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202-077
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-07 (PTD 202-077) Perf 09/13/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/19/2021 By Abby Bell at 1:01 pm, Oct 19, 2021 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: 10/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-07 (PTD 202-077) RMT3D C/O and Sigma Log 09/09/2021 Triplesat and Sigma Analysis 09/16/2021 Please include current contact information if different from above. Received By: 10/12/2021 37' (6HW By Abby Bell at 11:06 am, Oct 12, 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 13,529 13,119 feet true vertical 11,305 N/A feet Effective Depth measured 13,119 feet true vertical 10,935 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 10,528' 8,852' 1,008' MD Packers and SSSV (type, measured and true vertical depth)See Above 1,005' 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: 10,435', 11,196', 12,755', 12,789', 13,177', 13,377' 8,782', 9,354', 10,614', 10,643', 10,987', 11,174' WINJ WAG 32,901 Water-Bbl MD 201' 3,759' 11,415' TVD 281 Oil-Bbl measured true vertical Packer 4-1/2" 12,976' 13,529' 20" 573 Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Plugs ADL0312799 NORTHSTAR UNIT NS-07 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Casing Pressure Casing 4. Well Class Before Work: 472 Representative Daily Average Production or Injection Data 775495 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL Size STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 202-077 50-029-23081-00-00 5. Permit to Drill Number: Hilcorp Alaska LLC 2. Operator Name N 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-429 781 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 1,288 Gas-Mcf 1,327 Tubing Pressure 39,357 N/A measured 1,780' 740' N/A Liner Liner Conductor Length 201' 3,759' 11,415' Surface Intermediate 9-5/8" 7" 8,430psi 3,356' 9,516' 10,795' 13-3/8" Senior Engineer: Senior Res. Engineer: Collapse N/A 2,260psi 11,305' 201' 4,760psi 5,410psi7,240psi 4-1/2" TRMAX SSSV 9-5/8" Hydraulic-set, 9-5/8" LTP, 7" Permanent, 7" LTP, 4-1/2" Upper WFD, 4-12" Lower WFD 7,500psi 777-8333 Burst N/A 5,020psi 6,870psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:26 pm, Oct 11, 2021 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.10.11 12:03:42 -08'00' Torin Roschinger (4662) RBDMS HEW 10/11/2021 DSR-10/11/21 SFD 10/12/2021MGR15OCT2021 Well Name Rig API Number Well Permit Number Start Date End Date NS-07 Eline 50-029-23081-0000 202-077 9/9/2021 9/13/2021 No operations to report. No operations to report. 9/11/2021 - Saturday MIRU E-LINE. PERFORATE FROM 10886' - 10906' WITH 3.125" 6SPF 60PHASE HSC W/MAXFORCE CHARGES. RDMO ELINE. 9/14/2021 - Tuesday 9/12/2021 - Sunday No operations to report. 9/13/2021 - Monday 9/10/2021 - Friday Assist E-Line with PNL log. Pumped 194 bbls of KCl into the TBG at 0.5 bpm. Pumped a total of 955 bbls during the entire job. Freeze protected the surface equipment with 3 bbls of methanol. Final T/I/O= 0/1210/0. MIRU ELINE, LOG 3 C/O PASSES AND 2 SIGMA PASSES FROM 11200' - 10760', RDMO ELINE. 9/8/2021 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/9/2021 - Thursday T/I/O= 1800/1285/0. Pumped 320 bbls of 110 * F KCl into the tubing at 4 bpm . Slow the rate to 0.5 bbm to keep the gas out of the tubing during the log. Pumped 761 total bbls. Job continues on 9/10/2021. _____________________________________________________________________________________ Revised By: DH 9/28/2021 SCHEMATIC Northstar Unit Well: NS-07 Last Completed: 5/18/2002 PTD: 202-077 TD = 13,529’(MD) / TD =11,305’(TVD) 20” TOC @ 13,119’ Orig. KBE = 56’/ BFE = 40.2’ (CB 15.9’) 7” 8 11 5 6 17 20 22 7 9-5/8” 1 2 CRUSHED 7” X 5” Liner hanger, milled to 3.720” ID 13 19 14 Min ID= 2.375” @ 13,177’ 13-3/8” DV Tool at 1,606’ PBTD =13,484’(MD) / PBTD =11,262’(TVD) 3 13-3/8 ” 15 & 16 18 4-1/2” 4 9 12 10 21 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169 / X-56 / N/A N/A Surface 201' N/A 13-3/8" Surface 68 / L-80 / BTC 12.415 Surface 3,759’ 0.1497 9-5/8" Intermediate 47 / L-80 / BTC 8.681 Surface 11,415’ 0.0732 7" Liner 26 / L-80 / Hydril 521 6.276 11,196’ 12,976’ 0.0383 4-1/2” Liner 12.6/13Cr80/Vam Ace 3.958 12,789’ 13,529’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/JFE-Bear 3.958 Surface 10,528’ 0.0152 4-1/2” Tubing 12.6/13Cr80/Vam Ace 3.958 12,750’ 12,804’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,008’ 4-1/2” SLB TRMAX TSSSV 23,325’ST3: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 3,001’ 36,472’ST2: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 5,600’ 4 10,056’ST1: 1.5” GLM Port= 24/64”, Latch = RK, Vlv= S/O, TVD= 8,492’ 5 10,357’ 4-1/2” Pressure/Temp Gauge 6 10,418’ 4-1/2” X Nipple, ID 3.813” 7 10,435’ 9-5/8" x 4 1/2" Hydraulic-Set Packer 8 10,457’ 4-1/2” X Nipple, ID 3.813” 9 10,472’ 4-1/2” XN Nipple - Min ID 3.725” 10 10,527.6’ 4-1/2” WLEG – Btm @ 10,528’ 11 11,196’ 9-5/8” x 7” Baker Liner Top Packer 12 11,217’ 9-5/8” x 7” Baker Liner Hanger 13 12,755’ 7” x 4-1/2” Baker Permanent Packer, ID=3.875” 14 12,780’ 4-1/2” HES X Nip, ID= 3.813” 15 12,789’ 7” x 5” Baker Liner Top Packer 16 12,791’ 4-1/2” HES XN Nip, ID= 3.725” 17 12,803’ 7” x5” CRUSHED Baker Liner Hanger, Milled to 3.720” (4/11/2013) 18 12,804’ 4-1/2” WLEG, ID= 3.958” – Bottom @ 12,804’ 19 12,813’ 5” x 4-1/2” Cross-over, – ID=3.958” 20 13,125’ 4-1/2” CIBP @ 13150’ on 3/25/19 with 25’ of cement on top. Dumped 3/29/19 21 13,177’ 4-1/2” Upper WFD ER Packer,Min ID=2.375” (6/01/2013) 22 13,377’ 4-1/2” Lower WFD ER Packer,Min ID=2.375” (5/03/2013) PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C 10,802’ 10,822’ 9,048’ 9,063’ 20 4/20/19 Open 10,810’ 10,830’ 9,054’ 9,069’ 20 4/19/19 Open KUP C1 10,886 10,906’ 9,120’ 9,135’ 20 9/13/2021 Open Ivishak 13,186’ 13,320’ 10,983’ 11,107’ 134 6/27, 7/30 & 8/1/2002 Closed 13,334’ 13,374’ 11,120’ 11,158’ 40 8/26-27/2008 Closed 13,384’ 13,398’ 11,167’ 11,181’ 14 5/3/2013 Closed OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class “G” in 16” hole, TOC= surface 9-5/8"425 bbls lead class “G”, 165 bbls tail class “G” in 12-1/4” hole 75 bbls type “C” down squeeze, est. TOC= 2,750’ 7” 129 bbls Class “G” in 8-1/2” hole, est. TOC=11,196’ 4-1/2” 30 bbls Class “G” in 6-1/8” hole, est. TOC=12,789’ WELL INCLINATION DETAIL KOP @ 50’, Max Hole Angle = 42 deg. @ 10,452’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23081-00-00 Drilled and Completed with Nabors 33E – 5/18/2002 Shut off perfs with patch and add deeper perfs – 6/1/2013 ASR RWO – 4/14/19 Perf Add – 4/19/2019, 4/20/2019 and 9/13/2021 KUP C1 10,886 10,906’ 9,120’ 9,135’ 20 9/13/2021 Open 13 186’ 13 320’ 10 983’ 11 107’Cl d6/27 7/30 & 8/1/2002134 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): 13,529'N/A Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Liner 5,410psi 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 7-Sep Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:joleen.oshiro@hilcorp.com Contact Phone: (650) - 483 - 4774 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 COMMISSION USE ONLY Authorized Name: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL312799 202-077 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23081-00-00 Hilcorp Alaska LLC Length Size 11,305' 13,127' 10,922' 1,583 13,119' NORTHSTAR / KUPARUK OIL 201' 201' 12.6# / 13Cr / JFE Bear TVD Burst 10,528' 8,430psi MD N/A 7,240psi 5,020psi 6,870psi 3,356' 9,516' 10,795' 3,759' 11,415' See Schematic 4-1/2" 201' 20" 13-3/8" 9-5/8" 3,759' 7" 11,305' Authorized Signature: 9/7/2021 4-1/2" Perforation Depth MD (ft): See Schematic Tubing Grade: 9-5/8" LTP, 7" Perm., 7" LTP,4-1/2" WFD ER & 4-1/2" WFD ER and 4-1/2" SLB TRMAX 11,196 MD/ 9,344 TVD, 12,755 MD/ 10,601 TVD, 12,789 MD/ 10,631 TVD, 13,177 MD/ 10,975 TVD & 13,377 MD/ 11,161 TVD and 1,008 MD/ 1,005 TVD Joleen Oshiro NORTHSTAR UNIT NS-07 20 AAC 25.055 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. 13,529' 12,976' 740' 1,780' 11,415' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:47 am, Aug 26, 2021 321-429 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.08.26 08:29:33 -08'00' Chad Helgeson (1517) MGR31AUG2021 DSR-8/26/21SFD 8/26/2021 10-404 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 14:41:31 -08'00' RBDMS HEW 9/13/2021 Pulsed Neutron Log + Contingent Perf Add Well: NS-07 PTD: 202-077 Well Name:NS-07 API Number:50-029-23081-00-00 Current Status:Online Rig:E-line Estimated Start Date:September 7, 2021 Estimated Duration:1-2 Day(s) Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:202-077 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:2483 psi @ 9,000’ TVDss (NS-07 SBHPS, 10/22/20) MPSP:1583 psi (0.1 psi/ft gas gradient) Max Deviation: 42° at 10,452’ MD Minimum ID (within working area, above CIBP and TOC): 3.725” XN Nipple @ 10,472’ MD Reference Log:SLB, GR CHL, 5/6/2006, Final Brief Well Summary: NS-07 was re-completed in the Kuparuk in April 2019 and is currently perforated in the Kuparuk C2 sand. The Kuparuk C1 sand is an identified, known pay zone that has not been perforated; the C1 sand package is below the existing C2 perforations, and there is a 10’ TVD shale between the C2 and C1 sands in NS-07. NS-07 is in a down-thrown fault block that is in pressure communication with the main Kuparuk fault block. There are currently 4 active Kuparuk producers and 2 Kuparuk gas injectors (1 active, one shut in for reservoir management reasons). Northstar Kuparuk is a retrograde condensate. As time progresses, the Kuparuk reservoir pressure is declining because there is a finite amount of produced gas that we can re-inject, and the more valuable Northstar Ivishak reservoir has priority over the Kuparuk. Nonetheless, the declining Kuparuk reservoir pressure is causing the condensate yield (bbl/mmscf) to decrease and the watercut to increase in all of the Kuparuk wells. In order to maximize NPV and value from the unperforated NS-07 C1 sand package, it is in our best interest to execute these perf adds sooner rather than later, provided that we understand the current gas-water contact prior to perforating (waiting to perf will most likely result in a lower condensate yield and higher watercut, ultimately resulting in less recovered condensate, which we sell as oil). However, do not know where the current gas- water contact is; due to this, we are running a pulsed neutron log in sigma and carbon/oxygen (C/O) mode to de-risk the C1 perf adds. Based on the log results, we may elect to not add the C1 perfs (if the C1 is all water) or we may elect to shorten the perforation interval to give ourselves stand-off from the water contact. NS-07 is currently online, it currently makes 475 bopd, 490 bwpd (51% watercut), 33 mmscf/d formation gas (70,000 scf/stb GOR). Given our pre-pulsed neutron log view of the Kuparuk, if we perforate the C1, we anticipate the C1 add perfs to contribute 50-175 bbls of incremental oil rate. Objective: 1) Identify gas-water contact via running pulsed neutron log in sigma and C/O mode. 2) CONTINGENT add perforations in the Kupaurk C1 sand pending log results. Procedure: Slickline 1. RU SL unit. Pressure test PCE to 250 psi low / 3,500 psi high. s currently perforated in the Kuparuk C2 s or we may elect to shorten the perforation interval t Based on the log results, we may elect to not add the C1 perfs ( do not know where the current gas-g water contact is; Pulsed Neutron Log + Contingent Perf Add Well: NS-07 PTD: 202-077 2. Drift with BHA that sufficiently emulates a Halliburton RMT logging BHA down to target drift depth of 11,175’ MD. 3. Drift with BHA that sufficiently emulates a 30’ x 3-1/8’’ Halliburton MaxForce 230 perforation gun run (max swell in liquid = 3.338’’) a. Minimum target drift depth 10,930’ MD. b. If drift will not get down to minimum target depth, change up BHA length and size (i.e. 20’ length, 10’ length, etc). If still does not get down to target depth, contact OE. 4. RD SL unit. Eline Rig up #1 & Pumping Pumpers: 5. RU pumpers and pressure test surface lines. a. Load tubing with 1.5x wellbore volume of 1% KCl. b. While eline is logging pump at minimum rate to keep gas from entering the wellbore. Eline will be making multiple passes. Note total logging time is ~11 hrs; plan accordingly. c. Pump schedule below is recommended rate and volumes that can be adjusted at WSL discretion. Eline: 6. Note total logging time is ~11 hrs; plan accordingly. RU EL unit and pressure test to 250psi low 2,500psi high. 7. Petrophysicist, David Itter (cell: 907-538-3230), will be doing an independent interpretation of the saturation log. Please give him a heads up when logging starts. 8. RIH with GR/CCL/RMT-3D/Pressure/temperature and run saturation log per the logging table below. Tie-in log is Schlumberger GR CHL 5/6/06. 9. Rush process data interpretation. 10. Send data to David.Itter@hilcorp.com,snolan@hilcorp.com , and joleen.oshiro@hilcorp.com Pulsed Neutron Log + Contingent Perf Add Well: NS-07 PTD: 202-077 CONTINGENT Eline Rig up #2 (Approved Sundry required prior to proceeding) 11. Obtain “Final Approved Perf sheet” from OE/geologist. 12. RU EL unit and pressure test to 250psi low 2,500psi high. 13. RIH and correlate perforation gun run to Tie-In Log. Contact OE (contact info above) prior to perforating for final approval of tie in. Note: Guns require just enough fluid to cover the tool string to provide incompressible cushion around gun at time of detonation. 