Pump 1 spm DH flow na units unm( units @ ) Pump 2 spm Total flow Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres psi A V @ DC I I 11 .80 ppg 11.80 ppg Vise 55 secs API filt 6.0 ml HTHP 13.6 ml Mud Wt at Max Gas - -- PV 25 cP YI 17 Ibs/1 00ft2 Gel~-2- I ~ I 23....lbs/100ft2 pH 9,4 Sd #4 DS70FNPV 81/2 20.7 Jets: 14 \ 14 \ 14 \ 14 \ 14 \ 14 TF A: ------ Total Revs on Bit: 233k Footage for Bit Run I I ppg Trip CI: ppg Short Trip CI: Feet of FiB on Bottom: I I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg I Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Sh Sitst I Depth I to to to ---- ---- ---- ---- I I Logging Engineer:~~g Wilson / Tom Mansfield ~ ,: rn I I I I I I I I I I I I I I I Customer: BP Alaska ( Report No.: 21 Well: NorthStar NS 08 Date: 3/412002 sp~""V- sun Area: North Slope Depth 11,470 [J R I I-L. I N G SI!!-RV I c: E 5 Lease: NorthStar NS 08 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Test BOPE I Job No.: AK AM 22026 Report For: Gavin Kidd Mudlogger"s Morning Report Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data ~1R.O.p. ft1h r ftlhr ( ftlhr @ ) Pump 1 spm DH flow ,t Gas. units unm( units @ ) Pump 2 spm Total flow ;Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP .1. Pump Pres psi A V @ DC '" Vise 57 sees API filt 6.8 ml PV 23 cP YI 18 Ibs/1 O0ft2 Gel~ Bit Size: Hrs. On Bit: ft ft Trip Gas: Short Trip Gas: to ppg ppg ppg Connection Gas and Mud Cut ft unns ppg ft unns ppg ft unns ppg Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Sh Sltst Depth to to to ---- ---- ---- 24 hr Rec; Finish running liner. Circulated down last joint wI 4' of fill on bottom. Pump cement, bump plug, set liner packer. Circulated out excess cement from liner top. POOH. Slip and cut drill line. Continue POOH. La down liner set tool. Pull wear ring. Test choke manifold. Clean rig pits. Service rotary table. Begin testing BOPE. . Logging Engineer: B_~g Wilson I Tom Mansfield * 10000 units = 100% Gas In Air I~ I I I I I I I I I I I I I I I I I sper"""V- sun CJ R II-I- I N 13 5 II!: A V I c: 15 5 -", Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 08 North Slope NorthStar NS 08 Nabors 33E AK AM 22026 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 22 3/512002 11 ,490 20 Drilling Gavin Kidd .. ,,'; .". Current 24 hr Avg 24 hr Max Pump and Flow Data 56 ftIh r 90 ftlhr ( 282 ftIhr @ 11473 ) Pump 1 96 spm DH flow 35 units 26 unite.. ( 35 units @ 11485 ) Pump 2 spm Total flow 66 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 1850 psi A V @ DC J !~ l I Customer: BP Alaska ( ;~eport No.: 23 Well: NorthStar NS 08 Date: 3/612002 =~~['~: :-.~~ I Area: North Slope Depth 12,030 Lease: NorthStar NS 08 Footage Last 24 hrs: 540 Rig: Nabors 33E Rig Activity: POOH for liner I Job No.: AK AM 22026 Report For: Gavin Kidd Mudlogger's Morning Report Shows: I I Current 24 hr Avg 24 hr Max Pump and Flow Data na ftIhr 50 ftlhr ( 145 ftIhr @ 11873 ) Pump 1 spm DH flow na units 282 un~( 726 units @ 11512 ) Pump 2 spm Total flow 110 Deg F ( 110 deg F @ 12030 ) Pump 3 spm AV@ DP Pump Pres psi A V @ DC I I I I Mud Cut: Mud Cut: to I I Connection Gas and Mud Cut ft unros ppg ft unros ppg ft unros ppg I Drilling Breaks I I Depth Drill Rate Gas before during after before during after 11500 to 11554 25 113 32 40 726 60 11650 to 11900 27 148 28 80 570 65 to % Lithology Sst Cgl Sitst 60 40 40 50 10 - I ---- ---- ---- I I I Logging Engineer: Reg Wilson I Tom Mansfield * 10000 units = 100% Gas In Air I I I Customer: BP Alaska ~ .~eport No.: 24 Well: NorthStar NS 08 Date: 3n 12002 SP~""V- sun Area: North Slope Depth 12,030 CR I L..L-I N 13 - n ---_--_"-Oh Lease: NorthStar NS 08 Footage Last 24 hrs: 0 seRVICES - - Rig: Nabors 33E Rig Activity: Cementing Mudlogger's Morning Report I Job No.: AK AM 22026 Report For: Gavin Kidd Shows: I I Current 24 hr Avg 24 hr Max Pump and Flow Data na ftIhr na Whr ( na ftIhr @ ) Pump 1 114 spm DH flow 26 units 12 unm( 126 units @ 12028 ) Pump 2 spm Total flow 402 110 Deg F ( 110 deg F @ 12030 ) Pump 3 spm AV @ DP Pump Pres 874 psi AV @ DC I I VISe 44 sees API tilt 5.4 ml PV 10 cP YI 25 Ibs/1 00ft2 Gel~ ( I I I Connection Gas and Mud Cut ft un~ ppg ft un~ ppg ft un~ ppg I Drilling Breaks before Drill Rate during after before Gas during after Sst % Lithology Cgl Sltst I I Depth to to to ---- ---- ---- ---- I I UP to run 4.5" production Liner. Run Liner and Cement the same. I Logging Engineer: po_ug Wilson I Mark Lindloff I Schl.berger ~, ,qHA# 1 I . I Job # 40007223 Date In 13-Feb-Q2 Date (Jut 14-Feb-Q2 Hole Size 16 Customer BP ADW ßme In 18:00 Time Out 2:00 Hole Sect Surface Well NS-08 Depth In 201 Depth Out 406 Bha Type Steerable Field Northstar TVD In 201 TVD Out 405 Hrs BRT 8.0 I Rig Nabors 33E Drlg Hrs 0.9 Drlg Ft 205 Avg ROP 228 AFE # 831313 Slide Hrs 0.1 Slide Ft 40 Slide ROP 400 DD's TunnelVRinkeiRobertson Rot Hrs 0.8 Rot Ft 165 Rot ROP 206 I Co. Men KiddlClump Pump Hrs 1.6 Rotate % 80 Slide % 20 I PDM Run # 1 R/S 5/6 PDM Jet Blk Inclln 0.42 Az In 55.14 Bit>Srvy 37.5 PDM ser# 962-1126 Stages 3.0 Beartng Mud Incl Out 1 .27 Az Out 136.96 T/F Corr PDM Size 9 9/16 Rev/Gal 0.110 Rubber RM100D Avg Dis 1.1 Max Os 1.3 Plan Dls I Mud Type Spud Mud Mud WI 9.0 Sand % RPM 40 GPM 600 SPP On 450 BHT F 50 Mud VIS 105 Solids % 3.5 DIø TQ 3.0 WOB 5 SPP Off 470 Item Desalpflon v.JCfor SIN OD , ., S8I6 oø 'FA ~"" "', 'ëdî8 úngIh MX-C1 1 TFA=1.031 Hughes T69DF 16 1x12,3x20 7518RegP 1.35 1.35 9 5/8 Std PDM 1 .83° 7 518 Reg B 2 Float Ana 962-1126 9 9/16 Tool 15 7/8 1.10 65/8H-90B 26.06 27.41 Orienting Sub 6 518 H-90 P 3 Ana GLDD-105 8 2 3/4 65/8 H-90 B 1.46 28.87 MONEL STAB 65/8 H-90 P 4 Ana 800-011-SB 8 2 7/8 16 2.40 6518H-90B 5.54 34.41 5 MONEL LC 6518 H-90 P Corrosion Ring Ana 81D-O11-LC 8 2 13/16 6518 H-90 B 9.69 44.10 X-OVER 6 518 H-90 P 6 Ana ANA614 7x8 27/8 1.20 41f2IFB 3.09 47.19 26 Jts. HWDP 5" 41f2IF P 7 NAD 26 HWDP 5 3 41f2IF B 788.99 836.18 BHA and Run 0I:J ectIve Gyro drive pipe, slide if necessary, 8HA W8lgIJt BIt D8Ia Tool HIs. In firs. OUt Dry Wt 46,646 fADC # Motor 0.0 1.6 BHA and Run ResøICs Good results. Well steered away from Buoyed Wt 40,251 Footage 205 Jars 0.0 0.9 NS09 Incl Angle Hrs 0.9 0.9 Why POOH I eo.- Pick up rest of BHA Buoy+fncJ Wt 40,251 k Revs 5 k 1.6 - ----,,---------' Grade Will rerun bit BIt To AIM=X', Res=X', GR=X', D&I=X', PWD=X', Dens=X', Nuet=X' Comment I I I I I I I I I I I I I I I I Schl.berger ~. I:JHA # 2 I . I Job # 40007223 Date In 14-Feb-O2 Date out 16-Feb-{)2 Hole Size 16 Customer BP ADW TIme In 4:00 Time Out 5:00 Hole Sect Surface ! Well NS-08 Depth In 406 Depth Out 3344 aha Type Steerable Field Northstar TVD In 405 TVD Out 3234 HIS aRT 49.0 I Rig Nabors 33E Drlg HIS 20.7 Drlg Ft 2938 Avg ROP 142 ! AFE# 831313 SlldeHrs 6.2 SlideFt 750 SlideROP 121 I DD's TunnelURobertson/Nutter Rot Hrs 14.5 Rot Ft 2188 Rot ROP 151 Co. Men PolyaiClump Pump Hrs 29.1 Rotate % 74 Slide % 26 PDM Run # 2 R/S 5/6 PDM Jet Blk Inclln 1.27 Az In 136.96 Bit>SIVY 67.6 PDM ser# 962-1126 Stages 3.0 Bearing Mud InclOut 26.00 Az Out 318.30 TIF Co" 267.0 PDM Size 9 9/16 Rev/Gal 0.110 Rubber RM100D Avg Dis Max Os Plan Dis 2.5 Mud Type Spud mud Mud WI 9.3 Sand % 2 RPM 45 GPM 830 SPP On 1900 BHT F 70 Mud VIs 90 Solids % 4.5 Dla TQ 7 K ftlbs WOB 30 SPP Off 2050 Item De8t:rIptIon Vendor SM OD ID"OO FA ~ L_~"; 'euínLength 1 MX-C 1 TFA=1.031 Huahes T69DF 16 1x12,3x20 75/8RegP 1.35 1.35 9 5/8 Std PDM 1.83° 7 518 Reg B 2 Float Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6518H-90B 26.06 27.41 3 MONEL LC 6518 H-90 P Corrosion Ring Ana 810-011-LC 8 2 13/16 6518 H-90 B 9.69 37.10 MONEL LC 6518 H-90 P 4 Ana 810-013-LC 8 1/16 2 13/16 6518 H-90 B 9.96 47.06 MONEL STAB 6 518 H-90 P 5 Ana 800-011-SB 8 2 7/8 16 2.40 6518 H-90 B 5.54 52.60 ~D 6518~P 6 Ana 169 8 1/4 3 1/4 2.29 6518 H90 B 29.85 82.45 7 Orienting Sub 6518 H-90 P Ana GLDD-105 8 2 3/4 6518 H-90 B 1.46 83.91 MONEL STAB 6518 H-90 P 8 Ana 800-007-S8 8 2 7/8 16 2.39 6518 H-90 B 5.62 89.53 MONEL DC 6 518 H-90 P I 9 Ana 831-009DC 7 13/16 2 13/16 6518 H-90 B 30.83 120.36 MONEL DC 6 518 H-90 P 10 Ana 831-002DC 713/16 213/16 6518H-90B 30.69 151.05 MONEL STAB 6518 H-90 P 11 Ana 800-010-SB 8 2 7/8 16 2.40 6518 H-90 B 5.63 156.68 MONEL DC 6 518 H-90 P 12 Ana 831-001 DC 7 3/4 213/16 6518H-90B 31.55 188.23 HYD JARS 6 5/8 H90 13 DAILEY 1417-1009 713/16 3 1.68 41/21F 31.55 219.78 26 Jts. HWDP 5" 41/21F P 14 NAD 26 HWDP 5 3 4112 IF B 788.99 1008.77 DP 5" to Surface 41/21F P 15 NAD DP 5 4 8/29 41/21F B 1008.77 , BHA and Run ObjectIve Complete 2.5°/100 build & turn BHA ~ SIt Oatil Tool HIs.. In HIs. OUt Dry Wt 71,346 IADC # 117 Motor 1.6 30.7 BHA and Run Results 5°/100 sliding slight drop rotating Buoyed Wt 61,239 Footage 2938 Jars 0.9 21 .6 .-.-.---------------.-. - -----....--- Incl Angle 26 Hrs 20.7 Bit 0.9 21.6 WltyPOOHIComIrJents TD Buoy+lnc/ Wt 55,042 k Revs 153 k 29.1 ---..--.-.-......--.--------.--------- Grade 0-1-CT -M-E-IN-NO- TO Bit To AIM=X', Res=X', GR=65.63', D&I=67.6', PWD=X', Dens=X', Nuet=X' Comment Rerunable I I I ( I I I I I I I I I I I I I I Schlullbepgep \ ( qHA # 3 I I I I [ I I I I 'I I I I , . j Job # 40007223 DaIø In 1 S-Fe1>Ð2 DaIø uut 1 !l-Feb-02 Hole Size 12 1/4 Customer BP ADW Time In 5:00 Time Out 23:00 Hole Sect Intermediate ¡ Well NS-08 Depth In 3344 Depth Out 4713 Bha Type rss I Field Northstar TVD In 3234 TVD Out 4460 Hrs BRT 42.0 Rig Nabors 33E Drlg Hrs 6.1 Drlg Ft 1369 Avg ROP 224 AFE # 831313 Slide Hrs Slide Ft Slide ROP #DIV/O! , DD's RinkeIRobertson Rot Hrs 6.1 Rot Ft 1369 Rot ROP 224 Co. Men PolyaIClump Pump Hrs 18.6 Rotate % 100 Slide % PDM Run # R/S PDM Jet Inclln 26.00 Az In 318.00 Bit>STVY 59.2 PDM Ser# Stages Bearing Inc/Out V.50 Az Out 313.80 T/F ColT PDM Size Rev/Gal Rubber A vg Dls Max Ds Plan Dls 2.5 Mud Type SW polymer Mud WI 8.9 Sand % .50 RPM 120 GPM 900 SPP On 1600 BHT F Mud VIs 45 Solids % 3 DIg TO 9 KftIbs WOB 10 SPP Off Item DescI1pIIqtJ V8Icfor SIN OD ø.. OD F.N. ConnedIaIIS , --- cum LengIIJ 1 RS-163HDNS TFA=O.946 HycaloQ 201770 12 1/4 2x15,4x14 65/8 Reg P 0.75 0.75 PD Bias Unit 6 5/8 Reg B 2 Ana 90012 9 5/16 Tool 1.35 NC 70 B 3.20 3.95 PO Extention Sub NC 70 P 3 Ana 90003 9 1/4 Tool 75/8 Reg P 1.25 5.20 4 PD Control Collar 7 5/8 Reg B Ana 90051 9 3/16 Tool 2.36 6518 Reg B 10.14 15.34 5 XO FLOAT SUB 6518 Reg P *fIoat* Ana GLDD117 8 2 13/16 6518 H90 B 1.97 17.31 6 MONEL STAB 6 518 H-90 P Ana 800-013-$8 8 2 7/8 11 7/8 2.45 6518 H-90 B 5.44 22.75 ~O 6518 H90 P 7 Ana 8039 8 5/16 15.15 6518 FH B 22.82 45.57 MWO 6518 H90 P 8 Ana 0169 8 1/4 3 1/4 2.29 6518H90B 28.42 73.99 9 MONEL STAB 6 518 H-90 P baffle plate Ana aoo.oœ..se 8 2 7/8 12 1/16 2.40 6518 H-90 8 5.55 79.54 MONEL DC 6 518 H-90 P 10 Ana 831..QO2DC 713/16 213/16 6518H-90B 30.69 110.23 MONEL DC 6 518 H-90 P 11 Ana 831-001 DC 7 3/4 213/16 6518 H-90 B 31.55 141.78 MONEL STAB 6518 H-90 P 12 Ana 800-017-58 8 2 7/8 12 1/4 2.40 6518 H-90 B 5.49 147.27 MONEL DC 6 518 H-90 P 13 CorrosionRing Ana 831-OO9DC 713/16 213/16 65/8 H-90 B 30.83 178.10 HYD JARS 6 5/8 H90 14 DAILEY 1417-1009 7 13/16 3 1.68 41/21F 31.55 209.65 26 Jts. HWDP 5" 41/21F P 15 NAD 26 HWDP 5 3 41/21F B 788.99 998.64 Dart Valve Sub 4 1/2 IF P 16 BPX GM11240 6 3/4 31/8x4112 41/21FB 2.38 1001.02 DP 5" to Surface 4 1/2 IF P 17 NAD DP 5 4 8/29 41/21FB 1001.02 BHA and Run 0bjectIwJ 81M WtJwfMl BIt DaD Tool Hrs. In HIs. OUt Dry Wt 67,878 IADC # Motor 18.6 BHA and Run Results Buoyed Wt 58,676 Footage 1369 Jars 21.6 27.7 Incl Angle 27 Hrs 6.1 6.1 Why POOH / ComIJJMIs Bha would not respond to commands Buoy+/ncl Wt 52.281 k Revs 44 k 18.6 Grade 1-1-CT -A-X-I-NO-DTF BIt To AIM=X', Res=28.9O', GR=39.9O'. 0&1=59.20'. PWD=30.65', Dens=X'. Nuet=X' Comment RERUNABLE I I I I I il SchluDlblPger aHA# 4 I I I I I I I I I Job # 40007223 Date In ~Feb-02 Date Out 2O-Feb-02 Hole Size 12 114 Customer BP ADW Time In 6:00 TIme Out 16:00 Hole Sect Intermediate Well NS-08 Depth In 4713 Depth Out 4713 aha Type Steerable Field Northstar TVD In 4460 TVD Out 4480 HIs BRT 10.0 Rig Nabors 33E Drlg Hrs Drlg Ft Avg ROP #DIV/O! AFE # 831313 Slide Hrs Slide Ft Slide ROP #DIV/O! DD's RinkelRobertson Rot Hrs Rot Ft Rot ROP #DIV/O! Co. Men PoIyaIClump Pump Hrs Rotate % #DIV/O~ Slide % #DIV/O! PDM Run # 2 R/S 3/4 PDM Jet Blk Inelln 27.60 Az In 313.80 Blt>Srvy PDM Sri 962-3561 Stages 6.0 Bearing Mud Inel Out Az Out T/F Ccrr PDM Size 9 5/8 Rev/Gal Rubber RM100D Avg Dis Max Ds Plan Dis Mud Type Mud Wt 9.2 Sand % RPM GPM SPP On BHT F Mud VIS Solids % DIG TQ woe SPP Off Item 0esI:IIpII0n V8ndor SIN OD ., '...00 F.N. ConnectIonS Lenøth' Cwn Length DS69HFGLNPUV 1 TFA=1.035 HvcaloQ 202013 12 1/4 6X15 65/8RegP 1.00 1.00 9 5/8 XP PDM 1.150 6 5/8 Reg B 2 *fIoat* Ana 962-3561 9 5/8 Tool 12 1/8 6518 H90 B 30.80 31.80 MONEL LC 6518 H-90 P 3 Ana 810=001-LC 8 2 13/16 6518 H-90 B 10.45 42.25 MONEL STAB 65/8 H-90 P 4 Ana 800-002-SB 8 2 7/8 12 1/16 2.40 65/8 H-90 B 5.55 47.80 ~D 6~~P 5 Ana 8039 8 5/16 15.15 65/8FHB 22.82 70.62 MWD 6 5/8 H90 P 6 Ana 0169 8 1/4 3 1/4 2.29 6518 H90 B 28.42 99.04 MONEL STAB 6~ H-90 P 7 Ana 8Q0.013-SB 8 2 7/8 11 7/8 2.45 65/8 H-90 B 5.44 104.48 MONEL DC 65/8 H-90 P 8 Ana 831-QO2DC 713/16 213/16 6518H-90B 30.69 135.17 MONEL DC 6 518 H-90 P 9 Ana 8St-OO1DC, . 7 3/4 2 13/16 6518 H-90 B 31.55 166.72 MONEL STAB 6si8 H-90 P 10 Ana 800-017-SB 8 2 7/8 12 1/4 2.40 65/8 H-90 B 5.49 172.21 MONEL DC 65/8 H-90 P 11 Ana 831-00900 713/16 213/16 65/8 H-90 B 30.83 203.04 HYD JARS 6 5/8 H90 12 DAILEY 1417-1009 713/16 3 1.68 41121F 31.55 234.59 26 Jts. HWDP 5" 41121F P 13 Corrosion Ring NAD 26 HWDP 5 3 41/2 IF B 788.99 1023.58 Dart Valve Sub 41/21F P 14 BPX GM11240 6 3/4 3 1/8x4 1/2 41/21F B 2.38 1025.96 DP 5" to Surface 4 1/2 IF P 15 NAD DP 5 4 8/29 41/21FB 1025.96 BHA and Run 0IJjectIve 8HA W8IgIJt BIt Data Tool Hn.. In HIs. OUt Dry Wt 73,359 IADC # Motor BHA and Run Results Buoyed Wt 63,079 Footage Jars 21.6 21.6 Incl Angle Hrs Why POOH / CofJrIDøIå Buoy+lncl Wt 63,079 k Revs Grade BIt To AIM=X', Res=28.9O', GR=39.9O', 0&1=59.20', PWD=30.65', Dens=X", Nuet=X" Comment ì I I I I 'I I I I Schlumbepger ( í ~HA # 5 I I I I I Job # 40007223 Date In 2O-Feb-02 Date Out 22-Feb-02 Hole SIze 12 1/4 Customer BP ADW TIme In 19:00 Time Out 16:00 Hole Sect Intemdiiate Well NS-Q8 Depth In 4713 Depth Out 6899 Bha Type rs& Field Northstar TVD In 4460 TVD Out 6475 Hrs BRT 45.0 I Rig Nabors 33E Drlg Hrs 21.7 Drlg Ft 2186 Avg ROP 101 AFE # 831313 Slide Hrs Slide Ft Slide ROP #DIV/O! I DD's RinkeIRobertson Rot Hrs 21.7 Rot Ft 2186 Rot ROP 101 I i Co. Men PoIyaIClump Pump Hrs 28.1 Rotate % 1 00 Slide % I PDM Run # R/S PDM Jet Inclln 27.60 Az In 313.80 Bit>SIVY 59.2 I . I PDM Ser# Stages Beanng InclOut 23.33 Az Out 313.90 TIF ColT õT.2 PDM Size Rev/Gal Rubber Avg Dis Max Ds Plan Dis 2.5 Mud Type SW polymer Mud Wt 8.9 Sand % .25 RPM 120 GPM 900 SPP On 1600 BHT F 125 Mud VIS 47 Solids % 3 Dig TO 9 KftIbs WOB 10 SPP Off Item DescrfpfIoø Vendor 8M QI) .. -'I) StIi6'ØÐ; F.II.. ConnedIanS L=:::: CùlJtLenf IIJ 1 RS-163HDNS TFA=O.946 HycalOg 201770 12 1/4 2x15,4x14 65/8RegP 0.75 0.75 PD Bias Unit 6 5/8 Reg B 2 Ana 90118 9 5/16 Tool 1.35 NC70B 3.19 3.94 3 PD Extention Sub NC 70 P Ana 90086 9 1/4 Tool 75/8 Reg P 1.32 5.26 4 PD Control Collar 7 5/8 Reg B Ana 90031 9 3/16 Tool 2.32 65/8 Reg B 10.07 15.33 XO FLOAT SUB 65/8 Reg P 5 >tfloat* Ana GLDD117 8 213/16 65/8 H90 B 1.97 17.30 6-MONEL STAB 65/8 H-90 P Ana 80Q.002..SB 8 2 7/8 12 1/16 2.40 6518 H-90 B 5.55 22.85 ~D 6518 H90 P 7 Ana 8039 8 5/16 15.15 65/8 FH B 22.82 45.67 MWD 6518 H90 P 8 Ana 01ð9 8 1/4 3 1/4 2.29 6518 H90 B 28.42 74.09 9 MONEL STAB 65/8 H-90 P b8fIIe plate Ana 8000013-SB 8 2 7/8 11 7/8 2.45 65/8 H-90 B 5.44 79.53 MONEL DC 6 518 H-90 P 10 Ana 831-OO2DC 713/16 213/16 65/8H-90B 30.69 110.22 MONEL DC 6 5/8 H-90 P 11 Ana 831.QO1DC 7 3/4 213/16 6518H-90B 31.55 141.77 MONEL STAB 65/8 H-90 P 12 Ana 8Q()..Q17~B 8 2 7/8 12 1/4 2.40 65/8 H-90 B 5.49 147.26 MONEL DC 65/8 H-90 P 13 CorrasionRing Ana 831..QO9[)C 713/16 213/16 65/8 H-90 B 30.83 178.09 HYD JARS 6 5/8 H90 14 DAILEY 1417-1009 7 13/16 3 1.68 4112 IF 31.55 209.64 26 Jts. HWDP 5" 41/21F P 15 NAD 26 HWOP 5 3 41/21F B 788.99 998.63 Dart Valve Sub 4 1/2 IF P 16 BPX GM11240 6 3/4 3 1/8x4 1/2 41/21F B 2.38 1001.01 DP 5" to Surface 41/2 IF P 17 NAD DP 5 4 8/29 4112 IF B 1001.01 BHA and Run ObjectIve Orin tangent section to 9 518" casing BHA WeIgIJf BIt DatlJ Tool HIs. In III's. OUt point Dry Wt 67,877 IADC # Motor 28.1 BHA and Run Results Buoyed Wt 58,675 Footage 2186 Jars 21.6 43.3 Rotatry steerable preformed to e~:taöons /nc/ Angle 7J Hrs 21.7 bit#2 6.1 27.8 Why POOH / ComInMes Pulled for penetration rate Buoy+/nc/ Wt 52,280 k Revs 156 k 28.1 Rotatry steerable preformed to ~t)uns Grade 2-4-WT-T-X-IN-CT-PR Bit To AIM=X', Res=28.9O', GR =39.90' , 0&1=59.20', PWD=30.65', Dens=X', Nuet=X' Comment Rerun#1 I I I I I I I I [ I ( ( I I I I Schl.bepgør '~ qHA# 6 I . I Job # 40007223 Date In 22-Feb-O2 Date Out 26-FetH>2 Hole Size 12 1/4 Customer BP ADW TIme In 16:00 TIme Out 6:00 Hole Sect Intermediate Wen NS..Q8 Depth In 6899 Depth Out 9945 Bha Type Steerable Field Northstar TVD In 6475 TVD Out 9272 Hrs BRT 86.0 I Rig Nabors 33E Drlg Hrs 30.1 Drlg Ft 3046 Avg ROP 101 AFE # 831313 Slide Hrs 5.7 Slide Ft 192 Slide ROP 34 DD's Rinke/Robertson Rot Hrs 24.4 Rot Ft 2854 Rot ROP 117 I Co. Men PolyaIClump Pump Hrs 46.8 Rotate % 94 Slide % 6 I PDM Run # 3 R/S 3/4 PDM Jet Blk Inclln 23.30 Az In 313.80 Bit>Srvy 84.3 PDM Ser# 962-3561 Stages 6.0 Bearing Mud InclOut 23.89 Az Out 319.40 TIF Carr 67.2 PDM Size 9 5/8 Rev/Gal 0.200 Rubber RM100D Avg Dls 0.3 Max Ds 1.7 Plan Dls I Mud Type SW Polymer Mud Wt 9.9 Sand % .25 RPM 110 GPM 880 SPP On 3000 BHT F 138 Mud Vis 42 Solids % 5.2 Dla TQ 14 KftJlbs WOB 12 SPP Off 2700 II81II Des.:"'" VMdor SIll OD ., r.. 00 F oN. CoIIn8cfIGna I' ,"",,- èrìm L8Ðf1Ø8 I DS69HFGLNPUV 1 TFA=1.035 Hvcaloa 202013 12 1/4 6X15 6518RegP 1.00 1.00 9518 XP PDM 1.15° 6518 Reg B 2 *f1oat* Ana 962-3561 9 5/8 Tool 12 1/8 6518 H90 B 30.80 31.80 I 3 MONEL LC 6 518 H-90 P Ana 810=OO1-LC 8 213/16 6518 H-90 B 10.45 42.25 4 MONEL STAB 6518 H-90 P I Ana 800-002-SB 8 2 7/8 12 1116 2.40 6518 H-90 B 5.55 47.80 I LWD 6 518 H90 P ! 5 Ana 8039 8 5/16 15.15 6518FHB 22.82 70.62 i MWD 6518 FH P 6 Ana 079 8 1/4 3 1/4 2.11 6518 H90 B 28.28 98.90 MONEL STAB 6518 H-90 P 7 Ana 800-013-SB 8 2 7/8 11 7/8 2.45 6518 H-90 B 5.44 104.34 MONEL DC 6 518 H-90 P I 8 Ana 831-OO2DC 713/16 213/16 6518H-90B 30.69 135.03 ¡ MONEL DC 6 518 H-90 P 9 Ana 831-001 DC 7 3/4 213/16 6518H-90B 31.55 166.58 MONEL STAB 6518 H-90 P 10 Ana 800-017-SB 8 2 7/8 12 1/4 2.40 6518H-90B 5.49 172.07 MONEL DC 6 518 H-90 P 11 Ana 831-009DC 713/16 213/16 6518H-90B 30.83 202.90 HYD JARS 6 518 H90 12 DAILEY 1417-1009 713/16 3 1.68 41/2IF 31.55 234.45 13 26 Jts, HWDP 5" 41/2IF P COITosion Ring NAD 26 HWDP 5 3 41/2IF B 788.99 1023.44 Dart Valve Sub 4 1/2 IF P 14 BPX GM1124O 6 3/4 3 1/8x4 1/2 41/2IF B 2.38 1025.82 DP 5" to Surface 41/21F P 15 NAD DP 5 48/29 41/2IFB 1025.82 I BHA .xl Run 0bjet:tIve Hold while rotating and Drill tangent BHA ~jf BIt Data Tool HIs. In HIs. OUt section to TO. Dry Wt 73,341 IADC # Motor 46,8 røHA .. RIm Results Held while rotating & 2°/100 sliding Buoyed Wt 62,282 Footage 3046 Jars 43.3 73.4 -----.---.- -.-. --.--.- ---.---'-- Incl Angie 23 Hrs 30.1 8it#3 30.1 WlryPOOH/CommeIrIs TO Buoy+/nd Wt 57,331 k Revs 479 k 46.8 - -------'----------------- Grade 0-4-WT-T-X-IN-NO-TD BIt To AIM=X', Res=53.95', GR=79,20' D&I=84,2T,GR=82.28', PWD=55,70', Dens=X', Nuet=X' Comment I r I I I J I I I I ( [ I I I I I i ~ Schl.berger ( .r 9HA # 7 'I I Job # 40007223 Dale In 28-Feb-02 Dale OUt Q3-Mar-02 Hole SI29 8 1/2 Customel' BP ADW Time In 14:00 TIme Out 5:30 Hole Sed Intermediate Well NS-08 Depth In 9945 Depth Out 11470 Bha Type Rotary Field Northstar TVD In 9272 TVD Out 10717 Hrs BRT 63.5 Rig Nabors 33E Orlg Hrs 18.2 Orlg Ft 1525 Avg ROP 84 AFE # 831313 Slide Hrs Slide Ft Slide ROP #DIV/O! DO's Rinke Rot Hrs 18.2 Rot Ft 1525 Rot ROP 84 Co. Men Kiddl Dinger Pump Hrs 38.6 Rotate % 100 Slide % POM Run # 4 R/S 415 POM Jet Blk Inclln 23.89 Az In 319.40 Bit>Srvy 63.8 POM Sri 675-3690 Stages 7.0 Bearing Mud IncIOut 10.58 Az Out 327.50 T/F Corr PDM Size 6 3/4 Rev/Gal 0.500 Rubber RM100D Avg Dis 1.0 Max Os 1.4 Plan Ols Mud Type KCL Polymer Mud Wt 11.8 Sand % .05 RPM 100 GPM 500 SPP On 2500 BHT F 196 Mud VIs 49 Solids % 3.5 DIG TQ 14 kftIlbs WOS 13 SPP Off 2800 Item ~ V8ndDr SIN GO If)" OD F .N. ConMcIIons _:,¡;¡¡ø; - \-êiIm LengIh 1 Bit#4 DS70FNPV TFA=.902 HvcalOQ 202317 8 1/2 6x14 41/2 Reg P 1.00 1.00 2 6 3/4 XP 0° 4 1/2 Reg B *float* Ana 675-3690 6 3/4 Tool 8 3/8 20.05 41/2XHB 26.53 27.53 3 CDR (PWD) 4 1/2 XH P Ana 7130 6 3/4 Tool 6.80 5112 FH B 22.53 50.06 4 MWD 51/2 FH P Ana 217 6 3/4 Tool 6.90 41/2 XH B 27.80 77.86 5 NM STABILIZER 41/2 XH P Baffle Plate Ana 675-011SB 6 3/4 213/16 8 1/2 2.45 41/2XHB 5.62 83.48 6 NM FLEX 41/2 XH P Ana 675-31-O16FC 63/4x5 213/16 2.50 41/2XHB 31.01 114.49 7 NM FLEX 41/2 XH P Ana 675-31-021FC 63/4x5 213/16 2.50 41/2XHB 31.02 145.51 8 NM FLEX 41/2 XH P Ana 675-31-O14FC 611/16x5 213/16 2.50 41/2XHB 31.02 176.53 X-OVER 4 1/2 XH P 9 CorrosIon Ring Ana GLDD1042 6 3/4 2 3/4 41/2IF B 1.98 178.51 3 Jts HWDP 41/2IF P 10 NAD (3)5"HWDP 5 3 41/21FB 91.26 269.77 HYD JARS 4 1/2 IF P 11 DAILEY 1416-1574 6 1/2 2 3/4 1.69 41/2 IF B 32.63 302.40 12 23 Jts HWDP 4 1/2 IF P NAD (23) 5" HWDP 5 3 41121F B 697.73 1000.13 Dart Valve Sub 41/2IF P 13 BPX GM11240 6 3/4 3 1/8x4 1/2 41/21F B 2.38 1002.51 DP 5" to Surface 41/21F P 14 NAD DP 5 4 8/29 41/21F B 1002.51 BHA and Run 0bjat:IItIe Drill to T' casing point while controling 8HA W'II"-. BIt Data Tool HIs. In HIs. OUt dropping tendencies seen in previous wells Dry Wt 18,081 fADC # Motor 62.9 101.5 BHA and Run Results .9°/100 Drop & .5°/100 Righthand turn Buoyed Wt 14,831 Footage 1525 Jars 44.3 62.5 - . ------ All the turn was in the last 550' after angle dropped below 15° /ncl Angle 23 Hrs 18.2 18.2 WlryPOOHICOIIIIIIenIa TO Buoy+/ncJ Wt 13,652 k. Revs 382 k 38.6 -----------.-,-------'--'---' Grade O-O-CT -N-X-IN-NO- TD BIt To AIM=X', Res=33.62'. GR=44.62', D&I=63.77',GR=61.78', PWD=35.3T. Oens=X', Nuet=X' Comment r I 'I " I I I I I I I 1 I I I I I ~ Schl.blPger .~HA# 8 I I I ( , I Job # 40007223 Date In OS-Mar-O2 Date Out 07-Mar-D2 Hole Size 6 1/8 Customer BP ADW TIme In 4:00 TIme Out 5:00 Hole Sect Production Well NS-08 Depth In 11470 Depth Out 12030 aha Type Steerable Field Northstar TVD In 10717 TVD Out 11270 HIS SRT 49.0 I Rig Nabors 33E Drlg HIS 16.7 Drlg Ft 560 Avg ROP 34 AFE # 831313 Slide Hrs Slide Ft Slide ROP #DIV/O! DO's Rinke RotHrs 16.7 RotFt 560 RotROP 34 I Co. Men Kiddl Clump Pump HIS 27. 7 Rotate % 100 Slide % I POM Run # 5 R/S 7/8 PDM Jet 8 Inelln 10.58 Az In 327.50 Sit>Srvy 76.2 PDM Ser# 475-2603 Stages 2.0 Bearing OSB InelOut 7.86 Az Out 336.60 TIF CO" 43.9 . PDM Size 4 3/4 Rev/Gal 0.300 Rubber RM100D Avg Dls Max Ds Plan Dls I Mud Type Orill-N Mud WI 9.3 Sand % Tr RPM 80 GPM 340 SPP On 2000 SHT F 145 Mud VIs 46 Solids % 6 Dla TO 9 K ftIIbs WOS 25 SPP Off 1850 Item ~ V8øcIat SIN Oþ' If) S816oø'" FJI. ConnedIons .~ . :~,,-L.engtIJ I Bit#5 STX3OCD 1 TFA=.516 Hughes 5005871 6 1/8 3x15 31/2RegP 0.75 0.75 4 3/4 PDM SSS 1.15 3 1/2 Reg B . 2 Float Ana 475-2603 4 3/4 Tool 6 17.85 31/21FB 23.52 24.27 I NMFlexLC 31/21FP , 3 Ana 975301 4 5/8x3 9/16 2 1/4 31/21F B 7.69 31.96 NM IB Stab 31121F P I 4 Ana 60060811SZ 4 3/4 2 1/4 6 2.15 31121F B 4.87 36.83 I 4.75 ARC 31121FP 5 Ana 475-061 4 3/4 2 1/4 1.70 31/21F B 20.97 57.80 .1 SLIM PLUSE MWD 31121F P 6 Ana SPRM-Y666 4 3/4 2 1/2 1.41 31/21F B 33.98 91.78 4.75 ADN 31/21F P , 7 Ana AON-124 4 3/4 2 1/2 5 7/8 1.34 31121FB 27.13 118.91 NM DC 3 112 IF P 8 Ana 475-31-003DC 4 3/4 2 5/16 31121F B 31.01 149.92 NMDC 31121FP 9 Ana 475-31-002DC 4 3/4 2 1/4 3 112 IF B 30.91 180.83 PBL Sub 3 1/2 IF P 10 Daliev NOR475BP64 4 3/4 21/2x11/2 31/21FB 8.13 188.96 11 HYD JAR 3 112 IF P Corrosion Ring DAILEY 1400-1061 4 3/4 2 1/4 1.82 31121F B 29.62 218.58 XO 31121F P 12 NAD NR400001B 5 1/8 2 5/8 HT4OB 2.54 221.12 14 Jts HWDP HT 40 P 13 NAD 4" HWOP 4 2 11/16 HT4O B 429.73 650.85 60 Jnts. DP 4" HT 40 P 14 NAD 6ODP 4 4 3 5/16 HT4O B 1888.02 2538.87 m ~4OP 15 BPX HT27872 6 1/4 2 1/2 41/21F B 2.47 2541.34 Dart Valve Sub 4 1/2 IF P 16 BPX GM1124O 6 3/4 3 1/8x4 1/2 41/21F B 2.38 2543.72 aHA and Run 0IJjeåIve Drill production hole at 30' per hour BHA ~ BIt Data Tool HIs. In HIs. Out .--.---. Dry Wt 23.338 IADC # Motor 33.1 60.8 BHAandRunResuits BuoyedWt 20,032 Footage 560 Jars 16.7 ..-................-...-.......--.. ...................-...-..-------.--...---....------- InclAngle Hrs 16.7 Bit#5 16.7 WhyPOOH/Conunenfs Buoy+/ncl Wt 20,032 k Revs 182 k 27.7 --------.--..-..----....------- Grade 2-3-WT -A-E-IN-ER- TO 8IITo AIM=X', Res=41.98', GR=46.90', 0&1=76.20', PWD=X', Dens98.12', Nuet=101.68' Comment I [ I I I f I I I I I I I I ,~ï I. i Schl8bIPger t " ~HA# 9 I I , Job # 40007223 Date In 08 MIIr-02 Date Out Hole SIze 3 314 Customer BP ADW Time In Time Out Hole Sect Cleanout Well NS-08 Depth In 12030 Depth Out 12030 Bha Type Field Northstar TVD In TVD Out HIs BRT Rig Nabors 33E Drlg Hrs Drlg Ft Avg ROP #DIV/O! AFE # 831313 Slide Hrs Slide Ft Slide ROP #DlV/O! DD's Tunnell Rot Hrs Rot Ft Rot ROP #DIV¡m Co. Men KiddI Clump Pump Hrs Rotate % #DIV/O~ Slide % #DIV/O! PDM Run # 6 R/S 5/6 PDM Jet 9.00 Inclln Az In BJt>Srvy PDM Ser# 287-2456 Stages 3.3 Bearing Mud InclOut Az Out T/F Carr PDM Size 2 7/8 Rev/Gal 6.000 Rubber RM100D Avg Dis Max Os Plan Dis Mud Type Mud Wt Sand % RPM GPM SPP On BHT F Mud Vis Solids % DIG TO woe spp Off Ifem De8ctIpfIoø," 'WøcIàr SItI."ê:t,~ . ,," ',ID:" "S6ìfi'.:,,' FA ; 'Conn8cIIans >, """ yt+. I"CûIÎII.ength Mill 1 BAKER AFO1037 3 3/4 2318 Reg P 1.75 1.75 2 7/8 Std PDM 2 3/8 Reg B 2 Ana 287-2456 2 7/8 Tool Slick 2318 Reg B 10.54 12.29 CIRC SUB 2318 Reg B 3 BAKER 2125 3 1/8 1 2218 Reg P 1.05 13.34 xo 2 318 Reg P 4 NAD 238024A 3 1/8 1 2318 SLH90 B 2.01 15.35 22 JTS 2 3/8 DP 2 318 SlH90 P 5 NAD 22 DP 2318 2 3/8 2 2318 SLH90 B 692.26 707.61 Bottle-neck XO 2 318 SLH90 P 6 NAD NADX03 43/4X31/4 1 3/4 0.94 31/2IFB 1.10 708.71 xo 3 112 IF P 7 NAD NR400 0018 5 1/8 2 5/8 HT40 B 2.54 711.25 51 JTS 4" DP HT40 P 8 NAD 514'"DP 4 3 5/16 HT40 B 1604.02 2315.27 XO HT40 P 9 BPX HT27872 6 1/4 2 1/2 41/2IF B 2.47 2317.74 Il, DP 5" to Surface 41/2 IF P 10 NAD DP 5 4 8/29 41/2IF B 2317.74 IBHA and Run 0b ectIve Onll production hole at 30' per hour BHA W8Ighf BIt DIIIa Tool HIs. In HIs. OUt Dry Wt 148 IADC # Motor 33.1 33.1 BHA and Run ResuIIs Buoyed Wt #VALUE! Footage Jars Incl Angle Hrs BJttIð WhyPOOH/CoøIIrøJfs Buoy+lncl Wt #VALUE! k Revs Grade 2-3-WT-A-E-IN-ER-TD BIt To AIM=X', Res=41.98', GR=46. 90' , 0&1=76.20', PWD=X', Dens98.12', Nuet=101.68' 'Çornment j I r ( r r I I I r I ( ( I I I - - - .--. - ~ ~ - - -. - ~ - - - - - DRilliNG SERVICES - - ~ - ~ BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide I ~ No. Type Number In Out ftIhr % GRADE ~ 1 1 MX-C1 T250C 16 1.031 201 406 205 .9 228 40 5K 20 GREEN-WILL RERUN ~ ~ 2 1RR MX-C 1 T250C 16 .946 406 3344 2938 20.7 142 45 153K 26 0-1-CT -M-E-I-NO- TO ~ 3 2 RS-163HONS MJ6428 12.25 1.058 3344 4713 1369 6.1 224 120 44K 0 1-1-CT -4-X-I-NO-OTF I 4 3 OS69HFGLNPUV 202013 12.25 1.035 4713 4713 0 0 0 0 OK 0 GREEN-WILL RERUN ~ 5 4 RS-163HONS 201770 12.25 1.058 4713 6899 2186 21.7 101 120 156K 0 2-4-WT - T -X-I-CT -PR . ~ 6 5 OS69HFGLNPUV 202013 12.5 1.035 6899 9945 3046 30.1 101 110 479K 6 0-4-WT - T -X-I-NO- TO i i 7 6 OS70FNPV 202317 8.5 .9020 9945 11470 1525 18.2 84 100 382K 0 O-O-CT -N-X-I N-NO- TO . I 8 7 STX30CO 5005871 6.125 .516 11470 12030 560 16.7 34 80 182 0 2-3-WT-A-E-IN-ER-TO i 9 8 MILL TOOTH AF01037 3.75 .518 12030 12030 0 i ~ ! ~ I ~ ~ I . , ~ ~ ~ ~ I I I ~ ~ I ~ ~ i I I ~ ~ ~~- ~~~~ - - - - -, - - - - -- - - .- - - - - NORTHST AR NS08 BEAUFORTSEA,ALASKA NORTHSTAR DRilliNG SERVICES NABORS DRILLING RIG 33E BAROID DRILLING FLUIDS AK-AM 22026 Depth MW VIs PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm Pf / Mf Chlorides Calcium Comments I Date ft Iblgal sec L8J100 10S/10M ml/30 ml@deg F 32's % % % % mgeJl1g ppm ppm 02/12/02 20 9.0 lUO 1 ( 01 14/26 10.0 1 3.5 U.U ~O.O U o.~ 9.0 0.10 .1ur .bU 11SUUU 1200 RIU 02/13/02 46 8.9 117 15 57 18/36 15.07 3.0 0.0 96.0 0 0.5 9.3 1.10 .10r .00 17000 700 DRLG 16" v.... ...v... 1611 9.1 ISO 21 41$ 19/28 9.2 2 4.0 0.0 95.0 3 4.0 I.) 1.20 .20r .20 18000 920 02/15/02 3344 9.2 74 20 35 16/22 8.0 2 4.8 0.0 94.2 2 5.0 .20 .10/.90 17000 600 16" TD 02/16/02 3344 -g: I 5 ,14 15/21 8.0 2 6.1 0.0 93.0 1 5.0 0.10 .05/.90 17000 500 02/17/02 3344-8. j 5 :3 5/6 7.0 2 --oJJ O. 98.2 0 0.0 9,0 --o:ro- 0/.70 17000 540 0: '1 3364 8. j 5 :4 6/8 7.4 .8 O. 96.2 0 0.0 9.0 ( . 0/.70 17000 580 DRLG 12 1/4" 0: '1 4630 8.9 46 12 19 6/94.8 .0 O. 95.0 1 1.3 9.0 (. .15/.90 17000 320 4713 8.9 45 11 21 6/9 4.3 .0 0.0 96.0 .5 1. 8.6 (. .1011,20 ] 460 5745 --g:g- 47 11 ~ 9/12 4.7 2 3.0 0.0 96.0 .25 3. 8.6 0.30 .20/1.40 ] 440 6899.9 45 9 6/8 6.8 1 3.0 1.0 91 . .~ 5 5. 8.6 0.20 .10/1.<1 J 440 7318 '.0 45 10 6/8 7.4 -, 4:u 0.5 9j . .~ i) 5.5 6.5 lJ:2U- .10/.6 17000 480 9108 '.8 42 11 19 6/96.02 7.6 0.5 9'. .~5 9.5 8.4 .C. 0 .05/.6 17000 480 9945 10.0 41 9 18 8/17 5.7 12.4 2 8.1 0.0 91.0 .25 11.0 8.8 C. 0 .1011.20 17000 480 121/4" TD 9945 10.0 43 10 19 7/16.4 11.4 2 8.1 0.0 91.0 0 10.5 9.2 (¡.j 0 .20(2,30 '000 460 9945 ~-:-O' 43 10 20 7/16.8 12.4 2 8.1 0.0 91.0 0 10.5 9.0 0.20 .10/1.60 '000 460 9j .1 42 .1 20 7/15.5 12.8 1 -s:r 0.0 m. 0 10.5 9.0 0.14 .10/1. '000 540 )4 ¡) .8 49 ~6 17 7/15 5.2 12.0 -,- -'-:1 0.5 63. .05 7.0 10.6 'f:50 .70/5, 46000 600 DRLG 8 1/2" 13 ~ .8 43 17 13 6/266.8 13.6 1 1.3 0.5 83. .05 9.4 9.4 .00 .20/4, 57000 880 11470 11.8 03 23 20 8/26 6.5 13.4 3 1.9 0.5 1$3.0 1) 12.0 9.4 .00 .50/4.60 49000 880 8 1/2" TD 11470 -,-.,-;s- 58 23 9 7/23 6.4 13.8 2 12.9 0.5 83.0 11.0 10.5 .20 .(0/0.30 1000 1140 11480 9.1 46 9 9 8/10 4.0 9.5 1 4.8 0.5 93.5 0.0 8.0 0.00 0/.70 1000 240 DRLG 61/8" 11748 9.1 41 9 .0 9/12 4.6 9.6 1 47 1.0 93.5 . 0 0.5 8.0 0:00- 0/.70 1000 300 12030 9.3 44 10 25 11/195.4 10.0 1 6.2 1.0 92.0 .10 1.0 8.0-0:00 0/.70 15000 380 61/8" TD ~-.-,,~ ~, ~, ~ ,-"--"'- - - - - - - ANADRILL SCHLUMBERGER Survey report Client.. ............ .....: BP Exploration (Alaska) Inc. Field.... ..... ....... ....: Northstar Well.....................: NS08 API number..... .... ......: 50-029-23068-00 Engineer............ .....: Rathert COUNTY:............. ... ..: Nabors 33E STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS....... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..... .....: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 15.67 ft KB above permanent.......: 0.00 ft OF above permanent.. .....: 55.69 ft ----- Vertical section origin---------------- Latitude (+N/S-)... ......: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-)..... ....: -999.25 ft Departure (+E/W-).... ....: -999.25 ft Azimuth from rotary table to target: 318.56 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J - - - - -- - -- 6-Mar-200221:47:22 Page 1 of 6 Spud date................: 13-Feb-02 Last survey date.........: 06-Mar-02 Total accepted surveys. ..: 130 MD of first survey.......: 0.00 ft MD of last survey........: 12030.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date............: 12-Feb-2002 Magnetic field strength..: 1150.26 HCNT Magnetic dec (+E/W-) .....: 26.54 degrees Magnetic dip........ .....: 80.93 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference Criteria --------- 1002.69 ruGal 1150.26 HCNT 80.93 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees G..............: H.............. : Dip............: of G...........: of H...........: of Dip.........: ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.54 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 -~ '--~-. -;" - - - - - ANADRILL SCHLUMBERGER Survey Report --- --n--__n-_n- -------- Seq Medsun:~d # depth ( f t) --- -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 200.00 --------- ------ Inel angle (deg) ------ ------ 0.00 0.28 0.38 0.55 0.42 0.75 0.94 1.27 1.03 1.07 1.17 1.13 1.12 1.01 1.15 1.12 1.16 0.89 0.67 0.29 1.40 3.36 5.12 6.93 10.06 12.05 14.97 17.17 19.42 21.02 - - - - - - 6-Mar-200221:47:22 - - Page ======= ====== ======== ======== ================ =============== Azimuth Course angle length (deg) (ft) ------- ------- 0.00 67.68 75.70 13.24 55.14 141.70 142.89 136.93 125.78 108.60 90.22 88.05 83.07 76.12 76.03 70.57 65.12 69.03 66.71 34.94 286.08 293.52 300.45 303.80 306.35 308.62 310.62 313.80 318.85 319.44 TVD depth (it) vertical section (it) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) - -- - Srvy tool type ====== ======== ======== ================ =============== ===== ===== 0.00 50.00 50.00 50.00 50.00 73.00 30.00 62.00 115.00 90.00 92.00 98.00 89.00 96.00 95.00 95.00 58.00 97.00 95.00 93.00 97.00 95.00 93.00 97.00 95.00 95.00 95.00 101.00 86.00 29.68 [(c)2002 Anadrill IDEAL ID6_1C_10] 6 7 8 9 10 273.00 303.00 365.00 480.00 570.00 11 12 13 14 15 662.00 760.00 849.00 945.00 1040.00 16 17 18 19 20 1135.00 1193.00 1290.00 1385.00 1478.00 21 22 23 24 25 1575.00 1670.00 1'/63.00 1860.00 1955.00 26 27 28 29 30 2050.00 2145.00 2246.00 2332.00 2361.68 0.00 50.00 100.00 150.00 200.00 272.99 302.99 364.98 479.96 569.94 661.92 759.90 848.89 944.87 1039.85 1134.83 1192.82 1289.81 1384.80 1477.79 1574.79 1669.70 1762.44 1858.90 1952.85 2046.08 2138.44 2235.49 2317.14 2344.99 0.00 -0.04 -0.16 -0.09 0.03 -0.48 -0.92 -2.12 -4.40 -5.92 -7.29 -8.56 -9.62 -10.54 -11.37 -12.15 -12.53 -13.08 -13.51 -13.62 -12.56 -9.06 -2.65 7.12 20.78 38.66 60.58 88.36 115.32 125.57 0.00 0.05 0.13 0.41 0.75 0.52 0.17 -0.73 -2.27 -3.01 -3.29 -3.26 -3.12 -2.81 -2.38 -1.84 -1.40 -0.72 -0.24 0.17 0.70 2.13 5.33 10.78 18.88 29.99 44.17 62.99 82.54 90.30 0.00 0.11 0.39 0.60 0.81 1.32 1.59 2.37 4.08 5.53 7.28 9.25 10.99 12.74 14.48 16.28 17.35 18.94 20.14 20.78 19.78 16.11 10.03 1.44 -10.01 -24.44 -41.51 -62.17 -80.74 -87.45 0.00 0.12 0.41 0.73 1.10 1.42 1.60 2.48 4.67 6.30 7.99 9.81 11.43 13.05 14.68 16.39 17.41 18.96 20.14 20.78 19.79 16.25 11.36 10.87 21.37 38.69 60.61 88.50 115.47 125.71 0.00 67.68 70.92 55.87 47.25 68.37 83.76 107.19 119.08 118.55 114.29 109.40 105.86 102.42 99.32 96.44 94.62 92.17 90.67 89.52 87.97 82.45 62.04 7.61 332.08 320.82 316.78 315.37 315.63 315.92 2 of 6 _J ~ ===== ===== ====== DLS (deg/ 100f) 0.00 0.56 0.22 1.01 0.73 1.15 0.64 0.56 0.28 0.35 0.40 0.06 0.11 0.18 0.15 0.12 0.20 0.29 0.23 0.48 1.57 2.08 1.97 1.90 J.3L 2.14 3.11 2.35 3.20 5.43 TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYl<. GYR GYR GYR GYR MWD Tool qual type - ----- ------ ~- --=--- - - - - - - ANADRILIJ SCHLUMBERGER Survey Report --- ~------- -------- Seq Measured # depth ( f t) ------.---- -------- 31 32 33 34 35 2457.40 2554.38 2649.58 2744.75 2840.19 ------ ------ IIlel angle (deg) --~._-- ------ 23.01 24.05 24.66 24.11 25.48 25.83 26.47 26.90 26.46 26.19 25.47 25.71 26.06 26.25 26.27 26.24 26.22 26.19 26.55 26.53 26.74 27.16 27.44 27.58 27.32 25.77 24.30 22.85 21.84 21.59 - - - - - - 6-Mar-200221:47:22 - - Page ======= ====== ======== ======== ================ =============== Azimuth angle (deg) Course length (it) TVD depth (it) Vertical section (it) Displ +N/S- (it) Displ +E/W- (it) Total displ (it) At Azim (deg) - - - - .~~.-~~-. ----- ------ ----- ------ MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 95.72 96.98 95.20 95.17 95.44 96.58 95.24 93.02 97.67 52.78 137.01 96.07 95.21 93.02 96.69 95.91 96.05 95.20 96.35 94.64 95.51 94.00 94.21 98.30 91.91 94.09 96.15 95.50 96.52 94.12 [(c)2002 Anadrill IDEAL ID6_1C_10] 36 37 38 39 40 2936.77 3032.01 3125.03 3222.70 3275.48 41 42 43 44 45 3412.49 3508.56 3603.77 3696.79 3793.48 46 47 48 49 SO 3889.39 3985.44 4080.64 4176.99 4271.63 51 4367.14 4461.14 4555.35 4653.65 4745.56 52 53 54 55 56 57 58 59 60 4839.65 4935.80 5031.30 5127.82 5221.94 3 of 6 ----- ----- DLS (deg/ 100f) Srvy tool type Tool qual type ======= ====== ======== ======== ================ =============== ===== ===== ====== 319.74 321.48 320.57 321.49 320.00 320.82 316.76 317.42 318.30 317.77 318.24 317.06 316.33 316.31 315.73 315.78 316.12 316.23 316.06 315.16 314.27 313.74 312.63 311.46 312.69 313.81 315.67 316.70 318.41 319.84 2433.73 2522.65 2609.37 2696.05 2782.70 2869.75 2955.25 3038.36 3125.64 3172.94 3296.26 3382.91 3468.57 3552.06 3638.77 3724.79 3810.95 3896.36 3982.69 4067.36 .4152.73 4236.52 4320.24 4407.43 4488.99 4573.16 4660.27 4747.80 4837.07 4924.52 161.45 200.13 239.36 278.61 318.60 360.39 402.35 444.10 487.95 511.36 571.05 612.54 654.08 695.05 737.79 780.17 822.58 864.58 907.34 949.57 992.29 1034.75 1077.77 1122.88 1164.97 1206.84 1247.43 1285.59 1322.27 1357.09 117.62 147.55 178.07 208.61 239.59 271.82 303.37 333.96 366.48 383.88 428.25 458.91 489.16 518.81 549.59 579.99 610.50 640.83 671.69 701.90 732.03 761.62 791.19 821.60 849.99 878.79 907.41 934.96 962.03 988.36 -110.71 -135.26 -159.96 -184.67 -210.01 -236.65 -264.31 -292.74 -322.17 -337.82 -377.76 -405.72 -434.23 -462.54 -492.25 -521.85 -551.37 -580.48 -610.13 -639.71 -670.14 -700.78 -732.29 -766.00 -797.45 -828.09 -857.00 -883.44 -908.22 -931.00 161.53 200.17 239.36 278.61 318.60 360.40 402.35 444.11 487.96 511.36 571.05 612.54 654.08 695.06 737.81 780.20 822.63 864.65 907.43 949.68 992.45 1034.97 1078.07 1123.29 1165.51 1207.47 1248.13 1286.32 1323.01 1357.80 316.73 317.49 318.07 318.48 318.76 318.96 318.94 318.76 318.68 318.65 318.58 318.52 318.40 318.28 318.15 318.02 317.91 317.83 317.75 317.65 317.53 317.38 317.21 317.01 316.83 316.70 316.64 316.62 316.65 316.71 2.08 1.29 0.75 0.70 1.58 0.52 1.99 0.56 0.61 0.68 0.55 0.59 0.50 0.20 0.27 0.04 0.16 0.06 0.38 0.43 0.47 0.51 0.62 0.57 0.68 1.73 1.73 1.58 1.24 0.62 L£C-.