14. MU perforating tool strings with 3-1/8” Halliburton MaxForce 230 guns (6 spf, 60deg phasing) 15. Perforate as per “Final Approved Perf sheet” For reference, proposed add perforations (prior to logging) are in Table 1: NS-07 Contingent, Proposed Perf Gun Run a. Note any tubing pressure change in WSR. b. Ensure Correlation Pass and Shooting Passes have GR/CCL displayed 16. RD Eline. Table 1: NS-07 CONTINGENT, Proposed Perf Gun Run Note: Final depths to be confirmed in “Final Approved Perf Sheet” Gun Run # Perf Top Perf Bottom Perf Length Formation 1 ±10,885’ MD ±10,915’ MD 30’ Kuparuk C1 2 ±10,855’ MD ±10,885’ MD 30’ Kuparuk C1 Total 60’ Pulsed Neutron Log + Contingent Perf Add Well: NS-07 PTD: 202-077 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 9/4/2019 SCHEMATIC Northstar Unit Well: NS-07 Last Completed: 5/18/2002 PTD: 202-077 TD = 13,529’(MD) / TD =11,305’(TVD) 20” TOC @ 13,119’ Orig. KBE = 56’/ BFE = 40.2’ (CB 15.9’) 7” 8 11 5 6 17 20 22 7 9-5/8” 1 2 CRUSHED 7” X 5” Liner hanger, milled to 3.720” ID 13 19 14 Min ID= 2.375” @ 13,177’ 13-3/8” DV Tool at 1,606’ PBTD =13,484’(MD) / PBTD =11,262’(TVD) 3 13-3/8” 15 & 16 18 4-1/2” 4 9 1 2 10 21 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169 / X-56 / N/A N/A Surface 201' N/A 13-3/8" Surface 68 / L-80 / BTC 12.415 Surface 3,759’ 0.1497 9-5/8" Intermediate 47 / L-80 / BTC 8.681 Surface 11,415’ 0.0732 7" Liner 26 / L-80 / Hydril 521 6.276 11,196’ 12,976’ 0.0383 4-1/2” Liner 12.6/13Cr80/Vam Ace 3.958 12,789’ 13,529’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/JFE-Bear 3.958 Surface 10,528’ 0.0152 4-1/2” Tubing 12.6/13Cr80/Vam Ace 3.958 12,750’ 12,804’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,008’ 4-1/2” SLB TRMAX TSSSV 23,325’ST3: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 3,001’ 36,472’ST2: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 5,600’ 4 10,056’ST1: 1.5” GLM Port= 24/64”, Latch = RK, Vlv= S/O, TVD= 8,492’ 5 10,357’ 4-1/2” Pressure/Temp Gauge 6 10,418’ 4-1/2” X Nipple, ID 3.813” 7 10,435’ 9-5/8" x 4 1/2" Hydraulic-Set Packer 8 10,457’ 4-1/2” X Nipple, ID 3.813” 9 10,472’ 4-1/2” XN Nipple - Min ID 3.725” 10 10,527.6’ 4-1/2” WLEG –Btm @ 10,528’ 11 11,196’ 9-5/8” x 7” Baker Liner Top Packer 12 11,217’ 9-5/8” x 7” Baker Liner Hanger 13 12,755’ 7” x 4-1/2” Baker Permanent Packer, ID=3.875” 14 12,780’ 4-1/2” HES X Nip, ID= 3.813” 15 12,789’ 7” x 5” Baker Liner Top Packer 16 12,791’ 4-1/2” HES XN Nip, ID= 3.725” 17 12,803’ 7” x5” CRUSHED Baker Liner Hanger, Milled to 3.720” (4/11/2013) 18 12,804’ 4-1/2” WLEG, ID= 3.958” – Bottom @ 12,804’ 19 12,813’ 5” x 4-1/2” Cross-over, – ID=3.958” 20 13,125’ 4-1/2” CIBP @ 13150’ on 3/25/19 with 25’ of cement on top. Dumped 3/29/19 21 13,177’ 4-1/2” Upper WFD ER Packer,Min ID=2.375” (6/01/2013) 22 13,377’ 4-1/2” Lower WFD ER Packer,Min ID=2.375” (5/03/2013) PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C 10,802’ 10,822’ 9,048’ 9,063’ 20 4/20/19 Open 10,810’ 10,830’ 9,054’ 9,069’ 20 4/19/19 Open Ivishak 13,186’ 13,320’ 10,983’ 11,107’ 134 6/27, 7/30 & 8/1/2002 Closed 13,334’ 13,374’ 11,120’ 11,158’ 40 8/26-27/2008 Closed 13,384’ 13,398’ 11,167’ 11,181’ 14 5/3/2013 Closed OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class “G” in 16” hole, TOC= surface 9-5/8"425 bbls lead class “G”, 165 bbls tail class “G” in 12-1/4” hole 75 bbls type “C” down squeeze, est. TOC= 2,750’ 7” 129 bbls Class “G” in 8-1/2” hole, est. TOC=11,196’ 4-1/2” 30 bbls Class “G” in 6-1/8” hole, est. TOC=12,789’ WELL INCLINATION DETAIL KOP @ 50’, Max Hole Angle = 42 deg. @ 10,452’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23081-00-00 Drilled and Completed with Nabors 33E – 5/18/2002 Shut off perfs with patch and add deeper perfs – 6/1/2013 ASR RWO – 4/14/19 Perf Add – 4/19/2019 & 4/20/2019 _____________________________________________________________________________________ Revised By: TDF 8/24/2021 PROPOSED Northstar Unit Well: NS-07 Last Completed: 5/18/2002 PTD: 202-077 TD = 13,529’(MD) / TD =11,305’(TVD) 20” TOC @ 13,119’ Orig. KBE = 56’/ BFE = 40.2’ (CB 15.9’) 7” 8 11 5 6 17 20 22 7 9-5/8” 1 2 CRUSHED 7” X 5” Liner hanger, milled to 3.720” ID 13 19 14 Min ID= 2.375” @ 13,177’ 13-3/8” DV Tool at 1,606’ PBTD =13,484’(MD) / PBTD =11,262’(TVD) 3 13-3/8” 15 & 16 18 4-1/2” 4 9 1 2 10 21 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169 / X-56 / N/A N/A Surface 201' N/A 13-3/8" Surface 68 / L-80 / BTC 12.415 Surface 3,759’ 0.1497 9-5/8" Intermediate 47 / L-80 / BTC 8.681 Surface 11,415’ 0.0732 7" Liner 26 / L-80 / Hydril 521 6.276 11,196’ 12,976’ 0.0383 4-1/2” Liner 12.6/13Cr80/Vam Ace 3.958 12,789’ 13,529’ 0.0152 TUBING DETAIL 4-1/2” Tubing 12.6/13Cr80/JFE-Bear 3.958 Surface 10,528’ 0.0152 4-1/2” Tubing 12.6/13Cr80/Vam Ace 3.958 12,750’ 12,804’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,008’ 4-1/2” SLB TRMAX TSSSV 23,325’ST3: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 3,001’ 36,472’ST2: 1.5” GLM Port= 0, Latch = RK, Vlv= Dummy, TVD= 5,600’ 4 10,056’ST1: 1.5” GLM Port= 24/64”, Latch = RK, Vlv= S/O, TVD= 8,492’ 5 10,357’ 4-1/2” Pressure/Temp Gauge 6 10,418’ 4-1/2” X Nipple, ID 3.813” 7 10,435’ 9-5/8" x 4 1/2" Hydraulic-Set Packer 8 10,457’ 4-1/2” X Nipple, ID 3.813” 9 10,472’ 4-1/2” XN Nipple - Min ID 3.725” 10 10,527.6’ 4-1/2” WLEG –Btm @ 10,528’ 11 11,196’ 9-5/8” x 7” Baker Liner Top Packer 12 11,217’ 9-5/8” x 7” Baker Liner Hanger 13 12,755’ 7” x 4-1/2” Baker Permanent Packer, ID=3.875” 14 12,780’ 4-1/2” HES X Nip, ID= 3.813” 15 12,789’ 7” x 5” Baker Liner Top Packer 16 12,791’ 4-1/2” HES XN Nip, ID= 3.725” 17 12,803’ 7” x5” CRUSHED Baker Liner Hanger, Milled to 3.720” (4/11/2013) 18 12,804’ 4-1/2” WLEG, ID= 3.958” – Bottom @ 12,804’ 19 12,813’ 5” x 4-1/2” Cross-over, – ID=3.958” 20 13,125’ 4-1/2” CIBP @ 13150’ on 3/25/19 with 25’ of cement on top. Dumped 3/29/19 21 13,177’ 4-1/2” Upper WFD ER Packer,Min ID=2.375” (6/01/2013) 22 13,377’ 4-1/2” Lower WFD ER Packer,Min ID=2.375” (5/03/2013) PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C 10,802’ 10,822’ 9,048’ 9,063’ 20 4/20/19 Open 10,810’ 10,830’ 9,054’ 9,069’ 20 4/19/19 Open KUP C1 ±10,855 ±10,885’ ±9,097’ ±9,119’ ±30 Future Pending ±10,885 ±10,915’ ±9,119’ ±9,141’ ±30 Future Pending Ivishak 13,186’ 13,320’ 10,983’ 11,107’ 134 6/27, 7/30 & 8/1/2002 Closed 13,334’ 13,374’ 11,120’ 11,158’ 40 8/26-27/2008 Closed 13,384’ 13,398’ 11,167’ 11,181’ 14 5/3/2013 Closed OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class “G” in 16” hole, TOC= surface 9-5/8"425 bbls lead class “G”, 165 bbls tail class “G” in 12-1/4” hole 75 bbls type “C” down squeeze, est. TOC= 2,750’ 7” 129 bbls Class “G” in 8-1/2” hole, est. TOC=11,196’ 4-1/2” 30 bbls Class “G” in 6-1/8” hole, est. TOC=12,789’ WELL INCLINATION DETAIL KOP @ 50’, Max Hole Angle = 42 deg. @ 10,452’ TREE & WELLHEAD Tree ABB-VGI 5-1/8” 5KSI Wellhead ABB-VGI 13-5/8” Multibowl 5KSI GENERAL WELL INFO API: 50-029-23081-00-00 Drilled and Completed with Nabors 33E – 5/18/2002 Shut off perfs with patch and add deeper perfs – 6/1/2013 ASR RWO – 4/14/19 Perf Add – 4/19/2019 & 4/20/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 8/24/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL NS-07 PTD(202-077) CD: Jewelry Log GR/CCL Received by the AOGCC 08/24/2020 PTD: 2020770 E-Set: 33679 Abby Bell 08/24/2020 Hilm,,p A64.k MA: DATE 5/15/2019 Debra oUDEAN Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 NS -07 PTD 202-077)1 CD: CIBP AND TUBING CUT RECORD GR/CCL/HAL CIBP 3.4375 ]et cutter Please include current contact information if different from above. RECEIVED MAY 2 2 2019 AOGCC 2012077 30 83 1 Please acknowledge receipt by signing and returning one coov of this transmittal or FAX to 907 777.8337 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS EE C REINED APR 2 6 2019 1. Operations Abandon LJ Plug Perforations ! - Fracture Stimulat Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate Q - Other Stimulat Alter Casing ❑ Change Approved.Program ❑ Plug for Redrill ❑ erforate New Pool ❑� Repair Wel❑ Re-enter Susp Well ❑ Other: GL Complete ❑� 2. Operator 14. Well Class Before Work:5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Stratigraphic ❑ Ex lorato P rY ❑ Service ❑ 202-077 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23081-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL312799 NORTHSTAR UNIT NS -07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A NORTHSTAR / KUPARUK OIL 11. Present Well Condition Summary: Total Depth measured 13,529 feet Plugs measured 13,119 feet true vertical 11,305 feet Junk measured N/A feet 11,196, 12,755, 12,789, 13,177 & Effective Depth measured 13,127 feet Packer measured 13,377 feel 9,344,10,601, 10,631,10,975 & true vertical 10,922 feet true vertical 11,161 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,759' 13-3/8" 3,759' 3,356' 5,020psi 2,260psi Intermediate 11,415' 9-5/8" 11,415' 9,516' 6,870psi 4,760psi Liner 1,780' 7" 12,976' 10,795' 7,240psi 5.410psi Liner 740' 4-1/2" 13,529' 11,305' 8,430psi 7,500psi 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# 11 3C / JFE Bear 10,528' 8,843' 45/8" LTP, 7" Perm., 1,008 MD 7" LTP,4-1/2" WFD Packers and SSSV (type, measured and true vertical depth) ER & 4-1/2" WFD ER See Above 4-1/2" SLB TRMAX 1,005 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A p0u Treatment descriptions including volumes used and final pressure: N/A rJ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 6 4,107 Subsequent to operation: 1,079 54,644 24 304 832 14. Attachments (required per 20 AAC 25.070, 25.071, & 25,283) 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 Q Gas U WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-104 Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: WflVard(d7hilCOrp.COm Authorized Signature: Date: 4/25/2019 Contact Phone: 777-8547 r; nm, Afld Ra RBDMS-HO-/APR 2 91019 n Hames Aleake. LLC Ong. KBE = 56'/ BFE =40.2' (CB 15.9) TD=13,529' (MD)/TD=11,305' (TVD) PBTD=13,484' (MD) / PBTD=11,262 (TVD) SCHEMATIC Northstar Unit Well: NS -07 Last Completed: 5/18/2002 PTD: 202-077 TREE & WELLHEAD Tree ABB-VGI 5-1/8" SKSI Wellhead ji ABB-VGI 13-5/8"Multibowl 5K5I OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class "G" in 16" hole, TOC= surface 9 5/8" 425 bbls lead class "G", 165 bbls tail class "G" In 12-1/4" hole 75 bbls type "C" down squeeze, est. TOC= 2,750' 7" 129 bbls Class "G" In 8-1/2" hole, est. TOC=11,196' 4-1/2" 30 bbls Class "G" In 6-1/8" hole, est. TOC=12,789' CASING DETAIL Size Type Wt/Grade/Conn ID Top I Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68 / L-80 / BTC 12.415 Surface 3,759' 0.1497 9-5/8" Intermediate 47/L-80/BTC 8.681 Surface 11,415' 0.0732 7" Liner 26/L-80/Hydril 521 6.276 11,196' 12,976' 0.0383 41/2" Liner I 12.6/13Cr80/Vam Ace 1 3.958 12,789 1 13,529' 0.0152 TUBING DETAIL 0.0152 WELL INCLINATION DETAIL KOP @ 50', Max Hole Angle =42 deg. @ 10,4 JEWELRY DETAIL No Depth Item 1 1,008' 41/2"SIB TRMAX 7555V 2 3,325' ST3: 1.5" GLM Port= 0, Latch = RK, Mv= Dummy, TVD= 3,001' 3 6,472' ST2: 1.5- GUM Port=0, Latch =RK, VIv= Dummy, TVD=5,600' 4 10,056' STI: 1.5" GLM Port= 24/64", Latch = RK, Vlr- 5/0, TVD- 8,492' 5 10,357' 4-1/2" Pressure/Temp Gauge 6 10,418' 41/2"XNipple, ID 3.813" 7 10,435' 9-5/8" x41/2" Hydraulic -Set Packer 810,457' 40 41/2" %Nipple, ID 3.813" 9 10,472' 4.1/2"XN Nipple - Min ID 3.725" 30 10,527.6' I 4-1/2'WLEG-Btm@10,528' 11 11,196' 9-5/8" x 7" Baker Liner Top Packer 12 11,217' 9-5/8" x 7" Baker Liner Hanger 13 12,755' 7" x4-1/2" Baker Permanent Packer, ID=3.875" 14 12,780' 4-1/2"HES X Nip, ID=3.813" 15 12,789' 7" x 5" Baker Uner Top Packer 16 12,791' 4-1/2" HES XN Ni, ID- 3.725" 17 12,803' 7" x5" CRUSHED Baker Uner Hanger, Milled to 3.720' (4/11/2013) 18 12,804' 4-1/2"WLEG,I13=3.958"-Bottom@12,804' 19 12,813' S"x41/2"Crossover,-ID=3.958" 20 1 13,125' 4-1/2" CIBP @ 13150 on 3/25/19 with 25' of cement on top. Dumped 3/29/19 21 1 13,177' 4-1/2" Upper WFD ER Packer, Min ID=2.375" 6/01/2013 22 1 13,377' 1 41/2" Lower WFD ER Packer, Min ID=2.375" (5/03/2013) PERFORATION DETAIL Sands (Mp) Btm (MD) Top (TVD) Btm (TVD) FT Date -4/19/19& Status KUPC 10,802 10,830 9,048' 9,069' 40 4/20/19 Open 13,186' 1 13,320' 10,983' 11,107' 134 6/27, 7/30&8/1/2G02 Closed Ivishak 13,334' 13,374' 11,120' 11,158' 40 8/26-27/2008 Closed 13,384' 1 13,398' 111167' 11,181' 14 5/3/2013 Closed GENERAL WELL INFO API: 50-029-23081-00-00 Drilled and Completed with Nabors 33E - 5/18/2002 Shut off perfs with patch and add deeper perfs - 6/1/2013 ASR RWO-4/14/19 Perf Add -4/19/2019 & 4/20/2019 Revised By: TDF 4/25/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS -07 Slickline 50-029-23081-00-00 202-077 3/18/2019 4/20/2019 Daily Operations. 3/20/2019- Wednesday No activity to report. 3/21/2019 - Thursday No activity to report. 3/22/2019 - Friday No activity to report. 3/23/2019 -Saturday No activity to report. 3/24/2019 -Sunday Rig up E -line, PT lubricator to 300/4,500. RIH w/ Head/ERS/Weight/UPCT/BKR 10/3.65" HAL CIBP. DAL = 28', OAW = 250 lbs, Max OD = 3.66". Unable to move tools uphole at required depth due to unexpectedly high friction. Decision made to standby and pump Safelube to reduce friction. 3/25/2019 - Monday Pumped 200 bbls of safe lube. Set HES CIBP (3.66" od) @ 13,150'. LRS attempt to MIT tubing but pressure Increasing due to thermal expansion, will attempt again in the AM. Laid down equipment for the night. 3/26/2019 -Tuesday LRS performed passing MIT -T to 2,803 psi. Tubing pressure bled down to 1,000 psi. Rig up E -line and PT Lubricator to 300/4,500 PSI. Make 2 cement bailer runs to the CIBP at 13.15 '. Top of Cement at 13.134.4'. Continue dumping cement in the morning. "IN sk.:, -H-, 1�1 41sk1k Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS -07 Slickline 50-029-23081-00-00 202-077 3/18/2019 4/20/2019 Daily Operations. 3/27/2019- Wednesday RU Eline and PT lubricator to 300/4,500 psi. Attempt to make 2 cement runs however second bailer failed to dump. New top of cement at 13,126.6'. Return in the morning to complete final bailer run. 3/28/2019 - Thursday RU Eline and PT lubricator to 300/4,500 psi. Dump final bailer of cement on CIBP on 3rd attempt. Issues with cement setteling out in bailer. Top of Cement on plug at 13,118.8'. Return in the morning to verify cement top with drift and tag. 3/29/2019 - Friday RU Eline and PT lubricator to 300/4,500 psi. Drift at tag top of cement at 13,114' with 3.65" Blind Box. Clean pickup Make up tubing cutter and Jet cut the tubing at 12,750'. CCL to Cutter = 24.7', CCL stop depth = 12,725.3'. Cutter fired but communication to the IA. Pressure up on IA to 1000 psi and hold over night to monitor for change. 3/30/2019 -Saturday RU Eline and PT lubricator to 300/4500 psi. Bleed IA while RIH and pressure up tubing once at cut depth. TxIA communication established indicating first cut was good. Decision made to make second cut at 12,740' to ensure success. CCL to cutter = 24.7', CCL Stop Depth = 12,715.3'. 3/31/2019 -Sunday No activity to report. 4/1/2019 - Monday No activity to report. 4/2/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Surnmary Well Name Rig API Number Well Permit Number Start Date End Date NS -07 SIic e 50-029-23081-00-00 202-077 3/18/2019 4/20/2019 Daily Operations. 4010 \ 4/3/2019- Wednesday No activity to report. 4/4/2019 - Thursday No activity to report. 4/5/2019 - Friday No activity to report. 4/6/2019 -Saturday No activity to report. 4/7/2019 -Sunday MIRU ASR rig. Spotting and moving production equipment to accommodate ASR equipment. Start filling pits with 42bbls fresh water from facility, Bleed any gas off tbg Pull BPV, Set TWC. Prep for BOP Test as per Sundry, Conduct shell test 250psi/low 2,500psi/high charting test. Call for the AOGCC State Rep. Matthew Herrera. Begin Filling Pits with sea water 170bbls while waiting for AOGCC State Rep 4/8/2019 - Monday Continue filling pits and prep to test BOP's while waiting for AOGCC rep to arrive. Test BOP'S. Test 2-7/8 x 5' VBRs with 3.5" and 4.5" test joint to 250 low and 2,500 high test for good test. Tested annular to 250/2,500psi test with 3.5" test joint for good test. Tested all valves on choke / kill manifold to 250/2,500psi test for good test. Drawdown start @ 2,950psi down to 1,300psi. Recovery test 200psi @ 19 seconds - full recovery @ 81 seconds- witnessed by Matt Harrera from AOGCC. All tests charted. Blow down all lines and start tying in well to NS -10 disposal well and installing hard lines for filling and circulating well. Check line ups on circulation path and attempt to pump down backside of well and take returns up tubing to rock out diesel freeze protect. Pump 8 bbls and catch pressure on backside to 600psi with no returns up tubing. Re -check line up for good and make second attempt with same pressure build and no returns. Swap line up to pump down tubing and take returns from casing annulus. Pump 4 bb Is down tubing with returns out of casing @200psi. Swap to pump down NS -10 and pump 30 bbls down tubing taking returns to NS -10 @ 2bpm @ 1,100psi. Swap line up to pump down casing and take returns up tubing. Pump lbll and pressure build to 600psi w/ no returns up tubing. Call Engineer and discuss plan to attempt to pull tubing tail above assumed fill on backside and re -attempt circulation. Blow down circulation lines and prep to pull hanger and tubing. prep. to unland tbg hanger, BOLDS, make up landing jnt. Check I.A. OPSI, unland tbg hanger off seat at 100K drop off to 60k. Start working hanger through BOP Had to stop and get well head pulled over to center. TBG string wt broke over at 146k. lay down tbg hanger. Lay dwn 4 jnts of 4.5" #12.6 vam ace, strip on 13 5/8" X 8' spacer spool. prep to circ. out the rest of freeze protect out. Reverse Circ. 70 bbls tell tbg is clean. fill pits and swap over to Circ. conventional 170 bbls to clean up I.A. blow dry pumplines. 4/9/2019 -Tuesday Swap Crews, Continue and complete blow down lines, and clear line to NS -10, fluid checks, fuel equipment. Attempt to POOH w/ tubing, tubing began u -tubing diesel out of tubing, line all back up to NS -10, pump 60 bbls down backside to displace diesel from tubing. All tbg returns clean seawater. Blow all lines back down and clear line to NS -10. R/u spoolers, and string 2 cap strings and 1 fiber optic line over sheeves. Start POOH w/ 4.5" 12.6# 13Cr tbg laying down w/ 2 cap strings and 1 fiber optic line. Unclamping every collar. Joint 295 in elevators @ 05:30. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS -07 ASR 50-029-23081-00-00 202-077 3/18/2019 4/20/2019 Daily Operations. 4/10/2019 - Wednesday Swap Crews, fluid checks, fuel equipment, Continue POOH w/ 4.5" 12.6# 13Cr tubing. OOH @ 07:30. Shut blinds and make repairs to BOP Accumulator Schrader Valve. Simops move out 4.5" tubing. Continue move out 4.5" tubing and move in 3.5 inch work -string. Tally Work -string -Pump down and flush pits. Pumped 110 bbls into NS -10. Pick up 9-5/8" scraper and run in hole with 3.5" 10.3# work -string. RIH w/ scraper down to 10,790' MD. POOH with 3.5" 10.3# work -string laying down. 4/11/2019 - Thursday Continue POOH w/ 3.5" work -string laying down. OOH and lay down scraper assembly. No noticeable wear on scraper. Weather and visibility turning bad. Met with NS leadership and necessary to move out casing crew, and completion personnel due to POB and evacuation restrictions. Stand by for weather. Crews working light duty tasks and administrative projects. 4/12/2019 - Friday Standby due to weather. 4/13/2019 -Saturday Start making equipment ready to begin RIH with completion. Fuel equipment, fluid checks, clear out pipe rack area from snow piles. Begin MIRU Doyon, necessary to re -spot some equipment to accommodate Doyon Power Pack, installed heaters, on Doyon equipment to warm up hoses and hydraulic connections, move in tubulars and spot, tally tubing and completion jewelry. Have pre -job meeting with SLB, HES, and Doyon prior to pick up and run completion. Start pick up and RIH with completion. Pick up and start to make up comms line Pressure Temp gauge @ 18:00 hrs. RIH\w 126 Jnts of 4.5" 12.6# JFE Bear chrome tbg. Install First GLM\w 7' pup on top and bottom> shear valve installed Top @ 10,055.90', second GLM\w 7' pup on top and bottom> dummy valve installed Top @ 6,471.57' 4/14/2019 -Sunday ContRIH\w total of 236Jnts of 4.5" 12.6# JFE Bear chrome tbg. Install third GLM\w 7' pup on top and bottom> dummy valve installed Top @ 3,324.82', HES SSSV TR with 7' pup on top and bottom> top @ 1,008.43'. SLB Prep and test HES SSSV TR. RIH\w Total of 260 Jnts of 4.5" 12.6# JFE Bear chrome tbg. PU and MU 13 5/8" Vetco Grey hanger. run tech line and sssv cap string through tbg hanger. Land tbg, 74k down wt., SLB Temp Gage Top @ 10,357.22' with 7' pup on top and bottom, 1 jnt JFE Bear tbg, 7' pup, X -nipple I.D. 3.813" @ 10,417.86', 7' pup, 8.5' pup, HES Packer @ 10,434.72', 7.5' pup, 7.5' pup, X - nipple I.D. 3.813" @ 10,456.66', 7' pup, 7' pup, 1 jnt JFE Bear tbg, 7' pup, WLEG BTM @ 10,528.35. RD SLB and Doyon Csg. , RU to Circulate PKR fluid. Circulate 50 BELS treated PKR fluid followed by 160 BUS seawater down tbg through I.A. to NS -10. only about 200psidifferential circulating pressure. Bleed off lines, RU to Drop ball and rod ( Ball O.D. 1.865", Fish Neck 1.385", rod itself .75", length 9.1'), drop ball and rod and wait 15 min for rod to seat. Tbg was full, start pressure up the tbg took 2 bbls to pressure up to 4,000psi. chart 30 min to make sure there are no tbg leaks. Bleed off tubing to 2,000psi and ,pressure up casing to 2 500 si for MIT -IA test. Hold pressure for 30 minutes for good test. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number I Well Permit Number I Start Date End Date NS-07 ASR 50-029-23081-00-00 202-077 3/18/2019 4/20/2019 Daily Operations. 4/15/2019 - Monday Continue with completion of tubing test, chart scanned and put in well file. Bleed off tubing from 2000psi to zero with 2,500psiheld on backside in attempt to shear lower GLM with shear valve. Tubing bled to zero with no shear action. swap lines to pump into casing, pump up to 2,800psiand valve sheared. Allow casing to bleed to zero through tubing. Blow down lines. Pump 45 bbls diesel down casing and taking returns through tubing to NS-10 well. Close in backside. Diesel pumped and locked in casing to allow for later u-tube through tree (once installed) for freeze protection. Blow down and clear lines of diesel. Lay down Kelly hose, pull circulating lines and pull landing joint from hanger and install 2-way check. Begin RDMO operations of ASR. Cross ASR Rig and Pit trailer across ice road and meet BP Security for escort to Endicott. Continue RDMO of ASR rig to Endicott. Begin terminations on SLB psi/temp gauge and SSSV on well head. PSI/Temp gauge penetration stripped threads, necessary to chase threads with tap. Machinist re-dressed threads on penetrator/terminaton. w/ new penetration enroute from Prudhoe Bay. 4/16/2019-Tuesday New SLB termination arrived from Prudhoe Bay and installed successfully. SLB techs tested communication of temp gauge through wellhead to computer successfully. RDMO SLB. Clear out clean area around NS-06 and 07 trees, MIRU crane for tree installation, install trees on NS-07 and NS-06. Test VOID on tree on NS07 to 5000psi successfully. Test TREE on NS-06 to 5,000psi successfully. Pull 2-way check from NS-07 , install line from annulus to tubing and allow to u-tube diesel for freeze protection. Attempt to pull 2-way check from NS-06, found retrieval tool had separated from polish rod on lubricator. Rig down lubricator and start to bleed off well from closed downhole valve. WH personnel arrived with identical piece left in tree to aid in identifying a plan and tool for retrieval. Continue to bleed off and monitor well Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date NS -07 Slick & E -line 50-029-23081-00-00 202-077 1 3/18/2019 4/20/2019 Daily Operations. 4/17/2019- Wednesday WELL SHUT IN UPON ARRVAL, NOTIFY PAD -OP, PT PCE 300L/2,500H. PULL BALL & ROD @ 10,420' SLM. PULL 1.5" SHEAR VALVE & SET 1.5" S/O GLV (24/64") IN STA #1 @ 10,017' SLM / 10,056' MD. PULL 4-1/2" RHC FROM XN NIPPLE @ 10,428' SLM / 10,472' MD. RUN 20'x 3.50" DMY GUN TO 10,906' SLM / 10,950' MD . 4/18/2019 -Thursday Eline travel to the island & spot up equipment and get ready forjob to start in AM. OPS unloading fluid from well so that Eline will shoot perfs underbalanced. 4/19/2019 - Friday Well Unloading fluids on arrival. (SLB E -line Perforating). Rig up Eline, PT lubricator to 300/3,800 PSI. Perforate 20' interval from 10,810'-10,830'. La ,equipment down for the night -Notified pad op of well status - Ops to POP well for the night at MAX 20mm. 4/20/2019 -Saturday Rig up Eline, PT lubricator to 300/3,800 PSI. Perforate 20' interval from 10,802'- 10,822'w/ 2-7/8" Powerjet Omega HSD gun. CCL to Top Shot = 3.5', CCL Stop Depth = 108.5'. RDMO Eline. 4/21/2019 -Sunday No activity to report. 4/22/2019 - Monday No activity to report. 4/23/2019 -Tuesday No activity to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field, Kuparuk River Oil Pool, NS 07 Permit to Drill Number: 202-077 Sundry Number: 319-104 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner / DATED thislzd`af yo -f March, 2019. �BOMS� MpR � 31919 RNs VE ELE `�n, V � D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 '1 20119 APPLICATION FOR SUNDRY APPROVALS 9n AAr, 9s 9an r+ FR 0" - 1. Type of Request: Abandon ❑ Plug Perforations -A�a ❑✓ Fracture Stimulate L1 Repair Well El 11 Ope'`rations shutdown ❑ Suspend ❑ Perforate ❑✓ / Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑✓ Re-enter Susp Well ❑ Alter Casing ❑ Other: GI -Complete ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . Stratigraphic Service El 202-077 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23081-00 r`6v 7. If perforating: !i, ., l 26 ,¢,eFC zS- JS. . Well Name and Number: 3.5• /j� What Regulation or Conservation Order governs well spacing in this pool?r'S, •— C.O. 458A 3 S Will planned perforations require a spacing exception? Yes El No ❑ NORTHSTAR UNIT NS -07• 9. Property Designation (Lease Number): 10. Field/Pool(s): W"/ 7?{j- os ` ��KI) c✓ - �"/ /"'�/\ 3-S-17 ,.77 ADL312799 NORTHSTA /NORTHSTAR OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,529' 11,305' 13,484' 11,262' 447 &4111" N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 3,759' 13-3/8" 3,759' 3,356' 5,020psi 2,260psi Intermediate 11,415' 9-5/8" 11,415' 9,516' 6,870psi 4,760psi Liner 1,780' 7" 12,976 10,795 7,240psi 5,410psi Liner 740' 4-1/2" 13,529' 11,305' 8,430psi 7. psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2' 12.6# / 13Cr80 / Vann Ace 12,804' Packers and SSSV Type: 9-5/8" Liner Top Packer, T' Permanent Packer, Packers and SSSV MD (ft) and TVD (ft): 11,196'(MD)/ 9,344'(TVD), 12,755'(MD)/ 7" Liner Top Packer, 4-1/2" Upper W FD ER 10,601'(TVD), 12,789'(MD)/ 10,631'(TVD), Packer, 4-1/2" Lower WFD ER Packer, and 4- 13,177'(MD)/ 10,975"(TVD), 13,377'(MD)/ 1/2" HXO SVLN 11,161'(TVD), and 2,032'(MD)/ 1,971'(TVD) 12. Attachments: Proposal Summary Q Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/18/2019 OIL [0- WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. -�r„„i WExMn.