- - - - - - - - - - - - - - - ~ <~ -~o, -, ANADRILL SCHLUMBERGER Survey Report 6-Mar-200221:47:22 Page 4 of 6 --- _n__- -. - --- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --~ ------._-- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 61 1)317.16 21.52 320.61 95.22 5013.08 1392.06 1015.24 -953.39 1392.72 316.80 0.31 MWD 62 5411.51 21.53 322.01 94.35 5100.85 1426.64 1042.26 -975.02 1427.23 316.91 0.54 MWD 63 5507.53 21.43 321.88 96.02 5190.20 1461.74 1069.95 -996.70 1462.26 317.03 0.12 MWD 64 5603.23 21.03 322.93 95.70 5279.40 1496.31 1097.40 -1017.84 1496.76 317.15 0.58 MWD 65 5697.07 21.09 323.37 93.84 5366.97 1529.92 1124.39 -1038.06 1530.30 317.29 0.18 MWD 66 5792.61 20.95 323.24 95.54 5456.16 1564.07 1151.87 -1058.54 1564.39 317.42 0.15 MWD 67 5885.59 21.26 322.88 92.98 5542.90 1597.45 1178.62 -1078.66 1597.71 317.54 0.36 MWD 68 5978.22 21.76 322.88 92.63 5629.08 1631.32 1205.71 -1099.16 1631.53 317.65 0.54 MWD 69 6076.17 22.40 322.39 97.95 5719.84 1668.05 1234.97 -1121.51 1668.21 317.76 0.68 MWD 70 6171.76 23.14 322.37 95.59 5807.98 1704.96 1264.27 -1144.09 1705.09 317.86 0.77 MWD 71 6265.94 23.44 322.23 94.18 5894.49 1742.12 1293.73 -1166.86 1742.22 317.95 0.32 MWD 72 6360.69 23.47 320.90 94.75 5981.41 1779.78 1323.27 -1190.30 1779.85 318.03 0.56 MWD 73 6457.74 23.44 319.85 97.05 6070.44 1818.38 1353.03 -1214.94 1818.45 318.08 0.43 MWD 74 6553.04 23.38 318.09 95.30 6157.90 1856.24 1381.59 -1239.79 1856.30 318.10 0.74 MWD 75 6643.71 23.19 316.31 90.67 6241.19 1892.07 1407.88 -1264.14 1892.14 318.08 0.80 MWD 76 6742.57 23.11 314.43 98.86 6332.09 1930.87 1435.54 -1291.44 1930.96 318.02 0.75 MWD 77 6836.61 23.33 313.90 94.04 6418.51 1967.84 1461.37 -1318.04 1967.95 317.95 0.32 MWD 78 6931.47 23.03 314.13 94.86 6505.71 2005.06 1487.32 -1344.89 2005.20 317.88 0.33 MWD 79 7026.37 23.56 316.58 94.90 6592.88 2042.52 1514.02 -1371.25 2042.69 317.83 1.16 MWD 80 7121.39 23.67 318.33 95.02 6679.94 2080.58 1542.06 -1396.98 2080.75 317.83 0.75 MWD P'= - 81 7216.70 23.77 319.34 95.31 6767.20 2118.92 1570.92 -1422.22 2119.08 317.84 0.44 MWD 82 7310.83 23.15 320.35 94.13 6853.55 2156.38 1599.56 -1446.39 2156.53 317.88 0.79 MWD 83 7406.09 23.32 321.11 95.26 6941.08 2193.93 1628.65 -1470.17 2194.06 317.93 0.36 MWD 84 "7 50 1 . 28 23.61 320.50 95.19 7028.40 2231.80 1658.03 -1494.13 2231.92 317.98 0.40 MWD 85 "I 5 9 3 . 8 1 23.88 320.53 92.53 7113.10 2269.04 1686.78 -1517.82 2269.14 318.02 0.29 MWLJ 86 7690.22 23.46 320.49 96.41 7201.40 2307.73 1716.65 -1542.43 2307.81 318.06 0.44 MWD 87 7785.11 23.00 320.16 94.89 7288.59 2345.13 1745.46 -1566.33 2345.21 318.10 0.50 MWD 88 7881.36 23.22 320.04 96.25 7377.12 2382.90 1774.44 -1590.56 2382.97 318.13 0.23 MWD 89 7974.74 23.51 319.87 93.38 7462.84 2419.92 1802.79 -1614.39 2419.98 318.16 0.32 MWD 90 8068.90 23.21 319.83 94.16 7549.28 2457.25 1831.33 -1638.46 2457.30 318.18 0.32 MWD [(c)2002 Anadrill IDEAL ID6_1C_10] - - - - - - - - - - - - - - - - -='1 ~, ANADRI LL SCHLln.tJBERGER Survey Report 6-Mar-200221:47:22 Page 5 of 6 --- ---- - ------- ------ ------- ------ -------- -------- ================ --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual ( ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- ======= ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- ---------------- --------------- ----- ----- ------ 91 8164.26 22.96 319.06 95.36 7637.01 2494.63 1859.74 -1662.77 2494.68 318.20 0.41 MWD 92 8260.17 23.11 319.35 95.91 7725.27 2532.16 1888.15 -1687.29 2532.20 318.22 0.20 MWD 93 8355.55 23.29 319.08 95.38 7812.94 2569.73 1916.60 -1711.83 2569.77 318.23 0.22 MWD 94 8449.62 23.58 319.56 94.07 7899.25 2607.14 1944.97 -1736.22 2607.18 318.25 0.37 MWD 95 8548.09 23.36 319.21 98.47 7989.57 2646.35 1974.74 -1761.75 2646.39 318.26 0.26 MWD ~ 96 8643.08 22.99 318.93 94.99 8076.90 2683.73 2002.99 -1786.24 2683.77 318.27 0.41 MWD 97 8738.25 23.08 318.47 95.17 8164.48 2720.97 2030.96 -1810.82 2721.00 318.28 0.21 MWD 98 8828.73 23.13 318.15 90.48 8247.70 2756.48 2057.48 -1834.43 2756.51 318.28 0.15 MWD 99 8924.72 23.33 318.38 95.99 8335.91 2794.34 2085.73 -1859.63 2794.37 318.28 0.23 MWD 100 9020.70 23.51 318.89 95.98 8423.98 2832.48 2114.36 -1884.84 2832.52 318.28 0.28 MWD 101 9116.27 23.15 319.08 95.57 8511.74 2870.33 2142.92 -1909.68 2870.36 318.29 0.38 MWD 102 9213.46 23.15 318.65 97.19 8601.10 2908.54 2171.70 -1934.82 2908.57 318.30 0.17 MWD 103 9308.58 23.26 318.28 95.12 8688.53 2946.02 2199.75 -1959.67 2946.05 318.30 0.19 MWD 104 9402.4'7 23.08 318.32 93.89 8774.84 2982.96 2227.33 -1984.24 2982.99 318.30 0.19 MWD 105 9497.26 23.15 318.30 94.79 8862.02 3020.17 2255.12 -2008.99 3020.20 318.30 0.07 MWD 106 9592.7"7 23.31 318.78 95.51 8949.79 3057.84 2283.35 -2033.94 3057.87 318.31 0.26 MWD 107 9689.71 23.55 318.60 96.94 9038.74 3096.39 2312.31 -2059.38 3096.42 318.31 0.26 MWD 108 9785.74 23.68 318.58 96.03 9126.72 3134.86 2341.16 -2084.83 3134.89 318.31 0.14 MWD 109 9857.40 23.89 319.40 71.66 9192.30 3163.76 2362.97 -2103.79 3163.79 318.32 0.55 MWD 110 10065.80 24.06 319.64 208.40 9382.72 3248.43 2427.38 -2158.76 3248.45 318.35 0.09 MWD 111 10160.83 23.29 320.55 95.03 9469.75 3286.57 2456.65 -2183.24 3286.59 318.37 0.90 MWD 112 10256.13 22.63 321.17 95.30 9557.50 3323.72 2485.48 -2206.71 3323.73 318.40 0.74 MWD 113 10351.50 21.81 321.02 95.37 9645.79 3359.75 2513.54 -2229.36 3359.75 318.43 0.86 MWD 114 10444.89 21.25 321.06 93.39 9732.66 3393.99 2540.19 -2250.91 3393.99 318.46 0.60 MWD 115 10539.85 20.82 321.06 94.96 9821.29 3428.04 2566.70 -2272.33 3428.04 318.48 0.45 MWD 116 10634.70 19.63 321.82 94.85 9910.29 3460.79 2592.34 -2292.78 3460.79 318.51 1.28 MWD 117 10729.74 18.76 321.96 95.04 10000.05 3491.98 2616.93 -2312.06 3491.98 318.54 0.92 MWD 118 10824.82 17.74 321.11 95.08 10090.35 3521.71 2640.24 -2330.58 3521.71 318.56 1.11 MWD 119 10919.96 16.41 321.60 95.14 10181.29 3549.62 2662.06 -2348.03 3549.62 318.59 1.41 MWD 120 11012.44 15.02 323.69 92.48 10270.31 3574.60 2681.95 -2363.24 3574.60 318.61 1.62 MWD ((c)2002 Anadrill IDEAL ID6_1C_10J - - - - - - - "- ~ - - - - - - .- - ~""-~. -" ANADRILL SCHLUMBERGER Survey Report 6-Mar-200221:47:22 Page 6 of 6 --- -"------------ ------- -------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Az im (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 121 11108.64 14.13 325.76 96.20 10363.42 3598.66 2701.70 -2377.23 3598.67 318.66 1.07 MWD 122 11200.86 12.90 325.02 92.22 10453.08 3620.06 2719.45 -2389.46 3620.07 318.70 1.35 MWD 123 11296.06 11.54 325.75 95.20 10546.12 3640.07 2736.02 -2400.91 3640.08 318.73 1.44 MWD 124 11399.24 10.58 327.50 103.18 10647.38 3659.67 2752.54 -2411.81 3659.69 318.77 0.99 MWD 125 11594.98 9.81 328.41 195.74 10840.03 3693.85 2781.91 -2430.20 3693.90 318.86 0.40 MWD 126 11690.77 8.60 331.04 95.79 10934.59 3708.88 2795.12 -2437.95 3708.95 318.90 1.34 MWD 127 11786.11 8.75 332.43 95.34 11028.84 3722.88 2807.79 -2444.75 3722.97 318.95 0.27 MWD 128 11881.45 8.47 333.57 95.34 11123.10 3736.70 2820.50 -2451.24 3736.82 319.01 0.34 MWD 129 11946.73 7.86 336.50 65.28 11187.72 3745.59 2828.90 -2455.16 3745.73 319.05 1.13 MWD Survey Projected to Total Depth: 130 12030.00 7.08 340.70 83.27 11270.28 3755.76 2838.97 -2459.12 3755.93 319.10 1.14 proj [(c)2002 Anadrill IDEAL ID6_1C_10] ~. I I i I I I I I I I I [ I I I I I I I ,"; ¡ Q N S08 Formation Tops NSO8 ProJ!nosed Toos Actual Deoths Delta Formation TVDss TVDrkb MDrkb TVDss TVDrkb MDrkb TVD Top Permafrost 1149 1205 1205 1149 1205 1205 0 Base Permafrost 1520 1576 1576 1520 1576 1576 0 SV6 - Top Confinin2 Zone 3010 3066 3149 3006 3062 3152 4 Surface Casin2 Point 3170 3226 3323 3170 3226 3328 0 SV5 - Base Confmin2 Zone 3280 3336 3443 3279 3335 3450 1 SV4 3590 3646 3780 3589 3645 3800 1 SV2 - Top Upper Injection Zone 3990 4046 4215 3990 4040 4242 6 SV1- Top Maior Shale Barrier 4380 4436 4639 4380 4430 4680 6 TMBK - Top Lower Injection Zone - Top UJ!;nu 4725 4781 5014 4725 4775 5061 6 M87F - Top Schrader Bluff - Base Ugnu 6311 6367 6738 6326 6382 6782 -15 M60T - Base Lower Injection Zone (Top Colville) 6900 6956 7379 6911 6967 7435 -11 THRZ - Top HRZ 8565 8621 9189 8592 8648 9265 -27 BHRZ - Base HRZ 8652 8708 9284 8683 8739 9365 -31 Top Kuparuk 8722 8778 9360 8713 8769 9397 9 Kuparuk C 8932 8988 9588 8909 8965 9610 23 Top Miluveach 9172 9228 9849 9165 9221 9890 7 Intermediate Casin!! Point 9320 9376 10010 9216 9272 9945 104 Intermediate Lo2l!În2 Point 9320 9376 10010 9216 9272 9945 104 Top Kin!!ak 9687 9743 10409 9661 9717 10430 26 Geol Tar!!et #1 10670 10726 11478 10638 10694 11447 32 Top Sa!! River 10670 10726 11478 10638 10694 11447 32 Intermediate Casin2 Point 10700 10756 11510 10661 10717 11470 39 bp ~'! """"""'>,:"""""' ,?I'l" :'11', .;' ..: ~"" ,,' ,,:r, '"",;;;",: (" ( Date: 04-04-2002 Transmittal Number:92446 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 . f"ð 0 '0 Top SW Name Date Contractor LoÇJ Run Depth Bottom Depth LoÇJ Type - NS08 02-14-2002 SCH 1-7 200 12030 VISION - DENSITY NEUTRON; (MD) ~ ) NS08 02-14-2002 SCH 1-7 200 12030 VISION - DENSITY NEUTRON; (TVD) NS08 02-14-2002 SCH 1-7 200 12030 VISION - RESISTIVITY; NS08 02-14-2002 SCH 1-7 200 12030 VISION - RESISTIVITY; ,,- - - - -- - - - - d~ It Clo~fJ Please Sign and Re urn one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp ~.. ~\r';~;:;~ ..'.".' ":'.- ,;" ,."t~,: '*"'. .'.'~..'i,.;' ~j':""."¡,, -."",'.:;i:,a,')"",. po- ~~. ~ -' -' Date: 03-27-2002 Transmittal Number:92434 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ......... ....... ~ <::) <1S Top SW Name Date Contractor Loa Run Depth Bottom Depth Loa Tvpe NS14 01-23-2002 SCH 1 0 9533 DIPOLE SHEAR SONIC TOOL; NS14 01-23-2002 SCH 1 0 9533 MICROLOG; NS14 01-23-2002 SCH 1 0 9533 HIGH RESOLUTION LA TERLOG; , NS14 01-23-2002 SCH 1 0 9533 NEUTRON DENSITY; NS14 01-23-2002 SCH 1 0 9533 TRIPLE COMBO PRESENTATION; (MD) NS14 01-23-2002 SCH 1 0 9533 TRIPLE COMBO PRESENTATION; (TVD) NS14 02-17 -2002 SCH 1 0 12930 GAMMA RAY; CASING COLLAR LOG; I NS08 02-26-2002 SCH 1 0 9891 REPEAT FORMATION TESTER; NS14 02-26-2002 SCH 1 6192 3151 LDWG FORMAT (CD) ~I ~oc;\.. o;l' ~m~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED r " ,~ Iî, 2 -" ..,002 ' "I.' I.' ::-\l , L AIaira œ & Gas Cons. Commillion AndIorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ... ,I' bp ...... It:cI<':,,,,:,,:,,,,,,,,,,,,::,,,,,,;"',',,>r:J!ir,",',,,',":',"',,";,t',,',:," JI" ;, ~ '~ Date: 03-22-2002 Transmittal Number:92431 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 Bottom De th Lo T e NS08 03-06-2002 ANADRILL 12030 DIRECTIONAL SURVEY (HARDCOPY / DISKETTE;) ~ 0 do -0 I Mp\ l-O3Ip-lts. c:>/-i3-Q7 Sc.H (I) 'BC¡OD --11400 St.-1M GANIM" ¡?AY' ~ J ~ 5- / 50 ~~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) /-/SA WIf:;-e-JI'fI:: Attn: Buford Bates (Murphy Exploration (Alaska), Ine Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED ~.1' D 2 7 "OO? I ,.'"it . I L. - Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 'I:' I{ ~1f~1fŒ mJ~ ~~~~[\~ ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer , BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Northstar Unit NS 08 BP Exploration (Alaska) Inc. Pennit No: 202-021 Sur Loc: 1119' NSL, 642' WEL, Sec. 11, TI3N, RI3E, UM Btmhole Loc. 4087' FNL, 3262' WEL, Sec. 11, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. You have requested a waiver of the diverter requirements at 20 AAC 25.035 (c). Your request for waiver of the diverter requirements is granted for NS 08. Annular disposal has not been requested as part of the Pennit to Drill application for NS 08. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CM. ~~"¥ Carom ?echSli Taylor Chair BY ORDER OF THE COMMISSION DATED this 8th day of February 2002 jj c/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. I \, ALASKA of STATE OF ALASKA . ,NO GAS CONSERVATION COMMIE( PERMIT TO DRILL 20 AAC 25.005 )N v.J6A ~{11 0 Ì- k ()(t¡-OÀ ~\ H J{g{O7- 1 a. Type of work 181 Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 §.tratigraphic Test 181 Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas []"Single Zone 1;'A 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 55.7' Northstar Unit 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL312799 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1119' NSL, 642' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 3911' NSL, 3107' WEL, SEC. 11, T13N, R13E, UM NS08 Number 2S100302630-277 At total depth 9. Approximate spud date 4087' NSL, 3262' WEL, SEC. 11, T13N, R13E, UM 02/10/02 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) Y0179, 3068' MD NS09 is 5.6' away at 350' ~-~- ~ L/'I7Z Ifp 12076' MD /11276' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 Kick Off Depth 1400' MD Maximum Hole Angle 23.11 Maximum surface 4158 psig, At total depth (TVD) 11220' / 5280 psig 18. Casing Program Specifications Setting Depth C ize ToD Bottom Qu~ntitv of C'.emp.nt Hole Casino Weiaht Grade CouDlina Lenath MD TVD MD TVD linclurlp. stane data 20" 20" 169# X-56 WELD 161' Surface Surface 201' 201' Driven 16" 13-3/8" 68# L-80 BTC 3323' Surface Surface 3323' 3226' 586 sx PF 'L' 468 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 10010' Surface Surface 10010' 9376' 521 sx Econolite 613 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 1650' 9860' 9238' 11510' 10756' 252 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 716' 11360' 10617' 120761 11276' 70 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Interme~iate RECEIVE Production D Liner JAN 3 1 2002 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments 181 Filing Fe,e 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Barbara Holt, 564-5791 Allen Sherriff, 564-5204 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my ~nowl~~ge . ' I Signed Floyd Hernande- ~ ~ - Title Senior Drilling Engineer Date ~ 1"$1 0 L ,"~ :~~ :~\¡~;~~} 1<'\,,/;,;:,.:,;,:),,': ""',1 ",:"', ',i", "":"!,,:,:,,:',,i',:::,, Permit Number API Number Apprf~~ Da~, See cover letter 2.ð z.. ... 0"'2- I 50- ()2-¿:¡ ,..". ;? 3~B -. CD '^ l'-/.. Iry."" for other reQuirements Conditions of Approval: Samples Required 0 Yes S No Mud Log Required ' ~ Yes 0 No Hydrogen Sulfide Measures 0 Yes Ii(I No Directional Survey Required l&fYes 0 No Required W~rking Pressur~ for BOPE ,0 ,2K D3K ,q 4K 0 5K. 0 10K g 15K 0 3.5, K p~lor CTU Other: W~-e'Ý o~ dc:\I e ¡lh~'V"" re~"~.,e--c..e"'^-t i...... 20 1\1\(.. 'Z-S, OS S (c) (,:r~ +~ J ~/!if!fJV( Original SìgtM8 - BoP E 'to S' 000 ec. ¿ . by order of tt\((i¡\ , n " , 'Î., Approved By - ... "(1' ') I (' f\ I ^ I Commissioner the commission Date ~ 'J< In."¡--' Form 10-401 Rev. 1~-v 1-°"- "\,7 \ 10 I ~ t\ L Submit n Trfplicate t ( 'bp .,. ,\If."'. ....~~ ~...~ ~.- ~...- *.~ ~~. .'I'.~I\~ ". BP Exploration Alaska Inc. To: Tom Maunder - AOGCC Date: January 29, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS08 Application for Drilling Permit Mr. Maunder, NS08 is .currently scheduled for Nabors 33E on February 10, 2002. Spud date was initially estimatejto be Feb 14th. however, excellent drilling performance to date has moved the projected spud to Feb 10th. / A Diverter waiver is also requested on NS08. To date, BP has drilled eight development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. All eigh~, surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Please find attached the revised NS08 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact Allen Sherritt @ 564-5204 or Floyd Hernandez @ 564-5960. I will return to the office February 10th, 2002. Sincerely, Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 ( (" NS 08 SUMMARY DRilLING OPERATIONS Pre-Rig Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) RigJ)J)erations: I 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter .system, if required. NOTE: A diverter dispensation has beenV;equested. Confirm dispensation decision with the Drilling ßngineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directi~ally drill surface hole to +/-150' TVD below the top of the SV6 marker at approximately 3149' MD. Surface casing point has been picked at 3323' MD. POOH.v"" ,,/ 4. Run 13-3/8",68# surface casing. Cement the casing to surface in 1 stage. A TAM port collar will be run at +/- 1600' MD."'-' In the event the cement does not circulate to surface, this port collar will be utilized to ensure a successful cement job is performed. ,/' 5. ND diverter / riser system and NU casing / multi-bowl wellhead. NU BOPE and test !SV250/5000 psi. 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. ,/' 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to 12.5 ppg. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximat~y 10,010'MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the to!¥of HRZ and 9.8 ppg at the top of Kuparuk. POOH. 9. RU Schlumberger. Run open hole RFT's for pressures only. POOH and RD Schlumberger. 10. Make a cle~p out run, if required, and condition the hole for casing. POOH. ."..... 11. Run 9-5/8"; 47# intermediate casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus..-with 1 annular volume of mud upon installing and testing the packoff. Down-squeeze diesel to 2000' TVD for freeze protection after WOC. /' 12. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4300 psi with 9.8 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole.' 13. Drill out remaining cem~.t. Drill 20' of new formation below 9-5/8" shoe and perform a Formation Integrity test to 13.5 ppg. (FIT/LOT procedure on file with AOGCC). 14. Weight up to 11.5 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 11,478' MD. Intermediate casing point has been picked at 11,510' MD. POOH. ..../ 15. Run and cement a 7" 26# drilling liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting string. 16. RIH w/ 6;-1/8" directional assembly and clean out to the landing collar. Pressure-test the liner to a 3500-psi with 11.5-ppg mud, (this exceeds the minimum requirement of 500 psi over the leak off pressure for liner lap testing.) This test pressure may change based on the actual mud weight in the hole and the actual FIT. " ./ 17. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe with 11.5-ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.3 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.3 ppg drill-in fluid."""-' /' 18. Drill 6-1/8" production interval to the proposed TD at 12,076' MD. POOH. ./' 19. RU Schlumberger E-line unit. Run open hole RFT's for pressures only. POOH and RD Schlumberger. NSO8 Permit to Drill ( ( 20. Make a clean out run, if required, a;J.Ø condition the hole for a liner. POOH. 21. Run and cement the 4-1/2" 12.6# 13Cr liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting tool. ,// 22. Close the blind rams and pressure-test the liner lap to 3400 psi with 9.3-ppg fluid in the well for 30 minutes. 23. Cleanout the 4 Y2" liner to the float collar. Wash down and circulate prior to displacing to seawater. 24. Circulate to clean seawater (less than 40 NTU's) using spacers as per Baroid recommendation 25. POOH with the clean out assembly and prepare to run the 5 Y2" x 4 Y2" completion. .... 26. Run the 5 Y2" x 4 Y2", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting d~th to surface. 27. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +1- 2000' TVD (1996' MD) to surface. 28. Run space out pups and terminate the 2 - 0.25" control lines and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function test the fiber optic line. / 29. Set the TWC. ND BOP's. NU Tree. Test the tubing h~ adapter and tree to 5000 psi. 30. Set packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. .../ 31. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. .,/ 32. Bleed down the annulus to 3500 psi. Bleed down the tubing to 0 psi. This will shear the RP valve. 33. Pump corrosion inhibitor and heated diesel down the 5 Y2" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4165'MD). 34. RU the U-tubing manifold and allow the Freeze Protection fluid to u-tube through the GLM. 35. Bleed off annulus to 0 psi. Ensure both the tubing and annulus pressures are 0 psi. 36. Install (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Post-RiQ Work: .,/ 1. MIRU slickline. Pull the ball and rod I RHC profile from 'XN' nipple below the new production packer. 2. MIRU Schlumberger Wireline. Run USIT. RD Schlumberger Wireline. r 3. Perforate -140' Ivishak formation between the Top Ivishak and OWC. ./' 4. Perforate interval based on PE recommendation. Estimated Spud Date: February 10, 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 2 NS08 Permit to Drill ( ¡( NSO8 WELL PLAN SUMMARY l.!ïpe of Well (producer or injector): I Producer , Northstar Slot: NS08 Surface Location: 1119' FSL, 642' FEL, Sec. 11, T13N, R13E, UM X = 659834 Y = 6030902 Target (top of SAG): 3911'FSL,3107'FEL,Sec.11,T13N,R13E,UM 400' Radius X = 657308 Y = 6033631 10,726' TVDrkb Bottom Hole Location: 4087' FSL, 3262' FEL, Sec. 11, T13N, R13E, UM X = 657149 Y = 6033804 11 ,276' TVDrkb lB!9:J Nabors 33E .,..' I l.Qperating days to complete: I 35.7 , I AFE Number: 1831313 , I Estimated Start Date: , 2/1 0/02 I I MD: I 12,076 I 'TVDrkb: 111,276 I 'RKB/Surface Elevation: (a.m.s.l.)~ 55.7' /15.67' I I Well Desi9!!.-(conventional, slimhole, etc.U Modified Big Bore I *",. ~ective: 'Ivishak Producer with fiber optic surveillance control line I NS08 Producer 5175 psi @ 11,100' TVD 8.95 ppg 254 of @ 11,100' TVD ."..- MECHANICAL CONDITION: Cellar box: Elevation above MSL = 15.67' (estimated) RKB to Cellar box: 40.1' (Estimated) Rig Elevation: RKB + MSL = 55.77' Conductor: 201' MDrkb of 20", 169#, X-56 (pre-driven) 3 NSO8 Permit to Drill { (" MUD PROGRAM: Surf, Hole Mud P S ter SDud Mud 16" Hole Sect" From Surface to -3323' MO / 3226' TVO (-150' TVO below top SV6). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 see Initial 8.8-9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 , 100 - 200 30 - 45 >6 15 - 25 4-10 8.5 - 9.5 SV6 @ Interval TO *9.5 t/ 75 -100 20 - 35 >6 1 0 - 25 4-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Int, diate Hole Mud P rt" S ter Pol 12-1/4" Hole Sect" From Surface Casing Shoe to 10010' MO / 9376' TVO (-top Miluveach). Interval Density (DDa PV YP Tauo API/ HTTP FL pH Initial 8.7 -9.3 10-16 20 - 30 4-7 6 -10 8.5 - 9.5 Top HRZ 9.6 / 10-16 20 - 25 4-7 4-6/<12 8.5-9.5 Top Kuparuk to Miluveach 9.8 / 10-18 20 - 28 4-7 4-6/<12 8.5-9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 11510' MO / 10756' TVO (top of Sag) Interval Densit PV YP Tauo API FL Miluveach & Kinaak to toD of Saa 11.5 10 - 25 20 - 25 4 - 7 4-6 / <10 Product" Hole Mud P rt" S ter/CaCO3 Drill-In Fluid 6-1/8" Hole Sect" From Intermediate Casing Shoe to 12076' MO / 11276' TVO Interval Density (boa) PV YP Tauo APIFL pH Initial/Final 9.3 ,/' 8 - 12 20 - 25 4-7 3-5 8.5 - 9.5 4 NS08 Permit to Drill ( ( ~ 7~" " KOP: :f:1400' MD Ca,henarv curve 1°/100' build Maximum Hole Angle: :f:23.11 ° Close Approach Well: Surface- 10' well spacing ./ NS07 - planned well, not yet drilled. ./ NS09 - closest point at 350' MD center-to-center distance is 5.6 ft. Seal A-01 - closest point at 500'MD, center-to-center distance is 72.4 ft. Well is P&A'd. Gyro will be used for initial surveys and kickoff Survey Program: Gyros as required from surface to +/-1500'. Standard MWD surveys from +/-1500' to TD. SURFACE AND ANTI-COLLISION ISSUES: Well NS09 is 5.6 ft center to center from NS08 at 350' MD. Well Seal A-01 (P&A'd) is 72.4 ft center ./ to center from NS08 at 5000' MD. Both wells pass minor risk 1 :200 rule. Gyros will be run from surface to -1500' MD or until reliable MWD surveys can be taken. Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. Well Name Allowable Deviation (ft) Depth (MD) Precautions NS05 19.07 650.10 Pass major risk NS06 5.39 900.07 Pass major risk NS07 6.66 399.99 Pass minor risk 1 :200 NS09 2.68 349.95 Pass minor risk 1 :200 NS10 17.42 199.99 Pass major risk NS11 17.78 699.55 Pass major risk NS12 24.00 999.61 Pass maior risk NS13 12.71 2003.01 Pass major risk NS14 27.32 3416.40 Pass major risk NS15 24.63 2319.97 Pass major risk NS16 64.30 1200.27 Pass major risk NS18 89.46 549.81 Pass major risk NS21 122.84 449.98 Pass major risk NS23 84.05 2055.30 Pass major risk NS24 142.99 1198.88 Pass major risk NS25 162.87 449.98 Pass major risk NS26 31.33 3358.66 Pass major risk NS27 137.02 2292.02 Pass major risk NS28 178.59 1552.85 Pass major risk NS29 203.48 399.99 Pass major risk NS31 187.75 2258.45 Pass major risk NS35 248.52 1553.60 Pass major risk Seal #A-1 32.23 4984.65 Pass minor risk 1 :200 Seal #A-2 235.19 2803.78 Pass major risk Seal #A-2A 237.20 2803.42 Pass major risk Seal #A-3 242.23 2517.09 Pass major risk Seal #A-4 394.70 2501.41 Pass major risk ':X'~ 5 NSO8 Permit to Drill t ( LOGGING PROGRAM: 16" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Resistivity, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology . samples (40' intervals - 20' intervals at shows), Geochem samples from 8899' MDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: RFT pressures only Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, Resistivity (real time), PWD I Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GR/Directional, PWD, Resistivity (recorded), Density, Neutron I Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: RFT pressures only Cased Hole: USjT (after rig release) ../ ~./ wi .I 6 NSO8 Permit to Drill ( 1\ , IntegritY_Jesting: Test Point 12 Ÿ4" Surface Shoe 9 5/8" Intermediate Shoe 7" Drillina Liner Shoe De th Test T e 20' min from 12 1/4" shoe FIT 20' min from 9 5/8" shoe FIT 20' min from 7" shoe FIT EMW Target EMW Target EMW Taraet FORMATION MARKERS: ~ l, Formation Tops MD TVDss Pore EMW Comments Press. (ppg) (psi) Top Permafrost 1205 1149 542 8.65 Base Permafrost 1576 1520 709 8.65 / SV6 3149 3010 1379 8.65 Set surface casing 150' tvd below top of SV6 ., SV5 3443 3280 1500 8.65 SV4 3780 3590 1640 8.65 SV2 4215 3990 1820 8.65 SV1 4639 4380 1995 8.65 Top UQnu (UG4A) TMBK 5014 4725 2150 8.65 Top Schrader 6738 6311 2864 8.65 Top Seabee (CM3) 7379 6900 3129 8.65 Colville Shales Top HRZ 9189 8565 3878 8.65 Base H RZ 9284 8652 3917 8.65 Top Kuparuk 9360 8722 4235 9.28 Hydrocarbon bearing mainly gas. Top Kuparuk C 9588 8932 4333 9.27 Hydrocarbon bearing mainly gas. Top Miluveach 9849 9172 4333 9.03 Set intermediate casing into the top of the Miluveach Top Kingak 10409 9687 4690 9.26 Fault #50 10695 9950 Not expected to be encountered in wellbore. Top Sag River 11478 10670 4992 8.95 Set drilling liner into the top of the Sag River to cover up the KinQak. Hydrocarbon bearinQ. Top Shublik 11510 10770 5038 8.95 Hydrocarbon bearing. 11 587 Possible loss circulation zone. Top Ivishak 11 679 10855 5078 8.95 Hydrocarbon bearing. Possible loss circulation zone. Anticipated OW C 11 945 11100 5192 Top Kavik 12032 11180 5229 8.95 Proposed TD 12076 11220 5280 9.00 Top Lisburne 12120 11260 5405 9.19 Possible loss circulation zone \".»{~ ~ q SI?> - CASINGITUBING PROGRAM: Hole Size Casing! WtlFt Grade Conn. Casing Casing Top Hole 81m Tbg O.D. Length MDITVDrkb MDrrVDrkb 20" 20" 169# X-56 WELD 201' Surface 201 '1201' 16" 13 3/8" 68# L-80 BTC 3323' Surface 3323'/3226' 12 Ÿ4" 9 5/8" 47# L-80 BTC-Mod 10010' Surface 10010'/9376' 8 Y2" 7" 26# L-80 BTC-Mod 1650' 9860'/9238' 11510'/10756' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 716' 11360'/10617' 12076'/11276' TubinQ 5-1/2" 17# 13Cr Vam Ace 9850' Surface 9850'/9228' Tubing 4-1/2" 12.6# 13Cr Vam Ace 1510' 9850'/9228' 11360'/10617' 7 NSO8 Permit to Drill ,( REQUIRED MATERIALS: L-80 Surface: 3323' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 3/8" 17 - 13 3/8" x 15 3/4" 1 - 20" x 13 3/8" 1 - 13 5/8" L-80 Intermediate: 10010' 1 - 9 5/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 60 - 9 5/8" x 12" L-80 Drlg Liner: 1650' 1 - 7" 1 - 7" 40 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1-7" 13Cr Liner: 716' 1 - 4-1/2" 1 - 4-1/2" 35 - 4-1/2" x 5-3/4" 18- 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 13Cr Completion: 9710' 1650' 1 1 1 1 1 1 1 1 1 2 1 ( 133/8",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) TAM Port Collar SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing Head/Tbg head- 9 5/8", 47# L-80 BTC-MOD HES Super Seal II Float Shoe H ES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger' SV Rigid Centralizers 7", 26# L-80 BTC-MOD HES Super Seal II Float Shoe H ES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Yam Ace HES Super Seal II Float Shoe H ES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 5-1/2",17.0# 13Cr-80 Yam Ace 4-1/2",12.6# 13Cr-80 Yam Ace 5 Y2" Fox x 4 Y2" Yam Ace XO 5 Y2" ABB-VGI tubing hanger 5 Y2" ABB-VGI adapter flange 5 Y2" ABB-VGI 5-1/8" 5K Swab Valve wI tree cap CIDRA mandrel and 0.25" fiber optic cable (wI 5Y2" and 4 Y2" cable clamps). 5 Y2" SVLN and 2 - 0.25" control lines 5 Y2" x 1 Y2" GLM with dummy valve installed 7" x 4 Y2" Baker 13 Cr packer S-3. 4 Y2" WLEG (w/o holes) 4 Y2" 13 Cr X nipples 4 Y2" 13 Cr XN nipple PERMAFROST: The 13-3/8" surface casing will be run approximately 1500' TVD below the permafrost to -3323' MD I ~, 3226' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a 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. 8 NSO8 Permit to Drill (' t CEMENT CALCULATIONS: The foil Iculaf b d . I t 'b , .... .... . Casin 13-3/8" Surface Basis: Stage 1: lead: Based on 105' cased hole capacity from surface to 105' MD, 1471' of Open Hole + 175% excess from the permafrost to surface + 50% excess to 750'MD above the shoe. lead TOC: Surface Tail: Based on 750' of 16" open hole x 13 3/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2573' MD Total Cement / S acer Preflush 20 bbl sea water S acer 75 bbl AI ha S acer wei hted to 1.0 over mud wei ht lead 433 þbl I 586 sk 72431 ft of 10.7 ppg Permafrost 'l' Cement. 4.15 cf/sk, BHST 50° I BHCT 50°, TT = 6.0 hrs Tail 96.6 bbl I ~68 skI 542 ft of 15.8 ppg Premium 'G' wI 2% CaCI2. 1.16 cf/sk, BHST 50° I BHCT 50°, TT = 4.0 hrs The followin cement calculations are based upon a single stage cement job. Casin 9-5/8" Intermediate Basis: Stage 1 : lead: Based on 4145' of 12 1/4" open hole x 9 5/8" csg with 30% excess lead TOC: At -4215' MD (4046' TVD) ail: Based on 1650' of 12 %" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. ail TOC: At -8360' MD 7858' TVD Stage 1: Total Cement / Spacer Preflush Spacer lead 120 bbls sea water 50 bbl Alpha Spacer we~hted to 1.0 p~ over mud MW 301 bbIJ.,521 sk"'f 1688 ft of 11.2 ppg Econolite. 3.24 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs 126b9.!-1 613 sl('l 705 ftJ of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs Tail The followin Casin Basis: cement calculations are based upon a single stage cement job. 17" Drilling Liner I Stage 1 : Slurry: Based on 1500' of 8 1/2" open hole x 7" csg with 50% excess + 150' 9 5/8" csg x 7" csg liner lap + 1200' 9-5/8" csg x 5" drillpipe above Tal + 80' shoe joint. Slur TOC: At -9678' MD 9071' TVD Staae 1: Total Cement / Spacer Spacer 50 bbl Alpha Spac~r weighted to 1.0 ppg over mud MW Slurry 67.4j)bl I 252 sk~ 378 ft of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs The followin Casin Basis: cement calculations are based upon a single stage cement job. 14-1/2" Prod Liner I Stage 1 : Slurry: Based on 566' of 61/8" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 41/2" csg liner la 1+ 200' 7" csg X 4" drillpipe above Tal + 80' shoe joint. Slur TOC: At -11207' MD 10477' TVD Staae 1: Total Cement / Spacer Spacer 35 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Slurry 18.5 þbl I 70 sk'11 04 ft of 15.9 ppg Premium 'G'. 1.50"cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs 9 NSO8 Permit to Drill (' ( WELL CONTROL: ~~((: Þ<t¥l:>(~ ~ A Diverter waiver has been requested on NS08. To date, BP has drilled eight development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. All eight surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4500 psi. Surface Section: . Maximum anticipated BHP: 1379 psi @ 3010' TVDss - SV6 . Maximum surface pressure: 1078 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) I ntermed iate Section: . Maximum anticipated BHP: 4333 psi @ 8932' TVDss - Kuparuk IC' . Maximum surface pressure: 3440 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Drilling Liner Section: . Maximum anticipated BHP: 4333 psi @ 10670' TVDss - Sag River . Maximum surface pressure: 3266 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5280 psi @ 11220' TVDss - Total Depth ~ " ~~ . Maximum surface pressure: 4158 psi @ surface """"" ~,>~\Q-cJ \ "'\>\Û~ (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) 5~ ~ . Planned BOP test pressure: 4500 psi (annular to 3500 psi) . Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./ No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ./ No H2S was detected while drilling the NS10 waste disposal well, or any other Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-Of, A-O2, and A-O3. DISPOSAL: ./ Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS1 0 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS 10 Class I Waste Disposal Well. 10 NSO8 Permit to Drill ( \ ( SURFACE HOLE SECTION: . Mudloggers will be rigged up throughout the entire section. ,// No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre as required prior to penetrating sand intervals. Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. Hole stabilization in the shallow unconsolidated intervals can be problematic if mud properties are relaxed. Hi viscosities as used elsewhere on the North Slope should be sufficient to control any potential running gravels. Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2001 drilling season have not experienced hydrates. Mudloggers will be used continuously on ~,,$09"" ðf$ to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. .ÃJ . . . . . . INTERMEDIATE SECTION: . Mudloggers will be rigged up throughout the entire section. Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the /' 2000-2001 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. The shallow intervals beneath Northstar are, by interpretation, not faulted. However, if faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. ./" Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. The kick tolerance for the 12 1/4" open hole section would be 68.5 bbls assuming an influx from the Kuparuk interval at -8988' TVD. This is the worst-case scenario based on a 9.728 ppg (0.5 ppg over the known pore pressure) gore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, andl~.8iPpg mud in the hole. \ ) \j . . . . . . 11 NSO8 Permit to Drill ~ ( DRilLING LINER SECTION: . Mudloggers will be rigged up throughout the entire section. The directional target has been designed to avoid a faults; however, the potential exists for a fault intersection at approximately 9950' TVDss in the upper Kingak formation. To be prepared for any potential lost circulation, a copy of the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. ."