� FYgc VYATr Q\uARO Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrivafd hilcor .corn Contact Phone: 777-8547 Authorized Signature: Date: 3/4/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission sothat representative may witness Sundry Number: U `!moi% Ul _' 6 r taa Plug Integrity ❑ BOP Test LTJ Mechanical Integrity Test ❑ Location Clearance ❑ Other. .rt- Som Post Initial Injection MIT Req'd? Yes ❑ No ❑,__r(/ Spacing Exception Required? Yes No Subsequent Form Required: j u ElL APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ) � �j q/1 3 -IL _ II /� n ^ A Submit Form and !h�f'f / F6�rn110- 3�evised 4/2017 /`^ Approved appli�at�R f Ind INA om the date of approval. A ac menu "n Duplicate vil"' _ (/ V 1 ` VVV DMS-df;'/MAK 13 A'��, T - / ? K Ililcorp Alaska, M Kuparuk Recomplete Well: NS -07 PTD: 202-077 API: 50-029-23081-00 Well Name: NS -07 API Number: 50-029-23081-00 Current Status: SI — Cycle Well Rig: ASR Estimated Start Date: March 18, 2019 Estimated Duration: 18 days Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 201-086 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: 1921372 Well EZ Required Yes Current Bottom Hole Pressure (Ivishak): 076/5/17) Equivalent Mud Weight: 9 ppg Maximum Expected BHP (Kuparuk): 4,425psi @ 9000' TVD Equivalent Brine Weight: 9 Max. Proposed Surface Pressure: 4 7psi _'-" aWo )K,4s P C35�g'1 O��J 5,172psi @ 11,100' TVD (Based on BHP on NS - (Based on native/isolated Kuparuk reservoir) (RWO- Based on plug and cement isolating the Ivishak formation and no other perforations in the well with a column of 8.5 ppg seawater.) (Perforating - Based on a gas gradient of .1 psi/ft while exposed to Kuparuk which Kuparuk will remain isolated until after RWO.) Brief Well Summary: NS -07 is an Ivishak producer that is frequently shut-in due to high/uncompetitive GOR. A 200' gas shut-off patch was set on 6/1/13 but gas rates appear to have quickly return to pre patch rates suggesting a failure in patch or 4-1/2" liner. Going forward, the Ivishak formation will be isolated and a workover rig will be utilized to recomplete uphole as a producer in the Kuparuk. Notes Regarding Wellbore Condition: MPSP: All Ivishak perforations will be hydraulically isolated with a tested mechanical plug and cement prior to commencing with the RWO. BHP at the Kuparuk could be as high as 4,425psi @ 9,000' TVD datum (if seeing native/isolated Kuparuk). During the RWO, a column of 8.5 ppg seawater will result in a MASP of 447psi and the Kuparuk will remain hydraulically isolated through the entire RWO. Follow-up perforations into the Kuparuk are estimated to result in a MASP of 3,525psi with a .1psi/ft gas gradient. Additional Notes: • Well had passing MIT -IA to 1,500psi on 3/2/13 • OA has been down squeezed RWO Objective: Isolate Ivishak formation. Use workover rig to recomplete well to the Kuparuk. Perforate thru-tubing post -rig in the Kuparuk. -- — ----- Pre-Workover Prep Procedure Slickline 1. RU SL unit and pressure test to 250psi low/4,200psi high. k Recomplete Well: N Well: NS -07 PTD: 202-077 Hilw,p Alaska, LL, API: 50-029-23081-00 2. Pull WRDP-2 injection valve from 2,032' MD a. API certified valve HABS-0336 currently installed. Redress valve according to API 14-B and retain valve for use in BSEE well NS -09 only. 3. RIH and drift for 4-1/2" CIBP to ±13,170' 4. RD SL. Workover Procedure (Sundry Aouroval Reauired to Proceedl: Eline — Plug Ivishak and Jet Cut tubing 5. Spot E -Line unit to well and RU. 6. Pressure test lubricator to 300psi low/ 4,500psi high. 7. Roll tanks while heating seawater until heated to at least —70 degF a. Seawater heated to at least 70degF needed to minimize contraction forces on tubing. 8. Rig up hardline from LRS skid to Pump In Sub and pressure test to 300psi low/4,500psi high. 9. Begin to pump hot seawater from upright tank into the well at max rate until at least 300 bbls away. a. Wellbore volume of 4-1/2 tubing and liner is (.0152 bpf * 13,200' _ ± 200 bbls). 10. Once 300 bbls away, decrease rate but continue to pump as needed to maintain fluid pack. 11. Prior to setting mechanical plug, swap to diesel and ensure tubing freeze protected to ± 1,600' (at least 25 bbls diesel). 12. RIH and set 4-1/2" mechanical plug mid joint at ±13,150' . a. Tie into SLB Perforation Record dated 8-26-18 b. This places the mechanical plug in the lower 1/3 of a full 40 ft joint. c. Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to set for final approval of tie in. 13. MIT -T to 2800psi for 30 mins. Chart. , 14. RIH and dump bail minimum of 25' of cement onto mechanical plug. a. 4-1/2" Liner volume of 0.64 gpf should require at least 16 gallons of cement. b. BHT is 250 deg F for cement blend. c. Verify with final tag that Top of Cement is at ±13,125' ELM at least 25' above plug. 15. MU jet cutter string and RIH. 111' 16. Bleed back tubing/IA leaving tubing to 800psi over IA pressure. a. Tubing is fluid packed with seawater topped by 1,600' TVD of diesel while IA is fluid packed with seawater topped by ^'3,850' TVD of diesel. Hydrostatic and applied overbalance should result in—200psi indication in IA after cut. 17. Cut tubing at ±12,750' and in the middle of the V pupjoint above packer. Note TxIA pressure change in LIPX�%( WSR. `J a. Correlate to Tubing Tally dated 4/16/2002. b. Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to cut for final approval of tie in. c. Cut depth is below Fiber Optic Transducer to avoid cutting any control line. 18. RDMO Eline. WorkoverProcedure: 19. Mobilize ASR #1 and offload at Northstar Island. 20. Bleed TBG/IA pressures to —Opsi. k Recomplete Well: N Well: NS -07 PTD: 202-077 Rfl� Alaska, M API: 50-029-23081-00 21. Verify -Opsi on the annulus and tubing pressure. 22. Set BPV, NO tree and NU 13-5/8" BOP's. a. Mark tree for proper orientation during reinstall P r -Q b. Function test BOP prior to arrival of AOGCC inspectors. 23. Spot ASR over well and spot in supporting equipment. 24. Confirm Opsi on the well and pull BPV. If needed, circulate seawater and/or bleed any residual pressure off tubing and casing prior to pulling BPV. 25. Set TeWC. 26. Test BOPE to 250psi Low/ 2,500psi High, annular to 250psi Low/ 2,500psi High (hold each ram/valve and test for 5 -min). Record accUm�ulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11-03-15. P �l)P b. Notify AOGCC 24 hrs in advance of BOP test.``(? p 5� c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" & 4-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 27. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is ero a and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure. c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 28. Pull TWC. 29. Circulate the well with at least 825 bbls heated seawater to remove freeze protect and clean tubing. Take returns to flowline of nearby well. a. Tubing volume to the cut is .0152*12,750 = 195 bbls b. Annular volume to the cut is .0535*11,200 +.0186*1,550= 630 bbls c. Total volume to the cut is 825 bbls 30. Once circulation is compete, CMIT-TxIA to 2,750psi. Chart for 30 min. 31. Bleed TBG/IA pressures to -Opsi. 32. MU 4-1/2" landing joint and BOLDS. 33. Attempt to pull over string weight and confirm hanger is free wAay ra i. BF: (65.5-8.5)/65.5=.87 OEM If successful, move to step 36 . ed by average of 8.5 ppg fluid) t_ Recomplete Well: NS Well: NS-07 PTD: 202-077 uflvorn .Aln,ka. Lb API: 50-029-23081-00 34. Contingency 1: If hanger does not unseat, attempt to pull hanger with casing jacks. a. Set Casing Jacks on top of the BOP Annular with Tugger. Connect Hydraulics and function test. b. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point as 2,038psi (equates to —230.4 klbs or 80% of yield strength of 4-1/2" 12.6# L-80 Vam Ace). i. Yield strength of 4-1/2", 12.6#, 13CR with VAM connections = 288 klbs 1jN5 c. Set Casing Jack pressure to 1,062psi (120 klbs). Slowly pressure up on jacks. Hold for 5 min. :�k d. Increase pressure in 100psi increments holding for 5 min between pressure increases until hanger pulls free. e. Note: do not exceed 2,038psi (230.4 klbs). If unmoved, contact Ops Engineer for further discussion. 35. Contingency 2: If tubing will not pull at 230.4 klbs, RU EL and jet cut tubing at ±12,740' and in the middle of the 2nd pup joint above packer. 36. Once hanger becomes free check for flow to ensure well is dead. LD Tubing hanger. a. Contingency: (If a rolling test was conducted.) L MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 37. RU Spoolers and continue to jack/pull 4-1/2" tubing from cut at±12,750', and lay down the same in singles. a. The ASR can pull —155 klbs. If jacks were needed to unseat the hanger, continue to jack until string weight is comfortably less than 150 klbs. n b. Once the string weight is comfortably less than 150k #, set tubing in lower slips, retract casing Kjacks into lowered position and swap to 'Carriage mode'. Resume pulling the completion (loX utilizing upper slips only with rig while laying down the same in singles. �\ lJ c. From 0 — 2,032' there are two hydraulic control lines to the TRSSSV and a fiber optic line to the downhole gauge. d. From 2,032'— 12,715' there is a fiber optic line to a CIDRA Gauge (Weatherford). e. Install thread protectors on tubing after use. Thread protectors may be for VAM TOP threads but are still acceptable for this purpose. Tubing should be sent to inspection to make ready to re -use. f. Monitor fluid level in well and fill as needed. 4-1/2" displacement is —.183 bbl/joint 38. Install wear bushing with running tool. )✓ 39. PU 3-1/2" workstrine and MU 9-5/8" mule shoe casing scraper assembly. RIH and wash to 10,750' and �d circulate x2 bottoms up or until clean returns are observed. a. Packer setting depth is ± 10,540' md. _ 40. Line up to reverse circulate and reverse circulate 750bbls of completion fluid into well at 4-5 bpm. a. Completion fluid to be seawater w/ 0.5% corrosion inhibitor. b. 3-1/2" Workstring volume to is:.00838*10,750 = 90 bbls c. 3-1/2"x 9-5/8" Annular volume is:.0613*10,750 =660 bbls 41. POOH w/ 3-1/2" workstring and lay down. a. Monitor fluid level in well and fill as needed. Work string displacement is—.152 bbl/joint 42. Remove wear bushing with pulling tool. 43. RU Spoolers and MU 4-1/2", 13CR completion and begin to run. a. Ensure RHC plug body installed in XN nipple. b. Displacement from the well will be —.183 bbl/joint Recomplete Well: NS Well: NS-07 PTD: 202-077 lfilmra Alaska, M API: 50-029-23081-00 44. Run 4-1/2", 13CR tubing tail and completion with packer and P&T gauge to setting depth. a. Packer setting depth is ± 10,440' and and the WLEG depth is +/- 10,540' md. b. 10,540' and of 4-1/2" 12.3 Ib tubing= 129.6 klbs (dry) / 112.8kibs (buoyed by 8.5 ppg fluid) c. A single SSSV control line will be run from +/- 1,000' TVD to surface. d. A single TecWire cable will be run from +/-10,360' MD to surface. L Max running speed 12 joints/hr e. Note the packer is a hydraulically set and will only set with a hydrostatic overbalance of pressure from the inside of the tubing string. Risk of setting due to RIH speed is negligible. 45. Space out and land the tubing into the hanger. RILDS. Lay down landing joint. Test tubing hanger to 250psi low/ S,OOOpsi High. a. Space out to the nearest full joint and shift depths accordingly. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. 46. Drop ball and rod and complete loading tubing and hydraulically set the packer as per manufacturer's setting procedure 47. Conduct MIT -T to 4,OOOpsi and MIT -IA to 2,5001)si for 30 minutes (charted). 48. Terminate the control line. Pressure test control line to 5,000psi and the tubing hanger to S,OOOpsi. 49. Test TRSSSV. Set BPV. 50. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500bbl returns tank. 51. RD mud boat. RD BOPE house. 52. RU crane. ND BOPE. 53. NU 5-1/8" 5,000# tree and adapter flange. Pull BPV. Set TWC. 54. Test both tree and tubing hanger void to 500psi low/S,OOOpsi high. 55. Pull TWC. RD crane. 56. Move returns tank and rig mats. Post WorkoverProcedure: 57. Spot Slickline unit and RU. 58. Pressure test lubricator to 300psi low and 2,500psi high. l` 59. RIH and pull single dummy GLV at±8,150' MD. 60. Set single screen orifice valve at ±8,150' MD for well underbalance and kickoff. 61. RIH and pull XN plug from ±10,520' md. 62. Drift to 10,850' and w/ 3-1/8" dummy gun. 63. RDMO Slickline. 64. Utilize temporary gas lift jumper to circulate out completion fluids down to ±8,150' MD/7,000' TVD and allow for underbalanced perforating. a. Inject 5 bbl Meth spear prior to gas lifting to prevent freezing in the IA. b. Follow Recommended Gas Lift Unloading Procedure c. Once stacked out to gas, shoot fluid levels to confirm. d. Contact Ops Engineer to determine target tubing pressure to bleed down to obtain—500psi underbalance with — with formation. Initial Eline Perforations of Kuparuk C H Hilwra Alaska, LG 65. Spot E -Line unit to well and RU unit. 66. Pressure test lubricator to 300psi low and 3,800psi high. Kuparuk Recomplete Well: NS -07 PTD: 202-077 API: 50-029-23081-00 a. Note that NS -07 may be in an isolated fault block with native Kuparuk pressure. Once perforated with a .1psi/ft gas gradient, this could result in a MPSP of up to 3525psi. 67. MU perforating tool string with 2-7/8 to 3-1/8", 6-12 spf, guns. 68. RIH and correlate to Tie -In Log: Schlumberger Gamma Ray Log dated 6 -May -2002. Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to shooting for final approval of tie in. 69. Perforate 1" gun run per table below (specific intervals subject to change, confirm with signed final perforation sheet). a. Note TxIA pressure change in WSR. Gun Run # Perf Top Perf Bottom Perf Length Formation 1 ±10,815' ±10,835' 20' Kuparuk C 2 ±10,802' ±10,815' 13' Kuparuk C Total 33' Table 1: NS -07 Initial Kuparuk C Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" 70. Repeat steps 67 - 69 for Gun Run #2 per table above. 71. POOH. RD E -Line and demob. 72. Turn well over to production. Bring well online gradually per Northstar Kuporuk Well Drawdown Procedures *Contingency—Additional Kuparuk C Perforations (May be added based on initial well performance and whether there are any indications of water present) 73. Spot E -line unit at well and RU unit. 74. Pressure test lubricator to 300psi low and 3,800psi high. 75. MU perforating tool string with 2-7/8 to 3-1/8", 6-12 spf, guns. 76. RIH and correlate to Tie -In Log: Schlumberger Gamma Ray Log dated 6 -May -2002. Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to shooting for final approval of tie in. 77. Perforate 1" gun run per table below (specific interval subject to change, confirm with signed final perforation sheet). a. Note TxIA pressure change in WSR. Gun Run # Perf Top Perf Bottom Perf Length Formation 1 ±10,915' ±10,935' 20' Kuparuk C 2 ±10,895' ±10,915' 20' Kuparuk C 3 ±10,875' ±10,895' 20' Kuparuk C 4 ±10,855' ±10,875' 20' Kuparuk C 5 ±10,835' ±10,855' 20' Kuparuk C Total 100' Table 2: NS -07 Contingent Kuparuk C Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" 78. Repeat steps 75 - 77 for Gun Runs #2-5 per table above. 79. POOH. RD E -Line and demob. 80. Turn well over to production. Bring well online gradually per NorthstarKuporuk Well Drawdown Procedures Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Sundry Change Form Kuparuk Recomplete Well: NS -07 PTD: 202-077 API: 50-029-23081-00 K corn Ataska. LLC Orig. KBE = 56/ BFE =40.2' (B 15.9') TD=13,529' (MD) /To =11,305' (TVD) PBTD=13,484' (MD) / PI3TD=11,262' (TVD) SCHEMATIC Northstar Unit Well: NS -07 Last Completed: 5/18/2002 PTD: 202-077 TREE & WELLHEAD Tree ABB-VGI 5-1/8" 5KSI Wellhead I ABB-VGI 13-5/8" Multibowl 5k'SI OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class "G" in 16" hole, TOC= surface 9-5/8" 425 bbls lead class "G", 165 bbls tail class "G" in 12-1/4" hole 75 bbls type "C" down squeeze, est. TOC= 2,750' 7" 129 bbls Class "G" in 8-1/2" hole, est. TOC=11,196' 4-1/2" 30 bbls Class "G" in 6-1/8" hole, est. TOC=12,789' CASING DETAIL Size Type Wt/Grade/Conn ID Top I Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/BTC 12.415 Surface 3,759' 0.1497 9-5/8" Intermediate 47 / L-80 / BTC 8.681 Surface 11,415' 0.0732 7" Liner 26 / L-80 / Hydril 521 6.276 11,196' 12,976' 0.0383 4-1/2" Liner 12.6/13Cr80/Vam Ace 3.958 12,789' 13,529' 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/Vam Ace 3.958 Surface 12,804' 0.0152 WELL INCLINATION DETAIL KOP @ SO' Max Hole Angle = 42 deg. @ 10,452' Max Angle at Top Perf: 23 Deg. @ 13,195' JEWELRY DETAIL No Depth Item 1 2,032' 4-1/2" SSSV w/HXO SLVN Nip, ID= 3.813" 2 5,189' GLM ST 2: Camco, BK -2, Port= 0,Dev=33, VIv=Dmy, TVD- 4,526', Date= 6/14/2002 3 6,512' GLM ST 1: Camco, SK -2, Port- 0, Dev=33, VIv=Dmy, TVD= 5,631', Date= 5/14/2002 4 11,196' 9-5/8" x 7" Baker Liner Top Packer 5 11,217 9-5/8" x 7" Baker Liner Hanger 6 12,715' 4-1/2" Fiber Optic Transducer, IN3.958" 7 12,734' 4-1/2" HES X Nip, IN 3.813" 8 12,755' 7" x 4-1/2" Baker Permanent Packer, I13=3.875" 9 12,780' 4-1/2" HES X Nip, IN 3.813" 10 12,789' 7" x 5" Baker Liner Top Packer 11 12,791' 4-1/2" HES XN Nip, ID=3.725" 12 12,803' 7" x5" CRUSHED Baker Liner Hanger, Milled to 3.720" (4/11/2013) 13 12,804' 4-1/2" WLEG, ID= 3.958" - Bottom @ 12,804' 14 12,813' 5" x 4-1/2" Cross-over, - ID=3.958" 15 13,177' 4-1/2" Upper WFD ER Packer, ID=2.375" (6/01/2013) 16 13,377' 4-1/2" Lower WFD ER Packer, ID=2.375" (5/03/2013) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 13,186' 13,210' 10,983' 11,005' 24 8/01/2002 Closed 13,210' 13,304 11,005' 111,088' 90 6/27/2002 Closed Ivishak 13,300' 13,320' 11,088' 11,107' 20 7/30/2002 Closed 13,334' 13,354' 11,120' 11,139' 20 8/27/2008 Closed 13,354' 13,374' 11,139' 11,158' 20 8/26/2008 Closed 13,384' 13,398' 11,167' 11,181' 14 5/03/2013 Open GENERAL WELL INFO API; 50-029-23081-00-00 Drilled and Completed with Nabors 33E-5/18/2002 Shut off perfs with patch and add deeper perfs - 6/1/2013 SAFETY NOTE Well requires a SSSV. 4-1/2" Chrome Tubing & Liner Revised By: DH 4/18/2017 K Hilwr Alaska,L Ong. KBE = 56/ BFE = 40.2' (CB 15.9') TD=13,529' (MD) / TD =11,305' (ND) PBTD =13,484' (MD) / PBTD =11,262' (ND) N -11I���M Northstar Unit Well: NS -07 Last Completed: 5/18/2002 PTD: 202-077 TREE & WELLHEAD Tree ABB-VGI 5-1/8" 5KSI Wellhead ABB-VGI 13-5/8"MUltibowl5K51 OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 484 bbls lead, 97 bbls tail class "G" in 16" hole, TOC= surface 9-5/8.. 425 bbls lead class "G", 165 bbls tail class "G" in 12-1/4" hole 75 bbls type "C" down squeeze, est. TOC= 2,750' 7" 129 bbls Class "G" in 8-1/2" hole, est. TOC=11,196' 4-1/2" 30 bbls Class "G" in 6-1/8" hole, est. TOC=12,789' CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169/X-56/N/A N/A Surface 201' N/A 13-3/8" Surface 68/L-80/BTC 12.415 Surface 3,759' 0.1497 9-5/8" Intermediate 47/ L-80/ BTC 8.681 Surface 11,415' 0.0732 7" Liner 26 / L-80 / Hydri 1521 6.276 11,196' 12,976' 0.0383 4-1/2" Liner 12.6/13Cr80/Vam Ace 3.958 12,789' 13,529' 0.0152 TUBING DETAIL 4-1/2" 1 Tubing 1 12.6/13Cr80/JFE-Bear 3.958 Surface 10,540' 1 0.0152 4-1/2" Tubing 12.6/13Cr80/Vam Ace 3.958 12,750' 12,804' 1 0.0152 WELL INCLINATION DETAIL KOP @ 50, Max Hole Angle = 42 deg. @ 10,452' JEWELRY DETAIL No Depth Item 1 -1000' 4-1/2" TR SSSV 2 -3,450 ST3: 1.5" GLM Port= 0, Latch =RK, VIv=Dummy, TVD=3,100' 3 -6,115 ST2: 1.5" GLM Port= 0, Latch = RK, VIv= Dummy, TVD= 5,304 4 `8,150 STI: 1.5" GLM Port= 0, Latch = RK, VIv= Dummy, TVD= 7,000' 5 10,360' 4-1/2" Pressure/Temp Gauge 6 "10,400' 4-1/2" X Nipple, ID 3.813" 7 ^10,440' 9-5/8" x 4 1/2" Hydraulic -Set Packer 8 "10,480' 4-1/2" X Nipple, ID 3.813" 9 -10,520' 4-1/2"XN Nipple - Min ID 3.725" 30 '-10,540' 4-1/2" WLEG 11 11,196' 9-5/8" x 7" Baker Liner Top Packer 12 11,217' 9-5/8" x 7" Baker Liner Hanger 13 12,755' 7" x 4-1/2" Baker Permanent Packer, ID=3.875" 14 12,780' 4-1/2" HES X Nip, ID= 3.813" 15 12,789' 7" x 5" Baker Liner Top Packer 16 12,791' 4-1/2" HES XN Nip, ID=3.725" 17 12,803' 7" x5" CRUSHED Baker Liner Hanger, Milled to 3.720" (4/11/2013) 18 12,804' 4-1/2" WLEG, ID= 3.958"- Bottom @ 12,804' 19 12,813' 5"x4-1/2"Cross-over,-ID=3.958" 20 13,170' 4-1/2" CIBP with TOC at 13,145' 21 13,177' 4-1/2" Upper W FD ER Packer, ID=2.375" (6/01/2013) 22 13,377' 4-1/2" Lower WFD ER Packer, ID=2.375" (5/03/2013) PERFORATION DETAIL Sands (Top) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUPC 10,802 10,935 9,048' 9,146'133 Planned 13,186' 13,320' 10,983' 11,107' 134 6/27, 7/30 & 8/1/2002 Closed Ivishak 13,334' 13,374' 11,120' 11,158' 40 8/26-27/2008 Closed 13,384' 13,398' 11,167' 11,181' 14 Future Closed GENERAL WELL INFO API: 50-029-23081-00-00 Drilled and Completed with Nabors 33E-5/18/2002 Shut off perfs with patch and add deeper perfs-6/1/2013 Revised By: WLR 3/1/2019 H Ililmrp Alaska. i.i.0 2 1/16" 5N Manual al Milne Point ASR 13-5/8" BOP 03/27/2018 iM x 13 5/8" 5M 5 1/2" VBR Rams Slinds 5" 5M Choke Valves lanual and HCR HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: April 1s`, 2019 Subject: Changes to Approved Sundry Procedure for Well NS -07 Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. HAK Step Page Date Procedure Change Prepared B Initials -HA K Approved B initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date operations Engineer Date STATE OF ALASKA /AKA OIL AND GAS CONSERVATION COMA/110N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well Lj • Plug Perforations U Perforate U . Other1 Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmental $ Exploratory ❑ 202 -077 -0 t 3. Address: P.O. Box 196612 Stratigraphkj Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23081 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: 1 ADL0312799 NSTR NS07 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted NORTHSTAR, NORTHSTAR OIL • 11. Present Well Condition Summary: Total Depth measured 13529 feet • Plugs measured None feet true vertical 11305.02 feet Junk measured None feet Effective Depth measured 13484 feet Packer measured See Attachment feet true vertical 11262.26 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 156 20" 169# X -56 45 - 201 45 - 200.92 4260 2590 Surface 3715 13 -3/8" 68# L -80 44 - 3759 44 - 3355.63 5020 2260 Intermediate None None None None None None Production 11371 9 -5/8" 47# L -80 44 - 11415 44 - 9516.57 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 13186 - 13210 feet 13210 - 13240 feet 13240 - 13270 feet 13270 - 13300 feet 13300 - 13320 feet 13334 - 13354 feet 13354 - 13374 feet 13384 - 13398 feet True Vertical depth 10982.69 - 11004.7: feet 11004.73 - 11032.4 feet 11032.44 - 11060.33 feet 11060.33 - 11088.3 feet 11088.39 - 11107.1E feet 11120.31 - 11139.1 feet 11139.13 - 11157.91 feet 11167.42 - 11180.65 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 40 - 12805 40 - 10644.68 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NNE) JUN 2 € 20 13 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 837 69414 252 0 2534 Subsequent to operation: 36 3756 425 0 713 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator)L] Development ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil kf . Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -157 Contact Nita Summerhays Email Nita.Summerhays(7BP.com Printed Name Nita Summerhays / Title Petrotechnical Data Technician j____ 'W' j Signatur -- ,9 j/ . Phone 564 -4035 Date 6/25/2013 z ITI - RBDMS JUN 2 6 201 Form 10-404 Revised 10/2012 / v ��Original Only • • Daily Report of Well Operations ADL0312799 ***WELL FLOWING ON ARRIVAL * ** (pre coil acid job) CURRENTLY RIGGING UP SWCP DSL# 1 & WELL SUPPORT RIGGING UP KILL LINE 3/17/2013 * * *CONT ON 03/18/13 WSR * ** * * *CONT FROM 03/17/13 WSR * ** (pre coil acid job) DRIFT TO & PULLED 4 -1/2 WRDP ON X -LOCK FROM SVLN @ 1996' SLM (2032' MD) (Ser# HHS -661) RAN 2.30" CENT. DRIFT & SAMPLE BAILER TO TD © 13,397' SLM SAW OFFSET WLEG @ 12,785' SLM, NO ISSUES PASSING THROUGH. NO SAMPLE 3/18/2013 ** *WELL LEFT S /I, WELL TENDER NOTIFIED * ** T /I /O= 2600/629/96 Temp = Hot M1T -IA to 1506 psi *PASSED* (Pre Squeeze) Pumped 2.7 bbls of 42* diesel to achieve test pressure. Gained 7 psi / 1st 15 min. Gained 6 psi / 2nd 15 min. Bled back 5 bbls. FWHP= 2600/47/100. SV closed, WV, MV, SSV open. IA, 3/21/2013 OA OTG. CTU #3 - 1.75" Coil Job Objective: Mill obstruction and drift tubing patch Begin rigging up BOPS and coil unit 4/8/2013 ...Continued on WSR 4- 9 -13... CTU #3 - 1.75" Coil Job Objective: Mill obstruction and drift tubing patch Rigged up CTU. MU 3.72" crayola mill BHA. Stabbed well and pressure tested lines. Open well. Load and kill well w/ 1% SKCL w/ Safelube. RIH and displace meth in coil with slick. Dry tagged at 12,775' CTM, weight up at 12,764'. Tried locating 4 -1/2" nipple by pumping at slow rates. Established intial free spin at 2,500 psi at 2.5 bpm. Experiencing high weights. Calling out more metal to metal friction reducer. 4/9/2013 ...Continued on WSR 4- 9 -13... CTU #3 - 1.75" Coil ** *Continued from WSR 4- 9 -13 * ** Job Objective: Mill obstruction and drift liner patch. Tractor engine issues. FP coil with field triplex. Standby for replacement tractor. Re -kill well with Lube 776 cocktail. Begin displacing coil with water to resume milling. 4/10/2013 ...Continued on WSR 4- 11 -13... CTU #3 - 1.75" ** *Continued from WSR 4- 10 -13 * ** Job Objective: Mill obstruction and drift liner patch Mill through obstruction from 12758 -12768 seeing motor work and stalls from 12761- 12763. Reemed across interval with no noticeable motor work. RIH and dry tagged at 12,394' and weight up at 12,385' CTM. Corrected depths at 13,436' down and weight up at 13,427' CTM. POOH. Broke mill at surface. MU 4" GS spear w/ drift assembly. 4/11/2013 ..Job in Progress... CTU #3 w/ 1.75" CT ( CTV =34.9) Objective -mill and then drift thru obstruction at 12804' for GSO patch Finish POH after drift run. FP wellbore w/ 50 bbls McOH. LD BHA. Stab back on and blow down reel w/ N2. RDMO to SWS to reconfigure BOP's and perform planned maintenance 4/12/2013 Job complete • Daily Report of Well Operations ADL0312799 T /I /O= 2300/0/0; Conduct PJSM with S/L unit; Start barriers list= SSV & SV verify by independently bleeding tubing pressure off each valve, LTT passed; Remove tree cap flange and install ASV #13 on SV with new RX -44 ring gasket; Torque to API specs using 32 -022 truck and equipment calibrated 05/01/2013; Shell test to 300 and 5000 psi for 5 5/1/2013 min. LTT passed and charted; RDMO ***Complete*** ** *JOB CONTINUED FORM 5/2/13 * * *(E -LINE: ADPERF & PACKER SET) RIH W/14'x2.875" PJ HMX HSD GUNS, 6 SPF /60 DEG, PEN: 25.3" EH: 0.38" PERFORATED INTERVAL 13384' - 13398' RIH W/4 -1/2" WFD ER PACKER, OD= 3.69 ", ID = 2.375" SET PACKER MID ELEMENT AT 13380', TOP OF PACKER AT 13377' DEPTHS CORRELATED TO SLB PERF RECORD DATED 26 -AUG -2008 WELL SECURE AND S/I ON DEPARTURE, HANDOVER TO OPS FINAL T /I /O = 2650/0/0 ** *ACTUATED SWAB VALVE LEFT ON WELL * ** 5/3/2013 ** *JOB COMPLETE * ** T /I /0= 3200/0/0 Conducted PJSM w /crew; Start barrier list; Barriers= SSV & SV; Performed LTT (passed); Removed ASV #13 & installed tree cap; Torqued to API spec.; 5/6/2013 P.T. (charted) to 300 psi /5000 psi; Post E -line ** *WELL S/I ON ARRIVAL * ** (SL set patch) RIGGING UP SWCP NORTHSTAR S/L UNIT 5/17/2013 ** *CONTINUED ON 5/18/13 WSR * ** ? /I /O= SSV /0 +/0 +, Temp =SI. PPPOT-T (PASS), for tree repair. PPPOT -T: Stung into test port (0 psi). Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 5/18/2013 min (PASS). Bled void to 0 psi. T /I /0= 3700/0/0. Conduct PJSM. Barriers= SV and MV. Performed LTT on SV and MV independently. (Passed) Rigged up CIW lubricator with 5" "H" TWC to tree cap. Pressure tested to 300 psi low and 4500 psi high for 5 min each. (Both tests passed). Run in and set 5" "H" TWC (NS -3) at 135" with no ext. Bled tubing to 0 psi and perform LTT on TWC. 5/19/2013 (Passed). Rigged down lubricator and hung TWC sign. ** *Job in progress * ** ** *JOB CONTINUED FROM 5/18/13 WSR * ** (patch) STANDBY FOR TREE CHANGE JOB FOR SETTING PATCH SECTIONS POSTPONED TILL TREE FIXED STAGED EQUIPMENT IN STAGING AREA ON ISLAND 5/19/2013 ** *WELL TURNED OVER TO WELL TENDER * ** T /I /O = TWC /0/0. Conducted PJSM. Barriers = TWC & MV. N/D upper tree, c/o SSV & SV, re- install upper tree. Torqued flanges to API spec 1282 ft-lbs (L7M) & 1654 ft-lb (L7). ** *Job Incomplete * ** T /I /O= TWC /0/0. COnduct PJSM. Barriers =TWC and MV. Relieved day crew to complete SSV and SV valve replacements. Removed 6" Baker actuator barrel and replaced bonnett packing cartridge. Installed rebuilt Baker actuator barrel. Pressure tested tree to 300 psi low and 6500 psi high for 5 min each. (Passed, charted and saved to TRP folder) Rigged up CIW lubricator and "H" pulling tool to tree cap. Tested lubricator to 300 psi low and 4500 psi high for 5 min each. (Passed) Run in a reterieve 5" "H" TWC # NS -3 at 135" with no ext. Performed LTT on SSV and Swab independently(Passed) Rigged down and 5/21/2013 removed TWC sign. Final WHP's 3700/0/0 ** *Job Complete * ** 5/29/2013 12 i g up kill line to tubing and pressure test to 4700 psi. • • Daily Report of Well Operations ADL0312799 ** *WELL S/I ON ARRIVAL * ** (profile modification) RIG UP & PREP SWCP #08 5/29/2013 ** *WELL S/I ON DEPARTURE, PAD -OP NOTIFIED * ** 5/30/2013 Assist slickline standby for contingency. Job continued on 5 -31 -13 WSR ** *WELL S/I ON ARRIVAL ** *(profile -mod) R/U SWCP DC -8 5/30/2013 * * *CONT ON 05/31/13 WSR * ** * * *CONT FROM 05/30/13 WSR ** *(profile -mod) SET SECTION #1 - 4 1/2" SPACER PIPE x 30.7' @ 13, 323' SLM', 400# OVER PULL, SHEARED OFF RAN 4 -1/2" XN LOCATER & 3.70" CENT, UNABLE TO LOCATE XN -NIP @ 12,791' MD, SET SECTION #2 - 4 1/2" SPACER PIPE x 29.62' @ 13, 291' SLM, 400# OVER PULL„ SHEARED OFF SET SECTION #3 - 4 1/2" SPACER PIPE x 30.82' @ 13, 264' SLM, 400# OVER PULL, SHEARED OFF 5/31/2013 * * *CONT ON 06/01/13 WSR * ** 5/31/2013 Assist slickline, standby for contingency 6/1/2013 LRS unit 38 standby contingency for slickline ***WSR continued from 5/31/13 * ** * * *CONT FROM 05/31/13 WSR ** *(profile -mod) SET SECTION #4 - 4 1/2" SPACER PIPE x 31.68' @ 13, 234' SLM, 400# OVER PULL, SHEARED OFF SET SECTION #5 - 4 1/2" SPACER PIPE x 31.19' @ 13, 204' SLM, 400# OVER PULL, SHEARED OFF SET SECTION #6 - 4 1/2" SPACER PIPE x 30.7' © 13, 1724' SLM, 400# OVER PULL, SHEARED OFF RAN 4 -1/2" BAIT SUB, HES DPU, WFD ADAPTER, 4 -1/2" ER PKR W /SECTION #7 - 4 1/2" SPACER PIPE x 21.80' @ 13, 148' SLM, 400# OVER PULL TOP OF PAKER ESTIMATED © 13116' SLM * ** NOTE: TOP OF PATCH © 13177' ELM BASED ON WHERE E -LINE SET CENTER ELEMENT ON BOTTOM ANCHOR @ 13377' ELM * ** 6/1/2013 * * *CONT ON 06/02/13 WSR * ** * * *CONT FROM 06/03/13 WSR ** *(profile -mod) DRIFT W/3.85" NO -GO CENT & BRUSH TO 2016' SLM (2032' MD) SET 4 -1/2" WRDP -2 (ser# HCS -170) IN SVLN @ 2016' SLM (2032' MD) GOOD CLOSURE TEST 6/2/2013 ** *WELL LEFT S/I ON DEPARTURE, WELL TENDER NOTIFIED * ** 6/2/2013 LRS unit 38 standby contingency for slickline ***WSR continued from 6/1/13 * ** FLUIDS PUMPED BBLS 7.7 DIESEL 717 1% SLICK KCL 341 1% SLICK KCL W /SAFELUBE 106 60/40 METH 340 1% 776 LUBE WITH 0.25 PPB FLOWVIS 286 2% KCL W /SAFELUBE 30 GEL • Daily Report of Well Operations ADL0312799 129 METH 1956.7 TOTAL Casing / Tubing Attachment ADL0312799 Casing Length Size MD TVD Burst Collapse CONDUCTOR 156 20" 169# X -56 45 - 201 45 - 200.92 4260 2590 LINER 1780 7" 26# L -80 11196 - 12976 9344.3 - 10794.8 7240 5410 LINER 740 4 -1/2" 12.6# 13Cr80 12789 - 13529 10630.7 - 11305 8430 7500 PRODUCTION 11371 9 -5/8" 47# L -80 44 - 11415 44 - 9516.57 6870 4760 SURFACE 3715 13 -3/8" 68# L -80 44 - 3759 44 - 3355.63 5020 2260 TUBING 12765 4 -1/2" 12.6# 13Cr80 40 - 12805 40 - 10644.7 8430 7500 • • • • Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS07 PACKER 11196 9288.2 7" Top Packer NS07 PACKER 12755 10544.97 4 -1/2" Top Packer NS07 PACKER 12789 10574.6 5" Baker ZXP Top Packer " TREE= ABB-VGI 5-1/8" 510 WELHEAD= ABB-VG' 13-5/8" MULTBOVVL 5 NS07 —JOY NOTES: WELL REQUIRES A SSSV. ACTU2TOR = BAKER ***" CHROME TBG & LNR*** 4-1/2 _ . INFTIAL KB. E.E 562' BF. 8.B/ = 402 ((B 15.9') 16-1(i le ---I 13-3/8" DV Tool I KOP= 50' Ma Angle = 42° 10457 ... I D3tUM MD= 1270 2032' H4-1/2" SSSV w /HXO SLVN 141P, D = 3.813" I ' Datum TVD= 10500 SS 113-3/8" CSG, 682, L-80 BTC, I) =12.415' H 3759' I GAS LIFT MANDRILS ST MD ND GEV TYPE VLV LATCH PORT DATE Minimum ID = 3720" @ 12803' 2 5189 4526 33 SMOR OM( BK-2 0 05/18/02 1 6512 5631 33 SMOR DMY BK-2 0 06/14/02 CRUSHED BAKER LNR HGR ITOPOF r LNR I 11196' a 4 11106' H9-5/8" X r BKR UR TOP PKR, D = ? o 3 * 1121T H9-5/8" X 7" BKR LNR HGR, ID = ? I 19-518 CSG, 47It, L-80 BTRA-C, 13= 8.681" H 11415' I — A 1271 r I — 4-irr FBER opnc I TRANSDUCER, ID = 3.958" 12721' ELM 12734" H4-112" 2ES X M ID = 3.813" I 12766' 7" X 4-1/2" BKR PERM PKR, ID = 3.875' I 0 0 . 11 = 12780' H4-1/2' HES X NP, ID = 3.813' I I 12789' Hr x 5" BKRUNRTOP PKR, D = ? I TOP OF 4-1/2" LM H 12789' 12791' _I— 4-1/2" FES XN MP, ID = 3.725" P 12782' ELM 4-1/T 713G, 1261*, 13CR-80 VAM-ACE, 12804 i 1 12803' I-1 x 5" CRUSHB) BKR LTV HGR, 2 s .0152 bpf, ID = 3.958" MILLED TO 3.720 (04/11/13) , 1 I 12804' H4-1/2" WLEG, Cs = 3.958" I 7 LNR, 2041-80 Hydri 521, H 12976' 12774' SLM HOFFSET VVLEG, II) = 2.4" (see 06/15X)2 WSR) I .0383 bpf, ID= 6.276" L 12813' H5" X 4-1/2" X0, ID = 3.958" I PERFORATION SUMMARY REF LOG: PEX41121A-DSI on 05/10/02 M 1317T H4-1/7 UPPER INFO ER PKR, D = 2.375" (08/01/13) I ANGLEAT TOP PERF: 23° ' 13186' Note: Refer to Ftoduction DB for historical perf data SIZE SW INTERVAL (MD) Opn/Sqz SHOT SQZ 2" 6 13186 - 13210 C 08/01/02 2 12 13210 - 13300 C 06/27/02 I 2" 6 13300 - 13320 C 07/30/02 2" 6 13334 - 13354 C 08/26/08 I 2" 6 13354 - 13374 C 08/27/08 1537r H4-112" LOWER WFD ER FKR, ID = 2.375" (05/03/13) I 2-7/8' 6 13384 - 13398 0 05/03/13 M PBTD 13440 I I 4-1/2" LW, 12.62, 13CR-80 VAM-ACK —I 13529' I 'O '...........V .0152 bpf, ID= 3.958" DATE REV BY OIMMENTS I DATE REV BY COMMENTS NORTHSTAR 05118/02 BPIF IMT1AL COMPLETION 02/23/12 PJC DRAWING CORRBCTIONS VVE3.1.: NS07 11127/07 WM:MC WHIM/ LOC es "."4- • . 04/30/13 CJS/ PJC CRUSHED LW HGR (4/11/13) P132MT N3: 06/25/08 RCT/PJC GLV C/0 (05/18 & 06/14/02) 05/14/13 SET/JM) ADFERFS/SET B2 PKR (05/03/1: AM No: 50-029-23081-00 06128/08 VVRR/PJC [RAMC CORRECTIONS 06/10/13 vvECIJAA) SET UPPER BIRCR (06/01/13) SEC 11, T1312, R13E, 1109' FSL & 642' FEL 09/05/08 'AR/PJC PERFS (08(27- 27/08) 02/17/11 243/JOA) ADDEID SSSV SAFETY N:2 :I BP Exploration (Alaska) i • ` ) oF/Ty7iV T HE STATE A �� �I �i T Alaska i� and Gas F —_ ��� °f ALA SJ��l 1 Conservation Commission ice,_ __ -_ = -: a C ■ * , , GO VERNOR SEAN PARNELL 333 West Seventh Avenue (4 ' AL Q, Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Mark Sauve SCANNED APR 12 2013 Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 ., 0 - t1 -- O 7 7 Anchorage, AK 99519 -6612 � Re: Northstar Field, Northstar Oil Pool, NS07 Sundry Number: 313 -157 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy . Foerster Chair DATED this I ) a y of April, 2013. Encl. STATE OF ALASKA i it/ / L3 . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS , -, � .. s , f .. 20 AAC 25.280 ' 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ei . Suspend ❑ Plug Perforations el Perforate Q Pull Tubing ❑ Time Extension ❑ a c Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. cema -q 1-r Ze 151 ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. VL BP Exploration (Alaska), Inc. Development El . Exploratory ❑ 202 -077-0 , 4-/I // 3 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23081 -00 -00 . 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS07 Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312799 • NORTHSTAR, NORTHSTAR OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13529 11305 „ 13484 11262 None None Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 3715 13 -3/8" 68# L -80 44 - 3759 44 - 3355.63 5020 2260 Intermediate None None None None None None Production 11371 9 -5/8" 47# L -80 44 - 11415 44 - 9516.57 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4-1/2" 12.6# 13Cr80 13Cr80 40 -12805 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 15I BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 4/12/13 Commencing Operations: Oil 1151 . Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark Sauve.@BP_Com Printed Name Mark Sauve Title PE Signature . " Phone 564 -4660 Date 1/17/2013 / / / 7 3 - ?0 —/'3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313-(51 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS APR 12 201 Spacing Exception Required? Yes 0 No d Subsequent Form Required: jQ - 41, ��'/�, APPROVED BY Approved by: �i )14074---" COMMISSI THE COMMISSION Date: '� / 0 R� 801 A� A l �- fog /� / 1 0 Approved application is valid for 12 Months from the date of approval. Submit in Duplicate -t- `0 111 I,.- • • NS07 - CT GSO with Patch /Perforate To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead Date: March 28, 2013 Code: ANSNRWOS From: Mark Sauve IOR: 200 NS Pad Engineer Subject: NS07 GSO — with Patch and Perforating Sundry #: 313 -026 Reviewed by (D &C Personnel): Michael Hibbert NS07 is a high GOR well. It is advisable to use precautions typical when working on high GOR wells during this intervention. Please perform the following procedure: 1. C Mill XN nipple, Mill Obstruction at 12,804', FCO down to PBTD 2. E Perforate 14' and set lower KB packer for patch 3. S Stack patch and set upper KB packer, reset SSSV Current Status: Operable, Natural Flow Well Last Test: 01/04/12 1,115 BOPD; 287 BWPD; 73,347 MMSCFD; 65,754 GOR; WC 20.5% Max Deviation: 42° @ 10,452' MD Minimum ID: 2.4" @ 12,774' MD (4 1 /2" Offset WLEG) Last Downhole Op: 08/28/11 SL: Drift Tubing to 4 Y2" BBE SSSV at 1990' slm w/ 3.84" CENT. Last TD Tag 02/12/10 Caliper Survey — TD tagged @ 13,389' SLM w/2.27" CENT & S- Bailer (corrected depth of 13,398 MDBKB) Latest H Value: No H2S production at Northstar Last SBHPs 07/23/06 5,106 psi @ 256 F — 2 SI Days @ 11,100' TVDss Current estimated reservoir pressure is 5150 psi at 11,100 TVDss. Program Obiectives: II ! The objective of this procedure is to shut off all 174' of gas producing perforations in the well with a patch and add 14' of downhole perforations to increase standoff from gas and reduce GOR. Page 1 of 9 • NS07 - CT GSO with Patch /Perforate ' Well History: NS07 has undergone acid /scale inhibition treatments annually since 2003 and has historically responded well to these treatments. However the increasing gas rate from NS07 has severely restricted the liquid deliverability. During the well's completion, the tubing was run in and the WLEG tagged up on the liner tie back sleeve and partially crushed it. A caliper survey done in Feb -2010 showed a 4" section at the top of the liner tie back sleeve that had been crumpled, resulting in a restriction 2.4" id. The added perforations will be below the original oil water contact, so it is likely initial production may be at an elevated watercut. Watercut should decrease over time as oil and gas is coned to the new perforations. Any questions and /or comments, please call Michael Hibbert at 564 -4351 or 907 - 903 -5990, or call Mark Sauve at 564 -4660 (w) or 748 -2865 (c). CC: Well File North Slope CTU Milling XN and Obstruction: 1. RU 1.75" CT, tanks, associated equipment. Filter all fluids possible to 3 microns. • Make sure returns can be routed to tanks or to the facility separator. 2. Load and kill well as needed to RIH. • Welibore volume is 200 bbls to the top pert w/o CT in the well and 160 bbls w/ CT in the well. 3. MU left handed motor and 3.80" mill. Use Crayola style mill with fine grade Opticut cutting structure and string reamer. 4. RIH and mill XN nipple at 12,791'. • Continue to pump to keep hole full if needed. 5. RIH and mill up obstruction at 12,804'. • It appears to be 4" long and is crushed liner tie -back sleeve. (see caliper 3D pictures at end of procedure) • Back ream any tight spots thoroughly so that no sharp edges remain. 6. RIH and tag TD. Cleanout any fill encountered down to 13,425'. (Minimum cleanout depth is 13,398' for perforating). • If fill is encountered then pump Powervis gel sweep to help lift out any debris. 7. POOH. 8. MU MHA with 3.70" KB packer drift 9. Drift to 13,400' with KB packer drift • Ease through milled section and verify that there is no drag /weight bobbles. 10. POOH. Secure well and begin RD. Flag well to remain shut -in until such time as slickline can re -start patch deployment operations. EL Perforate and Set Lower Patch Packer 1. RU EL 2. MU 14' of 2 -7/8" perforations. • Tie -in with log attached below. Page 2 of 9 • NS07 - CT GSO with Patch /Perforate 3. RIH and perforate from 13,384'- 13,398'. 4. POOH. 5. MU lower patch KB packer. 6. RIH and set Packer 13,380'. 7. POOH. 8. RDMO. SL — Stack Patch and Set top KB Packer, and set SSSV 1. MIRU SL. 2. Stack patch sections on top of KB packer set at 13,380'. 7 sections. 3. Set top KB packer. 4. Install SSSV 2032'. 5. RDMO. Page3of9 NS07 - CT GSO with Patch /Perforate BP, Exploration ''' Short Well Name: NS07 04** LW Name: NS07 Operator: Schlumberger 2 L RUN_DATE: Drilled Depth: 13529' Spud Date: 2002 -04 -18 00:00:00 X Coordinate: 659835 Measurement Ref: KB Y Coordinate: 6030881 Ref. Elevation: 56.1 Vertical Scale: 1:600 _ayout Name: DigitalWF_web Plot Date: 15 - Feb - 2010 o -0 < BEST.R)OS 1 — N m w 0 0.2 Ome — 2000 D N N BEST.R83 1 • (n 71 T m 0.2 ommM 2000 N ?1 5 O O 0 -1 BEST BEST.DT_1 r �L , - , 0 0.2 OHMM 2000 105 US /F 55 BEST.PEF 1 p I n - 0 -0 m - m 0 BEST.RMED 1 BEST.NPHI 1 O GAPI 20 7 _ 0.2 omm 2000 30 PO 0 - J• .GR 1 BEST.RD BEST.RHOB O GAPI 150 0.2 OH MM 2000 2.2 GCC 2.7 ,' .,tea. } i ...'-- _.- -... --" -'- °' L I - - -- TSBC = I __ .. ..L- ----..L 31 I r I _____ T _ - TSSB = 10900 —..r -- - �... -' f - -- _ -- ------ . .._ F -- I-- _... t T31E --- t--._... r ---- . -.__..1 __ 13200 - __..._ .,___ _ I ... _ 28 _ -:. ; - r . T -- --- - r - - - - r — t r ---- - - -- �_ - H- -.. F __.' \ F - - - -- F- .. - 6 - F T ZC3 — . L __.._L-- '.1_- _.....L � I I I I _ 11000 I I -I I = - -- = 1- f F H -- ....I- - - -. i- - - -- i_. TZCC2 = L... - 13300 =_ I -.,.. _....I ._ - _. -- TZC1 = 1-- _ . __ ___... I-- - --. _ . F- Perforate 13,384' — 13,398 ' MD ▪ 1100 - • � 7-- - 1 - - ---- 1 --- - - C T H .. Tag TD 02/12/10: 13,389' SLM; corrected - 13,398' MD - = I I I I = - - -- ;TM PBTD: 13,440' r ----- . ..... _ — -. -.. I F__ -..F_ -i- a F L-- - L_ ▪ 11200 - - -r - -- 1 - - -_T_ _ -- I - t r--- ._ F__ - r - - -- 4_ 13500 = - - --- F - --... __ . _ .. {--_--...r- ---...1- --- -.- ---- 1 -- ._.. -F T 224K - _ L-- .._L-_- ...L- -_.1. -. I I I I I Page 4 of 9 0 • NS07 - CT GSO with Patch/Perforate Schiumberger Cornpar BP Exploration (Alaska). Inc. Well: - NS07 FINAL Field: Northstar Borough North Slope State: Alaska Perforation Record Li COL/ GR / 2 PJ 2006 —I .2 UJ g 26-August-2008 Z ...— ,._.— C 1109r FSL & 642 FEL Bell.: KS, 56.10 ft . z at Surface G.L. 16,90 ft .2 ,......i t 5 DE. 0.00 ft g t".■ K p 8, 141 g Permanent Datum: IVISL €01 0.00 ft Log Measured From: RIO 56,10 ft above Perm. Datum c I Dam Measured From; RIO al 2 10 CI 2 ..4.:: E API Serial No. Section Toymship Range so 2 A g 8 50-029430131 11 13N 13E L000ino Osze 26 Run Number 1 , _ Depth Drifter 13440 ft Schturnbarger Depth 14435 ft Bottom Log interval ' - 13374 ft „ „,,, Top Log Interval ' 13334 ft Casing Fluid Type Prodiotion Fkide Salinity I Density Fluid Level BIT/CASING/TUBING SVIIM Bit Size From To Casint u , ' ! Size 4.500 in Wei! 12.6 Ibmitt c ade 13 CR From Oft To 13529 ft Maximum Recorded Temperatures Logger On Bottom Time 26-Aug2008 1:01 Unit Nurrtpar Lgxialion 4101 1 PSU 1 L_____ 120eArr1gaA R.; la rhe4flevergn ,r hi I tinfetiv Page 5 of 9 • NS07 - CT GSO with Patch /Perforate ,.. ._,..,..:..