./ Full returns were lost while weighting up the mud system from 11.3 ppg to 11.6 ppg on NS27. PWD indicated an on bottom ECD of 11.8 ppg when the losses occurred. The new casing design isolates the weaker formations above by top setting in the Miluveach. Though initial mud weight will be 11.5 ppg, the new casing design allows flexibility to increase mud weight, as required, in the Jurassic shale interval. Gas in the SAG is possible. Circulate as required. According to Geology, the top of the SAG is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 13.5 ppg at the 9-5/8" shoe, and 11.5 ppg mud in the hole. / . . . / . . PRODUCTION SECTION: . Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. The drilling liner shoe will be drilled out with the 11.5 ppg mud. The mud will then be displaced with a 9.3 ppg drill-in fluid. ..'" Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Losses are not expected but calcium carbonate (CaCO3) will be maintained in the system. Severe lost circulation was encountered on the NS29. The Ivishak is a conglomerate section. Directional control will be maintained with MWD surveys to minimize doglegs. The well is not planned to penetrate the Lisburne limestone. On offset wells, losses have been encountered in the Lisburne. The project Geologist will be in charge of picking the base of the Ivishak and only rathole sufficient to bury the open hole logs will be drilled. However, if the Lisburne is penetrated, the LCM Decision Tree will be in place on the rig. The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TD. This scenario is based on a 9.45 ppg (.QA ppg over the anticipated pore pressur~..e --pore pressure gradient, a fracture gradient of ~1...q; ppg (based on FIT) at the 7" shoe, andtJ ppg mud in the hole. \../ ,// . . . . . . 12 ( ( NSO8 Permit to Drill NSO8 Rig-site Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used v continuously on NSOB to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. ~ Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. ~ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any previously drilled Northstar wells. Mudloggers will be used continuously on NSOB to help identify and trend any increase in background gas readings:' Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. ~ Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 Y2" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation, the 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. ~ Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick- up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. ~ Bit balling on the NS29 was experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. ~ The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ~ Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ~ Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 13 T~EE: ABB-VGI 5 1/8" 5ksi \ WELLHEAD: ABB-VGI13-5/8" Multibowl5ksi O(I...5INAL KB. ELEV = 55.9' NSO8 - Proposed KB-BF.ELEV=40.2' ca. ELEV = 16.0' 133/8" TAM Port Collar at +/-1600'MD 13 3/8", 68#/ft, L-80, BTC @ 3323'M D 5.5", 17#/ft, 13-Cr, Fox TUBING 10: 4.892" CAPACITY: 0.0232 BBLIFT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLIFT 9-5/8" 47# L-80 BTM-C @ 1001 O'MQ 4.5" X NIPPLE, @ 11305' MD' 3.813" ID 4.5" X NIPPLE, @ 11330' MD 3.813"ID 4.5" XN NIPPLE, @ 11345' MD 3.725" ID 4.5" WLEG, @ 11360' MD 3.958" ID 7", 26#/ft L-80, BTC-M @ 11510'MD I TD @ 12076'M D DATE REV. BY BMH COMMENTS 1/16/02 5 1/2" SSSV @ 2000' TVD w/ HXO SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4000' TVD (4165'MD) 5.5" GLM @ 4500' TVD (4708' MD) wi 4.62" ID "...' 5 1/2" x 41/2" XO @ 9850'MD - T' LINER TOP @ 9860'MD /' 'wi 4.5" Fiber Optic Transducer 3.958" ID 11315'MD 4.5" LINER TOP @ 11360'MD ,/" 4.5",12.6#, 13CrVam Ace // Northstar WELL: NSO8 A~L~Q: BP Exploration (Alaska) bp NSO8 Schlumb8rU8r Proposed Well Profile - Geodetic Report Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: January 7,2002 BP Exploration Alaska Northstar. Northstar PF I NS08 NS08 NS08 PDr ¥ 50029 NS08 (P6) I January 7, 2002 29.67r 13990.98 ft 15.103/0.354 NAD27 Alaska State Planes, Zone 4, US Fee! N 70.49094108, W 148.6932796E N 6030891.680 flUS, E 659833.940 flUS +1.23172370° 0.99992902 d 01/1 01 Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Minimum Curvature I Lubinski 318.560° N 0.000 ft, E 0.000 ft KB 56.0 ft relative to MSL 15.670 ft relative to MSL 26.532° 57513.397 nT 80.930° February 20, 2002 BGGM 2001 True North +26.532° Well Head ---~ Station ID Geographic Coordinates MD Incl Azim TVD DLS I Northing I Easting I Latitude I Longitude (ft) (O) (O) (ft) (°/1 OOft) 0.00 0.00 100.00 0.00 0.00 6030891.68 659833.94 N 70.49094108 W 148.69327966 500.00 0.00 100.00 500.00 0.00 6030891.68 659833.94 N 70.49094108 W 148.69327966 600.00 1.00 100.00 599.99 1.00 6030891.55 659834.80 N 70.49094067 W 148.69327263 700.00 2.00 100.00 699.96 1.00 6030891.14 659837.39 N 70.49093941 W 148.69325154 800.00 3.00 100.00 799.86 1.00 6030890.49 659841.70 N 70.49093736 W 148.69321647 900.00 2.00 100.00 899.77 -9.55 -2.12 12.03 1.00 6030889,82 659846.01 N 70.49093529 W 148.69318132 1000.00 1.00 100.00 999.73 -11.60 -2.58 14.61 1.00 6030889.41 659848.60 N 70.49093403 W 148.69316023 1100.00 0.00 100.00 1099.73 -12.28 -2.73 15.47 1.00 6030889.28 659849.46 N 70.49093362 W 148.69315321 1205.27 0.00 285.00 1205.00 -12.28 -2.73 15.47 0.00 6030889.28 659849.46 N 70.49093362 W 148.69315321 .-' 1400.00 0.00 285.00 1399.73 -12.28 -2.73 15.47 0.00 6030889.28 659849.46 N 70.49093362 W 148.69315321 1500.00 1.00 285.00 1499.72 -11.55 -2.50 14.62 1.00 6030889.50 659848.61 N 70.49093425 W 148.69316015 1576.32 2.53 285.00 1576.00 -9.60 -1.89 12.35 2.00 6030890.06 659846.33 N 70.49093592 W 148.69317871 1600.00 3.00 285.00 1599.65 -8.64 -1.60 11.25 2.00 6030890.32 659845.22 N 70.49093671 W 148.69318770 1700.00 5.20 302.22 1699.40 -2.11 1.50 4.89 ,...,2. 5 0 6030893.28 659838.80 N 70.49094518 W 148.69323969 1800.00 7.59 308.96 1798.77 8.75 8.07 -4.09 2.50 6030899.66 659829.68 N 70.49096312 W 148.69331309 1900.00 10.03 312.46 1897.58 23.93 18.11 -15.65 2.50 6030909.45 659817.91 N 70.49099055 W 148.69340758 2000.00 12.50 314.60 1995.65 43.39 31.59 -29.79 2.50 6030922.62 659803.48 N 70.49102738 W 148.69352317 2100.00 14.98 316.04 2092.78 67.10 48.49 -46.47 2.50 6030939.16 659786.44 N 70.49107355 W 148.69365951 KB Bid 1/100 Drp 1/100 End Drp Top Permafrost KOP Build 1/100 Bid 2/100 Base Permafrost Cry 2.5/100 NS08 (P6) report. xis Page 1 of 2 1/18/2002-3:47 PM Grid Coordinates Station ID I MD VSec NJ.S Northing Easting (ft) (ft) (ft) ftUS ftUS' 2200.00 95.01 68.78 6030959.03 659766.82 N 70.49112898 W 148.69381637 2300.00 127.07 92.42 6030982.20 659744.66 N 70.49119356 W 148.69399343 2400.00 22.44 318.48 2376.73 163.22 119.36 -111.42 2.50 6031008.61 659719.99 N 70.49126715 W 148,69419043 End Cry 2427.10 23.11 318.63 2401.72 173.71 127.22 -118.36 2.50 6031016.32 659712.88 N 70.49128862 W 148.69424716 SV6 3149.35 23.11 318.63 3066.00 457.22 339.97 -305.76 0.00 6031224.97 659520.97 N 70.49186981 W 148.69577909 13-3/8" Csg Pt -3323.31 23.11 318.63 3226.00 525.50 391.21 -350.89 0.00 6031275.23 659474.75 N 70.49200979 W 148.69614802 SV5 3442.91 23.11 318.63 3336.00 572.45 426.44 -381.92 0.00 6031309.78 659442.97 N 70.49210603 W 148.69640169 SV4 3779.97 23.11 318.63 3646.00 704.75 525.72 -469.38 0.00 6031407.15 659353.40 N 70.49237723 W 148.69711669 SV2 4214.87 23.11 318.63 4046.00 875.47 653.82 -582.22 0.00 6031532.79 659237.84 N 70.49272716 W 148.69803920 .-'" SV1 4638.91 23.11 318.63 4436.00 1041.92 778.73 -692.24 0.00 6031655.29 659125.17 N 70.49306838 W 148.69893869 Top Ugnu 5014.01 23.11 318.63 4781.00 1189.16 889.22 -789.56 0.00 6031763.66 659025.51 N 70.49337019 W 148.69973437 Top Schrader 6738.42 23.11 318.63 6367.00 1866.05 1397.16 -1236.97 0.00 6032261.83 658567.31 N 70.49475765 W 148.70339268 Top Colville 7378.82 23.11 318.63 6956.00 2117.43 1585.79 -1403.13 0.00 6032446.83 658397.15 N 70.49527288 W 148.70475143 Top HRZ 9189.12 23.11 318.63 8621.00 2828.04 2119.03 -1872.83 0.00 6032969.81 657916.13 N 70.49672934 W 148.70859273 Base HRZ 9283.71 23.11 318.63 8708.00 2865.17 2146.90 -1897.37 0.00 6032997.14 657891.00 N 70.49680546 W 148.70879343 Top Kuparuk 9359.82 23.11 318.63 8778.00 2895.04 2169.31 -1917.12 0.00 6033019.12 657870.77 N 70.49686667 W 148.70895497 Kuparuk C 9588.15 23.11 318.63 8988.00 2984.67 2236.57 -1976.36 0.00 6033085.09 657810.11 N 70.49705037 W 148.70943949 Top Miluveach 9849.09 23.11 318.63 9228.00 3087.10 2313.43 -2044.06 0.00 6033160.47 657740.78 N 70.49726029 W 148.70999321 9-5/8" Csg Pt . -10010.01 23.11 318.63 9376.00 3150.26 2360.83 -2085.82 0.00 6033206.96 657698.01 N 70.49738975 W 148.71033478 Top Kingak 10409.03 23.11 318.63 9743.00 3306.89 2478.37 -2189.35 0.00 6033322.24 657591.98 N 70.49771077 W 148.71118159 Fault Crossing 10694.99 23.11 318.63 10006.00 3419.14 2562.60 -2263.54 0.00 6033404.85 657516.01 N 70.49794082 W 148.71178844 Top Sag River 11477.81 23.11 318.63 10725.99 3726.42 2793.19 -2466.65 0.00 6033631.00 657308.00 N 70.49857058 W 148.71344988 Target 11477.82 23.11 318.63 10726.00 3726.43 2793.19 -2466.65 0.00 6033631.00 657308.00 N 70.49857058 W 148.71344988 7" Csg Pt -11510.44 23.11 318.63 10756.00 3739.23 2802.80 -2475.12 0.00 6033640.43 657299.33 N 70.49859683 W 148.71351917 Top Shublik 11586.54 23.11 318.63 10826.00 3769.11 2825.21 -2494.86 0.00 6033662.41 657279.11 N 70.49865803 W 148.71368065 Top Ivishak 11678.96 23.11 318.63 10911.00 3805.39 2852.44 -2518.84 0.00 6033689.11 657254.55 N 70.49873240 W 148.71387681 -- Top Kavik 12032.32 23.11 318.63 11236.00 3944.09 2956.52 -2610.52 0.00 6033791.19 657160.67 N 70.49901664 W 148.71462680 TO /4-1/2" Lnr pt 12075.82 23.11 318.63 11276.00 3961.16 2969.33 -2621.81 0.00 6033803.75 657149.10 N 70.49905163 W 148.71471916 leaal Description: Surface: 1119 FSL 642 FEL S11 T13N R13E UM Target: 3911 FSL 3107 FEL S11 T13N R13E UM BHL: 4087 FSL 3262 FEL S11 T13N R13E UM Northina (Y) rftUSl 6030891.68 6033631.00 6033803.76 Eastina (X) rftUSl 659833.94 657308.00 657149.11 NS08 (P6) report. xis Page 2 of 2 1/18/2002-3:47 PM --. -+-- 0> --. Q)....J ~C/) g~ a 0> N > II 0 ..c .S m T"""¡; ::: - a ..c:C! -+--(0 O-L() 0>- 0[(1 -~ m u.¡..:: .- 0> ~o:: > > Q) 0> :::JW l- I- 2000 4000 6000 10000 12000 8000 ( (' bp VERTICAL SECTION V:IEW Structure: Section At: BP Exploration Alaska NS08 (P6) Northstar Northstar PF 318.56 deg January 07, Schlumberger Client: Well: Field: Date: 2002 0 Bid 11100500, MD 500 TVD ,,/' 0.00' 100,OO~ az 0 departure 'Crp1ï100 eoo;¡"DeòöïVb ' 3,00' 100.0q' az .6 departure End Drp 11þO MD 1100 TVD 0.00' 100,þO' az -12departure ,;" - KOP Build 1/1001400 MD 1400 TVD i , ,/ ,,/"/ 0.00' 28~,OO' az -12 departure ! "l",(perii;¡,trj¡;1 1),j!:MD fZO:;~D"" .:,,':'~~~~:~-;--:~,~..'t~~,1~~:,~~~~~;,~~~~:~e,:,:'::' ';',,' ,...., ..'.. "'Ti";;¡;'F";iii,,'~¡;:,! Eï<."!',1D "ß7'fTVO" ---'--,---,.- Cry 2.51100 1600 MD 1600 TVD I , 3.00' 2~5.00' az .9 departure ! "1"": ,..,.. ""'" :::-~~~::E~dCt2;¡27MD"2402'TYD'" I ,-,---,_.---- 23,11'! 318,63' az 174 departure 13-3/8" Cag Pt3323 MD 3226 TVD 23,1 j' 318,63' az 526 departure I .!' ,',,' , +- .... ".., ,...., ,:V¡;":H,j\¡ ~11J :¡U¡)i) ;VO i I ! "';)v5":),!,~':; "j(),3::::i(\ TV!) I !'", "",)V~",W8" ~jl:r 'W;!'" ;';It) ....' i , ,:,'....1........,:':......::,..,..,:::'....::':'....':,:'..,..'::':....,:I......',..,....',..:......:::, - ¡ = = = = = = 1-- - I i J.. ..,.. ...., ,.... .... ".., ",.. ..I, I ! i I Hold Angle 23,1" ,...,...,....,.,......,.....,...,......i.......,......,......,..................,.................,....,....1..,.....................,.. I , i I 'I I , .1 c """::;;J~':':iii'3"r'M6";iii~;;':i'Vi:¡""":::""":.'.'.','" """,'" "... ",r'"" 'i'", ,¡O,""("'" ...." ..... "v, 'P.")', ~" 4, .'" v,) "'I<,fUgiïü ~hq r\~t) >lre1 ND ..... ..... ,.,.. I.. .,..,. ,.... j.... ....' ,...' ,... ..,.. I .l... i I Tiii,; <)(;hi~J,;; M~$ p;1r:, i,:'.~1 rVn Ti';¡'; C¿;ivi¡¡,I""i:)i~¡'M¡:j"'%%'p¡¡j' i ¡.. I T .....................,............,......,.........................,.....,........,.......................¡,.........................................,....,........ i , I I 9.5/S" Cag Pt I """""¡""""".'f1)ÖfÖ'MO"'smrvIY""""""'¡"""""""""""""'"...., . //23,11' 318,63'az I 3150 departure I ,.... ..[.. .... ::::: :::::. ..... ..... '::::: :,r: ':::. i .+.. ..... ..... ....,. I T;¡¡':~:~~~:¡;;~Pfl"~r>'H'I""'?x(r" ..... ..... ¡.... ...., ..... ,.... I'.t'"" i ,", " ,,', Ii,' ,",',"'~[',' """,',,' """n,', ..... ..,.. ¡.... '.... ..... ..... '.... ...., ..... i.... ..'.. ...., T,,~ ":,.,¡'")¡<;m',-,, i:;'1'\I[)"'" ..... :.... ..... ..'.. ..... ..... ..... ....' .¡--- ,.... K(ip',i'üh ("',!,'mrM,,"'&.WS"iV1J ..'.. ..... !..,..... ....,..... ...... ..... !,.. T',p r"""Nf,wl, !Je,W'MO '9:~~H TVI)' i i i . I Target I ........., ::i:'~i'..i~ir,¡.!.~ L....',~.;~ .':) ¡.!..'~:¡:,) ..~,~~~~..i,\~ [,',:, ,......: ::, ,..i::' ,.. ,.. :::::............ .....':.. ...... ï'::,'; ~';ii' ç','~;:;;:i;;!;""!,) ¡:;:i;; ~;;' ;,:) i;')i:;'~"".' .....,...1..... ':,:;:'i ~~Z1:~~r~;~~~" "\...... ........ ...,........ ...,...... \ )/ 7"CsgPI i \ \,~ -.,-"---"-- 11510MD 1075~TVD 'i'A b..",. ..... ..... ....,. 23".11""'318"63""""" :" 2\\;;: '.,', '...,' ':' ~~... r ..,. . TD / 4-1/2" Lnr PI i 12076MD 11276TVD ' i 23.11' 318.63'az i """""""""""""""""""""""""""","""""""..,.....................................................,................ """"""""""""3961d'~¡;~rt~;~"""""""""'1"""""" ":\".';'.:';jn.<,~..!~¡".,ó':,.,.,,:.1.14'?~, l.d¡';~.('~(;'Y"J[)':": t.:.. ..... ":j:""."~tli,,'II' 'iIAeX.MII....íi8¡"".iVD ..... . l)t"mll,,\1h-It'MD1\J9T!IIi.) . ! . "Y('P'¡:(¡Vik"1~()~) (;i[) f'i'::ôff1\i[j"" ..... ¡... .... ¡.... -2000 0 2000 4000 6000 Vertical Section Departure at 318.56 deg from (0.0, 0.0). (1 in = 2000 feet) . . bp ( PLAN ViEW ( Client: BP Exploration Alaska Well: NS08 (P6) Field: Northstar Structure: Northstar PF Scale: 1 in = 1000 ft Date: 07-Jan-2002 Schlumberger -3000 -2000 -1000 0 1000 Bid 11100500 MD 500 TVD /' 0.00' 100.00' az 0 N i 0 E End Cry 2427 MD 2402 TVD "'- -' ! 23.11' 318.63'az 127~ 118W --.----.-- // Drp1/100800MD 800!TVD """""""""""""""""~;::;:;:~;~~~";'~b~"~'~"";~~'~'~~'~~~:'::~:'::;"? '-"'~'3':0a-""roO:¡JO"äzTS";B'E""'" 3.00' 285.O0')az 2 S 11 E / I j / EndDrp1100MD 11001TVD Bd2l1001500MD 1500TVD 0.00' 100.00'az 3S 1¡5E 1.bo' 285.00' az 3 S 15 E , KOP Build 1/1001400 MD 1400 TVD ! 0.00' 285.00 az 3 S 15 E 5000 4000 I TO 1 4-1/2" Lnr PI 12076MD 11276TVD 23.11' 318.63'az 2969 N 2622 W r' Csg PI 11510MD 10756TVD 23.11' 318.63'az 2803 N 2475 W Targel 11478MD 10726TVD ...?~,.1J.~..':¡J8:~.~:..~~.... 2793 N 2467 W 3000 I 9-5/8" Csg PI~ 10010 MD 93 6 TVD 23.11' 318.6 °az 2361 N 2086 W ^ ^ ^ I I- ~ 0 Z 2000 1000 Kõ", : '0- j 4" .. ~~ ~~ ............................................¡.................................................¡......................~?~~~.....,..... I I- ::> 0 en V V V 0 True North Mag Dee ( E 26.53° ) 5000 I ....~... 1 I i I ..1. I I I I 4000 ...;.. 3000 2000 .......................................................,............... 1000 13.3/8" Csg PI 3323 MD 3226 TVD 23.11' 318.63'az 391 N 351 W 0 -1000 .........................................................................................................,.........................................................1....................................................;.............1- -1000 I -2000 -3000 -2000 «< WEST -1000 I ...............].........................................................L...........1- -2000 . I . I 0 EAST »> 1000 ( ( Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumb8PD8P 3940 Arctic Blvd, Site 300 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Friday, January 21, 2002 Barbara Holt Northstar NSO8 (P6) BP Exploration Alaska Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Nabors 33E Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Proqram: Instrument Type GYD-GC-SS MWD - Standard (declination corrected) Start Depth 40.20' md 1,500' md End Depth 1,500' md 12,075.82' md Close Approach Analysis results: Under method (2), all wells may flow, except for: NS09 - Closest point at 350'md, center to center distance 5.6 ft. Well will need to be shut in during the interval from 300'md to 1300'md. Seal A-01 - Closest point at 5000'md, center to center distance of 72.4 ft. The interval of violation is from 4750'md to 5225'md. However, the well is already P&A'd. Both of these wells pass the 1 :200 risk based rule. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach DrHlinq Aids to be provided: A drilling map, with offset wells on the plan view, and traveling cylinder will be provided. Checked by: Scott DeLapp 01/12/02 . { Schlumberger Anticollision Report (' -----"-------.---------------------. ---. .-.---- ------- ---.---------.-------.--.--. -----.---.--------------.-.-.----------------- . .--------------- ---- I . ¡ Company: BP Amoco I Field: Northstar ¡ Reference Site: Northstar PF Co-ordinate(NE) Reference: Well: NS08, True North i Reference Well: NS08 Vertical (fVD) Reference: NS08 plan 56.0 L- ~~ fer e n c_~-~ !~~~~~ ~.~._~ ~?_~_._._- -.---- --- --- -. ---. --.--- . ------ ----..---.----. ---.---- ------ --.-.--------... .-- ---.- -- - ---.--- -- .-.---. -. -- . -. - -.-.---. ----- -- - -.. ....- ....._. - -- -- ... ---. ---.-. --~ ~:_--~x~~~-~- ----_J -------._--. ------------- "-..------------------------ ----.------- I NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal PI~n & PLANNED PROGRAM! I Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse ¡ : Depth Range: 40.20 to 12075.82 ft Scan Method: Trav Cylinder North I I Maximum Radius: 2000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath I Date: 10/18/2000 Validated: No Planned From To Survey ;;lC~~~f~=~: ~::~ : ~~ Casing Points Date: 1/21/2002 Time: 08:33:30 Version: Toolcode 15 Tool Name --------.-----.--.- Page: 1 Gyrodata gyro single shots MWD - Standard -l GYD-GC-SS MWD ----- - - ----.- - ..-- - ----- -. -._--- ---. --- --... --- -- --.-.- .---.-. -- ----.. --- 650.00 900.00 400.00 350.00 200.00 700.00 1000.00 2000.00 3450.00 2300.00 1200.00 550.00 450.00 2050.00 1200.00 450.00 3302.23 2300.00 1550.00 400.00 2250.00 1550.00 5000.00 2750.00 2750.00 2500.00 2400.00 31.39 12.33 22.16 16.78 10.16 3.50 5.65 2.97 21.10 3.68 31.02 13.25 42.27 18.26 38.52 25.97 104.29 80.55 59.57 38.52 85.10 20.82 100.13 10.67 131.29 8.44 114.26 30.30 163.79 20.81 171.46 8.59 84.91 80.47 171.26 35.15 203.38 24.79 210.72 7.25 224.20 36.74 273.37 24.85 72.38 44.08 286.24 51.73 285.96 49.44 288.24 46.46 443.54 50.54 19.07 5.39 6.66 2.68 17.42 17.78 24,00 12.71 27.32 24.63 64.30 89.46 122.84 84.05 142.99 162.87 31.33 137.02 178.59 203.48 187.75 248.52 32.23 235.19 237.20 242.23 394.70 -----------.'-'" ---...-.--.-------'----.----------. -----.-------- -- .-- - -.- --------- ---... --.--.- ----..-.-. ---------- ,-- .---------- --.----. ---.- .__.. Name MD TVD Diameter . ft ft in -,... ,---.-----. .-., -- .._-~.--,_.,-,. ..... -.--..- ,- _'__h_._- ------..-.-.. --..- ,.....-.. .-.- ....-.-.-.--.--." ,-..-.-----. o.--o.--. .._,- _o.-_-o..h ..,--_... o.o.--.-.o.-..o.,"..- ---- _'h.' .o.... -.o."..o.. - .ho... -".. o._,- -' .... .,.'."-o...,--,,, ",-,--o..',... ,-, o....o..._,....' 3323.05 3225.77 13.375 16.000 133/8" 10009.63 9375.77 9.625 12.250 95/8" 11510.03 10755.77 7.000 8.500 7" 12075.29 11275.67 4.500 6.000 4 1/2" Summary Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Seal Island Seal Island Seal Island Seal Island Seal Island 650.1 0 900.07 399.99 349.95 199.99 699.55 999.61 2003.01 3416.40 2319.97 1200.27 549.81 449.98 2055.30 1198.88 449.98 3358.66 2292.02 1552.85 399.99 2258.45 1553.60 4984.65 2803.78 2803.42 2517.09 2501.41 NS05 NS06 NS07 NS09 NS10 NS11 NS12 NS13 NS14 NS15 NS16 NS18 NS21 NS23 NS24 NS25 NS26 NS27 NS28 NS29 NS31 NS35 SEAL-A-01 SEAL-A-02 SEAL-A-02 SEAL-A-03 SEAL-A-04 Plan NS05 V2 Plan: Pia Plan NS06 V7 Plan: Pia Plan NS07 V2 Plan: Pia NS09 V14 NS10 V17 Plan NS11 V2 Plan: Pia Plan NS12 V1 Plan: Pia NS13 V12 NS14 V9 Plan: Plan #9 Plan NS15 V10 Plan: PI Plan NS16 V14 Plan: PI Plan NS18 V1 Plan: Pia Plan NS21 V35 Plan: PI Plan NS23 V7 Plan: Pia Plan NS24 VO Plan: Pia Plan NS25 V2 Plan: Pia NS26 V22 NS27 V29 Plan NS28 VO Plan: Pia NS29 V22 NS31 V14 Plan NS35 VO Plan: Pia SEAL-A-01 V4 SEAL-A-02 VO SEAL-A-02A V4 SEAL-A-03 V4 SEAL-A-04 V4 Pass: Major Risk Pass: Major Risk Pass: Minor 1/200 Pass: Minor 1/200 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Minor 1/200 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk {" \ -_J Field: Site: Well: Wellpath: N orthstar N orthstar PF NSO8 Plan NSO8 0 '340 300 200 100 --- 0 ...200 300 NSIO (NSIO) ~ '340 180 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation (100ft/in] .-.-----..-"""'-"'" ~ ~ / Target: NSO8 l O'll: NS07,NS08 '\ .;ed on: Planned Program Vertical Depth: 10670.00 ft below Mean Sea Level Local +N/-S: 2792.78 ft Local +E/-W: -2467.11 ft Longitude: 148°42'48.420W Radius: 400 ft " Site: Northstar PF i Drilling Target Conf.: 99%\ Centre Location: Sag Tgt Map Northing: 6033631.00 ft Map Easting : 657308.00 ft Latitude: 70o29'54.854N Shape: Circle 3500 34-0C 320C 250C "'" 300C '\ 280C 24-0C ~ ~ / ~ 0 / / 220C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 IT) LD J N 0 IT) LD (I) N N N N N I I I I I I --.. ~. TRANSMIT AL LETTER CHECK LIST CIR CLE APPR 0 PRIA TE LETIERIP ARA GRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORA TION ANNULAR DISf.OSAL ~O INJECTION WELL ANNULAR DISPOSAL <--J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL AlL) ()f5 "CLUE" The permit is for a new wellbore segment of existing well . Permit No, . API No. . . Production should continue to be reported as a function of the original API number stated above. . In accordance with 2.0 AAC 25.005(f), all r~ords, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from . records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. ~ . ANNULUS <--J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company ~ame) will assume the liability of any protest to the spacing exception that may occur. ¡ . A__. /'--' ~' DATE 01/1//0~ CHECK NO. 00204435 H 20l1435 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 011602 CKOl1602B PYMT OMMENTS: HANDL NG INST: iOO.OO 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 -nSO8 ~3m RECE VED JAN 3 200) Alaska Oil & Gas Con ,Commission An TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100. 00' 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H2O 4 4 3 5 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00204435 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 I I AMOUNT $100.001 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 n '. -_.- -:/ . "'? j 1 ~\\ l .". 0.'.' /2.- -',I 3/1, /t~ - \ t, '>.,,-'<:'. ,";,--""".~. ~. {' . . ~ .¡~; ~ -- III 2 0 ~.~ :l 5 III I: 0 ~ . 20 :ì B ~ 5 I: 00 B ~ ~ . gill WELL PERMIT CHECKLIST COMPANY ¡:y-' X J WELL NAME /11.5 G/Z:S PROGRAM: Exp Dev /' Redrll Serv Wellbore seg Ann. disposal para req FIELD & POOL ~~D/~ INITCLASS ~V J' OIL. GEOLAREA _&90 UNIT# CJ//Ç'DO ON/OFFSHORE Or:-F= ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . - , N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . )N 12. Permit can be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . @ N ~ f ft 2-D ( I T.,J.l) ,( ,/J(s4-- 15. Surface casing protects all known USDWs. . . . . . . . . . . ,,()t'l ~A . ð. USpt<J r~ ¿¿.-f- /\/,-, .'-!þ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . W N .!. '9 UA--t< e"i-cPSS Cii+tl?4-<-f. 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~y EP 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, To B & permafrost. . . . . . . N * r N . ~3 £. 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N eL y~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N JJ. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Nt" i-{ . 23. If diverter required, does it meet regulations. . . . . . . . . . - N ~~ :. - iN të..-è. "~f ~f., <;. 24. Drilling fluid program schematic & equip list adequate. . . . . N ¡.J ~s t:. 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ;J HE, I ~ ~ t 26. BOPE press rating appropriate; test to 5000 psig. N MN;P':: ,+15t£, y;~. ¡"1O'f.~ CÇ.' ~':: 4'SOOfc.¿. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (Brí1.l-i" b-e{c/'(.,~P" ,,/ 30. Permit can be issued w/o .hydrogen sulfide measures. . . . . rYJ N 4. ~ ;I~ M, ~ ~ /J<1 <15 ~ ~ &.tr- , "'~ 31. Da~a ~resented. on potential overpressure zones*:. . . . . . '(i) N ~.,"' $tS:U: :fJ~ flO¡ ~~. ø-r.-. ~ 32. Seismic analysIs of shallow gas zones. . . . . . . . . . . .. /¡)11 -¥--N ¿ ~ ,,+--x r1'\ (..J "u ~R DATE. 33. Seabed condition survey (if oft-shore). . . . . . . . . . . .. NA -Y N - (JrA.d¡~ ¿.q Ò. q. ,o$Lß"i (rZi! ~ C/h~.~ I ~.-I- .'i-U- -Á~ ~'.~ 2~ 7'D2-- 34. Contact name/phone for weekly progress reports [exploratory on/rlAJ~ N- ~ v{fA (~ . fI V V (f - - - - 0 ¿J ANNULAR DISPOSAL 35. With proper cementing records, this plan ¿;.~ (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC TEM~ ì COT SFD# WGA f DTS ~ JMH ÆtLA3/02 1z~~:~-¿- ENGINEERING ( APPR DATE vJ6~ JJ1/.£.2- :() ?-{" 'Gd.- GEOLOGY ( APPR DATE Y N' J l Y N No c~ Pt IA.'c.e¡,,¿/ ~ ~ 5. 120 ~ r:J( . I Y N Y N Com ments/l nstructions: 4~~ aU/~ -Þ Øtð-71/~ ~.ekhJ d~I/~ ¿¡u~ ~-hJJ~ tA<-- ~~w£a...A"~ð., G: \geology\perm its \checkl ist. d oc ') ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically . . organize this category of information. SCANNED NOV 1 8 2004 ~ ),èJ J-.. - G ).. \ Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Oesc.: Pipe1 Use: Pipe20esc.: Pipe2 Use: BP EXPLORATION (ALASKA) INC. May 12, 2005 5752 1 5.5" 171b 13-Cr Vam-Ace Tubing 4.5" 12.6 lb. 13-Cr Vam-Ace Tubing and Liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: Top Log IntvI1.: Bot. Log I ntvl1 .: NS-08 NorthStar Alaska 50-029-23068-00 Suñace (MD) 9,603 Ft. (MD) 9,603 Ft. (MD) 11,374 Ft. (MD) Inspection Type: COMMENTS : Corrosive & Mechanical Damage Inspection This caliper data is tied into the WLEG @ 11,297' (Drillers Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate lhallhe 5.5" lubing is in good condilion. No significanl wall peneLraLions, areas of cross-sectional wall loss or 10 restrictions (with the exception of the tubing patch) are recorded throughout the 5.5" tubing. The caliper recordings indicate that the interval of 4.5" tubing and liner is in good condition. No significant wall penetrations, areas of cross-sectional wall loss or 10 restrictions are recorded throughout the interval of 4.5" tubing and liner logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. 5.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: .'~-); (,;j\\¡ì\~ K~ EJ)¡ ('j) ¡::-1i) {ìj 9 ~)fJ n ~; ~,\_, L Ii 'I!.../ ~~ CJ, ~I..ß';ILJ} No significant wall penetrations (> 20%) are recorded. 5.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded. 5.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. 4.5" TUBING AND LINER - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 20%) are recorded in the interval logged. 4.5" TUBING AND LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded in the interval logged. 4.5" TUBING AND LINER - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded in the interval logged. I Field Engineer: N. Kesseru Analyst: J. Thompson Witness: M. Harris ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 clds. Well: Field: Company: Counlry: N S-08 NORTH STAR BP EXPLORATION ALASKA INC USA I Tubing: Weight 1 7 ppf Grade & Thread 13-Cr Yam Ace Nom.OD 5.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 ffi:!ì!GI metal loss body 150 1-IB 1 to 1 0 to 10(Yo 20% over 85% 100 _______H___.. 50 I o ~ to 1% n. .. ....__.". ..___ 20 to 40 to 40% 85% _________~!!1.!?_º~_º_f.joj n ts an~..?s_~J.~Q1~L~~~~4}L_____.__.___________ pene. 14 189 39 1 0 0 loss 42 175 26 0 0 0 ._~~_.~...._-, -~_'_-_'_"'--'"..,._,_._...~_._-_.._-_.-."~-- Damage Configuration ( body ) 20 10 o isolated general line ring hole I pass pitting corrosion corrosion corrosion ihle hole ________~~æQ~J:J)l.1Q!D!~_Qª_I!!.ªggº_J~QtAL:"_JZL______________ 10 1 5 1 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 4.892 ins May 12, 2005 MFC 24 Exl No 040936 1.69 24 J. Thompson Nom. Upset Upper len. Lower len. 5.5 ins 1.2 ins 1.2 ins Damage Profile (% wall) _ penetration body o :E~Si'~ metal loss body 50 100 GLM 1 IF- ~ 47f 96f ~ br---- k::- L 143~ r r 193~ t Bottom of Survey = 235.1 Analysis Overview page 2 { PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 5.5 in 17.0 ppf 13-Cr Vam Ace 0.304 in 0.304 in 4.892 in Well: Field: Company: Country: Survey Date: NS-08 NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint I J1. Depth Pen.' Pen. Pen. Metal I Min. No. (F1.) Upset Body % Loss 1.0. (IllS.) (Ins.) (}~) (Ins.) __uJ_____ ____5JL___ ___JL___ __º-'º_.?__ _-1Z_____HL __.1ß.Q______ 1.1 94 0 0.02 7 J 4.88 PUP 1.2 106 0 0.03 10 4 4.88 PUP 1. 3 116 () 0.03 10!) 4.88 PUP 2 126 () 0.00 1 9 4.86 3 168 (),()() 0.03 11 2 4.86 Shallow pitting. 4 210 o,()() 0.02 7 6 4.86 Pitting. 5 252 O.O£) 0.02 7 __.L___4.87__________________ ______n______.._____u_ 6 290 O.O!) 0.02 7 3 4.87 7 332 O.[)6 0.02 7 2 4.88 Shallow pitting. 8 371 O,()() 0.02 7 2 4.85 9 41 "I 0 0.00 1 "I 4.85 to 450 0 0.00 1 7 4.87 11 493 () 0.02 7 9 4.86 _ .__J~__.____ ..__.?}~____.___uJL .. .__.Q·_91___..-.Z :3 4.87 13 577 () 0.02 7 3 4.86 14 619 0 0.05 17 14 4.84 15 657 0 0.00 1 7 4.86 _..L§u. _._§_~_~L._. ..Q .._º~.Q.~_.n_._Z. 5 ....___:~IJJ5. 17 739 0 0.00 1 1 4.87 18 781 0 0.02 7 6 4.86 Pitting. 19 820 0 0.01 3 5 4.84 20 860 () 0.01 3 6 4.85 21 899 0.05 0.02 7 B 4.82 Pitting. 22 939 0 0.01 2 5 4.85 23 979 () 0.01 2 2 4.86 Pitting. 24 1018 0.06 0.02 6 7 4.85 Pitting. 25 1060 0.06 0.02 7 6 4.87 26 1099 0 0.02 61 4.84 Pitting. 27 1141 0 0.02 6 2 4.86 28 1183 0.06 0.02 7 6 4.86 29 1225 0 0.00 1 11 4.88 ____Jº-_____J 7.6,5.._..._._.._ 0 0,07. 8 _£>__ 4.88 31 1307 0 0.02 7 1 4.86 32 1346 0 0.04 13 '13 4.87 Shallow pitting. 33 1388 0.05 0.02 7 2 4.87 34 1430 () 0.00 1 "I 4.85 3S 1469 0 0.01 2 2 4.87 36 1509 0 0.02 6 2 4.83 17 1.548 0 0.06 19 18 4.86 38 1589 0.07 0.04 15 9 4.86 ._.._-1~L.._.._ __..__.1þ2_~_.____._JL__.._._ºJH__n _.__...2.._._._._. _._._1_____1,ß_4__ __._____._._..__.._________ ...___.______._. __.____._.____.__ 40 1668 0 0.06 20 "12 4.85 41 1708 0,06 0.02 7 3 4.87 42 1748 () 0.02 6 2 4.86 43 1787 0 0.01 4 3 4.88 44 1827 0 0.02 6 2 4.86 45 1666 0 0.04 13 B 4.84 ._____1§ 1 906 _____ __--º_____.....QJ)1__ ___.Z__ _____L__. .__:hJI2..__ __S..hª!Lº~J~iJ1Lllg'__..___ ______._.__. 47 1945 0 0.02 7 2 4.88 Comments 1 Damage Profile I (% wall) 50 100 o _ __. _ ..__ __._....._n ._. _______ __________. u_.._ _., · .. f' -I ~ ~] .....--.-..--.-.-..-----------..--.-----.-.-.-..- .------.--.--e ., I , , ~ , ! --.........--- ....... ...-.......--. ........-- .--J ,~ --. .t · ;1 · I t r .-...---.--.---.----------.-----.--..--.p Page 1 · Penetration Body ~ Metal Loss Body Joint I Jt Depth PCIl. Pen. Pen. \ I\\etéll Min. No. (Ft) Upset Body % Loss I.D. (Ins.) (Ins.) (~~} (Ins.) I 47.1 1988 () 0.01 3 1 4.86 PUP .__~~~_~__.-.1_~2.L_____Jl~______.9__.__~º__.____._D___NiA___~~~y____ - ____ - -_.___. ---.--- --.------ ---'- - 47.3 2005 0 0.03 9 5 4.88 PUP 48 2010 0 0.01 2 :~ 4.88 Shallow pittin¡.?;. 49 2052 0.07 0.04 12 4 4.86 Shallow pitting. . _~º-____ ___.1.0.21_ __JL__~._.Q,º~___ __ _19__.. _HL__ _3~_~_ ________________________.___ 51 2131 0 0.00 1 B 4.88 Shallow pitting. 52 2173 o,()() 0.02 7 2 4.87 53 2214 0 0.02 7 1 4.86 Pitting. 54 2254 () 0.02 7 () 4.86 m....?'? 2.2..~.2.._._..._............j.>........____..._º,º2.. ._ '" ..fJ. J ..4AŒ..... .._.._ 56 2332 0 0.02 8 -I 4.86 Pitting. 57 2372 0.07 0.02 7 1 4.85 58 2411 0.07 0.02 7 1 4.87 Pitting. 59 2450 0 0.02 7 5 4..86 60 2492 0.06 0.02 6 '[ 4.85 61 2534 O.OS 0.02 7 2 4.84 62 2573 0 0.01 4 3 4.88 63 2615 0 0.02 7 5 4.34 64 2653 0 0.01 3 2 4.85 65 2695 0 0.02 7 2 4.87 66 2735 0,()6 0.02 7 3 4.86 67 2774 0 0.01 3 2 4.85 68 2814 0 0.02 7 6 4.86 69 2854 0.05 0.02 7 2 4.85 70 2893 0 0.04 14 11 4.87 71 1.~_1J_____.JH2.!i__QJ2L__ ___Z______:!_~.1_____._________..____.._.__.__..____._...._______ __________..____.._____..____.__________ 72 2972 0 0.01 3 2,.4.86 73 3012 () 0.01 3 1 4.86 7 4 3Q_~J_..____º=DJ?__ _.___º_,ºl___:L___ ___.._2__ _._.4~~t6___._..._________.______________.______~.____....___ ~ ___.___~_____.. __3_Q9-.~__._ ____._D_._.___._.._Q,Q2__.______·L________:?_____. ._4J~.2_. _.___.____________________ ...---.----------~~~~:::~__________~ 76 3134 0 0.02 7 2 4.85 r 77 . . 3176 ..._ 0 0.02. 6 . 1 4.84 ,. __._._______.__. __.. _._. ____ _~ ___ ... '_"n'___ __........_. _____.._____ _ ._..._._.. ...___.__ ___.._..__..__._____....___.._.___..___._....._.___..._..__._....._._.._.____._.......__....______, !I ¡¡II t-1It~~-·-~-···-~It-~:i~:-:~:--------------~· 84 1452 0 0.01 2 -4 4.81 r II ---~~-i---m_-1~-iJiîì-------·-----------------_i 90 3692 0 0.01 3 3 4.83 ! 91 3731 0 0.01 3 6 4.85 , 92 3771 () 0,01 2 3 4.84 L 93 3813 0 0.02 7 3 4.85 r -·--94·-----· --jiis-s'-'Q()G- - 0.02 -7·-·---- -..---,--.- --"4-:-8"6-'- ___.___._____._____n_____._.______.._____..__ ~ PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NomìnaII.D.: 5.5 in 17.0 ppf 13-Cr Vam Ace 0.304 in 0.304 in 4.892 in Well: Field: Company: Country: Survey Date: NS-08 NORTHSTAR BP EXPLORATION ALASKA INC USA May 12, 2005 Comments \ Damage Profile \ (% wall) 50 1 00 I o - ---~ t ~ ~u_~ 1 I --_._-~ ~ I f ~ ...... ..·....··m..·_·...··..._u___..._. Page 2 I Penetration Body "', Metal Loss Body 1':1, ,~\ , PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 5.5 in '17.0 ppfl3-Cr Varn Ace 0.304 in 0.304 in 4.892 in We!!: Field: Company: Country: Survey Date: NS-08 NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint J1. Depth Pen. Pen. Pen. ''''eta! Min. No. (Ft.) Upset Body % Loss 1.0. (Ins.) (Ins.) % (Ins.) 95 3895 0 0.02 7 4.84 ___9Þ__ ___J9.1Z___ ____._LL__,__-º-'_º-2____-.Í>____ _J___~tlH___ __.______________________._____ 97 3979 0.06 0.02 7 2 4.84 98 4018 () 0.02 7 2 4.86 YY 4058 () 0.02 7 3 4.85 100 4100 0 0.02 7 1 4.85 101 4140 0.06 0.02 6 1 4.85 102 4179 0 0.00 1 '[ 4.81 103 4219 () 0.02 7 1 4.84 104 4258 0 0.01 2 3 4.85 105 4298 () 0.02 6 3 4.85 t 06 4338 O.OS 0.02 7 2 4.85 107 4377 0 0.06 18 9 4.87 108 4417 0 0.02 7 1 4.82 109 4456___ 0 ___J),OJ_____2.___u___L____3~]___ 110 4496 0 0.01 3 1 4.86 111 4535 O,()6 0.02 7 2 4.85 112 4575 0 0.05 16 13 4.85 _ LIJ__ n' __A1iL!5. .__ _ ... .(L_ _Q,Q.:?_____ . 7.. _ .5 4J3li__ _ _n" _ __ _ 114 4657 0 0.02 6 2 4.85 115 4699 0.06 0.02 7 2 4.82 115.1 4741 0 0.03 11 5 4.78 PUP Shallow pitting. 115.2 4751 0 0 0 0 N/A GLM 1 (Latch @ 8:00) 115.3 4762 0 0.03 9 5 4.86 PUP 116 4771 0 0.00 1 '[ 4.83 117 4810 0 0.01 4 2 4.86 118 4850 0 0.01 2 2 4.86 119 4890 0 0.01 3 2 4.86 Shallow pitting. 120 4929 0 0.02 6 1 4.84 12' 4969 0 0.00 1 3 4.85 Shallow pitting. 122 5010 0 0.01 2 2 4.86 123 5049 0 0.02 7 5 4.84 124 5089 0 0.01 3 3 4.86 125 5129 0.05 0.02 7 4 4.86 126 5168 0 0.05 16 15 4.83 Shallow pitting. 127 5208 0 0.01 2 5 4.87 Pitting. '128 5248 0 0.02 7 9 4.87 129 5290 0 0.02 7 6 4.87 130 5332 0 0.06 18 16 4.87 131 .5174 0 0.02 7 2 4.86 1 :~2 5415 o.()? 0.02 7 2 4,85 __..J13..__ __.__.?.45 ª-__ ___fl__. O. 02 ..._~__ __1___ __-1.,ªZ_., 133.1 5486 o.cn 0.01 5 0 2.89 _ _ Jl:L___.__,.5.5.º_4___ ___J)._....__Q,.º2_. ....._1___ _ __1_____..4J?º__ 1 35 5539 0 0.02 7 a 4.87 136 5581 0 0.03 10 9 4.83 137 56.21 0 0.01 2 2 4.87 138 5660 O,()6 0.02 7 2 4.86 Pitting. _J,J.2______ 5700 .___...JL___ _Q. 02__ ____Z_,_ ._._L_... ._5-'--f}_.?_________.______.___________..._..__________________....__.. 140 5741 0 0.00 4.85 Comments o ~ = .. .. ~ ~ I I . ~ ~ ~ -J ~ r r -_._.._-_...._--~ I I, i r t.' IF' M . ~ ..·--·Patch~----------------------·--"·----·---------·-~ ,,---,,".---------,,--,,----------,,-------.----. -----"." '..----'- -.,----.,,---" - .--,,----."........ --'-_·'''-----'1 I ~ ~ "------, Page 3 1 Damage Profile (% wall) 50 100 I Penetration Body ~:il' Metal Loss Body { PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 5.5 in 17.0 ppf 13-Cr Vam Ace 0.304 in 0.304 in 4.892 in Well: Field: Company: Country: Survey Date: N S-Otl NORTHST AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint I Jt. Depth' Pen. \ Pen. Pen.' Metal I Min. No. (Ft.) Uµsct Body % Loss 1.0. Ons.) (Ins.) (~';) (Ins.) 141 5784 0 0.01 2 4.83 _.J12-_.. ..._~.ª~_~__ .~__JL_____(tQ2_______L_ .__J____3Jiº_ ____._~____________.____ 143 5862 () 0.03 11 1 4.84 Shallow pitting. 144 5902 0 0.01 3 '2 4.86 Pittin~. 145 5941 0 0.06 1913 4.83 __J4.6___ _ ...~_91n_~. _QJ2h__ __Q,º-2__. . ___L____....l._ __4.ß.:L. ____ .___.___.__.uu. _ ______. ___. _ .. _ ___________ 147 6023 0 0.02 7 2 4.85 ___J 48.___. _ 606_~________ (L._____p. O¡_.__l._._J___ ___4JH~___________.__________________ ____ _____ _____ 149 6107 0 0.01 2 '2 4.84 150 6149 0 0.02 7 '2 4.87 __._1!?J..__ .,___fdJJ2..._..._._ JL.. .,,_ .._Q,Q4. ,... .."""..7... ..,.... .".".."4.,..,,... 4.85 ..,."....""_",,........... """,.." ".... "....., .....................,,,............,,......,,....,, 152 623 1 0 0.02 7 12 4.86 Pitting. 153 6273 0 0.00 1 3 4.88 Shallow pitting. 154 6315 0.06 0.02 7 £> 4.86 ___J2~____(i]ªZ__ () O. 02 _º--_____L____1~ª.~_._.____..___..____.__________.._. '. ._._.._...____.. ,_.________ 156 6397 0 0.06 20 16 4.85 157 6437 0 0.02 7 2 4.87 158 6476 0 0.05 15 '( a 4.83 ._J.?_?__ . JJ._~lº_ 0 __9.,92__....7____.__J_._. _4,ª-Z_ 160 6556 0 0.01 2 5 4.86 161 6595 0 0.02 7 1 4.86 162 6634 0 0.05 18 12 4.86 163 6677 0 0.04 13 1 4.85 Shallow pitting. 164 6719 0 0.01 2 1 4.85 165 6761 0 0.00 1 '2 4.84 166 6803 0 0.02 7 2 4.85 Shallow pitting, 167 6843 0 0.01 2 7 4.86 168 6882 0 0.01 2 4 4.85 169 6922 0 0.02 6 6 4.86 170 6961 0 0.02 7 6 4.85 ' :=III~~ =~=ZQºi~=_:_~!2:i?5=_==~~º;Qi~=_==z=~~ ~~_='_:4~== ---¡,ß~Z===~~_~_===-_:==~:~===_~=~~===::-=:=::==~~=:====::==:=~-.---=~=::::--~=~=.r 172 7044 0 0.05 15 13 4.85, I 173 7084 0 0~02 6 5 4.86 ¡ 174 7'123 0 0.01 4 '2 4.85 175 7163 0 0.02 7 1 4.82 r 176 7203 0 001 2 3 485 . -177 7243 Ó.Ö(~·_·--6:'Õ4·""""i1'.. '2 "'"'4:'8s'" 's¡~~Ü~;"p¡tti~'g:""" . ''''b_'_~'''''''__'~ 178 7282 0 0.02 7 12 4.86 ~ 179 7322 0 0.02 6 4 4.85 m ~m [)~~ ~:~~ ~o ~3 i~t-------------------------- 184 7520 0 0.02 7 2 4.82 , 185 7559 0 0.01 3 4 4.84 Pitting. l 186 7601 0.06 0.02 7 5 4.84 I- 187 7619 0 0.03 9 3 4.87. a. . 188 7678 0 0.04 12 5 4.83 Shallow pitting, ' 189 7718 0 0.04 13 3 4.82 Line shallow corrosion. 190 7758 0 0.05 18 13 4.84 Comments , Damage Profile I (% wall) 50 100 o -~ ___ _ _n_ _'. t, ---~ ..,................,,~ n I I Penetration Body ¡'I Metal Loss Body Page 4 ( ( PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 5.5 in 17.0 ppf 13-Cr Vam Ace 0.304 in 0.304 in 4.892 in Well: Field: Company: Country: Survey Date: NS-08 NORTHSTAR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint J1. Depth PCIl. Pen. Pen. Metal Min. No. (F1.) Uµsct Body <Yo Loss I.D. (IllS.) (Ins.) % (Ins.) 191 7797 () 0.04 15 10 4.86 J92_~_d__llU-º-__J)JL0__ __9A>£______Z_ ___L______4.83________________ _n _ __________ __n_____ 193 7876 o,()() 0.02 7 :3 4.82 194 7914 () 0.04 15 6 4.RO 195 7954 () 0.02 7 4 4.85 196 7996 () 0.01 3 2 4.84 197 8035 0 0.02 7 2 4.83 198 8075 () 0.02 7 2 4.85 Shallow pitting. 199 8114 0.05 0.02 7 3 4.82 200 8155 0 0.04 1411 4.85 __....,2.QJ..... ..... ........8.19._.6.. ....... ............Q...... .. ......Q,Q,5......... 16 ..2... ..........4,ª~............linE;,..~h.ªUº\Y....çºn.Q.~j.Q.!J.,...... ..... 202 8237 0 0.02 7 2 4.82 203 8275 0 0.02 7 3 4.84 Shallow pitting. 204 8317 0 0.01 2 3 4.82 205 8359 0 0.02 8 2 4.84 206 8401 0 0.01 2 3 4.86 207 8443 0 0.02 5 4 4.81 Shallow pitting. 208 8485 0 0.01 4 2 4.84 209 8527 0.06 0.02 7 4 4.82 210 8567 0 0.07 22 13 4.82 211 8606 0 0.05 17 11 4.84 Shallow corrosion. 212 8646 0 0.02 6 :3 4.82 213 8685 0.07 0.05 15 11 4.84 214 8725 0 0.02 7 2 4.84 215 8764 0 0.01 2 2 4.81 216 8804 0 0.02 7 2 4.81 _.__2.1L___ _JHl1-4-...______o_º-__________Q. 0 1__ _..__.? 2 4. 79 __ljghtº~p_º5j~_.____. __ _______n____..____..___.__....___n 218 8883 0 0~01 3 4 4.83 219 8922 0 0.03 11 3 4.82 Shallow pitting. 220 8962 0 0.02 7 2 4.84 221 9002 0 0.02 7 3 4.85 Pitting. 222 9041 () 0.02 7 4 4.82 Pitting. on) l_;L.. ____~Q~H________.._.!)...___._j)J)J___ ___.lQ.________L_._ 4.80 224 9120 0 0.02 7 2 4.79 225 9160 0 0.02 7 2 4.83 226 9199 O.lJB 0.02 7 11 4.82 227 9239 () 0.01 5 :3 4.83 228 9279 0 0.04 14 3 4.84 Line shallow corrosion. 229 9318 0 0.02 7 :3 4.81 Pitting. ____219____._ ...._~1:i.ª___.._ .__J2.DZ___.__º,_Q3 1 0 ..1...-..__ _1JJ,2_ _ ._._________________________.__________________ 231 9397 0.05 0.02 7 3 4.83 232 9439 0.05 0.02 7 3 4.82 233 9479 0 0.02 7 2 4.81 234 9521 0 0.02 7 3 4.81 235 9563 0 0.04 13 :3 4.83 Line shallow corrosion. 235.1 9603 0 0 0 0 N/A X-OVER Comments o II - --·C .- .. I' L I .............~ f J ~ ,,,,, ............,,,..,,.... r ----------------J ~ --- -------r ~ p n Page 5 1 Uamage Profile \ (% wall) 50 1 00 I Penetration Body '", Metal Loss Body ~s. Well: Field: Company: Country: N S-08 NORTH STAR BP EXPLORATION ALASKA INC USA I Tubing: Nom.GD 4.5 ins Weight 12.6 ppf Grade & Thread 13-Cr Yam Ace Penetration and Metal Loss (% wall) _ penetration body 50 ß:'j,r¡¡,:T1'J metal loss body f:~=~Ji:--~:_:_~=:-- -==== o to 1 to 10 to 20 to 40 to over 1% 10<},0 20% 40% 85% 85% Number of joints analysed (total = 47) pene. 5 41 1 0 0 0 loss 20 27 0 0 0 0 Damage Configuration ( body) 10 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 1) 10000 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 3.958 ins May 12, 2005 MFC 24 Ext No 040936 1.69 24 J. Thompson Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 4.5 ins Damage Profile (% wall) _ penetration body o 1:;!'r:~;::;J metal loss body 50 100 l ! ~ '- J .. 10"1AJi1 \rn I¡a:-':I · ]1m ! ,... · ~ 20 'fm, f ,.. · 1 P · 30r !II , ì r II e- II 38 ~ - r -- · ~_. ....-.- -.-..--.-.....-..... -.....-- --- -.... -.......... -.-...--...-.. Bottom of Survey = 41 Analysis Overview page 2 , . ,~ ( PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 4.5 in ( 2.6 µµf t 3-Cr Vain Ace 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NS-08 NORTH 5T AR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint Jt. Depth Pen, Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) (~) (Ins.) 0 50 100 ___-'-L___.9606 ____.___1) 0 _--º____n_-º N/ t.__LOVl;;lL____________ ______ _ ____________. ______ __ _ ____ 1 9611 () 0.01 3 5 3.92 ¡j 2 9652 () 0.01 3 2 3.94 ~ 3 9694 () 0.01 2 I 3.96 I I 4 9736 0 0.02 7 4 3.93 r 5 9778 0 0.01 4 4 3.92 . fl 6 9818 0 0.00 1 1 3.93 ¡. 7 9859 0 0.03 10 1 3.93 8 9902 0 0.00 1 1 3.96 9 9943 0 0.01 2 1 3.95 10 9985 0 0.01 2 6 3.93 I~ 11 10026 0 0.0'1 2 7 3.94 ~ 12 10068 0 0.00 1 9 3.94 ~ 13 10109 () 0.01 4 t 3.95 ~ 14 10151 0 0.01 6 ~) 1.93 15 10193 0 0.01 3 4 3.91 t 16 10235 0 0.00 1 1 3.96 I 17 10277 0 0.04 13 -, 3.93 Shallow pitting. ~ __ __l~t___. __JQJ2_º______..Jt ___ __º~º~__ ____.I___ _ _.~L _____J_~l__ _ ____ I ______1~___. __.JJ!JþJ_______ ___D_.___ ___º~º1____3.____ ___ 9 3.94 - ----~-=.--===~_::_~=~~~:=:=:=.._-----=:==~:~::=:._:.-~:~~=~ 20 10402 0 0.01 3 9 3.93 21 10444 () 0.01 4 2 3.93 ! 22 '10486 0 0.02 7 5 3.93 23 10528 0 0.02 7 4 3.92 24 10570 0 0.01 4 4 3.92 25 10612 0 0.02 7 1 3.93 26 10654 0 0.01 4 1 3.94 ~ 27 10696 () 0.01 2 1 3.93 r 28 10738 0 0.02 7 2 3.93 29 107BO 0 0.01 2 2 3.93 30 10822 0 0.02 7 :3 3.93 r 31 10863 0 0.01 2 2 3.95 32 10905 0 0.01 4 5 3.94 33 10947 0 0.01 4 3 3.93 r 34 10989 0 0.01 3 3 3.94 35 11031 0 0.02 7 1 3.94 36 '11 073 0 0.01 2 2 3.95 37 11115 () 0.01 3 1 3.93 ~ 38 11157 0 0.02 7 t 3.92 38.1 111 99 0 0 0 0 N/A TRANSDUCER 38.2 11218 () 0.01 4 -( 3.95 PUP 3H..3 ___lJ22ß..___ ___JL_____.__º________º______._Q_____3.JH_.__._--KJ:'~JP..ELE.._________._________________________.______________________..__.__.__ 38.4 11230 () 0.01 2 1 3.94 PUP 38.5 11240 0 0.01 4 1 3.95 PUP 38.6 11250 0 0 0 0 N/A PACKER = 38.7 11253 0 0.02 7 0 3.94 PUP 38.8 11263 () 0.02 7 1 3.95 PUP 38.9 11272 0 0 0 0 3.81 X NIPPLE 39.1 11275 0 0.00 1 () 3.96 PUP 39.2 11283 0 0 0 0 3.73 XN NIPPLE I Penetration Body ¡¡t, Metal Loss Body Page 1 ( PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 4.5 in 12.6 ppf 13·Cr VJm Ace 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: NSOß NORTH STAR BP EXPLORATION ALASKA INC USA May 12, 2005 Joint J1. Depth Pen. Pen. Pen. 1\1 eta 1 Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) <X, (Ins.) 0 50 100 393 11289 () 0.03 10 2 3.88 PUP ~ 39.4 11297 0 0 0 0 N/A WLEG 39.5 11299 () 0 0 0 N/A HANGER 40 11313 () 0.01 4 _L.__ 3.91 1 st Joint 4.5 Liner -.------iI 41 11355 () 0.02 7 2 3.92 I Penetration Body ~J~~:.I Metal Loss Body Page 2 · \ TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" TAM Port Collar at +/-1582'MD 13 3/8", 68#/ft. L-80, BTC @ 3328'MD Min.ID = 2.44111 @ 5496' 5-1/211 WFD PATCH 5.5", 17#/ft, 13-Cr. Vam Ace TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT 4.5", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 9919'MD 4.5" X NIPPLE, @ 11228' MD' 3.813" ID 4.5" X NIPPLE, @ 11273' MD 3.813" ID 4.5" XN NIPPLE, @ 11284' MD 3.725" ID 4.5" WLEG, @ 11297' MD 3.958" ID 7", 26#/ft L-80, BTC-M @ 11461'MD 4.5" Fiber Optic Transducer 3.958" ID @ 11208' MD, 10460' TVD (Sensor ELM TVD = 10480') ~ - 7" PACKER,13 Cr @ 11249' MD, .. 10500' TVD I rE NS08 --4 I, ~ ~ t ~ ~ ~ r J II I '1 Ë jj PERFORA TION SUMlVlARY REF LOG: SWS USIT (3/18/02) ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2906 F\:!werJet, HMX; Pen: 27"; Hole: .36"; Phase: 60 deg SIZE SPF INTERV AL Opn/Sqz DA TE 2.88 6 11755-11895MD 0 03/22/02 (10998 - 11136 "ND) 2.88 6 11891 -11910 MD 0 12/06/05 (11133 - 11151 "ND) PBTD @ 11943' MD TD @ 12029'MD DA TE RBI BY COMMENTS 01/16/02 BMH NS08 PROPOSED 03/13/02 EMF UPDA TED DEPTHS 03/27/02 EMF UPDA TED PERFS 12/20/02 EMF UPDA TED KB INFO 02/08/05 MDCfTLH ADD PERFS (12/06/04) , .. RK8. ELEV = 56' ( 3F. ELEV =40.1' BASE FLANGE ELEV = 15.9' 5 1/2" SSSV @ 1992' MD, 1989' TVD w/ HRQ SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4037' TVD (4238'MD) 5.5" GLM @ 4746' MD, 4489' TVD w/ 4.62" ID 5496'-5506' 1- 5-1/2" WFD PA TCH. (01/29/05), ID = 2.441" I SAFETY NOTES: W AlVERED WELL?? , 5 1/2" x 4 1/2" XO @ 9603'MD, 8959' TVD !\. - 7" LINER TOP @ 9741'MD 4.5" LINER TOP @ 11293'MD ... ~ 4.5",12.6#, 13CrVam Ace DATE REV BY COMMENTS 03/05105 JAF/TlH PATCH SET (01/29/05) NORTHST AR UNIT WB...L: NS08 PERMIT No: ?? API No: 50-029-23068-00 SEC T N R E BP Exploration (Alaska) CONFIDENTIAL SCIIII8IIeP!IeP BP Alaska Northstar PVT Study Wells: NS-09, NS-13, NS-08 and NS-15 Surface Separator Samples ), Ù j-,U "1 J À ò / - a õ> (, ~ À ó .J.. - \) .>./ / .t J.. Ö Á - () j- y ~+<l{~ ~ }k~, F:'k A Report for: By: File#: Date: BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, AK 99519-6616 U.S.A. Oil phase - DBR Schlumberger 9419 - 20 Avenue Edmonton, Alberta T6N 1 E5 Canada (780) 463-8638 www.dbrgroup.com 20023132 May 25, 2004 SCANNED NOV 1 8 2004 .. OILPHASE . DBR \ ; . Quality Assurance Process '. . ,.",. ....-"....."".. "" """'" , '"'''' ,-"". "... Oilphase-DBR has a continuing commitment to provide the highest quality fluid property data and service to all its clients. The Company's philosophy is that all property measurements and calculations be performed to a level of accuracy and repeatability that is unsurpassed in the industry. This objective is achieved by continually improving and developing new state of the art measurement techniques and equipment. The key to maintaining this ability is a rigorous program of quality control and suitable management systems to maintain them. In particular, it is a requirement that all laboratory measurements be performed by qualified engineering technologists and be supervised by an experienced Research Engineer/Scientist at a Ph.D. or M.Sc. level. Open lines of communication are maintained so that qualified staff at all levels can provide input. The results of all the work are interpreted and reported by a Researcher supervising the project. Finally, following the completion of each report, an independent review is made by senior technical staff to confirm the technical consistency and readability of the report. All property measurements and calculation procedures for a particular study are maintained in the company Archives for a period of 3 years. These notes are available for review by clients if requested. Atl measurements are made following the most appropriate procedures for obtaining accurate and repeatable data. Atl measurement instruments are calibrated periodically as required, to maintain accuracy. Rigorous quality assurance programs are in place to insure and maintain the accuracy of our analytic procedures. Details of these calibrations are also available at the clients' request. Effective December 8, 1999, after meeting the International Organization for Standardization (ISO) quality assurance standards, Quality Certification Bureau Inc. has granted the Oilphase-DBR registration of our Quality Management System to the requirements of ISO 9001 :1994. To achieve ISO certification, Oilphase-DBR underwent an extensive and lengthy training and review process of operational procedures that culminated with the required third-party quality audits performed by Quality Certification Bureau Inc (QCB). Oilphase-DBR's certification was granted by QCB upon the successful completion of the audits. The ISO 9001 certification further strengthens Oilphase-DBR's position of industry leadership. The company has a stated philosophy that shortcuts in accuracy or technically appropriate procedures are not acceptable under any circumstances. The staff continuously strives to develop and maintain superior experimental procedures and quality control. Reference information indicated below provides traceability to the raw data related to this project. To answer any -questions, clients are requested to contact the Project Manager indicated below. Oilphase-DBR File No: 20023132 Oilphase-DBR Notebooks: 6/2001 & Trentl/2001 ( ( ( [ ( 1. Laboratory Procedures for This study 2. Data Correlation and Reporting ~A~~ '/,.~ -L- eß Craig Borman F . Lab Supervisor ~ \.~ Jinglin Gao, M.Sc. (Ch. E. Project Manager 3. Report Reviewing (l..-+ Moin Muhammad, M.Eng. Manager - Research And Fluid Analysis Services , , ..< ~"...__...,".._._-_._- ---"-'--''''._'-''''"'--~^' - Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 0 Oilphase-DBR ,',.".. .,...., - .. ..".. ..."........ ,.., . . ". . ,. . - .. ..... . . ..----.. -. . .... .-.. . ... ---. -.. ..... "-- .. . ... .... ... .._n, ....--.... .,,--.-........,,---..- "." .... . ....... . -- -. ,.- ..--. . .. -.. -- ..""- . ,__n.._.. .,,- ,....- . ........ .... . "'n..""-""-"., EXECUTIVE SUMMARY ..--..--.-- -...-. ...-.""..... . .... ....-- -.."....... -.. ....... -,_...." ,.... ...._.. --. ....._..--n_....._.._.m._..._.--. -----....-----------...---.----.'"'"". ..-..--- ..- Field: Wells: Sample Depth: Reservoir: Location: Northstar NS..09, NS-13, NS-08 & NS-15 Surface Separator Samples Ivishak Alaska Oilphase-DBR completed a series of PVT studies for BP Exploration (Alaska) Inc. on recombined reservoir fluids collected from NS-13, NS-09, NS-08 and NS-15 wells in its Northstar field. The major results are summarized below: ( Pressure: Temperature: Estimated - 5175 psia 254.5 of ( [ f ( ( { ( ( r r ( ( GOR STO API By single stage ambient flash: 2304 SCF/STB By DL test @ Tres: 2515 SCF/STB By 5-stage separator test: 2049 SCF /STB Single-phase viscosity at Psat & Tres: 0.131 cp 39.6 39.2 41.7 FVF 2.360 2.537 2.218 ( ( ( ( ( ( ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 1 Oilphase-DBR .......,..",.. ...... ,..."'.......,.......,...,......-......--.. "'--'--_U'--'"'''.m''' .-'" .. . ... ., . "'..".._,..,,,--,, .n".___.-..".""",...,,, . ......--"......, ..-...,.."---..,.."",,....,,. .n'..."".."... . .un.. ...,. ._..n",.,...".. ".......- TABLE OF CONTENTS , QUALITY ASSU RANCE PROCESS...... ...................................... ........ ......... ...... ............ ...........0 EXECUTIVE SUMMARY............. ........... ......................... ......... .......... ........................................1 1.0 INTRODUCTION..... ..................... ........................................................................................ 6 2.0 SCOPE OF WORK................................................... .......................... ..... ............................. 7 2.1 Sample Preparation and Analysis ............................................................................. 7 2.2 Sample Recombination.............................................................................................. 7 2.3 Phase Behavior Analysis.......................................................................................... 8 2.4 Dead Oil Wax Test & Formation Water Analysis........................................................8 2.5 I nterfacial Tension Measurement............................................................................... 8 3.0 FLUID PREPARATION & COMPOSITIONAL ANALYSIS .................................................8 3.1 Compositional Analysis............................................................................................. 8 3.2 Reservoir Fluid Recombination and Analysis............................................................ 9 3.3 Dead Oil Wax Test & Formation Water Analysis ......................................................9 3.4 Interfacial Tension Measurement... ....................................... .... ....... ......................10 4.0 PHASE BEHAVIOR MEASUREMENT ..............................................................................11 4.1 NS-09, NS-08 and NS-15 Reservoir Fluid Partial PVT Measurement ....................11 4.2 NS09/NS-13 Reservoir Fluid Full PVT Study............................... ... ............ ........... .12 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 2 Oilphase-DBR TABLES Table 3.1: C30+ Composition of NS-13 Separator Oil TC-1137 .................................................16 Table 3.2: C30+ Composition of NS-13 Separator Oil TC-1119 .................................................17 Table 3.3: C30+ Composition of NS-09 Separator Oil TC-1136 .................................................18 Table 3.4: C30+ Composition of NS-09 Separator Oil TC-1120 ................................................. 19 Table 3.5: C30+ Composition of NS-08 Separator Oil TC-1126 .................................................21 Table 3.6: C30+ Composition of NS-08 Separator Oil TC-1142 .................................................22 Table 3.7: C30+ Composition of NS-15 Separator Oil TC-1124 .................................................23 Table 3.8: C30+ Composition of NS-15 Separator Oil TC-1141 .................................................24 Table 3.9: C15+ Composition of NS-09 & NS-13 Separator Gases ...........................................26 Table 3.10: C15+ Composition of NS-08 & NS-15 Separator Gases .........................................27 Table 3.11: C30+ Composition of Recombined 5100psia Psat NS-09 Oil .................................28 Table 3.12: C30+ Composition of Recombined 4850 psia Psat Oil ...........................................29 Table 3.13: C30+ Composition of Recombined NS~08 Oil .........................................................30 Table 3.14: C30+ Composition of Recombined NS-15 Oil .........................................................31 Table 3.15: C30+ Composition of Recombined 5100 psia Psat NS-13 Oil ................................32 Table 4.1: CCE of Recombined 5100 psia Psat NS-09 Oil @ 254.5°F .....................................35 Table 4.2: CCE of Recombined NS-08 Oil @ 254.5°F .............................................................37 Table 4.3: CCE of Recombined NS-15 Oil @ 254.5C>F .............................................................39 Table 4.4: Separator Test of Recombined 5100 psia Psat NS-09 Oil ......................................41 Table 4.5: Compositions of Produced Gas by Separator Test on 5100 psia Psat NS-09 Oil ...42 Table 4.6: CCE of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F.......................44 Table 4.7: DL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Liquid Phase Properties. . . . . . . ... . . .. ... . . . . . .. . . . .. . . . .. .. . . . . .. . . .. . . . . . . . . . .. . . . . . .. . . .. . . .. . . .. . . . . . . . .. . . . . . . . . . . . . . . . . . .. . . . .46 Table 4.8: DL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Vapor Phase Properties.. ....... ........ ..... .......... ................ .. ........... .. .................. . . ... . . ........ ... .........50 Table 4.9: Viscosity of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ...............52 Table 4.10: Compositions of Produced Vapor by DL Test on4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ................................................................. ....................... .52 Table 4.11: Separator Test of Recombined 4850 psia Psat NS-09 + NS-13 Oil ......................54 Table 4.12: Compositions of Produced Vapor by Separator Test on 4850 psia Psat NS-09 + NS-13 Oil................ ..................................................... ....................... .55 Table 4.13: Separator Corrected GOR & FVF .........................................................................57 Table 4.14: Summary of PVT Test on 4850 psia Psat NS-09 + NS-13 Oil ..............................59 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 3 Oilphase-DBR FIGURES Figure 3.1: C30+ Composition Comparison - NS-09 & NS-13 Samples ...................................20 Figure 3.2: C30+ Composition Comparison - NS-08 & NS-15 Samples ...................................25 Figure 3.3: LP Separator Water Composition.................... .................... .................................. .32 Figure 3.4: HP Separator Water Composition........................ ................ .................................. 33 Figure 4.1: CCE of Recombined 5100 psia Psat NS-09 Oil @ 254.5°F....................................36 Figure 4.2: CCE of Recombined NS-08 Oil @ 254.5°F ............................................................38 Figure 4.3: CCE of Recombined NS-15 Oil @ 254.5°F ................ ........... .......... .......... .............40 Figure 4.4: CCE of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F .....................45 Figure 4.5: DL of Recombined 4850 psi a Psat NS-09 + NS-13 Oil @ 254.5°F - GOR as Functions of Pressure ................................................... .....................................47 Figure 4.6: DL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Liquid Phase Properties as Functions of Pressure................................................................ ..48 Figure 4.7: DL of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F - Vapor Phase Properties as Functions of Pressure................................... ......................... .......49 Figure 4.8: Viscosity of Recombined 4850 psia Psat NS-09 + NS-13 Oil @ 254.5°F ..............51 Figure 4.9: Separator Corrected GOR & FVF ..........................................................................58 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 4 Oilphase-DBR APPENDICES Appendix A: Summary of Oilphase-DBR Capabilities........................................................ A1 A.1 Fluid Preparation of Compositional Analysis..................................................................... A 1 A.2 Techniques & Apparatus................................................................................................... A 1 A.2.1 PVT Cell....... ..... ....,...... ............... .......... ............. ................... ....... ........ ...... ....... .... .... A 1 A.2.2 ODBR Solids Detection System................................................................................ A2 A.2.3 ODBR High Pressure Microscope (HPM) ... .................. ....... ........ ........... ........... ...... A2 A.2.4 ODBR Particle Size Analysis (PSA) ......................................................................... A3 A.2.5 Cambridge Electromagnetic Viscometer (EMV)..... ............. .......,.. ....... ...... ............... A4 A.2.6 Capillary Viscometer (CV)......................................................................................... A5 A.3 Procedures........................................................................................................................ A6 A.3.1 Constant Composition Expansion (CCE) ........................ ......................................... A6 A.3.2 Differential Liberation (DL) ....................................................................................... A 7 A.3.3 Constant Volume Depletion (CVD)...................................................................,....... A7 A.3.4 Multi-Stage Separator.............................................................................................. A7 A.3.5 Viscosity Measurement Using EMV .. ........................ ............................................... A 7 A.3.6 Discrete Isothermal De-Pressurization.................. ................................................... A8 A.3.7 Isobaric & Isothermal Titration.................................................................................. A9 A.3.8 Isobaric Temperature Sweep (Live Oil Cloud Point) .............................................. A12 A.4 Live Oil Bulk Filtration..................................................................................................... A 13 A.5 Dead Oil Pour Point....................................................................................................... A 13 A.6 Live Oil Pour Point .... ... ................................. ........... ..... ............ .......... .................... ....... A 14 A.7 Model Pipeline Test for Gel Strength............................................................................. A 14 A.8 Wax Appearance Temperature by Cross Polar Microscopy.......................................... A16 A.9 Core Flooding Apparatus .................. ........ .... .,... ..... ..,..... ............ .....,......... .... ...... ... ...... A 17 A.10 Asphaltene Content by Modified Syncrude Method..................................................... A 18 A.11 SARA Analysis............................................................................................................. A 18 Appendix B: Determination of Oil/Brine Inteñacial Tension ............................................. 81 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 5 Oilphase-DBR ~......-..... - "..... '''-''-'-'''''--'~'-''--'''''', .... ."".. ....... ""..." -....,....""...... . . ....".... ...--.....,.--.""..",..."..."...-....-...,.....-......"""...............-"-.......",..,,............-........-----.--,.------'.""'"'' ",,-,-""--~","- BP ALASKA NORTHSTAR PVT STUDY Field: Wells: Sample Depth: Reservoir: location: Northstar NS-09, NS-13, NS-08 & NS-15 Surface Separator Samples Ivishak Alaska -.w¡{.).)'(~ BP Exploration (Alaska) Inc. was interested in conducting a series of PVT studies on recombined reservoir fluids collected in its Northstar field located in Alaska. Oilphase-DBR, Edmonton, Canada was commissioned to perform the experiment. A scope of work is summarized in Section 2. Oilphase-DBR received the first batch of separator oil and gas samples in February 2002, which consisted of samples from NS-09 and NS-13 wells. In May, 2002, the second batch of samples consisting of separator oil and gas from wells NS-08 and NS-15 arrived. These separator samples were used to reconstitute a series of reservoir fluid. A complete inventory of samples received at Oilphase-DBR, Edmonton is summarized below in a tabular form: Summary of Separator Samples Sample Cylinder Well Fluid Description Sample Separator Receiving Number Designation Volume Conditions Date psigrF 1 st batch Feb., 2002 TC 1138 NS-09 Separator Oil 800cc 725/125 Feb., 2002 TC 1120 NS-09 Separator Oil 800cc 725/125 Feb., 2002 TC 1136 NS-09 Separator Oil 800cc 725/125 Feb., 2002 MM33085 NS-09 Separator Gas 20liter 725/125 Feb., 2002 MM38865 NS-09 Separator Gas 201iter 725/125 Feb., 2002 MM33082 NS-09 Separator Gas 20liter 725/125 Feb., 2002 TC 1119 NS-13 Separator Oii 800cc 740/128 Feb., 2002 TC 1137 NS-13 Separator Oil 800cc 740/128 Feb., 2002 MM38810 NS-13 Separator Gas 20liter 740/128 Feb., 2002 MM33040 NS-13 Separator Gas 20liter 740/128 April,2002 LP separator water 1 liter April, 2002 HP separator water 1 liter 2nd batch May, 2002 TC 1126 NS-08 Separator Oil 800cc 711/108 May, 2002 TC 1142 NS-08 Separator Oil 800cc 710/105 Oi/phase-DBR FILE #: 20023132 Oilphase-DBR BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 6 May, 2002 0342 NS-08 Separator Gas 20 liters 711/108 May, 2002 0327 NS-08 Separator Gas 20 liters 710/105 May, 2002 TC 1141 NS-15 Separator Oil 800cc 700.7/92 May, 2002 TC 1124 NS-15 Separator Oil 800cc 700.4/94 May, 2002 0329 NS-15 Separator Gas 800cc 700.7/92 May, 2002 0343 NS-15 Separator Gas 800cc 700.4/94 ~'1'l.)::~¡~ 2~1J ':"SãinPJ"PreparatloRi$>'Af!alysis a) Sample conditioning and restoration by heating, pressurizing and mixing. b) Separator gas analysis to C15+. c) Separator oil analysis to C30+ includes GOR and density. d) Dead oil molecular weight by freezing point depression. 2.2:\" ..":'.:Såm"";R~ØJn~in.t'On a) Reservoir fluid #1 - NS-09 reservoir fluid with saturation pressure of 5100 psia at Tres: Recombine -2 liters of reservoir fluid # 1 to a specified saturation pressure of 5100 psia at Tres (254.5°F) using NS-09 separator oil and gas samples. b) Reservoir fluid #2 - NS-09 and NS-13 mixture with saturation pressure of 4850 psi a at Tres: Add NS-13 separator oil into about 1 liter of the recombined reservoir fluid #1 (NS- 09 reservoir fluid) to have recombined reservoir fluid #3 with a saturation pressure of 4850 psia at Tres of 254.5 of. c) Reservoir fluid #3 - NS-08 reservoir fluid with GOR of 1602scf/sep. bbl: Recombine -1 liter of reservoir fluid # 6 to a separator GOR of 1602 scf/sep. bbl using NS-08 separator oil TC 1142 and gas 0327. d) Reservoir fluid #4 - NS-15 reservoir fluid with GOR of 1441 scf/sep. bbl: Recombine -1 liter of reservoir fluid # 7 to a separator GOR of 1441 scf/sep. bbl using NS-15 separator oil TC 1124 and gas 0343. e) Reservoir fluid #5 - NS-13 reservoir fluid with saturation pressure of 5100 psia at Tres: Recombine -2 liters of reservoir fluid #2 to a specified saturation pressure of 5100 psia at Tres (254.5°F ) using NS-13 separator oil and gas samples. f) Compositional analysis of the above recombined reservoir fluids #1 to #5 to C30+ 2.3PhaseSehávior.Analys;is On recombined fluid #1, which is the NS-9 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5 OF): a) Perform a Constant Composition Expansion (CCE) test at Tres. b) Perform a 5-stage separator test. c) Measure single-phase viscosity at Tres at two different pressures. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 7 Oilphase-DBR On recombined fluid #2, which is a NS-9 and NS-13 mixture that has a saturation pressure of 4850 psia at Tres (254.5 OF): d) Perform a Constant Composition Expansion (CCE) test at Tres. e) Perform a 6-step Differential Liberation (DL) test at Tres, including oil viscosity at each step. f) Perform a 5-stage separator test. g) Measure single-phase viscosity at Tres at two different pressures. On recombined fluid #3 and #4, which are the NS-08 and NS-15 reservoir fluids: h) Perform Constant Composition Expansion (CCE) Tests at Tres. 2i4¡'.,:.;::..',b8âd.,iOil".WšX:,,.,st'åå1d:Foïiñâtït)r1,,\Nâter..Ái1âtYsfš a) Measure Wax Appearance Temperature rNAT) of NS-09, NS-13, NS-08 and NS-15 dead oils using Cross Polar Microscopy (CPM). b) Wax content of dead oils using UOP 46-64 method. c) Compositional analysis of formation water samples. d) Prepare -200cc of dead oil from NS-13 separator samples and send to US Geological Survey in Denver, USA. 2~$, ','"lntMlåc.":T.nslOl)¡"urement a) Prepare and send 25cc of NS-13 dead oil and 50cc of recombined fluid #5 to the Petroleum Recovery Institute (PRI) in Calgary for interfacial tension measurement. b) Measure the interfacial tension (1FT) of the NS-13 dead oil with the formation water collected from the high-pressure separator at 200psia and 122°F. c) Measure the interfacial tension (1FT) of the recombined fluid #5 (NS-13 reservoir fluid with a saturation pressure of 5100psia at Tres) with the formation water collected from the high-pressure separator, at 5175 psia and Tres (254.5°F). After receiving the separator oil and gas samples in the laboratory, the first batch of samples was conditioned at 176°F and the second batch was conditioned at 122°F. The oil samples were allowed to gently and continuously rock for over 48 hours while maintaining the pressure at -1000 psi. The gas samples were hand-rocked occasionally. During conditioning, oil samples TC1138 and TC1126 were lost due to an unexpected release of the safety valve on the sample cylinders. 3.1CørtíPÔsiltional.i.ÄI1~'ysi$ The procedure is described in the fluid preparation and analysis section in Appendix A. The compositional results for the separator fluids are presented in Tables 3.1 to 3.8 and are compared in Figures 3.1 and 3.2 respectively for the first and second batches of samples. Oilphase-DBR FILE #: 20023132 Oilphase-DBR BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 8 f I.. ( (. ( ( ( ( ( ( ( ( ( ( ( ( ( (, ( ( ( ( ( ( f '. ( ( , ( ( These Tables include the measured and/or calculated molecular weight, and the compositions of the vapor and the liquid generated from the flash for each sample, and also contain the calculated properties of the C7+, C12+ and C30+ fractions including mole 0/0, weight %, molecular weight, specific gravity and boiling point. Separator gas samples were analyzed to C15+. The results are presented in Tables 3.9 and 3.10 respectively for the first and second batches of samples. 3~2 .litSeNolr FUJ.d~,~èc()rnt;)i¡)~ti()nand'An~lysÎ~ Reservoir Fluid #1: NS-09 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5°F). Separator gas from well NS-09 was recombined with the separator oil from the same well in such a way that the recombined fluid had a saturation pressure of 5100 psia at reservoir temperature of 254.5°F. This was achieved by adding a certain amount of gas and oil into a recombination cylinder. This cylinder was equipped with a mixing ring and placed inside a forced air circulation, thermostated oven. After addition of the gas and oil, a sub-sample was charged into a PVT cell where a pressure-volume relation test was performed to determine the saturation pressure. If the saturation pressure was higher than the specified pressure, more liquid was added. If the saturation pressure was lower than the specified pressure, more gas was added. This process was repeated until the measured saturation pressure was within an acceptable range of the specified value. The analyzed C30+ compositional data of this recombined fluid are presented in Table 3.11. Reservoir Fluid #2: This fluid was obtained by adding NS-13 separator oil into the recombined reservoir fluid #1 (NS-09 reservoir fluid). The resulting mixture had a saturation pressure of 4850 psia at Tres (254.5°F). The C30+ compositional data of this recombined fluid are presented in Table 3.12. Reservoir Fluid #3: NS-08 reservoir fluid. Separator oil and gas samples from well NS-08 were recombined to a separator GOR of 1602 scf/sep bbl. This corresponds to the producing GOR at the time of sampling (gas rate at standard conditions: 7.848 mmscfd; oil rate at separator c~nditions: 4898 bbl/d). The C30+ compositional data of this recombined fluid are presented in Table 3.13. Reservoir Fluid #4: NS-15 reservoir fluid. Separator oil and gas samples from well NS-15 were recombined to a separator GOR of 1441 scf/sep bbl. This corresponds to the producing GOR at the time of sampling (gas rate at standard conditions: 8.179 mmscfd; oil rate at separator conditions: 5674 bbl/d). The C30+ compositional data of this recombined fluid are presented in Table 3.14. Reservoir Fluid #5: NS-13 reservoir fluid with saturation pressure of 5100 psia at Tres (254.5°F). The NS-13 separator oil and gas samples were recombined into reservoir fluid that had a saturation pressure of 5100 psia at Tres (254.5°F). The C30+ compositional data of this recombined fluid are presented in Table 3.15. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 9 Oilphase-DBR 3.3 DeadOirWax.Tesfal1d'FormatlonWaterAnalysls Wax Appearance Temperature (WAT): Cross Polar Microscopy (CPM) was used to measure the wax appearance temperature 0N A T) of the dead oil resulting from flashing the separator oil at 176 of to ambient conditions. The sample is taken hot at 140°F and then cooled at a rate of 2°F/min to 32°F while the CPM photomicrograph is being recorded. The results are reported below: NS-09 dead oil W A T NS-13 dead oil WAT NS-08 dead oil WAT NS-15 dead oil WAT 89.0 of 92.1 of 96.0 of 92.7 of Wax Content: Wax content of NS-09 and NS-13 dead oils was analyzed by Maxxam Analytical Inc., Edmonton, Alberta using UOP-46-64 standard method. Briefly, this method involves dissolving about 2 grams of sample in petroleum naphtha. The solution is clarified using fuller's earth. The petroleum naphtha is evaporated and the clarified oil redissolved in an acetone-petroleum naphtha mixture. This solution is then chilled to 0 of and filtered through a cold filter funnel, the wax being collected on an asbestos mat in the funnel. The wax is then washed from the mat into a weighing flask, using hot petroleum naphtha. The naphtha is evaporated and the wax weighed. Probably because of sample mishandling (temperature was lower than the wax appearance temperature while sampling or transfer), the analyzed results were lower than expected: NS-09 dead oil wax content NS-13 dead oil wax content 0.26 wt% 0.16 wt% After discussions with Mr. Terry Wilcox of BP Exploration (Alaska) Inc., another sample was taken by flashing NS-13 recombined reservoir fluid (recombined fluid #2) at 176 of and sent to Maxxam. The sample was heated to 104 of for 10 minutes prior to sub-sampling for wax content analysis. The wax content of this sample was analyzed to be 3.36 wt%. I NS-13 dead oil wax content, 2nd analysis 3.36 wt% Wax content of NS-08 and NS-15 dead oils was analyzed by Norwest Labs, Edmonton, Alberta using the same method. The samples were heated to 104 OF for 10 minutes prior to sub-sampling for wax content analysis. The results are reported in the table below. NS-08 dead oil wax content NS-15 dead oil wax content 3.9 wt% 3.7 wt% Formation Water Analysis: Compositional analysis of formation waters collected at low- pressure separator (LP separator) and high-pressure separator (HP separator) was also performed by Maxxam Analytical Inc. The results are presented in Figures 3.3 and 3.4. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 10 Oilphase-DBR r ( r ( ( ( ( c ( ( ( ( ( ( ( ( ( { ( f " ( ( ( l l ( ( 3.4 . Irlt'rf..çl@I.'TØ"~lc),,(lffl));Meå$...r.em.nt After review the compositional data of the water samples, Mr. Terry Wilcox of BP Exploration (Alaska) Inc. decided to use the high-pressure separator (HP separator) water to conduct the interfacial tension (1FT) measurement. The measurement was performed by the Petroleum Recovery Institute of the Alberta Research Council in Calgary, Alberta using a pendant drop method. Both dead and live oils with formation water systems were measured. The dead oil was flashed from the NS-13 separator fluid, and the live oil was the NS-13 reservoir fluid with a saturation pressure of 5100 psia at Tres (recombined fluid #5). The 1FT of dead oil and formation water was measured at 122°F and 200psig in order to keep the system above the wax appearance temperature; while the live oil and formation water system was measured at Tres (254.5°F) and 5175 pisa. The results are presented below in the tabular form. A detailed report on 1FT measurement may be found in Appendix B. 1FT of NS-13 STO & formation water @ 214 psia &122°F 16.0 dyne/cm 1FT of NS-13 live oil & formation water @ 5175 psia & 254.5°F 25.9 dyne/cm '~'"'I'I:~:h'd::l~E The phase behavior measurements were performed using the techniques & procedures described in the fluid phase behavior measurement section in Appendix A. 4~1.. :'.'.'N$+O~~",,$4:lÎ.åria:'''$~1~''Bè;.~i¥gJr:::È.9.~i':;l?jl1iål"'Ø~;j\M~~"g~'ffl,n. CCE Test: A Constant Composition Expansion (CCE) test was performed on the recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres), #3 (NS-08 samples recombined to the producing GOR of 1602 scf/sep bbl), and #4 (NS-15 recombined to the producing GOR of 1441 scf/ sep bbl). The results are presented in Tables 4.1 to 4.3 and are plotted in Figures 4.1 to 4.3. The bubble point pressures were determined from the volumetric data and were also visually confirmed using a high magnification cathetometer. Psat of NS-09 Reservoir Fluid @ 254.5°F Psat of NS-08 Reservoir Fluid @ 254.5°F Psat of NS-15 Reservoir Fluid @ 254.5°F 5095 :t 15 psia 4885 :t 15 psia 4640 :t 15 psia These tables also contain the measured/calculated liquid densities and compressibility values in the single-phase region. The pressure relative-volume data in the single-phase region was curve fitted using the "TableCurve" software package (Windows based; developed by Jandel Scientific). The selected functions and the V-function values are provided in the table; the compressibility values were calculated using the derivative of the selected function. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 11 Oilphase-DBR Live Oil Viscosity: The viscosity of recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres) was measured using an electromagnetic viscometer (Cambridge) at reservoir temperature. The results are reported in the table below. . Live fluid viscosity @ 5500 psia and 254.5°F Live fluid viscosity @ 5200 psia and 254.5°F 0.106 cp 0.097 cp Separator Test: A 5-stage separator test was performed on recombined reservoir fluid #1 (NS-09 samples recombined to a saturation pressure of 5100 psia at Tres). The results are presented in Tables 4.4 and 4.5. Table 4.4 provides the equilibrium vapor and liquid phase densities, the individual GOR and formation volume factor values for each stage. Additionally, this table contains a summary of the cumulative GOR and residual oil properties for the complete separator test. Presented in Table 4.5 are the compositional data of produced vapor at each stage and the residual oil. The separator conditions are provided below in a tabular form. Pressure - psia Temperature - of Stage 1 750 160 Stage 2 Stage 3 Stage 4 Stage 5 325 70 20 15 157 157 157 60 4~2.': . ."S~9!N~~43,Jlelj~Øirfltll.d.;,Full;f'''J'~~1I~Y A full PVT study was performed on the recombined reservoir fluid #2, which was NS-09 and NS-13 mixture with a saturation pressure of 4850psia at Tres. CCE: The CCE test results are presented in Table 4.6 and plotted in Figure 4.4. The bubble point pressure was determined from the volumetric data and was also visually confirmed using a high magnification cathetometer. I Psat of NS-09+NS-13 Reservoir Fluid @ 254.5°F I 4855:t 15 psia I Differential Liberation (DL) Test: A 6-step Differential Liberation (DL) test was conducted at reservoir temperature (254.5°F) from the bubble point pressure to 1500psia. After completion of the last step, the equilibrium liquid phase at 1500 psia was flashed to ambient pressure at room temperature. As such, a total of 7 steps of the DL test were performed with the last step being conducted at room temperature. The data from differential liberation test are supplied in Tables 4.7 and 4.8. Table 4.7 provides the cumulative liberated and solution GOR, calculated liquid phase density, formation volume factor (FVF), and liquid viscosity values at each pressure step. The GOR data is also presented in Figure 4.5. The GOR was calculated by taking the total gas phase mass generated at each pressure step and converting it to a standard condition gas volume using the ideal gas law. The liquid density, FVF, and viscosity data are also presented in Figure 4.6. The liquid density at the bubble point pressure was previously determined from the CCE test and was used to initiate the calculations. The liquid density at each pressure step was calculated by mass Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 12 Oilphase-DBR balance. The viscosity of liquid at each step was measured using the Cambridge in-line viscometer. These data along with the single-phase viscosity of the original reservoir fluid are also presented in Table 4.9 and Figure 4.8. Presented in Table 4.8 are the measured equilibrium vapor phase properties at each step. As expected the vapor density decreases with decreasing pressure. Figure 4.7 shows the vapor density, gravity and deviation factor (compressibility) dependence with pressure. The compositional data of produced vapor at each step and the residual oil are presented in Table 4.10. Separator Test: A 5-stage separator test data are summarized in Tables 4.11 and 4.12. Table 4.11 provides the equilibrium vapor and liquid phase densities, the individual GOR and formation volume factor values for each stage. Additionally, this table contains a summary of the cumulative GOR and residual oil properties for the complete separator test. Presented in Table 4.12 are the compositional data of produced vapor at each stage and the residual oil. The separator conditions are provided below in a tabular form. Pressure - psia Temperature - of Stage 1 750 160 Stage 2 Stage 3 Stage 4 Stage 5 325 70 20 15 157 157 157 60 ( ( r ( Reservoir Fluid Properties From Differential Liberation Test & Separator Data: As stated in the Ihe Properties of Petroleum FluidsD (McCain, 1990), the underlying assumption in generating reservoir fluid properties from a PVT study is that at pressures below the bubble point, the process in the reservoir can be simulated by differential liberation, while the process from the bottom of the well to the stock tank can be simulated by the separator test. Based on this assumption, fluid properties at pressures below saturation can be calculated by combining the data from the differential liberation and a separator test. ( ( The measured and the adjusted solution gas GOR and formation volume factor data are shown in Tables 4.13. In each case, the fluid properties at a particular pressure step were calculated by drawing on the differential liberation flash at reservoir temperature followed by the change in fluid properties as that reservoir oil is produced through the separator train to the stock tank. However, at pressures above the bubble point, solution GOR is constant, while the FVF is reduced due to oil compressibility. ( ( r Shown in Figure 4.9 are the separator corrected GOR and FVF data as the liberated reservoir oil is produced at the surface. ( ( [ PVT Study Summary and Discussion: Table 4.14 contains summary information for the experimental study comparing GORs, formation volume factor and residual liquid properties from each of the three flashing procedures in the study. These include: . the single stage flash of the reservoir fluid in the GOR apparatus at room temperature. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 13 Oilphase-DBR . the differential liberation of the reservoir fluid at reservoir temperature. . the separator tests. Usually, an increased number of flashes at a fixed temperature down to atmospheric pressure results in a decreased total volume of evolved gas. That is, if an oil is flashed down over multiple stages, it is expected that the overall GOR and FVF should be lower than if the same oil was flashed in a single stage process at the same temperature. This behavior is important to consider when comparing the three different flashes in this study; however, it is equally important to recognize that the single stage GOR flash, differential liberation and separator test were completed at different temperatures which also has an effect on the resulting properties. As can be seen in Table 4.14, the DL flash has the highest GOR due to the relatively high temperature used for this test. Similarly, the FVF from the DL is also the highest and the corresponding residual liquid is the heaviest. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 14 Oilphase-DBR TABLES & FIGURES Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 15 Oilphase-DBR Table 3.1 BP Alaska Northstar Separator Fluid Well: NS-13; Cylinder TC1137 C30+ Composition Gas Component MW Mole % ,.c()~- ';44~{)1 "'.. '}»6;!4;~ ' H2S 34.08 0.00 "~ht~:...", . .~,'j: .~' '" ..:;2à¡Q~e!2~3J\~.:'<~~S,,:;;:()'~;}',.!{, C1 16.04 44.02 <:2«(; ~ : ""0 ,." ,'. ':';, ..;~;Q?'fh~'~+J,!;~(;::i~"$;,~:]d{,.' C3 44.10 17.00 1-C4 58.12 3.42 . N-C4 58.12 7.33 f.C5.72,15 /1.75 N-C5 72.15 1.88 C6 86.20 f04 MCYC-C5 84.16 0.16 8ENZENE 78. n '0.06 CYCL-C6 84.16 0.16 ci 100.200.28 MCYCL-C6 98.19 0.12 rÕ1:Qê~~' ~~ ':<92~~;~+'" '-', :?OJ)~'" CB 114.23 0.09 :~Lij'~~ijiæ:;'/,;.. ,~. ,:~~;ffPfi:;1f,:;-.(i': ::f">,;<:i1():~'jI;;; M&P-XYLENE 106.17 0.01 ~m~.~::!i¡~':':':j:"':', . .., 4~;1T':;>;::';;~¡;:~.j;'!fÔ:Qöié;A,):: C9 128.30 0.03 -(;10' . .. ,1341:.00 . ',' :tfõf >\ C11 147.00 0.00 C12161.00 . 0.00 C13 175.00 0.00 C14 190.00 0.00 CiS 206.00 0.00 ë~,6'" , . ;" ", ,', ;:2~:þQ~. ,', -: ;0.. ': :::Q:Otf¡':,',::' Ci7 237.00 0.00 -ç~$::i ".". .-,,',' .}!'i~~§1\QØ:; ._.""::"<,1~PlÔ.Ô(:'+";:'Z::. Ci9 263.00 0.00 P20'.' 21~:¡;OQ , 0;00:,,' C2i 291.00 0.00 .<:22'- ~"3bs;QÒ':, '.,: "..,' p.òtr~::,,',: C23 318.00 0.00 .ç24 ," . . . 331:,;~", ,.,', , . . ':q.ØQC': , C25 345.00 0.00 ~26 .' . 3~;oQ ,o:QtF C27 374.00 0.00 ~ . 3tt8.oQ.;" ß.OO , C29 402.00 0.00 CjO+..':' .. . .:sàÖ:òO .O.QQ, ",~s:ü~MVY(g~~O '.' ::..::>;' . '>" ." CaIC~late~ M~, (g/mol) 33.0 S'ngí~$täg.,F'lashGO~@STD. ..'5Èt2 ~I~~vi~, ,C,' 41.8 Average Gas'GnMty . . 1339 -cpr1þlmi~.atioil(wt%)*, DðadOilJ3asis Contamination Corrected GOR COntárrtinatiòtiCorreCt8d' API' Liquid Overall Wt% Wt% Mole % '';:,JI{)() ., " -"()J~1;£,'i,:' (;;;;~j';;-;:Z;2(). . 0.00 0.00 0.00 .'; "j' Ek/;iöi(i.íf< .': ;'?~;': ';qj)2)~8.~:~y;~;~t. ';{,'oiid¡;;~è? ~ 0.00 1.94 14.39 ".~':' ': :";;&:':;{J:~'o!!f,:i;{~;.; :~:~¡c;-6f'\1;¿2~.\2Þ:?~èëf;i)~;!~~.S;;~:jf:, '. 0.45 2.46 6.65 0.33 '.0.85 1.74' 1.29 2.34 4.79 'LOS' 1.302_;15- 1.60 1.82 3.01 3.34 3.28 -4.53 0.86 0.82 1.16 0220.21 0.32" 1.18 1.11 1.61 . 3.87 ' 3.6Ò 4~8 2.59 2.39 2.90 :",afar;: ,. ".~:o.:t4 '.: ò:ä§.; ,.. 5.22 4.78 4.98 : ".' .'. .' '/;;(i:~f';'~ /,ç.';i":'~:)¿?Ô;2~i:!l-þ.' "{:;:};:;"Ò:~1+;"¡~;i!:"~': 0.80 0.73 0.82 .' ..'.:. J,~ö~i<:;":'i:z:i(:'~'¥:tl~$~:'. ;1' ':,: ;,},;:>lo.CS;!;;/" ';0~ . 4.66 4.25 3.94 ':,5~.'. '.;,.':,", ,'S:;29' 4~71" 4.78 4.35 3.53 4.333:94 2.91 4.88 4.44 3.03 4.42 4.02 2.52 4.27 3.88 2.25 '3~71 ". 3.47 , ~~: \~;:a.Q,~J:; ~ '. . 3.36 ,2.75 . 2.59 .2;36. 2.25 '''.2;()5;, .' 1.87 . '1;7~ . 1.74 :J~9I 1.59 "7:7~;' . .' .'. 165~0 " " . 161.0 (1Ì,13¡M3) . Group Mole % . ?i29'.." 0.00 " :'.{':J;;¡~::,îtjQ;~;2Ã;'::!~~' 14.39 ~.:\i~:":5~g&;~.'; ;',':;,:c 6.65 1;74 4.79 2.15 3.01 7.62 '-. " - , " . ,,7,,~~ ~'. >:.;\:::~;JÒ\",~;'~-'- ,- ~ ~,,~ 18.71 16.70 3.16 '. c;"",~:;~-,::;~,~,,.:, : 3.06 '2.~ 2.36 , ';';;~2Uf6;: . . - 2.05 ':4:JJ7..i:';' ., 1.70 .:1.~a2 . 1.58 :',52.0., 1.45 ;7:1).3' 1.59 ;ë'::;9'f;~' """ 1.39 '1:08; 0.97 "0;84,: .',;. 0.77 ':.Q.,f5;1; -: 0.59 :Q~54;. 0.50 , ..0,47-; 0.43 'j~44' ",- -~.;' :,".\.:~~:>,:i ~ -~, ~'.. -,~', .:;~: ' ", 8.56 . . .. 6.85 :.1'A4', '~., ~, ::'" ~. ~, (SÇF/BBl) . Group Compositional Data for Different Groupings Mole % Wt% MW C12+ C30+ 258.3 580.0 25.3 1.44 54.9 7.0 119.2 315'; SG 0.88 1.03 . Estimated with the Skimming Method. (Gozalpour F" Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C, H., Fluid Phase Equilibria, 16, 137.150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 16 B.P. (OF)** 611 981 Oilphase-DBR Table 3.2 BP Alaska Northstar Separator Fluid Well: NS-13; Cylinder TC1119 C30+ Composition [ [ ( ~ C26 359.00 0.00 1.65 '1.50 0.50 C27 374.00 0.00 1.72 1.56 0.50 '''''''''''''>'''"':'\'',WJi;.''~'~''''~'~''",,"W:''II'>W¡;.'>''''''m.'¡'¡~,or 18.80 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 17 Oilphase-DBR Table 3.3 BP Alaska Northstar Separator Fluid Well: NS-09; Cylinder TC1136 C30+ Composition Group Mole % 2.28 0.00 Ò.09 . 14.31 5.29 6.93 1.79 . 4.90 2.17 3.02 -- -i'fj:$8\:;'i;:::\ (SCF/BBL) Group C7+ C12+ .' ,,::..-c30+ Compositional Data for Different Groupings Mole % Wt% MW 51.6 81.2 185.0 24.7 54.0 257.4 - . . - - . . 1A1-'.: . : '7~O:" .:5àò~o : SG 0.83 0.88 1.03 B.P. (OF)- 458 609 981 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A- -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747,1999) .. Boiling Points Calculated using the Twu Con-elation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 18 Oilphase-DBR Table 3.4 BP Alaska Northstar Separator Fluid Well: NS-9; Cylinder TC1120 C30+ Composition Component ÇQ~', .' H2S 8~;'" C1 ~Xi. }\'-.:; C3 :*~(¡À~~~&~tð~§'~~~~1J ( ( ( ( ( ( ( ( ( ( ( ( ( (" ( f ( ( (' ( ( ( ( ( ( ( ( ( ( ( ( ( ~~'i¡llt~%:*~;1i%~%~;~}X~;~\,~~~~~\:\~; C29 C:SO+\. . . .. Mea.~u~.V!HSVm~I)"i . Calculated MW (g/!"ol). . ~'l1g~,Stag~ fI~sÞ GOft@~Tp. API Gravity A~eragê'GåsGråvitY . COI1taJ1ilnatl()n(m %)It Contamination Corrected GOR Contamination Corrëcted API (SCF/BBL) Group C7+ C12+ C30+ Compositional Data for Different Groupings Mole 'Yo Wt 'Yo MW 51.0 81;0 185.2 24.3 53.8 258.0 1.44 7: 1 580;0 SG 0.83 0.87 1.03 B.P. (OF)** 459 610 981 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) ... Boiling Points Calculated using the Twu Correlation, (Twu, C, H., Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 19 Oilphase-DBR Figure 3.1 BP Alaska North Star Separator Fluid Well: NS-13 & NS-09; Cylinders TC-1137, TC-1119, TC 1136, TC 1120 C30+ Composition Comparison 1 00.00 -::---____m______~- -- -- - -- --- --~ -_._~----- --~--,-_._.~---_.._--,-_.__._----~-----------_.~ - -- ----~- - - -- ------- ----------~--- --------'---'----------'------,--------- - ---_._- -'------"-'- ~--__--m - --------------.--- -+-NS-13, TC-1137 - -~---------_.__._---- --_. -.-------------.---.-----------.-- -'-NS-13. TC-1119 _NS-09. TC 1136 -- .__._----------------~. ---~- --------.- -8-NS-09, TC 1120 -------_u u.-------- -----_..__._---------- - 10.00 -= ..... c Q) CJ ~ Q) 0- ..... s:. C) '¡; ~ 1.00 ~I 0.10 -= ~ 0.01 . . .. ,. . . . . . . . . . . . . . . . . . , . . . . . , . , . é" .¡¡-'" i!o'" ú~ ú'" ú" .p .¡J /R..P' {f' Ú''' .-,+'" ç1' ð ç1' #'" {f' .{/'''' $'" $'" v" vo$> V~~ ú<:> V~" ú~ V~ d" v~ db v~.. ¿f r!l &' r!P ð ¿p v~ & ¿p & ¿f ~ð #~ <IY $'~vv ....¿is , ..# a-Ç'- é}i ~'tY Components Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples Oilphase-DBR 20 Table 3.5 BP Alaska Northstar Separator Fluid Well: NS-08; Cylinder TC1126 C30+ Composition r l ",'1(t30 . '. , ' ." t ( ( ( ( ( r ( r ( ( ( t, ( r ( ( ( ( ( ( ( l 7.95 (SÇF/BBl) Group C7,*: C12+ C30+ Compositional Data for Different Groupings Mole % Wt% MW 50.8 81.0 186.5 24.0 53.8 262.2 1.79 8;9 580.0 SG 0.83 0.87 1.03 B.P. (OF)** 462 618 981 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H.. Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 21 Oilphase-DBR Table 3.6 BP Alaska Northstar Separator Fluid Well: NS-08; Cylinder TC1142 C30+ Composition , C~~ponent .ç,c)J"".;:;:',~; " H2S :Ni~:{\;;i;;i~': .; . , C1 .~;fj;:~;;.,è;~ . C3 f~i:. N-C4 ~::ii;:})t~~~!q;!:?;~ .': N-C5 ~':;,;:id~;:§5:; j,.. MCYC-C5 ØElfZENE : êvc(-è& wB:;i¡;ê¿tt~;{..; MCYCL-C6 t.~~Ià.,', C8 ~.' M&P-XYLENE ~;+:,:,,;;~:; C9 -~'~\íj:¡;~~i;:;¡¡\,¡r ::, l;1~: C13 ~i~t\¥,;;¡t:~\;~\8~;~:f':2:,:, .çi. C17 ,ç;¡. : C19 ,ç2fj C21 øi> C23 ~; C25 C28 C27 é~ C29 t_,.. . ~;'-'~~)J~' CalcLilated MW (ø/mol) !I'Î'Ig!~~".¡;:~hÇØJt@;S:rp '.' API Gravity AVêiáijéÖâåGnìVity .qOf'la~~cm(~%)~ ..:. ' Contamination Corrected GOR coßt.aiïí(riãûon~ API . . . \ '. --~ (SCF/B~L) Compositional Data for Different Groupings Mole % Wt% MW ~.8 80.8 184.2 23.8 53.2 258.3 . 1.Sg .7.1 580.0 ' B.P. (OF)- 456 611 981 . Estimated with the Skimming Method. (Gozalpour F" Danesh A., Tehrani A. -H., Todd A. C., Tohidi 8., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 22 Oilphase-DBR Table 3.7 BP Alaska Northstar Separator Fluid Well: NS-15; Cylinder TC1124 C30+ Composition fig]¡~t~:t:~;î~%" , N-CS ~{?y~:,~ ',,; MCYC-CS lBEtØENË,: èyëL~6' : ct,.:>,.:::}", . ...êõfCL::C6 (SCF/BBL) Component ~ø~~,> . H2S ~~'::,~~,., - C1 Ç~L¿: ,,~~~ ',~o. C3 ~;:~:i Group C7+ C12+ C30+ . Compositional Data for Different Groupings Mole % Wt% MW 50.9 81,0 186.2 24.3 53.9 260.0 1;64 8.1 580.0 SG 0.83 0.87 1.03 B.P. (OF)** 461 614 981 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 23 Oilphase-DBR Component MW l.iR1i{;\'f¡Š'¡!¡[š;t;;t~>", ":,;j:i:¡', . 'i1i'iØ~ø:1é,t',.: H2S 34.08 rø:7~:"?C!:~':::};L': ';:';;t:;A/ff~li,ii:;l~,': C1 16.04 ~.\" ,. ';;'~¿'~~i~~~;¡>;:})t;; " Î:.C4\ , ...,;Slt12.'i'" N-è4 5ÊU2 fl:?,i!;.\.';';: 'c. :?:'?';: >;g,;,g~~:~'~ :'. ~;,;;;:i::{~., ' <8ê~: MCYC-CS 84.16 .~Ê"/ C c..,. ''18211. CYCL-C6 84.16 ~!~~~;f::;:'::~}(t\:T.t ':~ ';"~," ./1~@~,;¡ MCYCL-C6 98.19 't~L~. ,92;14J . C8 114.23 Ç,2~~S ;,'ò''':;è;,,':iô6:?'17> ,." M&P-XYLENE 106.17 ~~',;~;1t~;:i;L;' .:::..\';1ö6~17";: C9 128.30 cïï 1~~OO C11 147.00 çJZ} ,., <161~øo:" C13 175.00 c;,. ". . . 19p;Òcf ' C1S 206.00 Ç16 . :222.00, ' . C17 237.00 è:ta: :. .2å1.Ðo:{';; C19 . 263.0Ò C~O. 215~Oò C21 291.00 QJïf(nc,;" ',.;:; .' ,,,,X:' í~'~:§~J,3f',~B':::~';' ;';4, è23 '318.00 ~ . .. :33't~OO C25 345.00 C~ . 359:00 . C27 374.00 ~:¡~;~~;;;1(":'~;>;::::è~;";:,: :;~;¡I¡s:!!~!~~:~: C30+.: ~,,/,;:;.' .'. .:;/580:00.,' ~~tM~;(~;,. ". ~al~ulatl!d,.MW (g/mol) ~liJgkt'.$~~:Ft.GOR@,STI) API Gravity AVêliijåýGåâGråVitY Ç~I1tIr.!.Øc.m(~%)~ . , ..".' - Contamination Corrected GOR èòRtâminatióri'CòìNtt8d APt c Table 3.8 BP Alaska Northstar Separator Fluid Well: NS-15; Cylinder TC1141 C30+ Composition Gas Mole 0/0 ,:ii¡Ìic,iiiz'Y ". '" ,I~~gi(:¡;;/i~: i",{ ,. 0.00 ':¡'¡c Fi.i,\1?to:äT?'5:~I'fV;~;::,':. 40.33 "'16)28, "li. 17.75 . ;3:61: . 7.93 '::.:'l':è<':~~''''. 2.25 .'J~$' . '. 0.22 ~;Ö8' 0.21 .,' .'~:'Ól~','";" 0.17 '0;04 0.12 "O.ÖØ ' 0.01 c'O~Qó'( 0.04 0;01 0.00 , . ',:;,Zþ:oa' ,",. 0.00 'O.~ 0.00 .. :cÜ)(j" 0.00 ;'biOò '.' 0.00 0:00 0.00 ::tj;t:)~,~Jz,¡:,'.~¡~p' ' 0.00 '(jJjp , 0.00 0:00 0.00 ;~i~;.' "ft:\~I~~i~~~:iÍ;F;"" " 0.00 '. ;0.00.: 34.5 6?.5 41.6 . '1;i9~ ''Dead Oil Basis Liquid Wt% ;':¡P:¡Ø:i::~~ " 0.00 ;ø;ÐØ;:- :: 0.00 ": :<. ,;.. ;:.,ø~OQ. 0.28 "O;~5 0.96 .' ",;if«~?;lA ~:.::.,: 1.44 ,'3~5'" 0.85 . 'O~3, 1.18 :3;'ÏjS<'<" ,;';"':;.',' 2.60 , ().~ 5.33 'aj~' 0.85 ;, ":.0:52'. 4.98 : 6;02 4.93 '4;44',' 4.91 :'4.~. 4.26 3;69. ' 3.39 . "'3.4$'. 3.17 2.71' 2.48 , ,'" I,' j '~~§;'W::'~ ',3 I"~ 2.13 tJÍ4 1.83 '(57 1.65 .i!!'1;S4i, 1.42 .,,9.13.:, - . ,'...,- ..~. 163.7 (M3/M3) Overall Wt % Mole 0/0 , .. "ii,:.Ol~¡::":"~,:'<:;it:{'i:g¡~¡¡::", .:; , 0.00 0.00 ,\:;::;~ ':I':Q:~", .'~'; )O;ò8i J>':':, 2.08 15.02 1.58 6.06 2.77 7.27 {);90 . . . . 'j:ra' ' 2.34 4.66 ':': :1~~ ,'. ',' . :; .."" ::~;Q"i\.' 1.80 2.88 . :S~. :'" ''''4~3é:' 0.81 1.12 '. "~Q;22"" . Ò;33 1.10 1.55 ':£~?..: '. :' Jf1~ 2.36 2.78 " O:"""O;~7. 4.78 4.84 .o:Pí4 . ¡ '0:1'$ . 0.76 0.83 ., YO.'ll .Ö~5f" ~'.: 4.44 4.00 5.35 . 4.62' 4.38 3.44 "'3:94' '. :';~K:;ýzfæ,; . 4.37 2.88 .'. ~,()? 2A£i 3.78 2.12 . 3.28 . 1:7.1 3.01 1.47 $~ö7': . 1;41, .~ 2.82 1.24 2A11~01 2.20 0.87 i~:4(\;~~~ '; ,. :.i"Ii!;"', \P" ;þftt~~~~ ',i:%!ít;;:¡ : 1.89 0.69 . 1 ;73' 0.60 1.63 0.55 1.39 QAS 1.46 0.45 ., 1::~t "c):41 1.26 0.36 8:12 1.62 . , . 115.6 390 Group Mole 0/0 (~~.)t:..":,,, 0.00 ;tõ;ó8\~ 15.02 6.06 7.27 .1;78 4.66 .i,~i~t:..,:".i 2.88 7.36 ;" . ..:;-;: .~, ~ 7.95 6.15 ..J.~.. . ;- .(SqF/~BL) (~CF/BBq Group C7+, C12+ C3o+ Compositional Data for Different Groupings Mole % Wt % MW . 50280.8 186.0 23.9 53.7 260.0 1.62 8.1 580.0 SG 0.83 0.87 1.03 . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) - Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16. 137-150 (1984» Oilphase-DBR FilE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 24 B.P. (OF)** .461 614 981 Oilphase-DBR ~ ~. ~ ~. c~ ~ ~, F"""'. ~ .""""""" .~ f""""""'. ~ ,~, r-"'. !"-~\ r-". .~ r'"""\ .'-' ~,-.~ F"""'. ~, .~ ~. Figure 3.2 BP Alaska Northstar Separator Fluid Well: NS-08 & NS-15; Cylinders TC-1126, TC-1142, TC 1124, TC 1141 C30+ Composition Comparison 100.00 ~' .,.,..,..,~,_....><-<-<--=,--,."......".~-,--.~~..........----_....----.........= --.--------.--- -+-NS-08, TC-1126 -.- NS-08, TC-1142 _NS-15, TC-1124 ---NS-15, TC-1141 10.00 -= .... c CI) CJ '- CI) D. .... -'= C) "¡ 3: 1.00 -=8 0.10 --:: 0.01 . . . . ., , ., I . L . I , . . . . . . . . . . . . , , , . . . . , . . . . . . . . . , . . . I .. . . . . . . . . ##~lf~~?~P~~~#~ð.~.#~###ð~~~~~~~~~~&ð&&d~~ð~~ð ~ð q,if o....<Y ~c;- .....o~ #~ 9.# ¡y-Ç- ð $' Components Oi/phase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples Oi/phase-DBR 25 Table 3.9 BP Northstar Separator Gas; Wells: NS-13 & NS-09 C15+ Composition Component MW c;Ø2 . ." ' ':";442Qt ~.~)c» H2S M.08 :N2 28.01 C1 16.04 Çï: " ,'3,g.ôl C3 44.10 t;ç4. ' 58.12' N-C4 58.12 ~> . 72ds N-C5 72.15 'Ce:' ;,". "", ~. 8tt20 MCYC-C5 84.16 ~~_NE " 7tJ..11 CYCL-C6 84.16 ct...:./" ~~ '100.20 MCYCL-C6 98.19 :fO~~NE . . 92j~4;:. C8 114.23 .ç2:81:NzEt4 . , . ..1~J'7~ . M&P-XYLEN 106.17 .o-)(.YLENE, '106J1. C9 128.30 .(;1& . . 134:00 . C11 147.00 C1ì . 16tOO C13 175.00 ~14. . 190.00 C15+ 206.00 Averat'e Molecular Weight Gas Mole % NS-13 NS-09 MM38810 MM33040 MM33085 MM38865 MM33082 . '6~/i;:i;ft; 0.00 0.89 78.14 . i~~ 4.02 'Ói51 1.11 Ô:2EL 0.29 , Qi1~' 0.03 0.01 0.02 .".trÔT' 0.02 tlOQ: ' 0.02 . .()iOO 0.00 0;00 0.00 O~OO 0.00 0.00 . 0.00 0;00 0.00 21.49 , . ;;6J5ST' , 0.00 0.82 78.15 7.82 4.00 Ô~57 1.12 . Ó;26 0.30 '.'020: 0.03 OJ).1 0.03 '0:07 0.03 ..'O¡Qo 0.03 0:00 . 0.00 .0.00 0.01 0.00 0.00 0;00 0.00 0.00. 0.00 21.53 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 26 , '$iß4': 0.00 0.94 78.44 7<t) 3.81 0;53' 1.02 '.:O~24:, 0.27 O;1~ 0.03 0.01 0.03 0:07 0.03 0:00'.' 0.03 0:00 0.00 0.00 0.01 0:00 0.00 0;00 0.00 0.00 0.00 21.40 :; ';~~::6.~~...: 0.00 0.89 78.M l:S:{ " 3.85 O~S5 . 1.05 '<O~26 0.30 ~.(};24, 0.04 0.01 0.04 0;1'1 0.05 :0;01 0.06 0.00. 0.00 0.00' 0.02 0.00 0.00 Ó:OO .' 0.00 O.ÓO 0.00 21.58 . '. "'>;é:isf:,>. 0.00 0;82 78.61 7~63. 3.94 0;55 . 1.01 ',"0;23 ' 0.26 . .~..:0:.;t;9. 0.03 0:91 . 0.03 Ò.Ò8 0.03 O:ÓO 0.04 O.ØD . 0.00 0.00 0.01 0.00 0.00 '0;00 0.00 0.00 0.00 21.41 Oilphase-DBR Table 3.10 BP Northstar Separator Gas; Wells: NS-15 & NS-08 C15+ Composition Component MW ( ( [ -çQ~::>": , " C \;' .. ~;Pc1: : H2S 34.08 N2;"'~"<': " . !'28~ol:' ," C1 16.04 Ç~;? ..':~QEÖ7'j C3 44.10 ï~~,>" :' '~5~.1:2\:':'::" " N-C4 58.12 13:~:> "'12£1.5";:;,: N-C5 72.15 C6, : '" .' ' ' : "~6á20'-: 3: . MCVC-C5 84.16 aENZI;NE' .' " '. .", '," .7~,1.:1. CYCL-C6 84.16 C7!Y}' ',:" ,'.' . "~ '. . "100:20' ' , MCVCL-C6 98.19 :tQby'g'~l~""'h" , ',',J~g,;14.~..:,-,., - C8 114.23 ç2~~~~Z~N: 106~7 M&P-XVLEN 106.17 O:XVLENE. ' t06~17 C9 128.30 0.10 ' "134~QO C11 147.00 C12" '161.iOO . C13 175.00 <:14 . .190~ÒO" C15+ 206.00 IAverage Molecular Weight ( ( ( ( ( ( ( ( ( ( ( ( ( ( l ( ( ( l ( ( ( NS-15 0329 0343 Gas Mole % NS-08 0342 0327 . ' ,:/::::::,,:J?~~~':¿:::':' 0.00 ',' :::}IOa::', . 79.20 '. ':,;l:¡~~~:_-"'" 3.40 "PA;4..,,' 0.81 ',.;J>:~:'7.:::'. 0.19 , .Oj13'", 0.02 . ,q;01,<,,;:\ .' 0.02 'EtaS", "'ÌJ . 0.02 ",Q,~9.t '. 0.02 0.00; 0.00 a~ob 0.01 , .c>.oo, 0.00 0;00, 0.00 0;00 0.00 21.07 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 27 " .. f):~7;~~" 0.00 ;-':t~~2::, 79.14 ,;,.'ta3,"'" 3.37 ':Q.~~..,' 0.79 . ",:0;'.1: '::/' 0.18 ;,0,;1.:1.- 0.02 " J¡t01.,::'>: 0.02 .:";"';0504:.,., ' 0.02 .. ""Q,;QjL\ .' 0.02 '0.0,0 . 0.00 .'O~OO 0.00 . O~OO ' 0.00 O.OQ" 0.00 . O~O(): 0.00 20.99 ..:t:¿:0~:~~,::b'<"::");': :,,§Ig~;+ri~;Y:::, 0.00 0.00 ." -¡"'/-Ø;~1t"':':;:' ,"")<',ø~ø~:.:(~~..,,:1 78.36 78.53 .... ':~1)i?:;:';;<":::'Z¡:ø~ ': ',~/' 3.75 3.70 ':.:Ø;~1;:f;;:\' ::'" :',¡¡::'¿:Ô'.~ij:'--. :"i~' 0.96 0.94 ~ ':t()}~gi':.::::;: ' ,: ,.'O~21': 0.25 0.23 - .{~A6 ". '0.15, " 0.03 0.02 ';',Œ01''-'::' 0.03 , ;', \:' ..()~oá. ", 0.03 " , ,().~l"..,: 0.02 . O.Op,'. 0.00 'O~OO 0.01 .0;00 0.00 ,,'O~ØO .;" 0.00 'Q~QÓ . 0.00 21.30 0.03 ! );;:::(M)6";;':~;'" 0.03 ".Q:~9:~ .. 0.03 ,O.Op , 0.00 .0.09 0.01 'O~QO.¡ ,:: 0.00 flOb' 0.00 '.O.OQ .' 0.00 21.38 Oilphase-DBR Table 3.11 BP Alaska Recombined Reservoir Fluid #1: NS-09, 5100 psia Psat C30+ Composition , ~ -- (SCF/BBL) . Estimated with the Skimming Method. (Gozalpour F, Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boilin9 Points Calculated using the Twu Correlation, (Twu, C. H.. Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 28 Oilphase-DBR Table 3.12 BP Alaska Recombined Reservoir Fluid: NS-09+NS-13, 4850psia Psat C30+ Composition Gas Liquid" Overaii Group Component MW Mole % Wt % Wt % Mole % Mole % C.02 :' 44',01- -' -- . - ..:..~i13 - -- - ':.9.09.' . '~;~'-',-:. - . :._':'\~~~ . ' 4~~;3:~ ""~-~ ' H2S 34.08 0.00 0.00 0.00 0.00 0.00 ~~ . . f\,,';;i~~~~~:: :'_:<'::~~;~~~ff\~",'~;':Zi5:Œ;'1:¡~~~Jð~j!~~YH'::¡~j1;;;~~~' "~~523 ~'. -~~3: C2 . : 30.97", "c'.8.BS- ;. . -, :p.QQ.:',§i-y;, }~J~1;~i~~f§~;~~;~&Æf¿~~1~~~~f'¡Ê¡(~~~:. ;~ð~¡t[~~î~~;W~~~;~ C3 44.10 6.31 0.13 3.88 5.08 5.08 J-:C4 .~5å:12 :t23' :...' "0:09:'.. : 'Ù~3.. .:,': H~~: :': :/~"{b3,>~"":_: N-C4 58.12 2.87 0.39 2.53 2.51 2.51 I-C~t'; - ]2.1,5 . .0.98 <. " .' .'0.51 ~, ,1~3Q ", 1;04' , ';J:~;'J. .',. N-CS 72.15 1.23 0.92 1.80 1.44 1.44 cø'. ". '::86.20 f, ,":1:05 "~'-';2.63.'" . ',-...2.95 '.1:97.'.;;.:" ',', MC'YC-CS' . 84::ï6 .' 0:1'9" ~ '0.73' Ö.69' "0:47 ..- '''. BÉ~E "7.8.11 . 0.97 ".~.'O.21~: "::,J:Q~1~", . :"JM9.(':'.'; CYCL-C6 84.16 0.20 1.04 0.90 0.63 3.23 Ç!~L~'ò:.,;:::;~~:~,~"j,,:~:~,~~,O'\\ ~,\,\",;.~;,¡~-~\\\",;~~:. o<;:;.~"'~;'~V,\,:\~1~Qg~~,q\;~~~t:,,¡,~ ".';M'~ .:\~~tò;"i,~~~~'~\:'::hg;~~>~~;\",~';'~:~'~;¿;;:i~~',~~:~:~~;;.¡~~~¡@Q1~~i~~~~~,.í~~~~,,#j~,~~ù~~~~:~Û~;~~¡;~~~~¿~:~\,{{;~~~~L~tifi1~ií:hmM~ì~~~~:,{'*:, ~~~~..;i~~~~~~:~~{~~~~;~~~~~ MCYCL-C6 98.19 0.18 2.23 1.70 1.00 IQ,btJ,I:E."',~,..",,,,,..,,w,,, , ".",,,,,. ,,,",,,",,,,,,,,,"J~~,,J~"W'W""""'''''''' """,.""i",~.,Q<,Q§",~,;"".,,,",,;W' .,,,,:¡.,,,,,,;,,,~,..Q.,,Q.i~;,i~,,,,.,,,,;.,,,,, i",,,,,,,,.:,,.,,,,~J?~t",,,,,,,~,,,;";'~"""'i,,,,¡i,,"g,",,~~~,.,,,..~,,i""""'"';'''¡''''~;''''''';''~&,:'''''''j''',';;''''' C8 114.23 0.15 5.05 3.52 1.78 ç~~!:N~~J;'.i,.- ;~,!::"\,-: \~;::\\0!;f1~:1t{~:::;,Ai,\ .':0';",,?t;1(iØl,99;:;li,,~;i;~',; A\2S:.\~;j3ip(1'~~;¡)j\;;jt;<;0;(i:i:;Hy,;gJgj;:;0;!J:1;¿'~%f~(t~¡~;;Q~j~:~t~~;Ù 'ji!;;¿i;~;tfŒ§â?~~1I~t~?:i'~!S M&P-XYLENE 106.17 0.01 0.84 0.57 0.31 ç~'~f'- i; Jii':..", . ",¡" :j,,;X;;A~,~Þ'i ;,: ,'\, ,:,:Z;::,:{;;;Q;q~Ú;:<i~":: }:V:H,f),\iØ;;r;~:~,,;¿i;0.~:::~j:;':-:,;:;t~¡MiWf::,;;11;;;i:~~':;;1:/P~g;i$$j:¡ii;~,i8i:! "~i£::;;;:!\ 'Y0~;W:i%';,;Yi::::v:;1:. C11 147.00 0.00 4.83 3.15 1.24 Ci2 161.00 0.00 4.40 2.86 1.03 C13 175.00 0.00 4.89 3.18 1.05 C14 190.00 0.00 4.63 3.01 . 0.91 C1S 206.00 0.00 4.24 2.76 0.77 Ci6 222.00 0.00 3.77 2.46 . 0.64 C17 237.00 0.00 3.48 2.26 0.55 5.88 c C19 263.00 0.00 3.30 2.15 0.47 2.97 Ç~~):, ; ..:i" . . 2\"}':::¡'~':;\1gt:~t;Þ;Q;;i:iÚ,::,,;~ ;:::;:/ba:;:(~~~Þ~:~::'i :: ;~j¡/~i;:f);~;~Q¡;A¿:;¡;j)'i .' ::gJ~::;;10»~i,::\;.;;:'/'::';:,;::;;;i';:\¡Q~:ij:!t:;i.i", ,:k:;;;~::,%;1:*::; :';~.:;{;)i:(0Z¡; C2i 291.00 0.00 2.62 1.70 0.34 Ç22»:' ; :.:,,: ::~\" .' : : '(::>ØQ5;:ÞÔ::,: ,:',,; . <::,';:,,;)Ô.:PÖ'\'; ~:. : >;,: ... \A2.~ß;¡.::'" ;".t;1.¡!i4::':.j:: :,,,i:::t5:;:::, ::';g,~~;~:~.';¡<': ';,;,', ,:;-';,;' . ; .:i:';;:~::;:!~ C23 318.00 0.00 2.27 1.48 0.27 g~'::j';;:':::/;':,:XL', :~:' :, .'~~~~': :.:'.' '::~:: ,':(S<¡;!:'::~~~~, /':".:, :'. ':,:: 'i,;~~~'::, ..:j;,. ' ::',<;,: <:~':~~!:\iii<'.',;:/::j:;;:L~:~~:;:" ê~~y!;.:;. '.;.: '.., .",:.L¿. :::,.":,;:::::~5~~QQ",:;:",,,,,:,: ..t:Xi;;::;:;;...QrQQ;,...~,;,.;<::,;:::::;2.;;;;:..:~j:j:~§lIi,:: '~. .~:;:;::j::i::;:~li~,:ü;;,:iL';:.t::~~L~:;~;;;f;;;ii;11è:,:': ':;,' ;, ,:,;!:,.¡;;;;i:i;::;;;¡;;:~¡,;;r£:,,;l~.;¡~ C27 374.00 0.00 1.74 1.13 0.18 C28. ."è,":>, ':';;'j3li8;oo'::;:,"':-"':~~.Q;QO,\,:'\'<,:,' ~ß2,(, '}',1,¡o~i(.> ':>:\",<:0;16 ~ C29 402.00 0.00 C3Ô*': '., .. ,"i : ' ':.<:SSÓ;OO;;;'();(W' I\IIftastl.r~.~V'H9/mp"'< ",::. , " ' ',' . .0:' .' Calculatèd MW (g/mOI) .. ...' .. ' . .. 25.6 S.il1gle~tå~flaøh'90R}~fS.Tt>,' . .410:4', , API Gravity 39.6 Àv,rage Gaš GraVity): ,i"': "',' ".,:;: ""'" ,().8a5/:': C()p~m'J:I~tipn(v4'Y~)~,., " D~d OilØss,j~: Contamination Corrected GOR ContinilriåtioriCorredØdAÞl . ( .' .(~~Fi~~ì;l, ..\ '\, ,,\'\ " ;,W~,:Qi'a"øl~ ,.: (SCF/BBL) Group C?+ C12+ C30+, Compositional Data for Different Groupinqs Mole % Wt% MW ',1,8.7, 62.0. .' 191;0." 9.1 42.2 267.1 0.76 . 7.7 ' '580;0 SG 'OJ~3 0.87 1~03 B.P. (OF)** :,:472' 626 .981. . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 29 Oilphase-DBR Table 3.13 BP Alaska Northstar Recombined Reservoir Fluid, Well: NS-08 C30+ Composition C27 çæ' . C29 ~3öf'~', ;.°," . ....ured .MY(,(g/~ÒI),' " . Calculatèd MW (9/mol) . $ilagié'S.Fìaitiè6R@;STD', API Gravity Avèra9ëGa~ Gravity" Ç~nti~~tiøÞ(Wt.%)~. . ,'.' . Contamination Corrected GOR CoriiaínhïatlònCórreèt8dAPI . . . .~ ~ - (S~F/~BL) Group Compositional Data for Different Groupinas Mole % Wt% MW ':U~;5": . . 8.6 0:46 254.9 .580.0 . Estimated with the Skimming Method, (Gozalpour F., Danesh A., Tehrani A. -H., Todd A, C.. Tohidi 8.. SPE Technical Paper # 56747,1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984)) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 30 Oilphase-DBR Table 3.14 BP Alaska Northstar Recombined Reservoir Fluid, Well: NS-15 C30+ Composition Gas Component MW Mole % CO2. ..::" . 44.01 .--' - '""'- "'6:50';'-',..' H2S 34.08 0.00 N2 ; . ',': . ",:'28.of'{' " :~. '~:o:~ C1 16.04 70.11 C2';' ,>.. . 39:Ô7.:~ '-: .: :~fiø1 ' C3 44.10 6.57 0.13 3.78 5.09 5.09 ~~~<~;,,"";"'''''- '".: ~,:..:~~~~ ,^" ..':" Jf."~~j.. -:-,: ':-'~~:r': '.: ?(~,;.,~:~~~},-~;:;j"""~".::~~;'i::~~' .~.~,>,~:.;~~~~c;::,,~~,¡ 1~5f~,":::~~":" -.':.': -"::'~!?~~1~:: :-<,~~. .:,. ':ö,iii;,!.. .,..tct69;;":;':"~>':"~:'~r1),.>~J~:r:":'.1;Ö,9~/:'\-' f",':.Q:~8~;,:-, N-C5 72.15 0.88 1.17 1.61 1.33 1.33 MCYC-C5 84.16 0.09 0.83 0.67 0.47 ì§B.lii'I~¡¥~~I0ìj*~æ~~w~iiîi¡~~)¡~¡U~f~t~~~JII~ljt~?it~i~j~liYA~ìli\~f~nl,'0\\;1.ii1tì~ltt~~II~jl'1.II~n.lililt~Da1 g~~:.L::~.~c', . .;, 1~;~'~:~;"~:~~ .,:g:;~..::;, ::n/:-~-:Zj:.::. 3.~3 MCYCL.è6 ., 98.19 ' '0.08 2.63 ' 1.90 1.15 TCLUÈNÈ: 92:14' . O~O2' ", O.84'{UW '..";c~:';Ð:39~ C8 114.23 0.06 5.44 3.82 1.99 çg.i@J:Ê,~~H~;~;',\i;;iF:~;; ;.::~:;1). j~;~~;;J:;!ì::;.{f~ ~¿!:¡f:~li1,f)J;gþ;~\\iR:ili~i2(~;:~;;¡:1¡i~;:~i9I1,~¡,tÚ~~i[jf,7 .(~\~!;5~~~~Q~:}{~~f!Rì¡iJ*!'3~*:m~~%i~))f;:\~ :f:¡!'K;;:~:X:>t;,~r~%))fi~}?~~;i[) M&P-XYLENE 106.17 0.01 0.84 0.59 0.33 g:~~y\ç~~g}:1t't,:rf,:;':'!PX;~;;<¡i~~[1~¡~~;;t:¡!;;;:\i'F':i~;;6:J!:!~9~qb,j~2(,;';!'Fi r~:;~;\;-;:¡9:~g,¡~;if';::~~~:1 :i~;\;~ßf,;3~~':~'ftf'lg~;S:¡i!:>~:,ti'1(t¡~~ti¡ð;1~í~t~K~~~;;;fi'?I~~~ii~@;~'¡l~~~; C9 128.30 0.02 5.16 3.57 1.65 7.50 C10 Liquid Wt% "'0:00' 0.00 '~.:O.OO:-'" 0.00 Overall , '. .- ..1. C14 190.00 0.00 4.63 3.18 0.99 C15 206.00 0.00 4.39 3.01 0.87 C16 222.00 0.00 3.78 2.60 .0.69 6.59 C28 388.00 C29 402.00 ç~Ö:t,\;.;§;::;,~;);~~;:.:,j":;.:.:,./;,,. .,;::i,:':;;iG~80:öQ;¡;:ii:, 'fj~~œ,~MY'I.:(wmplt;\". ..' .'. Calculated MW (g/mol) Single .Stage Flash GOR @ STD API Gravity A'Ìiage::Sâs'Qtäv,ty,: :, >::>';'.. çeìj~m~~~Hm'(!4,"olt,:~: '.. ...,-. Contamination Corrected GOR Contamination Corrected API (SCFIBBL) , _\ ~i":. " ->- -,.~,..\ (SCF/BBL) Group ,C7,,:, C12+ Compositional Data for Different Groupinqs Mole % Wt % MW "20:563,7 :184;8 9.7 42.1 258.1 >:'0;59: (."-' ,,:~:~80:0' SG ;::' '0;83 0.87 ",:'t:03' B.P. (OF)** '4~8, . 610 " .'-:' j98t.}~' . Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747, 1999) ** Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 31 Oilphase-DBR Table 3.15 BP Alaska Recombined Reservoir Fluid, NS-13, 5100 psia Psat C30+ Composition ,. , .'., ~~' ,.;' ", ' (SCF/BBL) C12+ :C30+ Compositional Data for Different Groupinqs Mole % Wt% MW \,1,8$13, ' 264.6 580.0 8.4 0.66 Group * Estimated with the Skimming Method. (Gozalpour F., Danesh A., Tehrani A. -H., Todd A. C., Tohidi B., SPE Technical Paper # 56747,1999) .. Boiling Points Calculated using the Twu Correlation, (Twu, C. H., Fluid Phase Equilibria, 16, 137-150 (1984» Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 32 Oilphase-DBR Figure 3.3 BP Alaska Northstar Formation Water Collected at LP Separator Compositional Analysis MAXXAM Analytics Inc. GlaSS NJA ;'::':..~::i'h1~.~:;1".(y' '."::::.:;":i:.~.:>."'1I:.~ (.';"":11:::' DBR Research Inc. C'f,:-'..:\'>.'N,:;.;;',:' DBR RESEARCH ----_._-~---_.~--------------------_._--~_.- 1t~~~'I"":":;~\;, WATER ANALYSIS 02.28273-02 l~~:,~': 1:-.'Y'~\\.~~!I~r t,:;,C' }j.'oh\:C' NJA DBR -----"--------- ¡'J,;'_r(1."~:-:~;::þ\}r ¡::¡:::'!\'l,h",:;' :';;,m~¡:...~ r.:~r.f DBR 2Q02.63JOB:20023 32 -$;~;~;~~';~:";~;;~~:;;;;;f.._.'.,--.......m....._--_m...._..... "'''''---''---'''''''-'''''''''''''''.....--........................