�,,_ Nr ■ — as— .at— a.- -._ ca■ai.a.aara.aa�a as ■.i rr�.irirrr�r.r��r■■r...� ■rr.irrr -- aa—aa - - -- a— aaaa- -- -- -- — a.■. ..�t�� a.a�aai�. 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OILY IF. RBI . 4117 (CB Vag) 1 0o' 1 EN Tod I PCP . 547 Max ANN at 47 10457 2Q32' H4-1i7 SSW vo moo sum 0. &sir I I • 1 t tiatarcwo; 'moss 0 1 I mu- maw L SiC, D. 'UAW hi Ira, I GAS LFTIMOEMBIS ST MD WO CB/ TYPE VLV LI1TGI FORT (ATE ilk1IIINIM ll) 212 2A' s 0 12803* 1 IIIP 2 WM 48 33 SAM DIff INA2 0 am esa2 1 8512 5631 33 SIAM EMT 61E4 0 06114112 OFFSET VV LEG (12774" SLM) ITEP cv r tie H filer • 1 two Hg,se-x r staufurcemt, e. 7 1 tl 11211 H0-66" x r IMIRLIMMON ro. 7 1 19.51" CSG, 47t, usa emsc, ca. tsar H 11415 12 715 4-117 FEER CFTC TRAPEOUCEN, D .astar I 1213or 1-14-ior NES X Iv, 0.1617 I 12755 r i<4,1tr BAR PERM PKFL 10. 3.677 el ME I 1278(r 1-14-107" HES X IC, D.1017 I 127sir H7" XV IMALMITOPIMA, D .1 I ITO:ICC 4.1/7 LAIR i' I 1 127,1* Wirt EA H4-10106104 PIR D .3327 I I 4-117 lEIG., 12.611 1301416 VNA -ACE, ILL , ;,..j11 9 1 --- --1 Vsoy Hr xs- EARLININGR, ta. ? I r Infi21111,13.3.1fir 12for 1-14oir MEG, D 3SW l 11271g SUN HOFFSET ALEIG., 42 it 2A. 111111116 OM fin? WSRli I r Liam* uaa oriti 62 t 12971F 12$12 Hs- x 44rig• XO, D . &oar .03631111, D .6276' TEN SLIAMARY L PEF LOa P13{4144LADSI an 05410112 AMIE AT 1CIP FEW° 23 0 13166 • Nober MANN Ptroduektre DS for hogasioad pod dots SIZE SW IINEFIVAL 411:0 °golf:Mx DATE I 7 8 13166- 13203 0 06111102 7 12 13210 - 13300 0 0627.432 7 8 13300 a 13320 0 07130f62 7 8 13334 - 1 ant 0 0628t011 7 8 1 3354 - 13374 0 wawa I : iirL jm 1 41 tr tia mut =RAD VAN-AE. 13—L 5,..._ k ort . 55,51 .0152 NA, Ea. 1267 DATE WV SY CATS BATE REV BY CCANENTS I NORINSTAR MAIM MIFF WIN_ COMPLETION 1 V23/07 WRARD MUNN LOOIVIDON 03144SOMOI.E WaL NSW 07.03+02 E&F AfD 0625,156 RCPRIC GLV ao (0611 8 41 Mil NM IT Pb 1 2020775 06.0662 BAF ALD PEWS 041213f06 IAIRIFRIC DRMAIMG CORRECOCON API Pb 60-029-23061-O0 12073112 OAF UFDA1EMIS PAO ONOSIO6 INFEMITC FETES (ON27- 27ota) sEc I I, T1& 1113E„ 1107 FSL & 647FEL 11O4/16 RN 164 FIAT 0217111 410.113 ADDED SSSV SUETY NOTE 07A3W6 WAR %LEG CCEIRECEDNION15412) IIIP &Mastodon (Aka} Page 7 of 9 • NS07 - CT GSO with Patch Perforate 0 PERFORATING PROCEDURE Vcr 1.2. Rev 10121,01 Well: N507 API*: 50- 029 - 23081 4 Date: 3128113 Prod Engr Mark Sauve Office Ph: 564 -4660 H2S Level: Home Ph: 0 Cost Est: 175,000 Cell /Pager: 740 -2865 CC or AFE: ANSPERFS WBL Entries IOR Type %dork Descipticn 250 E LPerforate from 13,384'- 13,398' Well (lhjactivac and Perforating Hatay- These perforations will be added prior to setting a patch fora GSO. Attachment: Reference log with proposed perfs annotated, 5'7100' scale Reference Log Tie in Log Add 0 feet Log: CCLIGR PEX- HRLA -DSI to the tie -in log to be on Date: 8/2512008 511012002 depth with the reference log_ Company: Hali SLB Depths (from -to) Depths (from -to) Feet SPF Orient_ Phasing Zone Add/Re-pelf 13384' - 13,398' 13,384' - 13,398' 14' 6 Random 60° Mshak APF • Requested Gun Size: 2 -718" Charge: 2906 PowerJet HMX Is Dravdovn NecessaryiDesiredfUnnecessary During Perforating NA Preferred Amount of DrawdovnlSuggestions to Achieve Draw down NA Last Tag: 13,389 ft ELMD on 2/1212010 Est Res. Pres. @ 11,100 110 is 5,106 psi est from offset wells Perforation Summary Summary Dist Well: N507 Town: Date: API 1: 50- 029 - 23081 -00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Based on Ref Log Gun Dia. Orient. SPF Phasing Zone AdperfUReperf 0181U - 01B1U - 01B1U - 01B 1 - 01B/U - 01B?U - 01B1U - Page 8 of 9 • NS07 - CT GSO with Patch /Perforate 3.17 3.11 3.12 3.21 1.11 2.11 2.GG '2.5G 2.51 2.51 2.11 3.11 3.27 3.1? 3.31' "" 3.11 3.55 3.31 3.G2 3.54 IN u m Mm = Page 9 of 9 • • Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS07 8/1/02 APF 13186 13210 10983 11005 NS07 6/27/02 PER 13210 13240 11005 11032 NS07 6/26/02 PER _ 13240 13270 11032 11060 NS07 6/26/02 ' PER 13270 13300 11060 11088 NS07 7/30/02 PER 13300 13320 11088 11107 NS07 8/27/08 APF 13334 13354 11120 11139 NS07 8/26/08 ' AP 13354 13374 11139 11158 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing Summary ADL0312799 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade LINER 740 1 -1/2" 12.6# 13Cr8( 12789 13529 10631 11305 8430 7500 13Cr80 LINER 1780 7" 26# L -80 11196 12976 9344 10795 7240 5410 L -80 PRODUCTION 11371 9 -5/8" 47# L -80 44 11415 44 9517 6870 4760 L -80 SURFACE 3715 13 -3/8" 68# L -80 44 3759 44 3356 5020 2260 L -80 TUBING 12765 1 -1/2" 12.6# 13Cr8( 40 12805 40 10645 8430 7500 13Cr80 • il • • • Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS07 PACKER 11196 7" Top Packer 9344 NS07 PACKER 12755 4 -1/2" Top Packer 10601 NS07 PACKER 12789 5" Baker ZXP Top Packer 10631 ti of T7� THE STATE Alaska Oil and Gas tv F .:: (ALASKA Conservation Commission A �_ 333 West Seventh Avenue '„ GOVERNOR SEAN Anchorage, Alaska 99501 -3572 rho PARNELL OF ALAS 907.279.1433 Fax: 907.276.7542 AYpEa FEB 2 6 na Mark Sauve SC W Petroleum Engineer � �� � FJ BP Exploration (Alaska), Inc. I P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS07 Sundry Number: 313 -026 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this Z? day of January, 2013. Encl. _ + RECEIVED • STATE OF ALASKA • JAN 18 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION 07 1/ ha APPLICATION FOR SUNDRY APPROVALS A 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill[), Perforate New Pool ❑ Repair Well El Change Approved Program ❑ Suspend El Plug Perforations'❑ U4 _, 19 • Pull Tubing ❑ Time Extension ❑ Operations Shutdown El Re-enter Susp. Well V F � 23 �/ 3 Stimulate ❑ Alter Casing ❑ Other. Cement Squeeze El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development El • Exploratory ❑ 202 -077-0 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23081 -00 -00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 458A NSTR NS07 Will planned perforations require a spacing exception? Yes ❑ No 19 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0312799 • NORTHSTAR, NORTHSTAR OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13529 ' 11305 13484 11262 None None Casing Length Size MD TVD Burst Collapse Structural Conductor None None None None Surface 3715 13 -3/8" 68# L -80 44 - 3759 44 - 3355.63 5020 2260 Intermediate None None None None None None Production 11371 9 -5/8" 47# L -80 44 - 11415 44 - 9516.57 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# 13Cr80 13Cr80 40 -12805 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil is ' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark Sauve.©BP.Com Printed Name Mark Sauve Title PE Signature if/ / Phone 564 -4660 Date 1/17/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 2Jj J----(312(40 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: (zsp",1 fiBDMS JAN 2 8 201 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / T1 — 4) a-- APPROVED BY C/ Approved by: .34C,"741----- COMMISSIONER THE COMMISSION Date: / —,,S -- 13 Q RTGI ed 1/2P10 Approved application is valid for 12 months from the date of approval. Submit in Duplicate L UL t l2 ,` ) 'I- • NSO7 CT GSO with OrganoSEAL and SqueezeCRETE To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead Date: January 10, 2013 Code: APBNRWOS From: Mark Sauve /Lea Duong IOR: 200 NS Pad Engineer /Petroleum Engineer Subject: NS07 GSO with OrganoSEAL and SqueezeCRETE Sundry #: Reviewed by (D &C Personnel): NS07 is a high GOR well. It is advisable to use precautions typical when working on high GOR wells • during this intervention. Please perform the following procedure: 1. D Shoot IA FL to determine IA load volume required 2. F MITIA at 1500 psi 3. S Pull SSSV. Drift and Tag with 2.3" toolstring to TD. Confirm BKB PBTD. 4. C Acidize. Gel and cement squeeze. Pressure test wellbore /squeeze. 5. S 2' dummy gun run, confirm BKB TD for perforating 6. E Perforate 14' with 2" HSD 2006 PowerJet Omega, HMX 7. T Flowback to test separator and well clean up tank. 8. S Install SSSV. Current Status: Operable, Natural Flow Well Last Test: 01/04/12 1,115 BOPD; 287 BWPD; 73,347 MMSCFD; 65,754 GOR; WC 20.5% Max Deviation: 42 @ 10,452' MD Minimum ID: 2.4" @ 12,774' MD (4 1 /2" Offset WLEG) Last Downhole Op: 08/28/11 SL: Drift Tubing to 4 1 /2" BBE SSSV at 1990' slm w/ 3.84" CENT. Last TD Tag 02/12/10 Caliper Survey — TD tagged @ 13,389' SLM w/2.27" CENT & S- Bailer (corrected depth of 13,398 MDBKB) Latest H Value: No H2S production at Northstar 5,106 psi @ 256 F — 2 SI Days @ 11,100' TVDss Last SBHPs 07/23/06 Current estimated reservoir pressure is 5150 psi at 11,100 TVDss. Page 1 of 13 r • NS07 CT GSO with OrganoSEAL and SqueezeCRETE Program Objectives: The objective of this procedure is to shut off all 174' of gas producing perforations in the well and add 14' of downhole perforations to increase standoff from gas and reduce GOR. Well History: NS07 has undergone acid /scale inhibition treatments annually since 2003 and has historically responded well to these treatments. However the increasing gas rate from NS07 has severely restricted the liquid deliverability. It planned to pump gel and squeezecrete cement into the existing perfs to shut them off and reperforate deeper in the wellbore. The reason to use this method is the probability of prolonging the life of the squeeze. Other squeeze methods tended to breakdown early and reintroduce gas entry. The added perforations will be below the original oil water contact, so it is likely initial production may be at an . elevated watercut. Watercut should decrease over time as oil and gas is coned to the new perforations. Any questions and /or comments, please call Lea Duong at 564 -4840 (w) or 720 - 951 -7238 (c) or Dan Robertson at 564 -5546 (w) or 529 -5818, or Mark Sauve at 564 -4660 (w) or 748 -2865 (c). CC: Well File North Slope Page 2 of 13 • NS CT GSO with OrganoSEAL and SqueezeCRETE • NS07 Procedure Coil Procedure: OrganoSEAL: This procedure includes the use of OrganoSEAL R gel to achieve matrix penetration to a radius of 2.25'.,/ Organoseal is a linear gel that is pumped at relatively low viscosity, then sets up to a gel with time and temperature. The gel will be followed immediately with SqueezeCRETE to provide a cement cap near wellbore to help hold the gel in place. SqueezeCrete: Schlumberger's SqueezeCRETE is a microfine cement with more rounded and smaller particle sizes than typical class G cement. SqueezeCRETE has low fluid loss values, high resistance to dehydration and high stability to free fluid and sedimentation. The objective with using SqueezeCRETE is to attempt to displace cement into the rock matrix as opposed to just filling perf tunnels or building nodes in the liner as is common with class G cement. SqueezeCRETE particles are on the order of 7 microns, while class G typically has 40 -50 micron particles. The pore throat size distribution chart below indicates predominantly 20 micron pore throats for the Ivishak reservoir. The pore throat size to particle size ratio is approximately 3, so some pore throat bridging may occur even with the finer cement, i.e. it is anticipated surface pressure will increase with cement across the perforations, but there is a chance it could be pumped into the matrix. Ideally at least some matrix penetration will be achieved. MACROPOREB MICROPORE8 — 0.008 Figure 78. Example — o_aoz M of trimodal pore -size — 0.006 x distribution often CHERT seen in Prudhoe Bay — 0.005 sandstone. Primary — 0.004 constituents of rock are intergranular gAOLIHITE — 0.003 pores, microporous chert and Kaolinite. — 0.002 The sample has an ERGRANULAR — o_aoi 4 average level of PORES permeability and I „" „ , , , ,,,, , , i,,,,” " ",,, , 0 porosity. 100 10 1 0.1 0.01 PORE THROAT DIAMETER [MICRONS] Primacy constituents of roa k- Page 3 of 13 • • NSO7 CT GSO with OrganoSEAL and SqueezeCRETE Procedure /Risk Discussion • All fluids pumped needs to be between 80 -100 F to provide adequate cooling of reservoir. • Annular capacity of the 1.75" ct x 3.958" ID tubing is 0.0122 bbls /ft. • Ensure that a ball drop cementing nozzle is available for use prior to job. • Post cementing cleanout if milling is needed: Pump biozan /flopro sweeps as needed for hole cleaning. Monitor for symptoms of cuttings buildup like pulling increased weight and pull uphole and circulate in the 4 1 /2" tubing as needed to aid in hole cleaning. There should be minimal cement cuttings to remove from the well if all goes as planned. Monitor returns rate to confirm squeeze is holding. Open circulating sub when done milling and circulate bottoms up at max rate prior to /while POOH. • OrganoSEAL R volume is based on 2.25' of radial penetration over 174' of perforations at 20% porosity. Wells group to confirm disposal options for unused product prior to ordering. • There is currently 8.6 ppg inhibited seawater from the packer to 3,887' MD/ 3,460' TVD in the IA. There is thought to be diesel from 3,887' MD to surface in the IA. • Total volume inside the 4 1 /2" liner from the liner top to TD at 13,440' MD is approximately 9.7 bbls. • DGLVs are currently installed. • 02/12/10 Caliper 328 jts 0 -18 %, slight to moderate buckling, increasing severity w /depth —2500 to —12,700' MD. • 08/11/2005 Acid treatment was performed. Injection rate observed of —5 bpm @ 800 -1000 psi. Pre - Squeeze: 1. Shoot IA FL to determine amount of fluid volume required. 2. RU pump trucks & fluid as necessary. Load and PT IA at 1500 psi with dead crude. If it fails, establish LLR. RU to bleed gas off annulus down flowline as needed to ensure IA is loaded to near surface. Burst pressure for the tubing is 8,430 psi. A maximum differential pressure of 2500 psi is expected throughout the entire treatment. 