-........,.........................................................--. '''''''''''''''''''''''''''''................-.....-...........-..'''''''' f.¡.!.rF:x....;..j,,,,,,...'}' :.I:bV'W\)r~ ".......-.." ,\*,"'"3':; --.m...... 1X!w.:1-'OfJ f"Y'I' r ;"!.f T~~:'í\ N'J. ~~u1';~~J .~'t~ú,'i~'t r f:~ I I t~;;;';'~:;;'''''''-- .~.~~~;~\.'¡'¡~.,,'1 ff..!("':'"') . í'JJ¡'f.Wr;iMt...-..t.:: ('¡Im~'.(,\ .:...t....tír.:~ ';~Í&u}4¡:'tl.c'~;.,~;i¡¡f,^P), '-¡ .-----..._.....~~~. ¡ i j NiÄ NiA 2002/04/11 2002/04/11 ~~~ -~~~ -- Ü"t~. ~r¡~{'(%$r.;-'1 O..;1'~$;-Il).\\;1}E<".~Î D~;"j fi\;.'»I\.Ÿ.~' Ctjror'f:,";þ..,jH'..~ [ ( CATIONS AN IONS .--~.~-------.._....--_......--....~~~...---L........------.~~~. CI 1670 i 47.1 j Ion Na 1280 55.6 K 10.4 0.3 Ca 19.4 1.0 Mg 5.8 0.5 Sa 0.3 <0.1 Sr 2.8 <0.1 Fe 0.1 <0.1 B H+ HC031 2481 4.1 S04 I 53.41 1.1 C03] <1 i <0.1 OH I <11 <:0.1 I I ! H2S I ABSENT I ( ( ( r ( ( l ( ( ( ( ( C ( l ( ( ( ( ( ( ( 1 C.a Logarithmic Patterns of Dissolved Ions (meq/l) 10 1 Q1 . . 1~- Na" ,I ¡ , I , I CiI '::'" ~d¡ :. . . I . ..- ~--.t .- Mg"'"ì~ . , - ..,.......,_... - --- - ~.._..... .-,._---_. --...........-. ~ ~~ ~7¡;j'P.f~;;'Z:~;V~-"'"'''''''''' ¡~'~';:'i~;r;.~.~:.~:¡;..-......~m._........ '....._.............,.........._....~ .........-................-.................-- }~~~~~ ~~ ~D ---..-.......,....................... --......_u_....u_-............... {.\=1'.¡~"),; MH~WÆDL --- .J~¡,::;I~1.1 Tota! VisoofWd SoÌ1\1s fmg/LJ ..........._.........~.!.Q. .m_.......m_..~~_§Q- C..Ic"lawc Toril! SlISpei'1ded Solids {mg.'!..; -........-.......-...""'"''''''-''' 1.002 -~--~ 1.333 ---_._~ f (';ùrrvt> ~a;,ry ftè!I3i."1i'i'e fndeJi 6.8 -""-,,,,,,,,,,,,,,,,"'"'''''''''' 1.73 """",,,,,,,--,,,,""""....-.. O/!..,w<!d pH ti&l>~'1'W ¡n",¡ :(§2fj'( 72&__.__--- 20a 1:""<1: ¡.~~1f"Cir-P7i"S$ 11$ C.!/0'')~. (J;¡lf'U ! (-tal AJJ41iJ.'1ttÞ' A$ C¡¡G'O-"ji¡Jbt,t.1 _._--~ ~:l{ñQ!10f ~W'~4,¡ í),I,-, Gr"","" Ir.....'t.) ..................-................. '...n.................................. ro.~(f:t:t(fDt?-,tJ ,otal M" ("'wC .....----~._~-- ""$110 r>k 1~ 1~ 1~ -, CI " , ' j. :.: -+ :. ~. ...~:..,. HC03 : I ; I, I um :-_.¡-::_~ 504 C03 ~~(rM(!fBa.'n ¡:!1i~ ¡P¡~ffl!cr/Jtl>:'r'1>aI;<:A !€(f<J1JM!<)r f: 1.111 ,p¡t511í\1 s Fið'\JIls!~ìaIe O!W!Qikm;¡f(.slM Remilf!is: LPSEPARATORWATER Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 33 Oilphase-DBR Figure 3.4 BP Alaska Northstar Formation Water Collected at HP Separator Compositional Analysis M!!!Ç! "'___~n_~!¥!!~~._~.~~ GIaS$ NtA WATER ANALYSIS 02w28273--01 --""-'--"""-' ':::':,-tH:::("'io,/...i...v,l~t'~ .~~~(,..,'..i,r.L~\ :.:t'tlf!(--Ú. ?..;¡V,I :.r;: G'~rI! ~,,:1 ~;~ ~{:~,1 DÎ/"1\\.\'j:,~.t~ DBA Research Inc. ~---... (~\.:,r,"'\\"".\:.t;"j~ t.5t. }}''<''ij,'(. DBR RESEA RCH N/A DBR ,'>';:')1'1 çlt ';¡""i"ß\..:" DBR 2002.62JOB:20023132 -~----'------"._---_.'-"---_Ü_'_-- -- ---.,----_.- -- ~------- - -'---- "M_~_-.._._------_._-_.__._--- -- ~-----'~-'---'---~-------_.__...,----------,----~--------_._----_._"--,--_.~--_.~._-- --~-------_..~-- f"~''.1.~,:.':'','(.,,}' .'-:1;¡:::Yð)} ~~$~'&:':> l;'WI5'~' '~0~f h~0P(ut:,SI.nt.':'- ,óJ"''1i.->':f:<\<, ~M.;~ 2002/04/11 2002/04/11 CATIONS ANIONS Ion meqlL mcq/L Na 6390 278 238 K 42.3 1.1 22.4 Ca 87.0 4.4 504 154 3.2 Mg 12.4 1.0 C03 <1 <0.1 Sa 1.0 <0.1 OH <1 <0.1 Sr 13.0 0.3 H2S ABSENT Fe <0.1 <0.1 B H+ .-~--~--_.~.- - ----,_._---------~-- n..-J9;1!:.!Ç"'¡'t'IÕ H':~~ 1".'>:..0 :: \';-g:;:;IifI .\1.~ MtiIRWß.DL Toral DlssoÍ\"f:d Solids (1'19t1.) .._m--1.§_ZQQ T(ltill Svsperæd S<,lids (rog.ti 1.011 1.335 p.l.1$1:I!r.",....¡:.oDt'1.Mt)' fì~'~ S1~ k;.1e~ 7.6 0.403 ~~'t!';>t)l!¡'(.':Q' J)h fie$Ji!)iit.'i~~'- ~'. .)(i" .?!)25 '( --------g§§ .. --..-__--___DgQ f{1f;tJ ri-:l.m~~~ J1$ C~rt'.Új. Ó¡:!~d..I r oral Alk'aÍ!r:I_~"" A~ C"'CÚ:" Ùng.L; MoJtf:tf~'1<Jf{wr\); Olí tI. o,~.. {m¡,iL/ fO~¿1í ¡:(; {n:~~~,-~.) r(l'~¡M11¡' J'ff:"L, ð'''<;!~v}-t 104 Na . . 1C-J 102 LogarithmIc Patterns of Dissolved Ions (meq/l) 10 Q1 Mg _.... . I, I,"~ , 10 102 103 r'" " I I I I I - "--'!;T,' .-.-- ~..----.-, .-:-- '~';''-, :,"'" . , '" ' i,' .' . .' -.l. . ,.~' .:-,., . '.. ..'-. ...:: .... 104 , CI Ca _..... .". . +':-~'~ ~ -: '1'-:- HC03 .. .- 504 Fa - -.. -~ --- ..- CO'" 3 :jr.'(1œ{!am~~~'íid.;:a!e m~~di1r.f).'~-~t:rm,¡;f1:)'1 Wt'JftJr.;~;')t [I,Iß ,paslt<t; S rIØ,I:af.'ï.5. H~$dls:(~::r~ l'ft.'¡)'~tJ~;eUlsk~kù HPSEÞARATOR'NATER Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 34 Oilphase-DBR Table 4.1 BP Alaska Recombined Reservoir Fluid Well: NS-09, Fie"d: Alaska Northstar Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V ,=V fDlV sat Liquid Density (g/cm3) Compressibility Co (10"psï1) y- Function Value Psat Vr = a+ b exp(-P/c) a= 0.87315985 b= 0.66771594 c= 3063.5963 Y -Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P y= P(VNsat-1) Co= - d(lnVr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 35 Oilphase-DBR 2.90 2.70 2.50 2.30 CD E ~ 0 > CD > ;:; ftS CD a:: 2.10 1.90 1.70 Figure 4.1 B P Alaska Recom bined Reservoir Fluid Well: NS-09, Field: Alaska Northstar Constant Com position Expansion @ 254.5°F - - - ~ - - -; - - - ~ - - ~ - - - - - - ~ - - _: - - - ~ - - ~ - - - 1- - - ~ - - _: - - - ~ - - ~ - - -1- - - ~ - - ~ - - - L- - - -1 - - - I I I I I h-,--T--'--'------'--'1.05 -1---.1--- -.-1- 1 I I I I - - - I - - -,- - -, - -, - - - - - - 1 - - . 1 , 1 1 I' 1- -I ----1- - - -- --+ - - - 1- - - +- - --f - - - - - - + - - . 1 , I, 1 - - - ï - - -,- - - ï - -, - - - - - - ï - - . - u ~ - u:- - - ~ - ~ u - - ~ -,1.00 I ! I! I - - .- --+ - - -1- .- --j - - - - - - + - - . I I I ( I - - - ï - - -1- - - ï - - 1 - - - - - - ï - - . - --1--- t-- t - - - ..! - - _1- - - 1.. -.- 1 - - - - - - .! - - , I' I I I I I h - ~ - - -:- - - ~ - - -I - - - - - f u. 0.95 - - -I -- - -1-- - ¡- - .. -j -- - - - T h_Lul__-L__1 u___L- 4800 I I I I I - - - ï - - -1- - - r - - ï -.- - - - i - -- -1- - - r - - , - - - - - - T - - -1- - - r- - - ""'t - - - - - - r - - 1-- - I - - ï - - - I 1 'I 1 -..L-.......-.......L...__.......-..l--.. 1 1 I 1 I' I , I I I I I I I 1 I I I J ---,---1- -,- ,- --'--,---,---r- ,------T- -,---r--,------r---'-- - - - .1 - - -'- - - L - - ..J - - - - - J. - - -'- - - L - - .J - - - - - - .L - - -'- - - L - .1 - - - - - - L - - -' - - - '- - - J. - - - I I I I I I I I I I I I I - - - ì - - -1- - - T - - -, - - - - - ì - - -1- - - r - - ì - - - - - - T - - -I - - - r - - ì - - - - - - r - - -I - - - ,- - - i - - - - - - ..I - - .1- - L -..J -- J....I - . -- L. .J - - - - - - .L - - _I - - - L - ..I - L - - ..J - -- ,. - .. ~- .. - ¡ I ¡ I I I I I I I ¡ I ¡ 1 , 'I I' 1 1 1 1 'I I , - - - .1 - - -1- - - L - - ...J - - - - - J. - - -1- - - L - - ..J - - - - - - J. - - _I - - - L - - ..l - - - - - - L - - ..J - - - - - - J. - I I I I I I I I I I I I I I - - - 1 - .1. f -, j f I - - - - T - - -, - - - I - - 'I - - - - - f - - - - - - - - - -! - - -1- - ~ - - -1 - - - ~ - 4- - - ¡... - -I - - - - - - -!- - - .-1 - - - I- - - -1 - - - - - +- - - ~ - -- L- 1 I I 1 1 1 I 1 1 I I , - - - I - - -1- - - "I - - -I - - - - - ï - - - ï - - - - - - ï - - -1- - - 1- - - ï - - - - - - T - - -I - - - ,'- - - - - -- - 1 I I' 1 I I I 1 I I I I 1 I I 1 1 I I - - -~ I I -I --I "I - -I - - ï - - - - - - - - - I' - - .- ....¡ -.- 1- t- -+ I- + ~I ~- -+ - + 1 1 I 1 I I 1 1 1 1 ----i----I---ï- -- --ï--'--;------ï----I--- --,------ï------------- t t- + - -I f- - -4 t " , " , - - - -+ - - -1- - - t- - - --J - - - - - - -+ - t- - --t - - - - - + - - -I - - - I- - - -t - - - - - - + - - --: - - - - - - -t -- - - - - - J. - - _1- - - 1. - - _I - - - 1... - - J - - - - - - .!. - - _I - - - - - J - - - - - - 1.. - - - - - - '- - - - - - - 1 1 I ! I: I I 1 I 1 -t---"-1"-- ---¡-----t- t 1 1 _I 1 1 ~ L - J - I L - 1 I I 1 1 1 I I 1 1 I I t I 1 _u~u_'---~ -_:u_---~--_:_--' --~--_u_~u_:u-L Psat = 5095 psia. I 1 I 1 I 1 I I I 1 r'-I --- T --I í -- - - -- - T -- -I - -- -.- - ~ - ~'l' .- ---..1- _'__~L- .J - ~ -.1-__'___L- ------J.-__'___L- -_1._--'-------'--- , , I' I' 1 I" 1 , - - - i - - -1- - - ï - - 1- - - - - - T - - -1- - - r - - "1 - - - - T - - -I - - - r - - ì - - - - - - r - - -, - - - - - - i - - - I I _L__.._n____..__L__..__--i-.---...___-__L- 1 I I 1 --I - r - - ..I 1. , I Two Phase Data c I I ~ ! Single Phase Data I 1.50 1.30 1 .10 0.90 -...... 5000 5200 5400 1 1 1 I 1 1 - ,- r -~, 1 l - - - - .J - - _1- - - L - - -J - - - - - - J. - - _I - - - L - - .J - - --~--_I_--~____-_L- ,,:,,_--'---~--~-- 1 1 1 I I I I I 1 --J I J ¡ J 0 6000 8000 2000 4000 Pressure (psia) Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 36 Table 4.2 BP Alaska Recombined Reservoir Fluid Well: NS-08, Field: Alaska North Star Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V,=VtÞl'lsat Liquid Density (g/cm3) Compressibility Co (10"psï1) y- Function Value Psat Vr = a+ b exp(-P/c) a= 0.87904361 b= 0.66593913 c= 2865.8933 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(ln Vr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 37 Oilphase-DBR CD 2.50 E :J Õ 2.30 > CD > .. 2.10 cu "i ~ 1.90 Figure 4.2 BP Alaska Recombined Reservoir Fluid Well: NS-oS, Field: Alaska North Star Constant Composition Expansion @ 254.5°F 3.50 - Î - ~ ~ - r - - ~ ~I- T -: - - I ~ - ¡- ~ -1- ~ - ~ ~ - ~ ~ - ~ ~ - ~ -I - ~ -: - ~ -: - ~ -1- ~ -:- ~ -:- 4 -:- ; - ~ ~ - - -1 - .... -1 - +- - - ~ -1- + -1- - -1- + - i- --'.-~-I-j... -+--1-+-1-- ,-.,-1.05 -.J_'-.J_L L 1_'___'_.1_'- I I I I I I I I I I I I I I I I I I ---I-~- ï-¡-ï-¡---I-j-I- - --I - -I - I ï -I - T -1-' - -1- I -,-r--,-,-- r-,-r-'---'-T-'- -Î-t---1-~- r-I-'t--I---I-T-!- 1 I 1 1 1 1 1 1 1 - --I :..--..j L- -I - !. .-1 - - - I - j.. -.. i ,.- = j = L =: = ~ = = =:= t =:= = =:= i =:= 1.00 I I I I I! I I I --¡- -1-1--1 -¡-ï-¡---I-ï-r- 1 1 1 1 1 1 1 1 , -ï-:-ï-:---ï -¡-¡---¡-í-r- - - - ¡-- -j - t- - - +- 1- 'f- -1- - -1- + -:- --I-'--I-'---+- '-+_'---1-.1.-1- _.J .J_'--__L '_L_'_- .1_,- I I I I I I I --:-~ --~--~ --:-+-'-0.95 - -I - I - - - ï -! ï - -1- T -1- -, - ,- --, -, - -, -I ,-,- - -,- T -,- - Î - i"'- ï - - r -I r -1- - -1- T -¡- " 1 1 1 1 1 1 , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 - ...l - L ...l - ~ - - l.. -I .l.. -1- - -1- -J. _1- .J. - - J - '- -! - I- - - L ...J - L _I - - _i - J.. _! - -1.. - - J.. -1- 4. -1- - 1- -i - I- --I - _.J__.J-,-__L_'- _,_- .1-'_.1__...1_1_...1 '- __L.J-L -'___'_L_'_l-_l-I_.1_'- _L -'-....1- __1- _1_.:...__1 __1_1 J.__.J- .J_~--!..._I-L-I-- 1 1-- .2. _I_~ .J- - _I - _I - ~ - ~ - - 1 - ~ _! ~ ~ ...! - 1- - '- _I - 1 ~I ~ ~ - - _1- I__,~ - ...!- 1 I I 1 1 I 1 I 1 1 1 I 1 1 1 1 1 r 1 ¡ I, 1 I 1 1 1 1 I 1 1 II! I 1 I 1 r I 1 ¡ I I 1 1 I -j-'--'ï-r- r-I- -j---I-T-;-ì--ì-I-i-r--rì-r-:---I-r-'-T--T T -\ -t--I-~-,ï- - --1 - - --1 - ~ - - 1- -1- -]- - -1- -t' -!- ;- - - --t - - -t - r - - ¡- -1 t- -: - - -I - r -! - t- - - + -1- ;- -1- ~ - 1- - - r-. '"1 - --1 - -1 f- - - +- +- ,-. - - 1 - -I -I - - -I - 1- -I - f- - - f- -1 I- -: - - -, - +- -I- - - + - 1- -I - 1- ~ - 1- - 1- -I - ..J - L ..J - L - - .L _I_.L 1- - _1- ...L _1- .J.. - - ~ - L ...J - L - - L ~ - L -i - - _! - L -; - ..k - - -1- -1- ..l -1- ~ - 1- ....;. - L .J - I 'I 1 1 1 1 " I I 1 " 1 1 , 1 I " I , ' , ' 1 1 1 , I: 1 1 1 1 I I 1 1 I 1 I' 1 1 1 1 I ' 1 1 -~---I----T ~ -- --~- ~-~~-~--~ -,---~;--~--7 ~ ~-~~- - -I -. -I - I - - T I ,- ! - - I I-'ï 1- 1- - - - - I T - I I -; -- 1- ï - ',,'-, r T- --,-T-'-l--,-,-l-'I---¡-,-,-,--'-, [- [-r T, -,- ,-,- -,-;-, ,--,-,-,--, --'-T T --,-,-, r---,,-r r T--T ,-1- -,-;- ,--,- I :, 1 1 I 1 ,I' 1 1 1 1 1 1 1 1 "I" 1 1 1 I 1 - -! - J- --1 - +- - - +- -1- .. .... -I - -1- -+- - '- ~ - - -+ - ~ -+ - I- - - ~ --1 - t- -, - - _I - +- - - +- - - +- -1- -+ -1- - 1- .....;. - l- ~ - - -.J - - ,.J -.. -- - - L _I - 1. .1 J. - - J 1--, J I L_"J L - L 1 -L - 1- - 1- ~ ,-- L- .J - .J - '- -' - '- - - L -'- 1 _,- -'- 1. - - 1. - - -1 - ,- -1 - ,- - - ,- -' - L - - - -' - 1 - - 1 - - 1 -'- 1. _,- - ,- -' _,- -1 - 1 I I 1 I I 1 1 ) I 1 I 1 I 1 1 I 1 I - -I "1"1 - I 1 - ~ - ~ - )- I - 1- ~ ) t - 'I -, - I - - I ~ 1- 1- - 1- I 1 1 I) I I 1 1 1 I 1 1 1 1 1 I I 1 I I I --1-;--' ---, ,-,- ,-T-'-l "-1 r r --,-, T [-'-1-,- -,- -,-,- - Î - - --, - - - - r -1- r -1- - 1- ì -,- Î - - ï -1- Î r - - r --, - ¡- - - - - - ï -:- ¡- - - T -1- 'T -1- - ---I 1 - - t-! n +- --1- - - + - -+ 1- - - r -.: - f- - - - - - t- + - - + -1-' -+ - I - -I - - -! - - - - +- -1- .I- -1- - -I ...L - - .... . - - 4 - I- .J - ~ - - ~ -! - I- -; - - _: - ~ -= - J.. - - ~ -1- .... .. -I- I 1 I 1 I I I 1 1 1 1 ... . , _I - ~'- t -'- - _,- ~ ,= 1= = j =:= L := = - ~ =: - t -' = = ~ 1 1 1 1 1 1 I 1 I 1 1 I I 1 I I I , I --I-i-ì-~--ï-I-T - 1-1 --I-¡- -I---ï-I-I-:--l-:-T-,-ï--ï-I-¡-I- - -: - -I ~ ,- r r ~- 1".'--- I -- T - 1 - - ì - 1---1 f" r- r -- - -'¡ n. r-, T roof --~---II_,_- ~~:-~ I _-II_~_"_~- ~-:-~__~_I_~_~"_~- '~,_.:_+--,~. '~-:--~'-:..-- _..J-:""--l-.:..._-L_!_.J..._i---I-.l.-,-.... . -I---I-~_-L--l-L-:---! .I--'-.J...---1--I-.... ._I- - .~J- - L _I - 1. _1- - 1 .1- J - - L - - L L - --- . ' ~ L -; - .L - - 1 .1! - _:.... ---- __I_J._'- -_J- 1___1__1- -;___i-L-:_l_- 1 1 1 I I 1 I , 1 ; I I 1 1 I 1 1 I 1 1 1 1 - -! - :- -I - ï -' - f -I - T - I - ï - i - T - - ! - - ï - 1- ï - t- - - -I - - - - ï - - ï = : = - : -' - ; ~: ~ f ~:~ t =:- ~ = ,- ~ - = ~ =:= ~ = ~ = = ~ ~ - ~ -, - - - , -- T - - : =:= ~ -:- 3.30 I Two Phase Data 3.10 ,- ~ 2.90 2.70 Single Phase Data I 4000 5000 5500 - 4500 1.70 1.50 1.30 1.10 0.90 0 1000 2000 7000 3000 4000 5000 Pressure (psia) 6000 8000 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 38 Oilphase-DBR Table 4.3 BP Alaska Recombined Reservoir Fluid Well: NS-15, Field: Alaska North Star Constant Composition Expansion @ 254.5°F Pressure (psia) Liquid Volume % (%) Relative Volume V,=V tDI'I sat Liquid Density (g/cm3) Compressibility Co (10"psï1) y- Function Value Psat :'l00Q>i::~', '. .'1OQ;ôO;f,i¥i:1ß[~~;t:¡¡;"1J.'. "':~::i"',,:; ';.:'O~~'::.;?;~:~:~::'¡:,i,'j'î',\,: " 6500 100.00 0.947 0.574 21.4 1~:j\:';,~J9!3t;~J;J;,;i~;M::::;:A~~1Q.Qij0]j~~,;!Z;ll~{~iQ~1';::¿'~~Li~f::.{':;;{t¡;:,~~t~;~iE;;¿;it~i:¿iff~~:Ð",0~:~i :Þ;):i;}5(t'i~:"?:);:;,';;","'~ 5500 100.00 0.971 0.560 29.6 :~}\~'<~QQ!::/?'.,:~;: ':;\\" {1~oïli~~'}~~];:::;;ij¡$ij}' ::t;:~;Y~;~: ': :~]I~~~f::?:;;>? 'l¡:~::Zf,~:~~:;jH'?'~!i; ,:e\:0F/?':::" ,.., ." 5000 100.00 0.986 0.551 34.6 - . .',1"'" . 1.000 ' . '.0.544 . 38:7' 4600 95.33 1.003 2.902 4200 82.20 1.037 2.818 .' " ~~gi' " : '}~:;¡/'~:/;:;;:.;;t\:';}'D;;~:i~~: <" ':; ',;': ,,; '." '. ?"':i ' ", i¡;~;:~,. ,'. ::' '';-:,' t7'~~\,\::,;: . C" . , ,,,~~.8.tC;';'::;:~ ;1:'~,:;'~;:,':5;:i~'~,~". .;, \, "'~(.":' ,::,.,:',:>{,,,,,,,<,.,,, "',:', ,1,:~~~. Vr = a+ b exp(-P/c) a= 0.89097759 b= 0.5691499 c= 2805.7273 Y -Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P Y = P(VNsat - 1) Co= - d(ln Vr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 39 Oilphase-DBR CÞ E ::s Õ > CÞ > ~ ca ãi a: Figure 4.3 BP Alaska Recombined Reservoir Fluid Well: NS-15, Field: Alaska North Star Constant Composition Expansion @ 254.5°F 2.30 2.10 I I I I I I I - I -- ï -I - ï - - r -1- r -I- I I! I I I I - ..., - t- -I - t- - - +- -I - + -I- I I I I I I I ! - -i - I- -I I- - 1-"-1 - +- : I I I I I I I - ~ - ~ ~ ~ - - ~ -.-11- I I I I I I I I I I I I I I - _I - L _I - L - L _1- - _I- I I I I I I I I I \ -------~-- - I I I I I I , I I I I I I I - - - ï -I - ï - - I -I - ï -I- I I I I I I I 1-1-1- i-I-T -I- I I I I I I I I I I I I I I I I I I I I - ï - r -I - r - - r -I - Î - - I I I I I I I r- -[ t- t- --I - t- --I - I I I I I I I - -i - t- -I - +- - - +- -I - + -I- I I I I I I I - -- ~ -I - ¡,... - - L -I - l.. -I- I I I I I I I I I I I I I I I I I I I 1 - .J - L_I - L - -- L _I - L _1_. - I I I I I I 1 1 - ~ - ~ _1- L - -.!... _I_.!.- _I- I ) I I I I I I I I I I I ---1-1-1- i"-I- I I I I I I - I" -I I - I I - I - I I I I I I I I I I I I I I I I , - ~ - í -I - r - - T -I T ~ I- I I I I I - - -- r' .-1 t- - T' -I - t- I I I I I - -< - !- -I - +- - - +- -I - + -I- I I I I I I ~ ¡...- +--1-1--1- I I I I I I I I j: J I -:- ~ -:- 1.05 -I--r-I- I I I -1-. + I I I -I-~-I- I I I I I I I I I _1- 1 _1- _:_.l I 1.00 I I I I ï -I- I I I -,- I -I- I I I I I I I I I -:- ~ -:- 0.95 -1- .¡ I I I -1- + -I- I I I t I I I I I I I I t I -1- -L. -1- -L. - - .J. - 1- -l - - - - - -I - 1... -I - - -I - j.. -I - J... I I I I I I I I I I I I I I I I I I --....L 1 I I 1 I I I I 1 I I I I 1 I 1_1_~- J-_I- -1_____1 L-' __I_L_I_l I 1 I 1 I 1 lit I 1 1 I _1- ...!. _\_...!. - - J - 1- ...! - '- - - - _I - - _1- "- _1- 1.. _1- 1 ¡ 1 I 1 I 1 1 1 1 1 1 1 1 I I I I I ,I I I I I I-I I -I I ~ - - - -I -I -I ¡- i I 1 I ¡ I 1 I 1 I I - - I" I - ~ -I I - - -, -I I -I i ¡ I 1 I I I 1 1 I 1 ¡ I I 1 1 1 I 1 1 I I I I 1 1 1 I I 1 1 1 -1- I ~:- .., 1- 1 - -"1 1 I T r I 1 I 1 1 1 1 1 1- --j - ~ ---1 >-- -I - - -I -, r t- , I 1 I 1 I -+ - 1- --f - I- - ~ - .......¡ - - -I - - -I - ~ -I - + 1 1 1 1 I I 1 I j L 1 -- t I I I I I I I I 1.90 1.70 1.50 1.30 1.10 0.90 0 1000 I Two Phase Data I ! ~ 4000 4500 1 I I 1 1 1 I - -' - L _I - L - - L _1- 1. _I- I I 1 1 -I I I 1 - - - ~ _I - !... - - !..- ~ - 1 - I I I I I 1 - ~ - - 1 I I [ I I 1 1 I 1 - - - ï -1-: - - T -1- ï -I- I I I 1 1 : I I I I I I I I 1 1 1 I I I 1 1 I 1 1 1 I I ---ri r--T-I-T-I---¡-i-!-ì--ì-I-ì-'- I I I [ I I : 1 I 1 1 -...... - r -1- r - - ï -1- t" -1- --1- -r -¡- î - - -r - r-""1 - ~ - -:- 1 1 1 1 I 1 1 1 1 1 I I 1 r ~- ¡ ~I--+ I, + ~t ~ ~1 1--1 1 IlL 1 1 1 I 1 1 I' 1 1 I ---~-!-~-I-~-:-~-:-, -:-~-:-~--~-~~--1-~~-~-:- I I , , " "" I , , , , I Single Phase Data I 5000 5500 I I I I 1 .J.. - '- ... . -1- - - 1- ..J - I- -- - I I I I I I I I 1 I 1 I I ~ __1- ~ _1- - - 1- .J - 1- -' - 1 I 1 1 I I I 1. - '- 1 - - 1- ...! - 1- - - 1 1 I [ I 1 1 1 1 I ï ï -- 1- "I -- 1- - - I 1 I I I I 1- I 1- - ,.- 1 I 1 I I 1 I 1 1 [ 1 1 I 1 I r r ,- 1- - 1-- -,, r I 1 1 I -t- T --1--1 r- I 1 I 1 I + - - -+ - 1- - - 1- -t - I- -' - I I - L I I I I I ~ -- ~ I I I I I I - - 1- .J - '- -' - I I Psat = 4640 psia [ 2000 3000 4000 5000 Pressure (psia) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 40 I I 1 - - 1- I - 1- - - , 1 - I- I 6000 7000 8000 Oilphase-DBR Table 4.4 BP Alaska Recombined Reservoir Fluid, NS-09, 5100 psi a Psat Five-Stage Separator Test PROPERTY STAGE .1 STAGE '#2 STAGE IJ3 STAGEt4 STAGE tIS STAGEt6 Vap. Den (gIcm') . 0.044 . 0.020. 0-006. . 0.003..... 0.000 " :'üèi~~:.::n1!r-~~ ',;.~,,~:'~~~~\:::':~'~~' r'~' "'~~;~:~:,::~ff:~':F ':;ê';Ç.;~~~¡;.:>,;\,,-:::, ~';'<""~~~~f .:: ¡''','. '::'.: '.~~'.;: ~~;:~~~~~;s; ~:';~Æ~f¡~~~f.?f,~t~f~tf~~;;?~:~¡~f~~~~f4fT1'¡¡; ;fi~1~~~?§tJ{:P;'.?'1£:;;Y:~~Jf~~Y;~;:~1~:fr/;:(;:::;ó:~";.':,'. . :;,;;¡.:~~,.: 'ý,,; + ~""~i/:~'~:~~:i">~}" . ::. ~.~:t.:,;)/: \~. '.: ':,,-'~''''J~S: :.'::,,':':." .':"~>:¡ ':':" ,:,,;. Q,.. GOR 1650 106 103 59 0 ~;~":'i;~(_~~,~::}~:; :':i1;"~:';:"'1;m:;'.Y.'~:( :.;:- '\.~,: )Lt7t.~~:¡;~:t:&':';'-; ~.'::.::::'c':.f ;f16\ .:' ,;;:,.: ,."; .:;~:{0s9 "~':,,<:~ ',;:' " . :0.:1.000 '. -<'J.' .' ~ . - -.,;':"":" ~ ~"\.-.,¡"~~.:~':.~/" ~ ,~'~;:.)" . i~;': -°.1 :"..i. ! a) Calculated, at 6O'F (81",1) b) Calculated, Dry basis BTUfad c) ad gaalbbl of 011 at STO conditions d) ad gasfbbl of 011 at separator conditions e) fluid volume at sep conditionsf uid volume at STO conditions Residual oil density at standard conditions 0.821 gIcm' Sep gas gravity (average) S. '" ŒRtSg¡ŒR¡] Where: R: GOR (set gasfbbl of 011 at STD conditions), j: sepmator stages 0.815 Sep gas heating value (average) Lo . [IR¡*Lo¡lIR¡] Where: R: GOR (set gasfbbl of 011 at STD conditions), j: separator stages 1239 BTUlscf (dry basis) Shrinkage FVF rom first to second Sep conditions 0.943 1.060 From .econd to thlnl~ .~offliitlø... O.~ 1..~ From third to fourth Sep conditions 0.950 1.053 From fourth ,to fifth $ø, côrldlllona 0.944 1.060 From fifth to'sixth Sep conditions' . ii.IIif-1:J-U8J:a:IIIMM.:.'::'~ "t~~GO".. Separator STO Gravity bSepa~rFVF . .2388 41.0 2.4'4 a) scfgasfbbl of condensate at STO conditions b) Fluid volume at Psat & TresfFluid volume at STD J('U_'1~.r.'''l('I.-''Jn'U('II''i Pressure - psia Temperature - F Stage 1 750 160 Stage 2 325 157 Stage 3 70 157 Stage 4 20 157 Stage 5 15 60 Stage 6 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 41 Oilphase-DBR Table 4.5 BP Alaska Recombined Reservoir Fluid, NS-09, 5100 psia Psat Five-Stage Separator Test Vapor Composition 1 at Stage 2nd Stage 3rd Stage mole ". 4th Stage 5th Stage COMPONENT MW Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 42 Oilphase-DBR Table 4.5 Confd BP Alaska Recombined Reservoir Fluid, N5-09, 5100 psia Psat Five-Stage Separator Test Vapor & Residual Liquid Composition 6th Stage Vapor Residual Liquid COMPONENT MW mole % 2.31 2.93 'C-4 5 CYCL.( '.'".' '".,;'..,',,, ",., " ,""',"","'.,,,.c., ,',": ':'.f:", :,'"',,,;'ii.':,." ,"""""',''';'"":",,,,- "'.' "«' .,..",... .... ( r ( [ r ( :8 ( r ( ( L ( ( ( ( ( \.. Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 43 Oilphase-DBR Table 4.6 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13 , 4850 psia Psat CONSTANT COMPOSITION EXPANSION @ Tres (254.5°F) Pressure (psia) Liquid Volume % (%) Relative Volume V r=V tølV sat Liquid Density (g/cm3) Compressibility Co (10"psï1) y- Function Value Psat Vr = a+ b exp(-P/c) a= 0.88992846 b= 0.58080472 c= 2926.866 V-Function is only valid for Pressures < Psat Equations for the Relative Volume and Fluid Compressibility are only valid for Pressures> Psat P - psia Psat - P ¥= P(VNsat- 1) Co= - d(ln Vr) dP Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 44 Oilphase-DBR ~ 2.30 ~ Õ > CD > ~ «S a; D: 1 .80 Figure 4.4 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13 , 4850 psia Psat CONSTANT COMPOSITION EXPANSION @Tres (254.5°F) 3.30 ¡ : 1 ¡ I : 1.30 : ; : : I : ; : : ! : : : : ! : - _I - ~ _I - ~ - - ~ _I - ~ _I", 1_1- ~ _1- 1 05 ¡ I ¡ I I I I i I ¡ I . I ! I I I t I I I ¡ I 1 1 1 1 1 1 1 1 1 1 1.04 - --I-'-I-ï--ï-I-I-I-- '-1- : 1 1 1 1 I 1 Iii 1.03 - I I 1 I I I 1 I 1 I --I'-ï-:-ï--I-I-I-'-- '-1-1.02 ! I I I I I I I ! I I _...!_!..._1_!...__~_1_.!.._1___1_..!._1_1.01 - 1 I I I I ) I ) I I - : : :: :::::: 1.00 ~ : : :: 1::: ::: 0.99 ~ - -; - ~ -: - ~ - - ~ :- ~ -:- - -:- { -:- 0.98 ~ -_:_~_:_~--~ :_~_:--_:_~_:_0.97 ~ : : :: : :: ::: 0.96 ~ -~-~-:-~--~-: ~-:---:-~-:-0.95 :, I , 1 I 1 1 I I I' I --.1- L _1- L - - L' .L -1-- -1- LI- 4000 4500 5000 5500 6000 - ) I I I I I I J [ I I I , I I " I I' I I I" 1 I 1 I' 1 1 I I I I 1 I I I \ 1 t I I I I I ! I 1 I 1 I I' , I I 'I "1 I I I I' "I' I' 1 I 1 1 , 1 I I' I' 1 I 1 I I I 1 I 1 1 1 I I I I I I 1 I' I 'I" - -1-. I- -I - I- -- -- 4- -I - 4- -I - - - 1- -> - 1- -> - - ~- ,- ...¡ - I- - - I- -I - .- -I - -I - 4- -, - .¡. - .¡. - 1-. .. -- ,- -I -. e- ...¡ - I , I' "I' I I I I I' I I 1 I I I I I I 1 I I I 1 I 1 , 1 1 I " "I' I I I 1 I I I' I I I I 'I I 1 I' I' 'I I , - -j - I- -I - I- - - I- -,- I- 1- - -1- + -1- + - - -t - 1- -t - I- - - I- -j - I- -, - - -I - I- -1- + - - + -1- + -1- - - ,- -t - I- -t - 1 , 'I "I I" I 1 1 I I 1 I 'I I'" I I I' 'I I , 1 , I I 'I I I' I 1 1 I I' 1 1 'I I I I I I I 1 I "I 1 - -t - ¡- -I I- - - I- -1- +- -I - -1- + '-1- + - - -t - ,- -i ¡- - - ¡- -j ¡- -I - - -1- 1--1- +- - +-,- + -,- - 1- -t - r- -j - 1 I 1 I I I I' 1 I I 1 1 I I 1 I 1 I I I I I I I' 1 I I I I , 1 I 1 I I I I I I I I I I' I I I I " 'I I I I I I 1 'I I I - --¡ - 1"" -, - 1"" - - 1"" -1- 1- -I - -1- 'T -1- -i - - -i - ¡-- --1 - r- - - r- --¡ - r- -I - - -1- r -,- T - - T -,- 'T -1- - - ,- --1 - r- -i - I I I I 'I I 1 I' I I l' 1 I I I 'I I I I I I' I' '" I 1 , I I 'I I' I' 1 I I' I 1 I" I '" I "I' "I' I ! I I I ¡¡I ¡ I I I I ! I f 1 I t 1 I ! I I 1 J I ¡! I ¡ r I I I I t I I ¡ I I I I I I , 'I 'I I' I 1 I I I' I 1 I 1 'I '" 1 I I I 1 "I' - , - , -I - r - - r -1- T -,- - 1- T -,- T - - , - r , - r - - r , - r , - - -, - T -,- T - - T -1- T -,- - - 1- , - r , - 1 I 1 I I I I' I" I I' I 1 I 1 " I" I 1 1 I I , 1 1 1 , 'I "I' I' I I 1 I I I I " I I I I I I 1 1 "I I - 1- , -I - ,-- r T -,- - - T -1- T - ì - 1- ì - ,. - - ,. -I - , -I -- - -1- T -1- T - - T '-1- I -1-- - ..- 1- ì - ,- I - I , 'I I I 1 I I 1 I I I I 1 1 I I I I' I I I 1 I I I I 1 1 1 I 1 I I I I' I I I 1 1 1 I I 1 I 1 I 1 I 'I I I I 1 I 1 1 I - -I - ï -I - ï - - ï -1- T -1- - -1- -1-' - - ï - 1- ï - 1- - - I -I - I -, - - -1- 1 -1- 1 - - , -1- , -1- - - ,- ï - 1- ï - 1 , I' "I 1 1 I 1 "I I 'I" 1 1 'I 'I 1 1 "I' I I 1 I I I 1 I I I I 1 'I I I I I I I I I 'I I I 1 I I I 1 I - -: - : -: - : - -: -:- : -:- - -:- ¡ 1- ¡ - -; -:-: -:- - -: -: -: -: _1- -pl-Sl a-'-t'': _4'8-5'-51 -p'-s- 8.-a'- ï ï{ :.- I'll "II 1'1 1111 'II' - I!--+ I , 1 I 'I I' 1 1 I I 'I 1 I I' 1 1 ,. , . ,,' ,- I 1 I' "I 1 I 1 I' 'I' I I' 1 1 I'" "I 1 'I I , I 1 1 1 1 1 I' 1 1 'I I I I 'I 1 1 1 1 1 I 'I 1 I I' 1 , - -I - ï -I - ï - - ï -,- ï -1- - -,- ï -1- I' - - ï - - - ,- - - ï -, - Î -I - - -I - " -1- ï - - ï -,- ï -1- - - ,- ï - 1- I - 1 I I I I I I I I I I J I I ¡ I ! I I I I ¡! I I I I - _I - L. _I L. -- - 1- .-' - .!.. - .- '. - !. -' - - -' - 1- --1 - L. -' - 1- .!.. 1. - 1 1 -' 1- J I 1 l' 1 I' I I' I " 'I I 1 I I I I I , 1 I I' "I 'I 1 1 1 I I I' 1 1 I 1 I 1 1 I' 1 1 _-!_L L__l._'_.L __'_-'_I_-'__-1_I_-1_L__L:J I.L J. '_-'_I 1_-1_1_-1- 1 I , 1 I' I 1 I' I I 'I I I I 1 'I I 1 1 , I I I 1 1 I I 1 I 1 1 I I 1 1 I I I I I 1 I 1 1 , _J L.J_L__L_I_l_1 _'_J_I_J- J._LJ._l_- L_I_L-I_- J_'_J_I_¡_.I_..J__L.J- I 1 I' 1 1 I 1 I I 1 1 'I I' 1 I 1 1 , , I 1 1 I 1 , I I I I I I I I I I I I I I I I I I I I I I I I I I I J I ! I : I I Two Phase Data 2.80 ~ Single Phase Data I 0.80 0 2000 8000 3000 4000 5000 Pressure (psia) 6000 7000 1000 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 45 Oilphase-DBR TABLE 4.7 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F - LIQUID PHASE PROPERTIES GOR Data Pressure Cumulative Produced Solution Gas GOR (psia) GOR1 RS1 (scf/STB) (scflSTB) Calculated 011 Density (g/cm3) Liquid Data 011 FVF2 (bbIlSTB) 011 Viscosity (cp) Viscosity Ratio 01l/Gas3 . This step was peIfonned at room temperature Dead Oil Density at STD Conditions (60°F & 15.0 psia) 1Gas Volume @ STD I Residual Oil @ STD 280, Reservoir Oil Volume @ P,T per Unit Volume of Residual Oil @ STD 3Gas Viscosity Calculated from Lee et a!. correlation 0.829 gtcm3; 39.2°API TABLE 4.8 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F - VAPOR PHASE PROPERTIES Pressure (psla) Vapor Density (g/cm3) Vapor MW (g/gmol) Vapor Data Vapor Gravity1 (air=1) Z Facto~ Total Gas Total Two Phase FVF3 FVF' Co (bbl/mm set) (bbIlSTB) (10"psr1) Calculated Gas Viscosity6 (cp) . This step was peIfonned at room temperature 1 Vapor Phase MW IMW Air 2 Z=PV/nRT 3 BG, Reservoir Gas Volume @ P, T I Gas Volume @ STD 4 Sr. Oil FVF + [(Total liberated gas)' Gas FVF] 5 CD=-1/BD[(dBJdP)-BG(dR,/dP)] 6 Lee et a!. Correlation (Lee A., Gonzales M.H., Eakin BE, JPT, 997-1000, Aug., 1966) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 46 Oilphase-DBR Figure 4.5 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F 3000 2500 f ( ( ( [ ( ( ( ( ( l t ( " ( ( ( ( ( ( t ( ( ( ( ( ( 2000 - In t- tn ¡¡:: U fn - 0 1500 ;:¡ C'G 0:: Õ fn C'G C) 1000 :: I 1 I : I ! I I I I ! I J I I I I I - - ..J - - L - - - - '- - 1 - _1- - .L - _I - - L - - - - L - ..J - - L - ...1 - - - - .l. - _1- - L - _I - - - - ..J - - L - ..1 - - L - - I ' I I I I! J I I I I I 1 I I I I I I I I I , I I -I i ~ 1- I - 1- ï I" -] - - I - - - :- - I - . I I I I I I I! I I . I I I -; - - !- - - - -- - - ~ +- -¡ - - j-- - - - - - - -1 ~- 1- - 1- - - - - + - --1- - t- - -I - - - - --i - r -! - 1- - - 1 1 ¡ I I 1 I I I I 1 I I ¡ I I - - J - - 1- - - - - - - - - - 1 - - L - - - - L - .J - - 1- - 1 - - - - 1. - _1- - L - _1- - - - _I - - L. - J - - L - ~ 1 1 1 1 '" I I I I I 1 1 1 1 1 I I I I 1 I I I I I I , 1 I I I , ......- Produced I " 1 , 1 1 1 'I 1 1 1 1 - - ~ - ,- - -" - - ,- - - - -:- - ~ - -: - - ~ - - - - ~ - ~ - - ~ -8- Solution - -: - - - - ~ - - ~ - ~ - - , I I I ¡ I I I I I I I I ! I ! I I 1 - - ï - - ,- - -; - ï - -,- - ï - - - - ï - ï - - ,- - ï - - - - ï - -1- - ï - -,- - - - -, - - ï - ï - ,- - - 1 1 , 1 " '" I I" I 1 1 , 1 --I--+--'-'- ----- ----I- 1---1----+--1--+---1- --1 - -- -I -,--- I I I I I I I J I I I I I I I 1. - - L. - - 1- J 1- - J - - - -.1. _1- L.- -.' '-. - '- - - I "I I 1 I I 'I I 1 "I I I I I " , - .-. "I - , 1 __J__I__~ , , , , , I I I I I , I , , - - .J - -- 1- - - - -1-- .I.. - .-1-- L- I I 1 I I I " I I - - ï - ï -. -.- - ï - I I- I " I I I 1 I - - -I - - 1- - ~ - - i- - - - -1- - + - -I - - +- - - - - ~ - -I , I I 1 I I 'I -_J_- ---~----___I__l- _L- L... I I ' I I I , 1 I I" I , I , 1 --1--1--- I I I I 1- I - ,- - - I 1 I -1----1--1--- 1 , 1 .. '- - -' - - 1- - - , , I , , I " I , 1 I I I I I' 1 1..-..1--1--..1----.1 -1- .1..--1------1- 1 , 'I 1 I I 1 I I I I I I I 1 , ï - -1- -1- - - - ï -- -1- -I - -1- -- - -I- I I 1 I " I - -+ - - - - + - -1- - t- - -1- - - -.., I I I I , - .1. - _1- - 1 - _1- - - I I I I , I , 1 I 1 I 1 , 1 _1- - .I.. - -, 1 I 500 I I 1 I ¡ I I I ¡ I I I I I - - ...l - - L - ..1. - -'- - - - _1- - J... - -1- - L - - - - L - ....1 - - L - .J. - - - - 1. " . I 1 I 1 'I" 1 I I I I I ! I I I - - ï - .. ,- - ï - - -, - ,- ï - ,- -- ï - - - - ï - -I- I I , I I I I 1 I I I I I - - -j - -1- - -+ - - i- - - - -1- -- + - -1- - t- - - - - -- - -I - -1- - -I - - .. - + - - - + 1 1 , 1 I I I " I I I I " ' 1 I I " I 1 1 1 I --I--I--~-- -----I--ï- -j----¡--ï--¡--ï----- -,--¡--- , I I 1 , I I I I I I I I I I j I I I I 1 1 I 'I I I I I I I I I -.....1- 1....-'- ____I__1.....'_..L____L _..J.._'-- -___.1__1__1.__'- I I 1 I I' " I I 1 1 I 1 1 1 1 I' I I " I 'I I - - ï - - t- - ,. - -,- - - - -1- - T - -1- - I" - - - - I - ï ¡- - I - - - - ï - -1- - T - - - --I 1 I, I' " I 1 I 1 I I' I ---1- 1---+--:--- -1- + t- --1--1---+-----+----1'--+---1-----1- I I I I II! ¡ I r I I I I I - - -' - '- - .. 1 -- '- - - '- - J - - ,- - J - - - - .1. - _1- - 1 - I 1 I 1 , I I I I , I 1 'I " I I I 1 I 1 I 1 I I 'I I 1 I I I 1 I I , I I I I 1 I I 1 I I 1 'I I 1 - - .J - -- ,- - -' - - '- - - - _1- 1. - __1- -- L .. - - - I.. -. j -- - ,- .. ..I.. .. - .1 - _1- - 1. -. _1.- .. .. - -I - - I.. - - - 1- - - I I I I I I I I I I I I I I 1 , , I 1 1 " I I " I I I' I I , I - - I -. - 1- T - '-1 - . ï - - - 1- ï - ,- I - - - - ï - -, - r --I ---, -- ¡- - I - 1- .. - I I, I" I I I I I I I I I I I I I - - -j - - 1- - -+ - '- - - - -1- - 4- - -, - - ¡.. - - - - I-- - -j - - I- - -+ - - - - + - -1- - . - - -I - - - - -I - - I-- - -! - 1- - - 1 1 I 1 I 1 'I I 1 1 1 I 1 '" J - - 1 -- !... - - - - '- J - 1- - -' - - - - .!. - _1- - .!... - - -- - _I - - '- - -' - - 1 , I 1 1 I I I I 1 I 1 ~ ~ ! ~ )! !!! ! ~ ! I I I I ----1-_1.._-1__1__- I 1 I I , 1 1 , I -I - - - - -, .. - ,- ï - 1- - - 1 '" 1 -I - - - - .., - - -- - -I - - 1- - - 1 'I I 1 ____1__'-_-'__1__- , I I I I 1 I , I , I , 1 .. L ..I L .. .. , 1 1 1 , 1 -I-ï--I--- 1 I I I- -I - - I~ 1 1 - J - - '- - - , I , 1 0 0 2000 3000 Pressure (psia) 5000 4000 1000 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 47 Oilphase-DBR FIGURE 4.6 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL liBERATION TEST @ 254.5°F- liQUID PHASE PROPERTIES - ('I) E ~ 0.80 .9 ~ .~ 0.70 Q) 0 "C .S 0.60 C'" ::¡ 0.90 0.50 T - -, 1- r T -,- - r T -,- r -, -,- r T - - r ¡- , -,- - ~ -,- r ¡- - -,- r T -,- - r -; -,- r - , -,- r , - - r ¡- , -,- -t -, - ,- +- - -1- r- -t --1 - - ¡- -t -, - r- - -¡ -,- r- -t - - r- t- -¡ -,- - - -, - r-- t- - -,- r- -t -I - - ¡- - -,- r- - -¡ -,- ¡- -t - - r- t- -¡ -1- + - I~ ~ - -I.~ I- + -I - - t-. -+ -I ~ I- - -f -1- f- -+ - - f.-.. t- -, -1- - -t -I - 1-" +- -1- I- -+ -J - - - ~ -"I -.. ~- - --i -1.- \- --+ - I-- \. -1 ..L -, - 1- L. - -I - L ..J.. -I - - L- .J. -1- L - ..J -1- L .1 - - L L ..1 -1- - ..¡ _I - L l. - -1- L ..L _I - - L ...l _1- L - ...J _1- L J - - L L ..J -I- I I! I I I I I I I I I I I I I -.1 .-' -'- -,- L J. -,- - L .1 -.,- L - ...1 -,- L J. - - L L ...1 -'- - J. -,- ,- L - -,- L.1 -'- - L -'- L - ...1 .-'- L...1 - - L L ...1 J I I ¡ I I I I I I I I I I I I I I I I I I I I I I -~--~-- --I--~~ ~-~ ~~--~~~ -- ~~- ~~ -~- ~-~ ¡~--~T~ - I - I - 1- ;- - 1- ï - - I I - 1-- Î I I - - 1- I ,-- I' - 1- I - - I - I - --I I ( -- - 1- ï I - T -, - 1- I - -1- 1- T -I - - I 1- - ï -1- ï I - - 1- ï I -1- - - -I - 1- I - -1- r T -I - - r ~ -1- r - ï -1- r I - - 1- ï ï -1- , " , , 1 1 I' 1 1 I' 1 1 '" 1 I I, I' , 1 1 1 1 1 -T--I-'- -,-rT-'--¡-T-,-r ,--¡-T--r'¡-,-I- -'-r¡-- rT-' -¡--;-,-r--,'-,-¡-,--r¡-,-,- - Î - 1- - -I -- r i -I .- - r Î -I - r' -1 .-. I - t- "'i -I - - t- ---I - r- - '1 -. 1-" 1- -t -- r-'r---1 - T 1- :- - -I - t-t'-I - - r --t ~ 1 -, r---1 .~ I." t.. -t - - t- t- -t - - - r r - -I - r 1" -I -- - t- -r r' - '-1 - 1-- -- -t .- -- r- t- -I - 1 - - .+ -¡ - 1- - - -1- ~ .+ -I - - I- ...J. -1- I- - -4 -1- I- ...J. - - i- +- -4 -1- - .... -I - ~ ~ - - - I- ..... -1- I- - -I -1- I- -+ - - I- . ... -I -I- I I I I I 1 I 1 1 I I I I 1 1 'ii 1 I - ..1 _I - 1- i.. - _1- L ..1. .-J - - L ..1 _1- L - .J -1- L ..1 - - L L -L _1- - ~ _I - L L - _1- L ..1 _I - - L .J _1- ~ _1- L ...1 - - L L .J _1- - 1- _1- - _1_1- ,1 _1- - L 1_1_1- - J __1- L 1 - _1- L J _1- -. ,- _1_1- L - _I_!.... 1 ,_1- -- L.J __1_1- J _I-!.... 1_1 J ._1- I I. 1 1 1 1 1 1 1 1 1 J 1 t t 1 I ¡ 1 1 1 1 1 I 1 I II! 1 lit I - ï - - 1- - - -I - t- ï -I - - ï ï -1- 1- - ï -¡- ï I" - - 1- II -1- - - -1- 1- ï - -1- j ï -I - - ï ~ -1- 1- ï -1- ï ï - - t- 1 1 - ï -¡ - 1- ;- - -1- f ï -I - - f 1 -I - f - ¡ -1- 11 --.- I 1 -1- - ¡ -I - 1- I - -1- f 1 -I - Ii -1- f - - - - - - - - - - - - 0 500 4500 5000 1000 1500 2000 2500 3000 3500 4000 3.0 I I I I I I I 1 I , I I I I I I ---I--i--I--T----ï- -ï--I-----j- -ï- --+-- -ï--'---¡-----I--T--I--¡-- :=:J::::::ï:::::::,::::::1:::::::::::::::¡::: :::::¡::::::L:::::::::::::ï:::: :::1:::: :::t::: =j-:::L:::::J:::::: = =:::1= =:¡:::: =,==:¡:=::: --~--~--:--~----~- , -~--~----~- 1 -~- 1 -{- 1 -~--~-~-----:--~--:--~-- -1- I- -I--r--- -t--I---¡ -r--.- ¡---,- r- -I---¡--I-.--I ---'-1- '¡---I-- ~I - - r -'1 _. - Î - - - - -¡ -- 1- -1- r - - - -- r - -I T -- -1- -- -r - - 1-- ì - - r - -, - - - '-1 T ~ -1- - 2.2 - - :::::::::: F - ::: F ::: ::: ::: ::: F ~ -- - - - F - - F ::: - + ::: - F ::: F ::: ~::: ::: .:: - ::: F::: -, - ~ ::: ::: - - ~ - - L - _1- - .L - - - - J. - _1- - .J - - L - - - - L - _1- - .L - _1- - l - _1- - ...1 - - L - ..J - - - - -,- - _1- - J. - - . - -1 - - ¡.. - _1- - J.. - - - - ...J. - - 1- - ..J - - L - - - - J.... - -1 - - J.. - -1- - ~ - -1- - J - - L- - -1 - - - - - - -1- - ..J.. - - . - --I - - +- - - + - - - - -+ - - 1- - ..., - - f- - - - - ~ - -I - - + - -1- - + - - 1- - -+ - - f- - --I - -I - - ~ - -1- - + - - LI..> 1.8 - - -j - - t- - -,- - T - - - - -r - -,- - ., - - ,. - - - - ,.. - -,- - T - -1- - i - -1- - ., - - r - - - -,- - r - -1- - T - - LI.. ---:--~- -+----~- -~--'~--~~-~--- --:--+- -:-- -- õ ::: ~Lr---~~-:-->--¡<--L~+-~~-.--H--¡-~ m 2.6 I- en - ::c e. ã: ~ ~ .(ñ 0 0 U) :> "0 .S C'" ::¡ 0 5000 1000 2000 3000 4000 0.5 ---:--~- -í- --~--:-_~__I ----~--;--T -:---~-;--~--~_.~-~~--;--~--:--~-- : := =, = = L = = 1: = = = = ::¡ = = 1= = J = - = = = = = = =: = = 1: ::: :::'::: ::: ::: ::: ::: I::: ::: ::¡ ::: ::: L ::: J ::: ::: ::: ::: :::1::: ::: L ::: :::1::: ::: 1: ::: ::: ::: ¡ - ~- -l~_:- -l- - ~: ~~ ~:~TI~l_=:= :_--~-~ - _l: ~ -- ~ :~:~ - [: ~::: !~; - - -I - - ~ - -1- - +- - - - - -+ - -1- - -I - - f- - - - - .L - -I - - + - -1- - - - 1- - -+ - - ~ - -t - - - - -1- - +- - -1- - + - - - - -, - - r - -1- - r - - - - ., - - ,- - ., - - ,- - - - - - - -, - - ï - -1- - - - - r - r - ., - - - - -I - - ¡- - -,- - T - - 0.2 - - ,- -¡ -::)- - - -~: -:::~: -:; - --:;'-I-'--~~-:- j -:~ - ~ ~- 0.. 1 I 1 1 I 1 1 I I I 1 -r----r--- - r ~- -"I T - - - - ì 1 I - -I - í - 1- -r ~ - r - ì ~ - ~ I r T - - ::: ::: L ::: :::'::: ::: 1: = ::: ::: ::: ::¡ ::: ::: '::: ::: ::! ::: ::: ,= = ::: ::: ::: ::: ::: ::: ::: ::: 1: ::: ::: :: :: :: '::: ::: ::¡ ::: :: L ::: ::! ::: - ::: = ='::: ::: L :: :: I :: :: - - L - -,- - L - - - - -l - _1- - --l - - L - - - - L - -, - - .L - - - - - ,- - -l - - L - ...1- - - - -1- - L - - .L I . I I I I .. I' I I I I I I I I I 0.0 0 1000 5000 2000 3000 4000 Pressure (psia) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 48 Oilphase-DBR FIGURE 4.7 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F - VAPOR PHASE PROPERTIES - C") E u Š 0.30 0.40 :: ~=: =:= r : ~ =: =:= = :; -: -:- ~ : ~ -; -:- = = ~ =: =:= t : ~ =: =:= = - ~ =: = = = i = =: =:= ~ i ~ _: _:= = i'~ : - := i I I I I j I I I I I I I I I I I I I I t I I -Ti -Ii -I--'T.I--I--II -ï-t-I-I--- --ï- I---T-I-I-- 1-:-i-j- "III, IIII 1-r--t---t~1111 III1III II 111 II ¡.'-r-r-----t- - l. .J _i _1- - l. .J _I - 1- - l. .J _,_,- - l. .J _i - ,- - .:. .J _, - ,- - 1. .J _,- ,- - - .J _1- '- - 1. - _1- 1 .J _1- 1- - 1. .J _,- 1- ~ : ,- j =: =:= = ~ j =: =:= = ~ j =: =:= = ~ j =: =:= = = j -1- 1- = ~ j =: =:= = ~ j =: - ,- - ~ = -: - := : i j =: =:= = i j =: = := ~ 0.20 I!I I f I I 1 I I! ¡) j , I ) 1 I I I I I ' I I I I I I! I' I , ~ : t ~ -, - 1- = t ~ =: =:= = t ~ -I - 1- = t ~ -I - ,- - , ~ =: =:- - ~ ~ =: -:= = i ~ -,- ,- = t : -1- 1- t ~ =: =:= = t ~ =: = := ... - + -I -I -1- - + -I -I - 1- - + -I -I -1- - + -I -I -1- - -I - 1- - + -j -1- 1- - + -1-1- ,- - + - .-1 - 1- + -I -1- 1- + -j -I - I- S. 0.10 .: : :: :::: ::: I ::: 1 ::::::: I::: :;:: :::: :::: ca -Tï-I-I--Tï-I-I---- 1- Tï-I-I--Tï-I-I--Tï-I-I--Tï-I-I--Ti-I-I- lï-I-I--II-I-I- > : : : =: -1- - T .J _I _1- = : : =:=:= :: =: =:= = = : :: =:= = : : ::::: = = : =: = :: = : : =:: := :: =: =:= = : : =: = := ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ 0.00 [ ( 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 ( r ( ( ( ( ( (: ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ( ~ 'S; ! C) ... 0 Q, ca > 1.3 I I I I I I I I I I j ! I I ¡ l I I I ¡ I I I I I 1 : ¡, ¡ I I I I I I I I I - + -j -I -1- - + -j -I -1- - + -+ -I -1- - + -+ -I - 1- - -'- -+ -1- 1- - + --I -1- 1- - + --I -1- 1- - + -< -1- 1- - + --I -1- 1- - + --I -1- 1- 1.2 :::: :::: :::: :::: ,::: :::: ;::: :::: I : : :: : :: . ï ï -I -1- - ï ï -I - 1- - ï ï -I - 1- - ï ï -1- 1- - , ï -I - 1- - ï 1 -I - 1- - ï ï -I - 1- - ï ï -1- 1- - ï ï -1- 1- - 1 -1- 1- 1.1 - I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 .J -I -1- - 1. .J _I _1- - 1. .J _I _1- - 1. .J -1- 1- - l..J -1- 1- - 1. .J -1- 1- - 1. .J -1- 1- - .L .J -1- 1- - J..J - - - J. .J -1- 1- 1.0 .: 1 1 1 :::: :::: :::: :::: :::: :::: :! 1 1 1 1 :: :::: . T ì -I -1- - -1-1- - T ì -1-1-- - T ì -1-1- - T ì -1-1- - T ì -1- 1- - T ì -1- ,- - -1-1- r T ì -1- 1- - T ì -1- 1- 0.9 1 1 1 1 1 1 1 1 1 1 I 1 1 Iii 1 1 1 I 1 1 1 ' , 1 ill: 1 I 1 1 1 1 I 1 - 1. .J _I _1- - 1. .J _I _,- ~ 1. .J _1- 1- - -'- .J _I _I~ - 1. .J _1- 1- - 1. .J _1- 1- L 1. .J _1- 1- - 1. .J 0.8 ' : : :: :::: ::: 1 :::: ;:::::::::::::: I : : :: :: 1 1 . t- -I -1-1- - t- -t -I - 1- - t- -t -I -1- -. T -t -1-- 1- -- 'r-j -1- 1- - t- -t -1- 1- - T -t -1- 1- - T ..., -1- 1- T -t -1- 1- - t- -t -1- 1- 0.7 .. I ¡ I I I I I I I I I I I I I I I I I I I I I II! I I I I I I I I I j I I 1 1 1 1 I 1 1 1 1 1 I 1 1 1 1 'I 1 1 I I 1 1 1 1 1 1 0.6 ::: I I ::-:-:--:: I I -:: I ¡ -:: I I -T: I :--:: I 1-: 1--:-:- ::-:-:--:: 1:- - + -+ -I -1- - + -+ -I - 1- - + -+ -I -1- - + -+ -1- 1- - .I- -+ -1- 1- - + --I -1- 1- - + --I -1- 1- - + -' -1- 1- + --I -1- 1- - + --I -1- 1- 0..5 .... ì. ì. . ì .. ... ì . ì .. . i ., i" I ,. ì. .,., ì'" 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 1.05 " I 1 " ' " , I I ' " I , , , , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I ' I I 1 1 1 1 I 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ~ 1.00 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 0 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 - 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 U 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 I 1 I I 1 1 I ca I 1 I 1 1 I 1 I 1 1 1 1 1 1 1 1 1 I 1 I 1 I 1 I La. 1 I 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 N 0.95 - 1 I I I 1 1 1 1 1 1 I 1 1 1 1 I 1 I I 1 I 1 1 1 I 1 1 I 1 I 1 1 1 1 1 1 I 1 1 1 I I ! I 1 , , 1 1 ... I I 1 1 1 1 1 1 I 1 1 I 1 1 1 I 1 I 1 I I I 1 I 1 0 1 I I 1 1 ! 1 1 1 1 1 1 I 1 1 I I 1 I 1 I , 1 1 I Q, 1 1 1 1 1 1 1 1 1 1 1 ' I 1 1 1 1 1 1 I 1 I 1 1 I ca 0.90 . 1 1 1 1 I 1 1 1 1 1 I 1 I 1 1 1 1 1 1 1 I I 1 I , 1 > 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 I 1 I 1 I 1 1 1 1 I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 I 1 1 I 1 1 1 1 1 1 1 1 I 1 I 1 1 I 1 1 111" 1 1 ! III I I 1 1 1 0.85 "" ... I . I I I '" I . I . . I ... I . I I I. I'" 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 Pressure (psia) Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 49 Oilphase-DBR TABLE 4.9 BP Alaska Recombined Reservoir Fluid, NS-G9 + NS-13, 4850 psia Psat VISCOSITY DATA @ Tres (254.5°F) Pressure (psia) Liquid Viscosity (cp) Status $i"gl~..Rþ~.t.;igIJIØ. Single Phase Liquid '~~polåbKI Psat , .~ 5.5ØQ, 5175 '.0', ; O;t~8.' 0.135 Ø~131'. . Psat 4855 ., .;¡,.: 0.131 :0i'>"<Ói(1ái . 0.156 . ,Ql~$Z.> .: 0.235 :~Q;~øø' 1 " F.,:-.;:'>-":-: ;--'~;-:/:-: Extrapolated }~;fi9m;Q~j1t4J;S;;2èf:' Liqui~ fro,':'1. D~).est ,~:~Jqy~,;tïQmi~4,r~st. . Liqui~from DL ,.est .,..~¡g&;ìtQ'Ø9m'ptI~.(?:~.' " . -.',,-".;-:..' , ~....~::..' Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 50 Oilphase-DBR Figure 4.8 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat OIL VISCOSITY @ Tres (254.5°F) ( ( ( ( ( r (, ( ( ( t ( ( ( ( ( ( ( r ( ( ( ( ( ( ( ( ( ( ( ( l Q: ~ ~ 0.3 u¡ 0 Co) II) :;: 'a 0.2 'S C" :::¡ 0.5 = ~ = ~ ~ =:= 1 =:= ~ =: = ~ =1 = ~ =' = ~ ~ = [ ~ = ~ ~ = := = =:= = = = ~ =1 = ~ =: = ~ ~ = ~ = ~ i = ~ = = := i =:= ~ =1 = ~ =: = = _: - = ~ = ~ ~ = ~ ~ = : = = i =:= 1 =:= : =' = : = = = =: = : : = = : = ~ i =:= = =:= = = = : = = = =: = : : = : = ~ i = : = =:= : =:= = = = : =: = = =: = = : = ~ : = = ~ 0 1 I I I ~ I I I I I I I I I I I I I I 111 I I I \ 11 I \ I I ) I! I 1 .4 -~-~~-' --:~-~ -~-: ~~u~ ~~-:--' ---~--~-:-~-: ~-~~-:u-:-~' ~- ~-:---:u-:-~~: - 1- - -!.. _I L - _. J - 1- J - 1- - ~ - - l L _I .- - J - 1- J - J- - J. 1. - -. .!... _I - - _I - - _I - ~ ' I I I I I I I I I I I I I I I I I j I I I I I I I I I -"'--11-1-- T-I-T--r --rî--i-ri-I---I-'-:-'T -ï- -r-'--ï--r"'-'I-'--I-¡-I-T- r -I --i-r-,-'I- - --1 - L .J - \- - __1- ..1. _1- 1. - - 1.-1 -- L - - -.J - L .J - 1- - - 1_- ..:. -' - 1. - 1.. _I - L -I - - ..J - L ..J - 1- - - L ..1 - 1- 1.. - - 1. ~- --I - - -.J - L --1 1_.- I I I ¡ \ I I I I I I ¡ I I I I ¡ I I I I I I I I ! I I I I I I I I ¡ I I I I I I! I I I I I I I I ¡ I I I I I I I I I I I I I I I I I I I I I - -I -- r- -t - -1- + -1- +- - - +- -I - t- -1- - - - I- -t - - ~ 1- ..... -,- + - - + -1- t- -1 -- - -i - r -i - 1- - -t t- .- - +- -J ~ ~ -I ~ ~ -1 r.. --I .- 1- - _J I_J -1-1_I_l- 1.._1 L~I _.J_LJ- __I l__l_I_L_I__J_LJ_I___I_l_I_.l.- 1 -_I___!_l.J I_- I 1 1 J! I! 1 1 1 I 1 ¡ I I, ~ 1 1 1 1 I 1 1 1 1 ) 1 t I 1 1 I 1 I I - -, - ,- ì - ,- - -,- T -,- T - - , -, - r -, - - -, - r ,- ,- - - ,- T -, - - , -1- , , - - , - , , - ,- - -,- T -,- T - - , -,- r -, - - ì r ì - ,- - - ...j - ~ -I - ,- - - ,- ... -1- ... - - ... -I - I- .-! - - ...j - ~ -I - 1- - - 1- ..;. -' - ... - - -I - I- .-! - - ...j - ~ -I - ~ - - 1- -I -1- ... - - .¡.. -I - - -I - - ...j - ~ ...j - I- - , 1 I' 'I I' "I 1 I'" " 1 1 1 1 1 1 'I' 1 'I." I" 1 1 1 1 I 1 1 1 1 1 II! I J 1 1 I I 1 1 I 1 I 1 1 1 1 1 I 1 I 1 1 1 I I I - ., - Î ï - 1- - -J- T -1- Î - - 1"" -I - 1'"" .., - - ., - ï ï - 1- - -1- ~ -,- T - - r -1- r ï - - ï -r - r- - - 1- ï -1- T - - Î -1- i -I - - ï - r- ., - ï - - .J - 1- .1 - '- - _1- .L _1- 1. - - 1- _I - L .J - - .J - L ..J - '- - -'- .L -- 1. - - 1- _1- L -, - - .J - L - -'- J. _1- .L - - 1- -'- .L _I - - .J - L ..J - L - , 1 'I I'" 1 1 " 'I" ,¡ 1 "" 'I 1 I"" 1 1 '" 1 - ï - 1- ï -1- - -,- T -,- T - - I -I - ¡ -, - - ï - ,- ï - 1- - -1- T -,- T - - I -1- ¡ -, - - ï - ï ï - 1- - -, -''iT - - ïl - ;- -, -, - ï ï - ,- - - ...j - ~ -I -1- - -,- + -1- + - - ;.. -I - ¡.. ...j - - ...j - I- -I - 1- - -,- + -,- ... - - ;.. -,- ¡.. ...j - - -I - ~ -I - I- - -,- + -1- ... - - ;.. -,- ... -, - - ...j - I- -I - I- - 1 I I 1 1 1 I I I 1 II! 1 I 1 I I 1 I I I ! ) I I ¡ I 1 I 1 I Iii 1 I! I 1 I I I I II! 1 ¡ 1 ¡ 1 I J I I 1 I I 1 II! ¡ I I I I I I 1 I I 1 I 1 I! I I --'-,,-'---'-T T --,-,-,-,-- ,-'" '----'-T-'-T--', r,--,-" ,-- '--'-'-'T--,-'- -, --l--r-l-'-- -...J-I--1-I---I-..J.-!-..L--.i._. 1.....1- -1-I--!-I- -1-..4.- J. -.L-I-L--!---I-.I-..J.-!-.--I--1.-I-J.- ~l.--I L--I---I-I-.j l- I I ) 1 I I ¡ I I 1 ! 1 1 I I II! I I 1 I I 1 I 1 I ¡ I -1-1-1-'-'--'-1-'-' -'-'-¡-'--I-,-ï--,-- ,-,-T--T-'-¡-'---'-'-I-'---'-I -, --,-ï- ï - --j - I- --j - ,- - -1- -j- -,- + - - + -, .- ¡- -j - - --j - I- -¡ - ,- - -1-'" -,- + - - + -,- ¡- -, - - -j -- ¡- --j -- I- - - ,- -j- -,- -j- - +-, - + -I - - -j - I- --j - r' - 0.0 "" 'I' I "" "" "" I 1 I' "" I' I' "i' "I' 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Pressure (psia) 0.1 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 51 Oilphase-DBR Table 4.10 BP Alaska Recombined Reservoir Fluid, NS-D9 + NS-13, 4850 psia Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F Produced Vapor Composition 1 st Stage 2nd Stage 3rd Stage mole % 4th Stage 5th Stage COMPONENT MW 16 )4 E E I '2.' 7~,.48 ',. :VCL-C6 8 O. i ,- .,..- VVI ....... 06.17 ).( H o.~ . - }.~ 0, " 16 0.2: o. 12 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 52 Oilphase-DBR Table 4.10 (Continued) BP Alaska Recombined Reservoir Fluid, NS-09 + N5-13, 4850 psla Psat DIFFERENTIAL LIBERATION TEST @ 254.5°F Produced Vapor & Residual 011 Compositions COMPONENT MW 6th Stage mole % 7th Stage Residual Uquid mole 'Yo [ ( ( ( [ ( ( r ( ( [ t [ [ r C:!3 C 0 C:!5 ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 53 Oilphase-DBR Table 4.11 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat Five-Stage Separator Test PROPERTY STAGE #1 STAGE #2 STAGE #3 STAGE #4 STAGE #5 STAGE #6 a) Calculated. at60°F (air=1) b) Calculated. Dry basis BTU/set c) set gaslbbl of oil at STD conditions d) set gaslbbl of oil al separator conditions e) fluid volume al sep conditionslfluid volume at STD conditions Residual oil density at standard conditions 0.817 g/cm' Sep gas gravity (average) SII '"' ŒRtSIIIŒR¡J Where: R: GOR (set gaslbbl of oil at SID condilions), j: separator stages 0.823 Sep gas heating value (average) L" = ŒR¡*L,,¡ŒR¡] Where: R: GOR (set gaslbbl of oil at SID conditions), j: separator stages 1254 BTU/scf (dry basis) Shrinkage FVF From Psat & Tres to first Sep conditions From first to second Sep conditions From second to third Sep conditions From third to fourth Sep conditions From fourth to fifth Sep conditions From fifth to sixth Sep conditions 0.549 0.948 0.951 0.950 0.960 1.822 1.055 1.051 1.053 1.042 .:t~:I.::.':J'.:.' (.J:-=tIJ.~II!'¡r.::.':\" a) set gaslbbl of condensate at STD conditions b) Fluid volume at Psat & T resJFluid volume at SID Ir.}(_~..~r.I"'('I.~.OImrl.m. Pressure - psia Temperature - F Stage 1 750 160 Stage 2 325 157 Stage 3 70 157 Stage 4 20 157 Stage 5 15 60 Stage 6 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 54 Oilphase-DBR Table 4.12 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat Flve-Stage Separator Test Vapor Composition 1 at Stage 2nd Stage 3rd Stage mole % 4th Stage 5th Stage COMPONENT MW CO2 .Ò,oo. .~ '6:35:h.r¿SJti~ . .'7;30'" " .f24 .' . 0.00 ' H2S 0.00 0.00 . 0.00 0.00 0.00 0.00 N2 ,0.00 " 0;84 OÀ1(M1 0.14 . ,0.00 C1 0.00 76.55 67.68 37.83 11.91 0.00 C2 ',O;Oô .,8:20 ., .12;Ò4 ,i18:98' 13~12 :0.00 C3 0.00 .Ù87.34' 18.84 26.81 0.00 10C4 . . x;Ò.oO': ;;Ò.$J'\' ,:~ 1JtÔ3:42" 777.11 ' '\ 0:00: " N.c4 0.00 1.37 2:18 iÛ 17.28 Ò.OO icvc-cs " 0.00 '0.05 " 0.05 ' 0.20 ,', 0:68 '0:00' ~~"E!,,", 0.00 0.02 'O.O~ 0.08 '0;25' 0:00 èŸcL~6' , 0~00..0.06 , °;05 , 0;19. O.¥ . 0;00... C7 .', , " '0.00 ,,",0.13' '0.08 ,,: . ;'.0,34'" , '1'.05' 0.00;.,; MCYCL.cS 0.00 0:06 'ò:òa Ó.14 0.42 0.00 ' T,OtÜENE:" , 0:00 '::0:02 '0.01:: . ,,"ltò4:" '.Cf1J\(U)Ö; . C8 .. 0.00 Ò.07' 0:01 0.09 0.20 ' 0.00 C2;:øENZEN, " '.0.00: "<', . ".0.00' 0;00.'. . (tOO ' .' "0,00, :'0;00> M&P-xYLENEO.OÒ' " , "0.01" 0.00 . 0.010.Ó1 0.00 O~LENE';' '0:00',0;00,' '0:00" 'O;oo""O;QÖ;'Q,òCf ' C9 0.00 0.03 0.00 0.020.02 0.00 C12:: ',6.00 "'Ò:ôO " ,,\'0:00:";.:,. "0:00, JO:OÔO.OO C13 0.00 ' 0:00 0.00 0.00 0.00 0:00 è14 ,0.00 ,Ó.OÓ ' .. o.oo:~' .'():ÒO 0.00' : ò;óo' , C1S 0.00 . 0.00 '0.00 0.00 ' 0.00 0.00 C1. ,.,', ,.tJJJÔ ,,0:00 ,::Q;O():"O.oQ\' , ö.oo;, "'9,00' C17 0.00 0.00 0.00 0.00 0.00 0.00 C1.0:()(i' 0:00' '0:00' . O:QOO,QO ' ,o:otf C19 Ò.OO 0.00 0.00 . 0.00 0.00 0.00' c:~~ " ,;:~.OÖ: ' ,0;00, '0;00; '0;00 ' -,);00 , ô.t:íØ C21 0.00 0.00 0.00 0.00 0.00 0.00 C22 ',0:00 "J.,.'o:oo:" '::0;00" :'" 0.00" 0.00 '. ",Ò.OÖ' C23 ò.ÒO 0.00 '0.00 0.00 0.00 0.00 C24 ó,Oô ' , oJxf \¡.,o~oo ' ø.oö' ' 0,00 .0;00', C2S' 0.00 0.00' " ò.ÖO 0.00 O.ÓO 0:00 C2a '0:00' 0;00 ''ôJ)o'O;OO '0:00"0.00." C27 0.00 0.00 o.Òo' 0.00 0.00 0.00 " C28 0.00 ,. 0.00 0.00 . 0.00. O~OO 0.00 C29 0.00 0.00 0.00' 0.00 0.00 '0.00 C30+ þ:QO i .Ó.Oo'O;OO::: ' . .., 0.00 '0.00 '. ,0.00 Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 55 Oilphase-DBR Table 4.12 Continued BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psla Psat Flve-Stage Separator Test Vapor & Residual Liquid Composition 6th Stage Vapor Residual Liquid COMPONENT MW mole % MCVC-C5 CYI::L-C6 ,., ..I"1t:. ........... lD_YV' ~..~ ..'.,',.':' '..:.,' :\', '- ~i.cU~'W<':', " >,:,>x'>, ,',H1,.,:¡ Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 56 Oilphase-DBR TABLE 4.13 BP Alaska Recombined Reservoir Fluid. NS-09 + NS-13, 4850 psla Psat Separator Corrected GOR and FVF Pressure Measured GOR (Rs) Corrected GOR (Rs)' Measured FVF (Bo) Corrected FVF (BO)2 (psla) (scflbbl) (scflbbl) Single P~. Data " .,<~15:.. .,?,~39 ",",}856 .. 1514 . 'i'2jj64- 794 '. :'::~;r C); "< @4" 1807 :1.412:. 1173 ~. 544 ". '264.' 2~1. . 2.070 J:i~'.. 1.690 . (§~~:. 1.350 . nsa. -4855 : 4700 ,'MøO:.;;' ;~.;.' 2500 .;,150() . ~.53t ' 2.368 . Z:'Ì$2 : 1.933 'j.:i~':. 1.544 .l~(),;":' '::-', ;',1 ' Notes: 1. R. = R.Sb - (R.ob - R.D)(BoSb I BoOb) 2. Bo = BoD (BoSb I BoOb) [ ( WhR. Bo R.o R.st, RsDb BoD BoSb BoOb - Separator Corrected Solution Gas GOR - Separator Corrected FVF - Gas in Solution at Specified Pressure - Gas in Solution at Saturation by Separator Test - Gas in Solution at Saturation by Differential Liberation - FVF at Specified Pressure - FVF at Saturation from Separator Test - FVF at Saturation from Differential Liberation [ [ ( ( ( ( ( ( ( r ( l ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 57 Oilphase-DBR I I I I , I , - = = = ~ - = = = =: - = -= ~ = = = = : = : = ~ : - : : : : : = =1 : -= -= -= : = = -= :1 -= - = = -= -= -= : :1 -= - - -= : -= -= - = 1:= := -= -= . - -, - -1 - - - - - - - ~j -- -. - .- - - - - -1- - ~ - - .- -- - -I - ~ -1- - - - - - -I - - - - - - - - -, - - - - - - - - -I - - - - - - - - -I - - - - - - - - -t - - - - - - - - - - - - - - - -1- - - - - ----~--------~--------~---------I-- ::::J::::::::J:::-::::J::::::::J:: ----~--------~--------~--------~-- ----~--------~--------~-------~- -----~- ----------- - - - - --, - -. - - - - - --1 - - - - - - - .- ---j - - - - - - - - -I - - - - - - - -1- - - - - - - -1- - - - - - - -1- ... : : : - J : : : : : : - : J : : : : : : : : :1: : : - : : : ::1 : - - - - : : :1: : : : : : : : :1: : : : : : : : :1: : : : : i 2.2 ~ = ~ ~ ~ ~ = = ~ ~ = ~ = ~ ~ ~ = ~ ~ = = ~ ~ ~ ~ = = = ~ = - -I : - ~ ~ ~ ~ ~ ~ ~: - - = - : : : : ::: : - : ~I = ~ = -I - = = ~ : ~ 2.0 .-J_------_.-J_------_.-J_--- ____I --______1_________1_________1____- W ----~--------~--------~--- -- E - J:=-_=_=_=I::- -__1_- ~ 1.8 1 1 1 1 1 - = = :: : J = - - - - - - : J - - - - - - - 1 : : : : - - : : : :: = :1: = : : : : - : :1: : - - - - - - . >0 - - - - --< - - - - - - - - --< - - - - - --< - - - - - - -I - - - - - - - - -1- - - - - - - - -1- - - - - - - - -1- - - - - 1.6 -- -,--------,--- ----I - ---1---------1---------'---------1-- C :::::~::::=::- ::::::: ,_::::=:==:==::::::::: -Unadjusted ::::::::: ¡ 1.4 ~~~=J:=~~~;==~:===:;=~J=~~~~~~~~:===~=~~~~:~_~~dl~~t~d =::1::=:: E ... 0 LL ::- 2500 .Q .Q ¡¡:: u .!. 2000 Q: 0 C) 1500 fI) ca C) 5 1000 :¡:¡ ~ Õ en 500 - ~ 2.6 - :E :S.. 2.4 Figure 4.9 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat Separator Corected GOR AND FVF 3000 I I I - - - - ..., - - - - - - - - ì - - - - - - - - T - - - - - - - - r - - - - - - - - r - - - - - - - - 1- - - - - - - - -1- - - - - ------r-- -T----- r----- --¡- 1---' --1---' - - - - ...., - - - - - - - - "t - - - - - - - - + - - - - - - - - t- - - - - - - - - ~ - - - - - - - - 1- - - - - - - - -1- - - - . +--- -+ _._-----t-~-------""- ----1--- ----I- I I ¡ ) - - - - ~ - - - - - - - - -J. - - - - - - - - j. - - - - - - - - L. - - - - - L. - - - - - - -1- - - - - - - _1- - - - . -J._. 1- - L- ----L __1___- _1_- - - - - - 1 - 1 - - L - L - - - - 1- - - 1 -----,---------1.--______1_____-__L ____I --- ____I ____1____. I I t 1 1 1 1 1 1 - - - - ~ - - - - - - - - - - - - - - - - I - - - - - - - - - - - - - ï - - - - - - - - 1- - - - - - - - -1- - - - - - - - - - - - - - - ï - - - - - - - - ï - - - - - - - - - - - - ï - - - - - - - -1- - - - - - - - -1- - - - . - I - I - 1- - 1- - 1 - - - - - .., - - - - - - - - ì - - - - - - - - T - - - - - - - - - - - - r - - - - - - - - 1- - - - - - - - -1- - - - - I -r---- --r---- --r------- - - 1"" - - - - - - - - r-- - - - - - - - - 1- - - - - - - - -1- - - - . - - - t- - - - - - - - ' '- - - -1- - - - . -- - - - ~ - - - - - - -- - Unadjusted - - - -:- - - - . = = = =: = = = = = = = = -J. = = = = = ~ ~ = ~ = = = = = = = = ~ = = = = = = = = L ~~d!~~t:~ - - = = = =:= = = =: ____1- ____1--- L_-------I- -______1- -______1____. I 1 I I I I 1 I I I - - - ï - - - I 1- 1- - - - - 1- ------T--------r--------r--------r--------r------- - - - - ï - - - - - - - - ï - - - - - - - - ï - - - - - - - - ï - - - - - - - - I" - - - - - - - - 1- - - - - - - - -1- - - - - 0 - - - - .., - - - - - - - -: - - - - - - - T - - - - - - - - :- - - - - - - - :- - - - - - - - - ~- - - - - - - - -~- - 1000 2000 3000 6000 7000 8000 4000 5000 2.8 --~--------~--------~------- ------- ~- ------1 - --1-------- -------- - - - - - - ~ - - - - - - - - ~ - - - - - - - -I - - - - - - - - - - - - -1- ===:J:_-----_J=:======~=--_~=:==I::===_===i===:__-- -: - - - - - -: - - - - - - - -! - - - - - -! - - - -! - - - - - - ------- -----1----- ------- ------- 1.0 1000 6000 7000 8000 3000 4000 5000 Pressure (psia) 2000 Oilphase-DBR Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 58 TABLE 4.14 BP Alaska Recombined Reservoir Fluid, NS-09 + NS-13, 4850 psia Psat PVT STUDY SUMMARY DATA Gas-OiI Ratio 1: Type of Liberation Total Solution Gas Stock Tank 011 Gravity (° API) Formation Volume Formation Volume Facto~ Factor3 ,,::'W,i>; .,,,.. "',2304" Differential Liberation .,r~r.~~'t.:<,~.,,;.;:t/,.;';:t~~~~..",:; , 2515 39.2 , ' ,~ò~,.:,., 2.509 '~ . .'. .." ':"';' .:' '41:7 .:,.J .;.,. :ô., '~~;1~3('>" 2.537 " 2:218 ";r'> :- (1) Gas-Oil Ratio: set of Gas per bbl 5TO at 60°F (2) Volume of Reservoir Oil @ Pres, Tres per volume 5TO @ 5TD conditions (3) Volume of Reservoir Oil @ Psat, Tres per volume 5TO @ 5TD conditions ( ( ( ( ( Oilphase-DBR FILE #: 20023132 BP Alaska Northstar PVT Study Wells NS-09, NS-13, NS-08, NS-15 Separator Samples 59 Oilphase-DBR APPENDIX A SUMMARY OF ODBR SERVICE CAPABILITIES ODBR retains a number of specialized pieces of equipment to complete high pressure and temperature measurements on petroleum fluid systems. In addition, ODBR retains advanced GC-based analytical capabilities for completing hydrocarbon fluid analyses. For detailed compositional work other than GC (e.g. SARA & HTGC), we call on the extensive expertise of the analytic chemistry department of the Alberta Research Council (ARC) in Edmonton. For organic solids (wax and/or asphaltene) stability evaluation in crude oil systems at realistic production conditions of pressure, temperature and/or composition (e.g. lift gas operation), OOBR offers two state of the art techniques, namely a laser-based solids detection system (50S) and a high pressure microscope (HPM) equipped with cross polars. While the 50S (rated to 15,000 psi and 390°F) is an established near infra-red (NIR) light transmittance method, the HPM (rated to 20,000 psi and 390°F) is a recently developed visual technique which enables direct detection of organic solids onset conditions and, more importantly, makes it possible to monitor the associated morphological changes. A distinguishing feature of the HPM technique is its capability to discern the nature of precipitated solids such as waxes (when viewed under polarized light mode) versus asphaltenes (when viewed under normal light mode). Descriptions of the aforementioned and other key flow assurance techniques, procedures, and typical results are provided below. _A'::".!1I1[.]~~.J:t.I[.]~'A'ItA'~r~'..~t:j Upon arrival, a sample bottle is connected to a 20,000 psi pump from the water side to check the opening pressures at room temperature. Next, the sample bottle is heated to T res, pressurized to at least Pres and allowed to equilibrate under continuous rocking for about five days. This process would help disperse deposited/coagulated asphaltene particles, if any, into solution. Following the sample preparation and conditioning described above, a sample of each equilibrated live fluid is isobarically displaced, one at a time, into a pre-cleaned and evacuated pycnometer for density, GOR, and C30+ compositional analysis using a flash procedure. In this technique, an accurately measured volume of the single-phase fluid is isobarically displaced into a pycnometer where its density and mass are evaluated. The pycnometer is then connected to a GOR single stage flash apparatus where the oil is flashed to ambient pressure and temperature conditions. Next, the evolved gas phase is circulated through the residual liquid for a period of time to achieve equilibrium between phases. Following circulation, the volume of equilibrium vapor and the mass of liquid remaining in the pycnometer are measured. The vapor phase is resolved to C15 by natural gas GC, while the residual liquid is analyzed to C30+' From the measured composition and total mass of each phase, the composition of the original live oil may be calculated by mass balance. r.i3f8I::(II:I~I[.lIJ::t.."".!'::~A'III~ ~2~~:j,iiCI~i.ølil;. Figure A.1 is a schematic of the ODBR visual PVT Cell. The main body of the cell consists of a Pyrex tube housed inside a steel shell with vertical tempered glass plates to permit visual observation of the internal tube contents. The Pyrex glass tube is 15.2 cm long with an internal diameter of 3.2 cm. This translates into an effective working volume of approximately 120 cm3. A specially designed floating APPENDIX A Oilphase-DBR SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A 1 ( r ( ( ( r ( ( ( r ( ( " ( ( , (" c ( piston (described below) and a magnetically coupled impeller mixer are mounted inside the Pyrex tube to allow for a mercury-free operation. The volume, and hence the pressure of the fluids under investigation, are controlled by a variable volume OOBR displacement pump which allowed for the injection or the removal of the transparent hydraulic fluid. The same transparent displacement fluid is connected to the outer steel shell to maintain a balanced (minimal) differential pressure on the Pyrex tube. Equilibration of the fluid under investigation is achieved by means of a magnetically coupled impeller mixer mounted on the bottom end cap. It should be noted that the bottom end cap is specially designed to achieve two main goals: (i) shield the cell contents from any magnetic effects/flux and (ii) provide for charging and sampling the test fluid. If PC 11 - - - - - .JEFRI ~ ",&- --, ~W. / , O_n Bounderles PVT CeI~.1 I" ..... -. ~--~-TI - ....1--. I.D.~,':,~~~~.J Jf" ", I ',._..L.., /1, I ~. ~ \. I 1 ! '\ I fJ. ~ ~ ~~ -- \. 100 \ I ~~~"" \ . .. Plslon8d I 1 I 01° I , I ~}." ~~ ------ \ 0 Ilnd"l5 . l!1!° ~ ,~" , ,e I Y'" 0 Q I ~)." ¡ 'I!' - I 'ø. J~ ~ ....-~ ,it:. ~i(J! 1\." I I ~ I 'Ør~~z LWI-- . 7'~" k \ ~,." -- '~..... \ f ~ ~J/ ~ I - .-. rI. . J L___...J___J \. . I OBR Magnetic \. I M~MS~œm \. " , / ... , ..... / , / ..... ." '------- ~ Constant Rate .JE F RI Pump r.;;;;] ~ Pressure I~el Side View of PVT Cell Figure A.1 - Schematic Diagram of ODSR PVT Cell Equipped with SDS The entire PVT cell is mounted on a special bracket, which can be rotated through 360°. Accordingly, the PVT cell can be inverted to sample any liberated gas when/if required (for gas diluent studies, the cell is kept inverted at all times, Le. the floating piston is positioned on the bottom and the magnetic mixer at the top of the cell). The bracket and PVT cell are housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum RTO and is displayed on a digital indicator with an accuracy of 0.2°F or 0.1°C. The cell pressure is monitored with a calibrated digital Heise pressure gauge accurate to :t 0.1 % of full scale. The maximum operating pressure and temperature for this PVT system is 15,000 psia and 392°F, respectively. A.2.2:::'ÓDQR,$pli.~Ðétec:t¡o.n'SY$~nr.($Þ$) The visual OOBR PVT cell described above is equipped with fiber optic light transmission probes (source and detector) to measure the onset of organic solids precipitation (due to temperature, pressure and/or compositional change) concurrently with fluid volumetric data. These fiber optic probes are mounted across the windows of the visual OOBR PVT cell as illustrated schematically in Figure A.1. The visual OOBR PVT cell along with the optical probes and the computerized pump are termed 80lids Oetection System (808). The measurement principle of the SOS is based on the transmittance of a laser light through the test fluid while either the temperature, the pressure or the fluid composition was being changed. The entire system is controlled by a proprietary software package that accomplishes two significant objectives. Firstly, a computerized pump is used to control and maintain the system pressure during isobaric temperature sweeps for wax precipitation experiments, isothermal pressure drop and/or isobaric injections of solvents/titrants for asphaltenes precipitation studies. Secondly, the APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A2 software (in real time) records and displays the system temperature, pressure, solvent volume, time, and most importantly, the power of transmitted light (PTL) through the test fluid. ~;~;~;~Þ_ø~:8i&f~..\~;~M) The standard SDS configuration discussed above has been further improved with the addition of OOBR high-pressure microscopy (HPM) in series. A schematic diagram of the set-up is shown below in Figure A.2. The HPM cell is a small sapphire prototype with variable internal diameter and, in turn, working volume. It is connected to the bottom of the PVT cell inside the same air-bath oven. The total dead volume in the HPM cell, tubing and fittings has been minimized and estimated to be 1 cm3. Video L-JJ Recorder Oven Boundary i------------------~ . . : Iln-line : I HPM . . . . . . . I . I . . . ~, : . n . I ~ . . . . . . v V . : O~O : I 0 0 . : 0 0 : . 0 0 . t:::::J : DBR n' n : L1 I PVT I . Cell . . L----I . I Solvent : : ' Cyli nder L______------------~ ~ Insulated Transfer Lines Q ~~~ 8 ~Q Storage Cyli nder ~ 0 ~. '--¡ --" t- ---; o~ Positive Displacement Pump Figure A.2 - Schematic of the OCBR High Pressure Microscope (HPM) 4;;~,~QDEJ",P.rtiØ',-I,ze;~.lysi.(PSA) ODBR retains a particle size analysis (PSA) capability based on proprietary imaging software that operates as a synchronous feature of the HPM system. The system was calibrated using particle standards of varying concentrations and size (1-50 ¡.tm) as well as micro-scale objectives. The PSA software scans digital HPM photomicrograph images in real time at a high sampling rate and simultaneously discretizes such images within a restricted field of view, on a pixel-by-pixel basis. From these data, histograms of particle size distribution are produced continuously and frequently over the residence time of an experimental sample contained by the HPM cell, thus providing information regarding relative abundance, morphology changes and onset conditions. Figure A.3 exhibits a sample PSA report generated during discrete depressurization of an unstable live oil at reservoir temperature. The reported particle diameter is the diameter of a circle with an area equivalent to the projected area of an asphaltene particle. The number counts are cumulative value obtained from analysis of 20 images at a given pressure. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A3 10000 1000 .i.-- 100, 1~~ - - 10000 , 1000 +- .- 1001 1 ojlL... - 1 ¡ lUBin/if! 10000, 1000t 100 ~ 1~ . -(ß,- -.---.--- --- ~---._-,---- - .- n -. ---. '1 P = 9000 psi I ----..-----------.-'.--------. -----------. - -------..--.----------- - r ( ( ( f ( ( f ( ( t ( ( (- ( ( ( ( ( (' ( ( ( ( ( 10000 1000-. - 100 -\k1m 1 ~-lIIIWm ~ n 10ooo¡ 1000+ 1~ .~~n' 10000, 1 000 ~ C 100 +-.- ð 1~t~. Ü 100001' 1000 +, '" 1 00 -h-c-- .... 1~ ilk~n 10000 1000 ~ '-' ,~-'"-.. 1 ~~:~.=nfin~ f ~- 10000 1000 -' .1' :., ...... '~:~. P = 6500 psi I 1000 r:. '~f '~M~~~:; 1000 r;:' -... . . ',' . ì - - '~f ~~.,..w n n 10000 T'.'w", ',"",",',""",""" . 1 000 'qbiß~~_' .',., ..- """ , ' , ' , .. , , ,'," ,"'," , , . .,':, ... , , ' " " P" = 40, 00 psi 1~~ f 1IIIIIIIIIIim.~.ñn;niih-'~oo'o'~-11 ~._~...,~:~=~- -on"n- 0-- - - ~-=-=- - '-'-'- -- - 1 0000 ì 1 000 .t:-. 100! OOmm 1 ~. gUlI8loo0Ilmirrn<.rm"- "'" ,.... L. -, ,"¡¡.m. --'II1ouL- 1 I P = 3500 psi I ----- ----- - ---- 11 21 31 41 51 61 71 81 91 101 111 121 Size (~m) Figure A.3 - Sample PSA Histograms for a Discrete Depressurization Experiment APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A4 A.2.' :Çärllbridge.Electromagnetlc'Vlscometer (EMY) For viscosity measurements, OOBR retains a Cambridge EMV model SPL440 (See Figure A.4). Such a High Pressure Viscometer is a precision instrument designed to accurately measure the viscosity of petroleum fluids. It was developed in cooperation with Cambridge Applied Systems and capable of continuous operation to 138 MPa (20,000 psi) and 190°C (374°F). The SPL440 system can be configured as a stand-alone system or as an in-line component with the ODBR Visual PVT Phase Behavior system. Performing viscosity measurements over the range of 0.1 to 10,000 cP on very small volumes of fluid makes this instrument an ideal component for petroleum fluid laboratory studies. A number of electronics options are available for operating the SPL440 Viscometer, including the ViscoPr02000, a device that is able to provide unparalleled accuracy over the greatest measurement range. Even with this outstanding degree of precision, accuracy and functionality, the SPL440 Viscometer is still easy to install, operate and service. It has only one moving part, a small magnetic stainless steel piston located inside the sensor that is driven up and down using coils, simplifying installation and servicing. The measurement chamber, connected to both top and bottom system lines, allows for easy introduction, measurement, and removal of a fluid from the Viscometer. Measurement Chamber Figure A.4 - Schematic Diagram of Cambridge Electromagnetic Viscometer A..2.~ .....Ç.P¡"'f¥.¥Jscorneter(CV) ODSR also retains a capillary viscometer (CV) rated to 10000 psi and 374°F. The CV set-up consists two high pressure cylinders (32 ml each) connected to a 1.83 m (6 ft) in length and 0.076 cm (0.03 inches) in diameter capillary coil. A differential pressure transducer is used to monitor the pressure drop across the capillary coil. The fluid sample is pumped from one cylinder to the other through the capillary coil by an opposed pump (See Figure A.5). From the measured fluid flow rate and pressure drop, the viscosity can be determined using the Hagen-Poiseuille relationship for laminar flow in tubes, namely: APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page AS ~=ci(~~)=cik Where Jl is the fluid viscosity, Ap is the pressure drop across the capillary tube of length, L, and a radius r, and Q is the volumetric flow rate. The tube constant k is determined by calibrating the viscometer using standards of known viscosity at test pressures and temperatures. Oven Boundary \. .-------------------. In-line - . Densitometer . . Magnetic Coupled . DP Mixer Assembly ------- . Transducer T1 1 ~ ~ . A. ...- . \j) ~ ~ +-Pyrex Tube . / / . . ~-..--lIquid Level . . /~ ~ Tapered Piston Vent\Vac. Line. . /~-/~ . DBR JEFRI . . Capillary Viscometer . . . L---J : ' Sample / DBR JEFRI : . Cylinders PVT Cell . -------------------- / ,.. Vent\Vac. Line r~~- --0== === ==0- F - DBR JEFRI Sample Cylinder DBR JEFRI Opposed Pump =e===9WP - L .-.J !-- DBR JEFRI Injection Pump Figure A.S - Schematic of Capillary Viscometer Setup ~¡{.IIt::l11IJ:~~ ~~¡~';~i~:i~ø~ÞitJ~~m,pq',*~n;~í.rj,fì~~;:(~~~} The CCE test is initiated by charging a known volume of the equilibrated fluid to the PVT cell at T res and Pres. At these conditions, the fluid density is measured and the initial mass of the fluid in the cell is calculated. Thereafter, the fluid is expanded isothermally to a lower pressure, which is still in the single- phase region. The total system volume is measured after equilibration at this pressure, and this volume is used to calculate the single-phase density at this pressure. This procedure is repeated a number of APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A6 times until the bubble point pressure is reached. Subsequently, the pressure is reduced further by selected pressure intervals into the two-phase region, and at each pressure point the vapor and liquid phases are equilibrated, phase volumes measured and plotted as a function of pressure. The intersection of the single phase and two-phase lines in the PV plot and the visual observations in the PVT cell are used to define the bubble point. A.3.2Differentii'-' Liberation (DL) Following the CCE test, the fluid is pressurized slightly above the measured bubble point pressure and is allowed to equilibrate at such conditions for about one hour. The single-phase fluid is then flashed to the first specified pressure condition of the differential liberation study and equilibrated for at least 30 minutes. Subsequently, the equilibrium vapor and liquid volumes are measured using the cathetometer. A portion of the liberated vapor phase is isobarically displaced into an evacuated pycnometer for gravimetric density determination and compositional analysis. After collection of the vapor phase sample, the remaining portion of the vapor is isobarically displaced from the cell. Next, about 5 to 6 cm3 of the liquid are charged into the Cambridge electromagnetic viscometer for viscosity evaluation. Finally, the remaining liquid volume is measured and subsequently flashed to the next specified pressure condition. This procedure is repeated for a total of the specified pressure steps. k'3.'~.',,'..;~n.tant:\Î~fûra1ØDêplétiOn'(Øvø) The CVD test is initiated by charging a known volume of the equilibrated fluid to the PVT cell at Tres and P res. This volume is important as it is used to establish the reservoir volume to which the PVT cell contents are returned after each depletion step. The CVD test involves reducing the system pressure from Pres to the first specified pressure step at which the fluid is equilibrated. Next, the resulting vapor and liquid volumes are determined. In addition, a portion of the equilibrium vapor is displaced from the top of the PVT cell and analyzed for its C30+ composition and density. Finally, additional vapor is displaced to return the fluid system to the initial single-phase reservoir volume as defined above. The system pressure is then reduced to the next specified depletion pressure step and the above measurements are repeated. In all, measurement procedures are completed at 6 to 10 depletion steps. A:314..."""uItÎ..8tåge.$epärafor A known mass of homogenized fluid is transferred into the PVT cell and equilibrated at the bubble point pressure and reservoir temperature. The pressure and temperature are then set to the first specified separator condition and the system is allowed to equilibrate. Subsequently, the equilibrium vapor and liquid volumes are measured using a cathetometer. A metered sample of equilibrium vapor is isobarically displaced into an evacuated pycnometer for gravimetric density determination and compositional analysis. The remaining portion of the vapor phase is then isobarically displaced from the PVT cell. Next, a metered sample of the liquid is isobarically collected into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure. After measuring the remaining liquid volume in the cell, the system conditions are adjusted to the second specified stage. Again the liquid and vapor phase volumes are measured and a sample of each fluid is taken for density determination and compositional analysis. This procedure is repeated a number of times until the last separator stage has been reached. k3..~.."'VisèosityMéaSUrem'f1tlJsingEMV The test fluid is charged to the vessel and the piston is surrounded by fluid. Subsequently, the piston is moved inside the vessel by imparting a force on the piston using two electromagnetic coils inside the sensor body. After travelling the length of the test vessel, the piston is returned to its starting location by APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A 7 reversing the magnetic field of the electromagnet The motion of the piston inside the vessel is impeded by viscous flow around the annulus between the piston and the measurement chamber wall. Viscosity is determined by measuring the piston transit time for a complete cycle of piston movement and comparing this to times obtained using calibrated standards. ~3.6 ...Discre~ê.....lsótta@flllal/I)()~ê.,!I.ú~fJ~1\ After charging the reservoir fluid to the PVT cell at T res and Pres or higher, the SDS components are mounted across the full length PVT cell windows. A reference scan of the light transmittance through the fluid is then performed at the initial system pressure. The pressure of the cell is then lowered isothermally at discrete pressure steps (100 psi) with -5 minutes of equilibration time at each pressure step while the cell contents are mixed continuously and vigorously (-1,400 rpm). The experiment is stopped soon after a sharp and dramatic drop in the power of transmitted light (PTL) is observed. This drop in PTL corresponds to the onset formation of a solid phase and/or gas phase. To this end, it is useful to summarize some of the main factors known to influence the light transmittance (L T): . L T is inversely proportional to density; hence, if the density decreases then L T increases. Oensity is proportional to pressure (above bubble point); hence, if the pressure decreases then PTL increases. . L T is inversely proportional to particle size (PS); hence, if the PS increases then L T decreases. . L T is inversely proportional to the nucleation density of solids (NOS); hence, if the NOS increases then the L T decreases. It is also useful to present and describe (qualitatively) typical SOS de-pressurization traces measured for two low content asphaltenic crude oils with (OIL 2) and without (OIL 1) asphaltene precipitation problems at respective reservoir temperatures. These are depicted as Figure A.6 for ease of comparison [Hammami et aI., Energy & Fuels 14 (2000) 14-18]. In the case of OIL 1, the power of transmitted light (PTL) increases more or less linearly as the pressure is decreased isothermally from 62 MPa to 34 MPa. This is likely due to the decrease in fluid density with decreasing pressure within this pressure range. At about 34 MPa, the PTL signal drops dramatically to noise level. This drop is visually confirmed to correspond to the formation of a vapor phase (Le., bubble point is reached). The emerging liquid-gas interfaces cause instantaneous and significant scattering of the laser light at and below 34 MPa. With the removal of the liberated vapor phase below the bubble point, the PTL signal through the liquid phase decreases nearly linearly as the pressure is depleted to about 2 MPa. This is plausible because with decreasing pressure, the residual oil density increases as the dissolved light ends continue to evaporate. In the case of OIL 2, on the other hand, the PTL signal increases linearly from 62 MPa to an intermediate pressure of about 50 MPa. With further reduction in pressure, the PTL curve exhibits a plateau (initially) and then commences to decrease gradually and progressively. At about 39 MPa, a vapor phase starts to emerge (Le., bubble point is reached) and, in turn, the PTL signal drops to noise level. The point of departure of the PTL curve from the linear behavior at approximately 50 MPa is interpreted as the onset of asphaltene precipitation for this oil. Below the bubble point, the PTL curve decreases (initially), but then starts to level off at about 24 MPa. The observed break in the curve is likely the net effect of two competing processes. Opposing one another are the effect of liquid density, which increases with decreasing pressure, and the effect of asphaltene re-dissolution, which also increases with decreasing pressure. Accordingly, the increase in liquid density causes the PTL to decrease, whereas, the simultaneous decrease in size and/or amount of precipitated asphaltenes tends to increase the PTL APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A8 - {I) .-= = ;;J ~ ... e - :s ... ~ b ~ £ ... ï ~ _OIL 1 @ 80.6 C) ---OIL 2 @ 68.3 C) , ASJÌlakene Onsa f ~ 50.4 MPa ~ 24.4 MPa ,,= '. :It :: -,.".....-1" .."If Bubble Point ",,¿,,~~'Jt '~IIII'I I I I I I I I I I I I I I I I I I I I I I I I 0 10 20 30 40 50 60 70 Press ure (MPa) Figure A.6 - SDS Depressurization Traces of Live Oils With & Without Asphaltene Instability [Hammami et al.~ Energy & Fuels 14 (2000) 14-18] Figure A.7 depicts an SDS depressurization trace for a South American crude at corresponding reservoir temperature. HPM photomicrographs taken simultaneously during the isothermal pressure depletion experiment are superimposed on the same figure for ease of comparison. As can be seen, the HPM photomicrographs are consistent with the SDS trace; they help explain the observed trend and provide visual evidence (at the microscopic level) of the nucleation and agglomeration of asphaltenes during the isothermal depressurization process. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A9 æo 250 ~ S; .. ~ 200 . ::i " . .. .. E 150 . C I! ... 'õ 100 . .... . ~ 0 D.. 50 .t"f"'~~.~ C f1("l'" ¿.- :rJ-"'¡"" '! ~'.' .", ~+",. . l ( ( ( r ( r ( ( ( ( ( ( f ( ( , ( ( ( ( ( 0 .' 1500 3500 5500 7500 Pressure (psla) 9500 11500 13500 Figure A. 7 - SDS Depressurization Trace of South American Live Oil & Corresponding HPM Photomicrographs at Tres 1f;~{I"'I~g~",c:.~,jJ~ØA1,.âJf:mr',#Q~ The SOS can be used to identify the onset of solids formation from a given crude oil due to isobaric and/or isothermal solvent/gas injection. The procedure involves charging a known amount of oil sample to the pre-cleaned and evacuated PVT cell. Thereafter, the PTL is measured and recorded continuously (in real time) while the solvent/titrant is being injected at the desired rate (continuous or discrete) and the resulting cell content is mixed vigorously. The experiment is stopped when a dramatic drop in PTL is observed as illustrated in example A.B. Qualitative description and/or interpretation of such a trace is provided below. The PTL increases more or less linearly as the concentration of solvent/titrant is increased isothermally and isobarically from zero rN 0) to an intermediate level rN*). This increase in PTL is likely caused by the decrease of fluid density with increasing concentration of the lighter n-alkane (making it easier for the laser light to pass through). Above W*, the PTL signal starts to decrease gently and progressively to noise level with further increase of n-alkane concentration. The drop of the PTL curve starting at W* is believed to correspond to the onset of asphaltene precipitation from the liquid. Hence, the onset point is defined to be the maximum concentration of solvent prior to the observed drop in PTL. ( k ( ( ( APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A10 :::f' t: : - ' - .s::. . 0)' :::J : ]I : :e . E : ~ ' I! : ~ . 't5 ' ~ ' J : 0 ' a. . Wo ,_...."''''-...,''_.--.~ W* a._tot A sp"'lII ne Preclpllltbn . .. I . . . . .. I . . I .. .. .. . ~ .. .. I . ~ .. . I I . I. . . . . Weistlt Percent of Solvent Figure A.8 - Typical SDS Titration Trace Depicting Onset of Asphaltene Precipitation Typical HPM Photomicrographs taken during titration of an asphaltenic crude oil with n-alkane are superimposed on the simultaneously measured SOS titration trace for the same oil as illustrated in Figure A.9. It is evident from this graphical comparison that the HPM is noticeably more sensitive than the laser-based SDS technique. This is plausible because the registered light transmittance represents the net effect of oil dilution with lighter n-alkane (resulting in decreased mixture density; hence, L T tends to increase) and formation of a dark solid "asphaltene" phase (L T tends to decrease). The maximum in the SDS titration curve occurs when the latter effect (solids formation) surpasses that of the dilution. This usually occurs when the asphaltene particles grow to a critical size and/or increase in concentration at a critical n-alkane concentration. ~ c: ::s ~ ~ :e !!. ... .c 0) :J "0 S ... 'E fI) c: e I- .... 0 ... C1) ~ 0 a.. I Asphaltene Onset I determined by HPM ~ ~ \.. '-- Volume % n-C5 in n-C5-OiI Mixture (arbitrary units) Figure A.9 - SDS Titration Trace and Corresponding HPM Photomicrographs of Fluid Mixtures Prone to Asphaltene Instability APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A 11 A.;38"I,a."',....~84~::Tid"" "',',' "<",,".:..:~;,:ø;.' . ~',:T' 'III .'. '.n":~~~'o~D~'.\ ,:, '''~h/!R9M~:;.IroPt~.~4~R:':''_.lwV:@~v~lœ~!~MlØu The SOS can be used to measure the cloud point temperature of the fluid (both live and dead) at constant pressure. The maximum cooling rate is - 1°C/min. procedure involves charging a known amount of oil sample to the pre-cleaned and evacuated PVT cell. Thereafter, the PTL is measured and recorded continuously (in real time) while the cell temperature is being lowered continuously at constant pressure (using the computerized OOBR pump). The experiment is stopped when a dramatic drop in PTL is observed (see example Figure A.10). The temperature at which the drop occurs is interpreted as being the cloud point temperature for the fluid at the test pressure. -250 ( l I Coo /in g , ! i - i §'-"- 2 0 0 _...u.. ..... U ........;.. u.... u..... U ".....,.....,........ u.... u,. u. u. u.............. ~........- . . . . . , . . "0 .,. ':; ~ ~ ~ ~ ü: r 1 50 - u...... ..u..u...,........" ¡"" I~ 1; .~,.; ~ ~'~:~I'I'" .,u..,... u.... '1"""'- 1100 -"u"""",u""f """"'U"""UU¡""""""""""U','U'U"""""'U"U """'- ~ 5: ~:<n»m»~»m:::I:::[:::[::~ I I I I I 80 100 120 140 160 Tern perature (OF) ( ( ( ( ( [ ( Figure A.10 - Typical SDS Cooling Trace Depicting Onset of Wax Precipitation [Hammami and Raines., SPE Journal" 4 (1999) 1-10] ( [ Typical partially cross-polarized HPM Photomicrographs taken during isobaric (15,000 psi) cooling of waxy crude oil are illustrated in Figure A.11. Asphaltene particles are also evident in the HPM photomicrographs for this crude. The atmospheric wax appearance temperature for the same sample was measured to be 48°C/118°F. ( APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR ( L Page A12 Wax Cr}staJs Tempemtllre =;; 75...,'JCII68"F Tl'mperatllrl' =;; 66. 7(Yï/52" F Tempaatllre = 66"5"(ïI5l. 7"P Figure A. 11 - Cross Polarized HPM Photomicrographs of Waxy Crude Oil Taken During Cooling @ 15000 psi (1034 bar) [Karan et a/., SPE Paper 62945, 2000J A.4 Live Oil Bulk hl;l~ For filtration of live oil, OOBR retains a bulk precipitation/deposition apparatus, which may be used simply for removal of suspended solids in live oil or for quantification of solids precipitated at high pressures. Briefly, the apparatus consists of two stainless steel OOBR high-pressure cylinders (1 litre capacity) equipped with floating pistons. The cylinders are suitably connected to each other and a high- pressure 0.2 J.lm Silver Millipore filter is placed in-line such that the contents of both cylinders can be displaced through it. A mineral oil hydraulic fluid and a motorised OOBR high-pressure displacement pump are used to displace the cylinder contents from one cylinder to the other through the filter for separation and analysis. The entire apparatus (excluding the displacement pump) is enclosed in a constant temperature controlled air-bath. The filtration can also be performed directly from the PVT cell by displacing the test fluid through a high-pressure 0.2 J.lm Silver filter. This alternative is significantly cheaper than the bulk deposition apparatus described above, but the sample volume involved is barely sufficient to yield reproducible results. A.S Dead Oil Pour Point In the modified ASTM 097 method, the oil is initially heated to a temperature 10°C above the wax disappearance temperature (determined by CPM) as opposed to heating the oil to a temperature 9 °C (for oils with pour point> 33°C) above the expected pour point required by ASTM 097. Briefly, this test involves the visual examination of the sample during cooling. At each temperature slep (3°C/5.4°F decrement) the ASTM sample vial is poured or tipped to determine if the oil has any mobility. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A13 Ä.6 Live Oil Pour Point A new experimental apparatus has been developed to measure Live Oil Pour Point (Karan et aI., SPE Paper 62945, 2000). The live oil pour point will be measured by a method similar to that described in section A.5 above. The live oil will be introduced in a sapphire cell (approximately 35 mm diameter and 150 mm high) initially filled with synthetic gas mixture at test pressure. Sample oil will be transferred to fill in up to a height of 50 mm. The oil is allowed to be cooled according to the ASTM 0-97 method. The fluidity of the oil is checked every 2-3 °C by tilting the cell slightly and observing the movement of the interface. The temperature at which the interface ceases to move is deemed as the live oil Pour Point. I I Back Pressure Y Regulator ~ II Pressure Gauge Rotatable S~O II I I Temperature Indicator ~ I !--------1-""~-------------""1 I I I I : "'"" ".." : : í I : . . ~I.I I i ' II j' .1-n-.i',!:' Gas i : ' :J ¡ i:!. j : : ' :1 j "I' 1 : I ! ~ 0 I I : .'1 I å :1 i: I . 'I ,I . : ! :1 ,I : : '. : I I I . I I I I I I I I I I I I I . I I I I I I . I ~-----------------------------_. Temperature Controlled Air Bath ~ I i ~ Gas Cylinder ! ! L---.J ~lmr 8= i - Positive Displacement Pump í i ê ~ Oil Cylinder ~ Qm 8= I - Figure A.12 depicts the live-oil pour point apparatus schematically. Positive Displacement Pump Figure A.12 - Schematic Diagram of the Live Oil Pour Point Apparatus The gel strength or yield strength of waxy crude oils have been successfully determined using the model pipeline test (MPT) apparatus. A high pressure MPT apparatus was recently developed and tested (Karan et al., SPE Paper 62945, 2000). A schematic diagram of the model pipeline test apparatus is shown in Figure A.13 below. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A14 Oilphase-DBR Heated Lines r--""-"-'- 1- - - _L~'==='='~"--'-""-'"'''''''-''-'-''--''''''''''''-''''''''-'''.........-...... I I I I 1 I 1 1 1 1 1 I I 1 1 1 1 1 1 1 I I I I 1 1 I I 1 I I I I I 1 1 I I 1 I 1 1 1 1 1___________1 High Pressure Circulation Pump """1 r"-""'.~=-I i I I . þ Back-Pressure Regulator .& / ----1 r----- JEFRI Pu~ '..--Temperature . Controlled Bath Test Coil Figure A.13 - Schematic Diagram of the Model Pipeline Test Apparatus The apparatus consists of two stainless steel coils - each 7.04 mm I.D. x 6.10 m long - that are placed in a temperature-controlled bath. The total volume of each coil is -240 cm3. However, for each experiment approximately 350 and 700 cm3 of oil sample are required depending on the whether one or both coils are used. The thermal pretreatment of the oil is an important part of the experiment. The oil sample is maintained at a temperature higher than the Wax Dissolution Temperature (WDT) in an oven for at least 12 hours to erase the thermal history. Dead Oil Charging: For dead oil testing, the experiment was initiated with the evacuation of the cleaned coils and the heating of the water-bath to the "Starting Temperature" (generally 10°C above WDT). After the bath temperature attained the starting temperature, the oil is charged in the coils and the connecting lines. The oil is then circulated through the coils for at least 30 minutes. This method helps to remove any trapped air bubbles from the coils, which could drastically affect the gel strength value. Upon completing the circulation, the pump is isolated from the coils whereas the flow line connecting the oil container/reservoir (containing oil at starting temperature) to the coil inlet is left open. Live Oil Charging: For live oil testing, the experiment is initiated with the evacuation of the cleaned coils and heating the water bath to the starting temperature. This is followed by charging the saturation gas (separator gas) to the coils and to the connecting lines. Next, the gas is pressurized to the test pressure, which is controlled by the back-pressure regulator. After the water bath attained the starting temperature, the live oil is filled in the coils and the connecting lines in a pre-determined sequence. The gas in the transfer/connecting lines and the coils is displaced through the back-pressure regulator. Cooling and Aging: The oil cooling under static condition is done under specified cooling rate. An example of the cooling rate profile to simulate the pipeline situation is demonstrated in Figure A.14. After the target test temperature or aging temperature is reached, the oil in the coils is allowed to age for at least 6 hours (or any specified period of time) to let the oil develop its gel strength. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A15 Ungelling: After the aging, the ungelling of oil is started by pressurizing the coils with nitrogen gas. For this purpose, the pump and the reservoir is isolated from the coils by closing the relevant valves. Nitrogen pressure is increased in steps of 1 psi over 0-10 psi range, 2 psi over 10-30 psi range and 5 psi thereafter. Exactly 5 minutes are allowed between each pressure increase for oil to ungel. The pressure at which the oil is observed to have started to move is deemed as the Yield Pressure. Gel Strength Calculation: The yield strength ('t) can be calculated from the measured Yield Pressure using a force balance equation and is reported below. 't = PD/4L P = ungelling pressure D = tube inside diameter L = coil length Note: The procedure (stress loading rate, aging time etc.) may be modified according to the requirements for a specific project. 60 Estimated pipeline cooling profile Simulated cooling profile ( u 45 ~ 30 ~ ~ 0.6 C/hr Aging ~ 15 ~ þ ~ ~ 0 ( l ( ( ( ( ( ( ( TIME, hr Figure A.14 - Experimental Simulation of Pipeline Cooling Profile _1~líI8I. . II ~. " ... l'mlto}""1:8I']~1~ ( ( t ( ( ( The use of CPM for the study of wax crystallization is based on the fact that all crystalline materials rotate the plane of polarization of transmitted polarized light. Hence, by crossing two prisms on opposite sides of the oil sample, all light is initially blocked and the entire field of view appears black. On cooling, the crystallizing material appears as bright spots against this black background. This technique usually provides the most conservative (or highest) value of the crude oil cloud point temperature due the CPM's abaility to detect small crystals, Le. during early stages of wax crystallization. ( ( C ( The experimental procedure involves preheating the dead oil sample in a water bath to 65°C for 30 minutes to melt the waxes and homogenize the sample. Next, the corresponding sample container is hand-rocked prior to transferring one drop of the oil to a special glass slide, which is then covered with a cover slip. The glass slide containing the oil sample is inserted in the CPM hot stage and the field of APPENDIX A Oilphase-DBR SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A16 view was brought into focus. The temperature of the programmable hot stage was then increased at a constant rate of 10 °C/min from ambient temperature to 10°C above the wax disappearance temperature (WOT). The WOT is defined as the temperature at which the last trace of wax disappears from the field of view upon heating. Next, the sample is allowed to equilibrate at the maximum temperature for 1 minute. Finally, the sample was cooled at 2°C/min from the equilibration temperature to O°C. The corresponding wax appearance temperature (WAT) is identified (off-line) as the temperature at which the first detectable bright spots (Le., wax crystal size in the order of 111m) emerged in the black field of view. An example of the W ATtesting using CPM is shown below in Figure A.15. TerrlS'åtIe = EIre WAT=24°e T6f11Øålre = ere OIL A CD ~ ::s .. as ~ CD a. E CD I- Te.tf.ØéÀlre = EIre V\AT = 41°e -. - ... .,," -.. - ...... , - ...... .-. . " , .. ..... ".. ,.:. ...I- , ~.........,., """- - .". ". ......... - - .... . "'. ... .... .. - ~ T €I ltJEf"cåre = ere OILS Figure A.15 - Example photomicrographs of crude oil depicting wax crystals (bright spots) under polarized light. OOBR retains three (3) OOBR Core Flooding Apparatus rated to 10000 psi and 390°F. Each apparatus is divided into four subsystems: Injection System, Core Holder System, Production System, and Instrumentation. One of the Core Holder Systems consists of a stainless steel 316 cylinder 54.9 inches long with an internal diameter of 7 inches. The other two Core Holder Systems consist of a stainless steel 316 cylinder, 8 inches long with an internal diameter of 3 inches. The fluid pressure inside the core is controlled by movement of the displacement fluid to and from the apparatus using a OOSR positive displacement pump. Confining pressure is applied using water in the annular space between the sleeve and the stainless steel cylinder. Each Core Flooding apparatus is housed inside a steel shell equipped with a temperature controlled water bath. A re-circulation system insured constant temperature along the entire length of the system. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A17 Oilphase-DBR The temperature is measured with a thermocouple and displayed on a digital temperature indicator, which is accurate within 0.1 °C. Each Core Flooding system is mounted on a support system, which allows for variability in the angle of dip, and is also mounted on an axially rotating mechanism that eliminated fluid segregation effects caused by gravity. Briefly, the procedure involves dissolving 2.5 g of dead oil/residue sample in an equal amount of toluene in a 300-cm3 flask. When the oil is fully dissolved, 40 cm3 of n-C7 is slowly introduced for each cm3 of toluene previously added. The flask is then capped and shaken thoroughly for 5 minutes and the precipitate is allowed to settle in subdued light for 2 hours with occasional shaking. Next, the contents of the flask are filtered through a filtering funnel (using a 0.22 Jlm filter) into a filtering flask under slight vacuum. The flask is then rinsed with n-C7 and the washings were transferred to the filtering funnel. The precipitate is then washed until the effluent is colorless. The filtering funnel and the original flask are then dried at 105°C. Finally, the filtering funnel and the flask are re-weighed to quantify the asphaltenes (n-C7 insolubles). ( ( ( - ( ( ( ( ( ( ( ( ( ( C ( ( ( ( ( ( ( ( (. ( ( Figure A.16 depicts saturates-aromatics-resins-asphaltene (SARA) fractionation protocol. Briefly, the procedure involves fractionation of a dead oil into two cuts by distillation at 270°C (i.e., the boiling point of C1s). The C15- fraction «270°C) is then subjected to supercritical fluid chromatography (SCF) to determine the aromatics-to-saturates ratio. The C1s+ residue (> 270°C) fraction, on the other hand, is dissolved in n-heptane solvent at 50°C; the mixture is filtered hot (i.e., at 50°C) to remove undissolved asphaltenes (defined as hot n-heptane insolubles). Following this, the filtrate is cooled and filtered at - 10°C. The resulting precipitate (essentially wax insoluble at -10°C) is then weighed and denoted as the wax content. The wax fraction may be dissolved in CS2 and analyzed by high temperature gas chromatography (HTGC) to C100+. The assignment of the weight percent data to the appropriate n- paraffin and iso-paraffins will be based on the measured retention times of the calibration standard n- alkanes. The weight percent of iso-paraffins for a given carbon number will correspond to the sum of the area percent values of the peaks in between two consecutive (neighboring) n-alkanes. Subsequently, the solvent is evaporated from the de-waxed and de-asphalted filtrate. The remaining maltenes are dissolved in n-Cs (i.e., carrier solvent) and injected into a packed column filled with silica and alumina. The silica section of the column strips out the polars (i.e., resins), the alumina section removes the aromatics and, hence, only the saturates initially elute through along with the carrier solvent (i.e., Cs). The column is then washed with a medium strength polar solvent to remove the trapped aromatics. Finally, the column is washed one last time with a fairly strong polar solvent to recover the remaining polars/resins. Typically, the saturate fraction recovered is observed to be white and opaque, like candle wax, whereas the aromatic fraction appears to be brownish and the resins have a very dark color. APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Oilphase-DBR Page A18 ~ < 270°C «518°F) ~ SFC ¿{;:turates~ CAromatics~ ¡ WAX .. ~ATURATEj) e DISTILLATION I ~ HOT N_HEPTANE SOLUBLES I COOL TO -100C/14Of & FILTER I ~ > 270°C (> 518°F) I ADD N_HEPT ANE HEAT TO 50oC/1220F & FILTER I + dOT N_HEPTAþE INSOLUBLES IIAsphaltenes" ¡ De-Waxed + De-apshalted Oil (Maltene) COLUMN CHROMATOGRAPHY - + C RESINS =:> ~ROMATICj) Figure A.16 - SARA Fractionation Protocol APPENDIX A SUMMARY OF ODBR CAPABILITIES PVT & SOLIDS DETECTION SYSTEM Page A19 Oilphase-DBR APPENDIX B ( ( ( ( f ( ( ( ( ( ( ( ( ( ( C (: ( ( ( ( ( ( ( ( ( ( DETERMINATION OF OIUBRINE INTERFACIAL TENSION APPENDIX B Determination of Oil/Brine Interfacial Tension Oilphase-DBR Page BO 07/10/2002 WED 15:52 FAX 7804501668 OILPHASE - DBR I4tI 0011009 Rmf!~~f DETERMINATION OF OIUBRINE INTERFACIAL TENSION Prepared by PRI business UIÙt of AJbcrta Re8ca:rch Council June 2002 Confidential APPENDIX B Determination of Oil/Brine Interfacial Tension Oilphase-DBR Page B 1 07/10/2002 WED 15:52 FAX 7804501668 OILPHASE - DBR r t ( ( [ t ( ( ( ( ( ( ( t ( ( C ( ( ( ( ( ( ( ( ( ( l APPEND Determination of Oil/Brine I nterfacial Tension DBR groups IFr Project No. 3700016 lwe 2002 TABLE OF CONTENT 1.0 EXECUTIVE SUMMARY -..-.....................-.-.................................................._..1 2.0 EXPERIMENTAL PROCEDURES ...............-.............. .. ""'''..1-.''''"111''''' I "0 ... ...-, 2.1 OIL AND BRINE SAMPLES . ...._.....h-_-._-.-- . . .- .._--3 3.0 RESULTS -' ~... ------.....-.---- - -.-....-..--1 3.1 D'1' OF Ð~JIJ'BIIJl(E. S'YSTDf-...-, . --.. ;"'........K_U';,nl;.....;nH".........;;u.n;,............,..........3 3.2 IFI' OF LIVE OILIBRINE SYSTEM___- .. - ---_.....3 4.0 REFERENCE __-a ...- Y- . ..........,- . . -- - --5 LIST OF TABLES TABLE 1: FLUID DENSITIES----- -- -- .... .. .--.." ---.. .,,-...'. T." -..-".... -- --, --.. --.....---,. TABLE 2: DEAD OII.JBlUNE INTERFACIAL TENSION AT 111 0, AND 100 PSIG ..............._.....4 TABLE 3: LIVE OnJDRlNE INTERFACUL ttllfSlOJ.'ll AT 254 ¡r AND ~17~ }>S1A-......-......4 LIST OF FIGURES FIGURE 1: DROP SHAPE OF DEAD OIL IN BRINE AT 200 PSI AND 122 of ..--................-6 FIGURE 2: DROP SHAPE OF LIVE OIL IN BRINE AT 5175 PSIA AND 1545 0.- ....--..._.......7 PRIlARC Page B2 141 002/009 .- .-4 -DBR 07/10/2002 WED 15:53 FAX 7804501668 OILPHASE - DBR DBR ¡roups IFf Project No. 3700016 JWlC 2002 1.0 Executive Summary Intecfacial tension (lIT) between a crude oil sample and produced brine had been determined using Axisymmetric Drop Shape Analysis (ADSA) technique. The IFf between stock tank oil and produced brine at 122 lip and 200 psig was determined to be 16 mN/m. The 1FT between the saturated oil and produced brine at 5175 psia and 254.5 ~ was detennined to be 25.9 mNlm 2.0 Experimental procedures The experimental system. consists of a high pressure high temperature cell, made up of Titanium and Hastelloy parts with glass windows on opposite sides. The cetI is capable of oper"4itÏng at pres8umi up to 70. MPag and temperatures up to 200 nC. The glass windows allow the captut'e of droplbubble profile images by using a light source on one side and a camera. system on the opposite side. Elevated pressures are achieved through the use of fluids handling system consisting of pistoned pressure-vessels. lùgh pressure pumps and a back-pressure regulator. Elevated temperatures are achieved by the use of a Blue M oven as a source of heat. The camera system is connected to an NTSC monitor and a personal computer equipped with an image capnm: board and the image analysis software including the Axisymmetric Drop Sha¡)e Analysis (ADSA) program to iteratively calculate the interfacial tcnsÏon. The optical cell details are quite similar to the contact angle cell descn"bed elsewhere!. The pendant drop technique was used in this study which consists of oil drops hanging 1Ï'om a capillary tube within the surrounding brine solution. The bottom part of the optical table supporting the test cell and the camera system is loaded with sandbags to minimize vibrations and enhance clarity of the profiles of the drops and bubbles captured on the computer hard-drive. 'The cell housing also contains a live oil reservoir equipped with a piston driven by high pressure water to enable the maintenance of the fluids at reservoir temperatures and pressures at all times during the course of the experiments as well as to flow the oil in the fom of droplets within the field of view of the camera which sends the drop profile images to be captured by the computer. PRIJARC APPENDIX B Determination of Oil/Brine Interfacial Tension Page B3 IdI 003/009 Oilphase-DBR 07/10/2002 WED 15:53 FAX 7804501668 OILPBASE - DBR DBR gro11pl 1FT Project No. 3700016 1':IDC 2002 r ( ( f ( ( r ( ( ( ( ( ( ( ( ( (" ( ( ( ( ( ( ( ( ( Interfacial tension, being very sensitive to fluids contamination. imposes cleanliness as a basic requirement during experimentation. The titanium. and Hastelloy lines and valves were flushed with large amounts of water to remove any excess brine or salt which may have accumulated within the system. A dilute solution of nitric acid and hydtochloric acid can be used when required. The lines WClC then flushed with acetone to remove resic1ual water. The lines were then flushed with methylene chloride (to remove trace hydrocarbons), and with acetone to remove any mnaining methylene chloridc. A final flushed with high purity HPLC grade isopropyl alcohol was used to remove any rem.ai1ùng contaminants. The lines were then dricd by purging with high grade nitrogen. The titanium parts of the cell and injection needles were clcan.cd using the same sequence of solvents. The quartz windows, the ruby calibration sphere was cleaned in a heated bath. of suIphuric acid and atWtlonium persulfate for two hours. These components WClC subsequently rinsed with de.lonized water. Images are acquired U$Ïng the digitization apparatus in the following manner. Drop images are displayed and centered on the NTSC monitor. The video camera, optical cell, and tight source are arranged in it collinear få5hion. When the light intensity is at the appropriate level, so that it is within the dynamic range of the video camera, the drop profile can be brou¡ht into focus. The image of the drop profile is then captured in a ftame buffer and its digital representation is then saved on the computer hard-Give. After a set of images have been saved on the computer hard-drive, each image is individually recalled and analyzed. This is done by reading the desired image back into the video board's 1Ì'amc buffer. First a low pass digital filter is used to smooth out the jagged interface. Then a Laplacian low dimensional second derivative is applied to the filtered image to identify the drop edge. The image is now scanned along the drop edge. This supplies the x-y co-ordinate data for a representation of the drop interface. The co- ordinate data are converted into polar co-ordinates and then fitted using the method of cubic splines. Once the data has been appropriately fitted, the fitted function is then converted back into Cartesian co-ordinates. It is this fitted funct1o\' that is used to obtain up to 50 or 60 points on the interface as input to the ADSA program for calculating the PRIlARC APPENDIX B Determination of Oil/Brine Interfacial Tension Page B4 141 0041009 2 Oilphase-DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPBASE - DBR DBR group' 1FT Project No. 3700016 June 2002 interfacial tension using equation 1. Details of the ADSA program and its use in 1FT measurement can be obtained fÌ'Om the teference of Cheng et al2 . ðP = Y (llR] + l1R2) (1) where Y is the interfacial tension, Rl and R2 arc the principal radii of curv~ of the oil drop AP is the pressure difference across the interface 2.1 Oil and Brine Samples The stock tank elUde oil, saturated live oil and produced brine samples were supplied to us by D.B. Robinson Research Ltd. The density of the stock tank crude oil and produced brine were determined with an Anton Paar densitometer. Density of the live oil was provided to us by DBR Research Limited. 3.0 Results 3.1 1FT of Dead-oll/brlne system The values of the interfacial tension between the produced brine solution and the stock tank erode oil are presented in Table 2. The average value of the measurements is 16 mNIm. This value is significantly smaUer than the nonnal 1FT value of of between 30-40 mNlm for erode oil and water. An image of the oil drop çaptured during the test is presented in Fi~ 1. 3.2 1FT of Uve Oillbrine system The interfacial tension between the produced brine solution and the live oil at 5175 psi and 254 F are presented. in Table 3. The average value of the measurements is 25.9 mNlm. An image of the oil drop captured during the measurement of the liveoillbrine system is presented in Figure 2. PRI!ARC APPEND.. . - Determination of Oil/Brine Interfacial Tension Page B5 I4J 005/009 - ...... .___-DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPRASE - DBR ( r r ( ( l ( ( [ ( ( ( ( (, ( ( ( APPEND Determin Interfacial Tension ( , ( t DBR groups 1FT Table 1: Ftuid De.skies s~ tank oil density at 200 psi and 122 ~ (gm/m1) Produced brine density at 200 psi and 122°F (gm/ml) Uve oil density at 5115 psi and 254 CP (gm/ml) - ProdÜccd bÇne density ~t 5175 psi and 254~ (gm/ml) 0.814 1.009 0.52 0.97 Projec:tNo.37ooo16 June 2002 Drop # 1 2 3 4 .~_. 6 7 8 Average 1FT Table 2: Dead OillBrioe lnteñacial Tension at 122 .., and 200 psig Calculated 1FT mN/m 16.3 16.2 16.3 15.8 15.8 15.7 15.7 15.8 16.0 Table 3: Live OillBrÎDc IntcñaeialTension at 254 'F and 5175 psia DRQP# - - 1 2 3. 4 S 6 7 8 Average 1FT PRIlARC Page B6 26.7 26.2 25.7 25.6 25.6- 25.8 25.8 26.0 25.9 140 006/009 4 -DBR 07/10/2002 WED 15:54 FAX 7804501668 OILPHASE - DBR APPEND Determin Interfacial Tension DBR groups IFf Project No. 3700016 June 2002 4.0 REFERENCE 1. A new technique for reservoir wettability characterization, D.N. Roo M.G. Girard, Canadian Joumal of Petroleum. Technology, Ian. 1996 Vol. 35, No.1 2. CheDg, P., Li D., Bomvka, L., Rotenberg, Y., and Neumæm, A.W., "Automation of Axisymmetric Drop Shape Analysis for Measurement of Intertàcial Tensions and Contact Angles", Colloids and Surfaçes, 43, pp. 151-167, 1990. PRIlARC Page B7 III 007/009 5 -OBR 07/10/2002 WED 15:54 FAl 7804501668 OILPBASE - DBR ~008/009 DBR groups 1FT Project No- 3700016 l\11le 2002 ~r," .' . .,. ..~". . . . ., ."' '" . .. .. . "",'" . '", ........ ...,..,....... ,.' '.""5> . , . , : . ,\ r L ":.. . . ' , ~ I ! .' t... .. .,' ",', " . to. , ; 0' ., I . ; . . . . . ,...,... . . . " ! I '. . . to. t . ,,t.~' . ',';''' ~, . I 'f",' [ [ l ( Figure 1;. Drop shape of dead 011 In brine at 200 psi and 122 of ( ( l ( ( ( ( ( PRIIARC 6 ( it. APPEf\ Determination of Oil/Brine Interfacial Tension 3e-DBR l ( ( ( Page B8 07/10/2002 WED 15:55 FAX 7804501668 OILPHASE - DBR DBR groups 1FT Project No. 3700016 June 2002 Figure 2: Drop Shape of Live Oil in brine at 5175 psia and 254.5 of PRIlARC APPENDIX B Determination of Oil/Brine Interfacial Tension Page B9 ~ 009/009 7 Oilphase-DBR