3. RU SL. Pull SSSV. Drift and Tag with 2.3" toolstring to TD. Tie -in @ wellsite leader's discretion for depth control. It is critical to confirm an accurate BKB PBTD to determine if a ct cleanout is required prior to cementing. - 12,774' SLM Offset WLEG, ID =2.4 ", may be able to correct to this jewelry. CTU Gas Shut Off: 1. RU 1.75" CT, tanks, associated cement squeeze equipment. Filter all fluids possible to 3 microns. q p 2. Apply 1000 psi to the inner annulus and monitor/ maintain 1000 -1500 psi throughout job. Do not exceed 2,500 psi differential pressure from tubing to IA or vice versa at any time. 3. Fluid pack well by bullhead 1.5 tubing volumes 3% NH4CL at —100° F. Perform step rate test at .5, 1, 2, 3, 4 bpm toward end of liquid packing. Do not exceed 0.62 psi gradient during liquid packing, acidizing or gel placement. 4. RIH with —2" ball drop nozzle BHA. RIH and tag PBTD at 13,440' MD. Correct to BKB depth based on prior slickline tag and ensure liner is obstruction free. Pump the following down the CT while reciprocating over the interval 13,186- 13,374' MD. Objective is to acidize all perforations to ensure they are able to take gel /cement. Pump below frac gradient of 0.62 psi /ft. Page 4 of 13 • ■ NS07 CT GSO with OrganoSEAL and SqueezeCRETE Acid Program • a. Establish injectivity with 3% NH4CL as needed b. 48 bbl 12% HCL c. 48 bbl 9:1 mud acid d. 300 bbls 3% NH4CI spacer water (to overdisplace acid well back into the formation, pump at , least 50 bbls of this down the ct with the nozzle —10' above PBTD to remove any acid from the sump, the remainder can be pumped down the ct x tbg annulus). Avoid jetting at PBTD to prevent stirring up solids and plugging perfs. Check acid additive packages for BHST of 256 °F and 8 -hour protection time for L -80 liner and 13cr tubing. Acceptable acid concentrations +/ -1% for HCI and +/ -0.25% for HF. Fluids should be less than 100 °F, if possible. 9:1 Mud Acid A264 ACI 10 gal /Mgal A201 Inhibitor Aid 60 gal /Mgal A153 Intensifier 20 Ib /Mgal F103 Flowback Aid 2 gal /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal U067 Mutual Solvent 50 gai /Mgal 12% HCI A264 ACI 8 gal /Mgal A201 Inhibitor Aid 60 gal /Mgal A153 Intensifier 10 Ib /Mgal F103 Flowback Aid 2 gal /Mgal L058 Iron Control 20 gal /Mgal W054 Antiemulsifier 5 gal /Mgal U067 Mutual Solvent 0 gal /Mgal 5. POOH 6. Perform step rate injection test down backside at 0.5, 1, 2, 3, 4 bpm to confirm injectivity prior to cementing. Injectivity of —5 bpm at 1000 psi is anticipated i.e. high injectivity (based on 8/11/05 Acid Job). If the injectivity is substantially outside this range please contact the program authors prior to pumping the gel and squeezecrete as it may be desirable to alter the planned volumes. 7. PU ball drop type cementing nozzle. RIH to TD. Pump 100 bbls NH4CL down backside to cool liner prior to cementing. Ensure at least 50 bbis is pumped down the ct with the nozzle just above the PBTD to cool the rathole below the bottom perfs. Do not circulate with the nozzle at PBTD to avoid stirring up solids that will likely plug perforations. 8. Pump —10 bbls of diesel or 60/40 methanol down the ct x tubing annulus as needed to freeze protect the tree and near surface during the cement squeeze. 9. Mix 100 bbls OrganoSEAL —R. Batch mix 25 pumpable bbl SqueezeCRETE to meet the following specifications. OrganoSEAL-R: Volume to pump: 100 bbls Gel thickening time: 5 -6 hrs minimum using BP Temp ramp below Viscosity during pumping: 20 -30 cp Ultimate viscosity: ringing gel Page 5 of 13 NS CT GSO with OrganoSEAL and SqueezeCRETE Recipe: Fresh water 6% by weight J491 Gelling Agent 0.3% by weight J525 Crosslinker 0.3% by weight J524Crosslinker (adjust as needed based on pre job testing) Note: OrganoSEAL -R can be disposed of as Class 1 Non - Hazardous material. Contact Penny Goodstein, HSE, at 564 -5069 with any questions. SqueezeCRETE: Volume to Pump: 25 bbl total (Have additional 25 bbls on -hand, if a re- squeeze is needed.) Cement Type: SqueezeCRETE Thickening Time: 9 -12 hours using BP ramp below Ultimate compressive strength: 3700 psi (not a requirement, but a typical number for reference if milling is required Fluid loss: <15 m1 /30 min, ideally 5 m1 /30 min Density: 14 ppg Pv: -50 cp Ty: >5 -15 Ibf /100 ft2 Filter cake: <5 mm (ideally no filter cake) Free water <2 ml Recipe: D163 Squeezecrete cement D206 Antifoam D145a Dispersant D173 FLAC (adjust as needed based on pre job testing) Estimated Batch Mix Time - 3 Hours Estimated Pump Time -1 Hours Estimated Clean -up Time - 2 Hours BP Cement Testing Schedule (BP ramp): 180 minute Batch time: 90 degF and 0 -500 psi 30 minute ramp to 190 deg F and 5000 psi 30 minute ramp to 215 deg F and 7000 psi 60 minute dwell at this temp and pressure 30 minute ramp down to 5000 psi and start a 1.5 deg F per minute increase to BHST. Hold until end of test. Page 6 of 13 NSO CT GSO with OrganoSEAL and SqueezeCRETE 10. Catch samples of OrganoSEAL gel and SqueezeCRETE cement for QC testing. Place samples in bath on site at 256° F. Also, transport samples to SWS NS lab for to monitor gel and UCA testing on cement. Line up cementers to the coil. 11. Ensure the backside choke is closed. Pump the following down the coil: a) 10 bbl spacer fresh water b) 100 bbls OrganoSEAL R c) 5 bbls spacer fresh water d) 25 bbl SqueezeCRETE cement e) 10 bbl spacer fresh water f) 1 -1/2# biozan 12. Monitor WHP while pumping. WHP should be 160 psi prior to pumping gel into the perfs, with a full column of NH4CI in the ct x tubing annulus. Reciprocate across the perforations 13,186'- 13,374' MD while pumping the gel out the nozzle. 13. Nozzle should be at the bottom perforation as the first cement exits the nozzle. Pull uphole slowly until 0.5 bbls of cement is above the nozzle, then pull uphole at a 1:1 ratio i.e. so that the ct nozzle stays just below the top of cement. Time the running speed so that the nozzle pulls above the top of cement just as the last of cement leaves the nozzle. Pull uphole an additional 100 -200' above the worst cast top of cement. (WCTOC if no cement is placed behind liner is 12,125' MD; 9.7 bbl 4 %" liner volume to PBTD plus 10.3 bbls of cement in 4 '/" tubing). With backside choke closed, begin increasing wellhead pressure by pumping down CT. o After cement is in place in the wellbore it is critical to ensure the wellbore is not underbalanced until after the cement and gel have set up. This is to avoid flowing any cement or gel back into the liner. If WHP increases with cement at perfs: 14. Pressure up psi 2500 si incremental pressure at the perfs in 500 psi increments. Hold each increment for 5 -10 minutes. Hold 2500 psi for 30 -45 minutes. 15. Open choke and bleed back to 500 psi. Swap to 11/2# biozan and drop ball. Chase ball to nozzle then RIH at 1:1 jetting at max CT pressure and clean out to TD. Leave biozan in liner across perf interval. It is critical to ensure no cement left in liner. The 2.4" tubing restriction will make later removal of cement difficult if it is allowed to set up in the liner. 16. Swap to slickwater and jet uphole at 80% running speed and max CT pressure. 17. Take barrel count to ensure 1:1 returns. 18. Slow down across all jewelry. Critical to maintain 500 psi backpressure at all times to keep pressure on the squeeze. Leave at least 1000 psi on the wellbore while waiting on cement. If WHP does not increase after pumping all cement: 19. Over displace all cement into perforations by —5 bbls with the water spacer. 20. Swap to biozan and clean out to TD. POOH at 80 %. It is critical not to leave any cement in the liner that may set up and have to be drilled out later. 21. Wait until Sqzcrete thickening time expires. Pressure Test. Discuss with Lea Duonq (907 - 564 -4840 work or 720 - 951 -7238 cell) or Dan Robertson (907- 564 -5546 work or 907 - 529 -5818 cell, or Mark Sauve at 564 -4660 (w) or 748 -2865 (c) whether to resqueeze immediately or move off well and allow cement and gel to set up. Page 7 of 13 with OrganoSEAL and SqueezeCRETE GSO wit ueezeCRETE O g q 22. If re- squeeze, repeats Steps 11.c. to 13. above. Pump cement only, NO OrganoSEAL, if re- squeeze. Obtain an injection rate at 1000 psi for comparison with later pressure test. 23. POOH. 24. Freeze protect w /2000 ft of 60/40 McOH. Fullbore Procedure: 25. Wait 3 days. Pressure test tubing at 1000 psi for 15 minutes with diesel or methanol. Establish liquid leak rate if pressure test fails. If there is a decreasing trend in injectivity, consider waiting awhile longer and try again. Contact program authors as needed with test results to confirm next step. E -Line Procedure: 26. Perforate from 13,384' to 13,398' MD 14' with 2" HSD 2006 PowerJet Omega, HMX - Correlate Tie -in Log with Schlumberger CCL /GR/2" PJ 2006 dated on 26- Aug -2008. Flowback Procedure: 27. Pop well through test separator and well clean up tank (500 bbls). Monitor for gel and solids returns. If the job works as planned there should be no solids or gel returns. After well stabilizes and an absence of gel returns is confirmed, obtain well test and divert to production. a. Expected rates: 1500 bfpd, 10K -20K GOR, 80% WC initially, with gradually decreasing watercut P P and increasing GOR. Slickline Procedure: 28. Install SSSV. WELL SERVICE REPORT WELL DATE JOB SCOPE DAY SUPV NS-07 8/28/2011 SSSV MAINTENANCE MCGUINESS COST CODE PLUS DAILY WORK NIGHT SUPV ANSFLDWL07 VALVE -SSSV- -SET NARDINI MIN ID DEPTH TTL SIZE KEY PERSON UNIT 2.4 " 12803 FT 0 " SWCP- MARINOVICH SWCP #08 DAILY SUMMARY * * *CONT FROM 08 -27 -11 WSR * * *(sssv c /o) SET 4 -1/2" CA.WRDP -2 SSSV (HHS -661 / 89" OAL) (has 2 sets normal packing & 4 -1/2" x -lock) IN HXO SVLN @ 1990' SLM / 2032' MD, GOOD CLOSURE TEST * **WELL FLOWING ON DEPARTURE * ** LOG ENTRIES !nit Tbg, IA, OA -> 1 3,8001 321 461 TIME COMMENT 00:01 CONT FROM 08 -27 -11 WSR. MAKING UP SSSV, REMOVING OJ's, & PURGING C/B LINES ** *.125 STN, TS = 8' x 2 -5/8 STEM, 1 -7/8" LSS * ** 01:15 RIH W/ 4 -1/2" X -LINE, XO, 8' 1 -1/4" PRONG & CA.WRDP-2 SSSV (HHS -661 / 89" OAL), (has 2 sets of normal packing also has 4 -1/2" x -lock) SET AT 1990' SLM / 2032' MD. POOH. 02:10 OOH. LINE UP TO TEST SSSV. BLED BAUCTRL LINES TO 0 psi. T 3875 / IA 0 / OA 0. BLED 300 psi OF OFF TBG TO 3575 psi. MONITOR FOR 10 mins 03:15 TBG PRESSURE HOLDS. PRESSURE UP ON SSSV & TBG PRESSURE COMES BACK UP TO 3875 psi, BEGIN PURGING BAUCTRL LINES 03:45 AFTER PURIGING 4 gals, RECIEVE CONSTANT HYDRO RETURNS @ BLEED TANK 04:00 BEGIN R /D, TREE CAP ON & PT'D, SSV TURNED BACK OVER TO PANEL 04:39 SWING OVER, UNSTACK PCE, LAY DOWN LUB. SECURE WELL HOUSE, CLEAN AREA 05:56 SECURE EQUIPMENT, CLOSE OUT PERMIT W/ PAD OP & BRING TO CONTROL ROOM 06:02 R/D COMPLETE, CLEAN EQUIPMENT, PAD OP BRINGS WELL ON. MONITOR WELL. Page 8 of 13 • NS07 CT GSO with OrganoSEAL and SqueezeCRETE 07:59 UNIT CLEANED & SECURE. LEAVE NS & TRAVEL TO PM - DOCK 08:00 END TICKET Final Tbg, IA, OA ->1 3,8751 0 I 01 BP Exploration Short Well Name: NS07 C 4 LW Name: NS07 Operator: Schlumberger "\ �L RUN_DATE: Drilled Depth: 13529' Spud Date: 2002 -04 -18 00:00:00 X Coordinate: 659835 i Measurement Ref: KB Y Coordinate: 6030881 Ref. Elevation: 56.1 Vertical Scale: 1:600 _ayout Name: DigitalWF Plot Date: 15- Feb -2010 8 BEST.RXXS 1 N m 0) 0 0.2 OHMM — 2000 F 11 – N N BEST.RXS 1 lz V) -Ti m m 0.2 OHMM 2000 m T _ O O O 0 C BEST.RS 1 BEST.DT 1 F m - , 0 0.2 OMAN 2000 105 US /F 55 BEST.PF.F 1 N I r i T T m-1 mU) BEST.RMED 1 HEST.NPHI_1 — 20 -, 2 0 ^' -, _ H 0.2 OHMM 2000 30 e0 0 BEST.GR_1 BEST.RD 3 BEST.RHOB_1 0 GAPI 150 0.2 OHMM 2000 2.2 GCC 2.7 - 31 _ .I___ - __e_L_ -...L � ` -`� - _ - -- T SHD = _L_- -1-- --"T- — — - - -_ l- . L -- -'1 tr 31 - I ... r -1- L- -..L_ i. L_ . — 2 -- ..-- 1 3200 _ _...I .. TZD = ..�- - f - - -.... .... 1----t-- - S _ - -- - 28 — --- - - - - .� ..2 1 1 1 1 T 4C3 — L__.._ _L --_.L __. c = - E- - - -- 11000 - _ _ . J -- -'- -'- --'-' _ --- - �r - � -- - - -- --- 1 -- _1 - -- 1 - --.. I - - - T 46 — 13300 = --_.�- ----... _..._ - - L, �/� I ___ _ ___. L_ I I 1 1 _ T 501 L . - -- .... . .. ___... - --._.� ° ° I ._ ...I .....i _..__ T 1100 Perforate 13,384' - 13,398' MD 1 - - - -- `a T 4 1 B FI E. 134 Tag TD 02/12/10: 13,389' SLM; corrected L � =_ 13,398' MD I = - – r I— I .. s3la - PBTD:13,440' .. r --- r - --..r _ - _ _ _ -. --- H - - t - -- _.}- L __... -- -...L- -_..L T 401 _ — 11200 — - I -- T - - - - -- 1- _ = - -_ r -- 1 ----- 1 ------ 1 - 13500 f- _. — - -_.- 1--- -___ ___...1_..__. -I._ T 24 : } _ _ L- ...L- ..L- -.L i = 1 1 1 1 Page 9 of 13 • . • . NA/CT GSO with OrganoSEAL and SqueezeCRETE i 1 SChIUMberger Company: BP Exploration (Alaska), Inc. Well: NSO7 FINAL Field: Northstar Boromili North Slope 310t, Alaska Perforation Record CCL / GR / 2 PJ 2006 -1 -2 IT I 26-August-2008 2 5 1109 FBI & 642 FEL Sew: KB. 56.1011 E 0 s z at Surface G.L. 1510 ft g 0 IR D.F. 0.00 ft Permanent Datum: ' MM. fa Log Measured F rom : ... RKB Elev,: 0,00 ft ,.. 56,10 It above Perm. 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Dv Tod I _.. . . _. . . .. _ . . _. ._. .... _ KO . 50 Mb Argh . 47 @ 10457 1 2632* 1-14-112' SSW w MO SINN FE, D. 3.517 I -----,......--------- 011ursTVD. 10500 SS lb 1134E' OSG, Mk 660 811C, ID. 12.417 H 371, I GAS LFTMOJCIIELS ST M) ND I CB/ TYPE I VLV I B LAT DUE 2 51 3 S CRY B as/to I hin imum N3 22.4 12 58 1 1 3 S C ft 12803' 1 1111P 81 4524 3 I= K-2 0 n 853 3IM DRY K-2 0 06/14432 1 OFFS ET WLEG (12774' SUN) , me oF r u H 11191r . II 1111111r 1 X T BKRLARTOP FiCR, U.? T---___I 1121T H9-511" X r DKR LNRFIGR co. 7 Kerr CSG, 47O,1410 ffrokc,a). tow H 11416 L i iqi !_ gi 4.1 ti• FUER ORE 1RMEDUCER 13 .3 oar I 12734* H4 letr FES X MP„ D. 3.411T I 12797 HT' X 4 V7 BARMEN RR, ID. &RS' I 1, Illts. I 127811 H4-142^ FES X FIR D. 3 Al T I UM 1-17 X 6" EICRLARTOPPIR, D .1 I IMP OF 4117 LIR i . . I 12/191* arra' Will 1-14-117 FES Ea MP, 0 14. V2" 1BG, 121141L 1301141 vsas-hca, mu•JAI 1 I --- --failf — Fir x 5" BKR UR FGR, D. ? I a r .0152 Opt, ID. 3.05r 1210; 1-14-117 MEG, D 112174 81.11 Fiir N.H. m rair (sir oan 5 MB) I i r ail. 2ts L40140,4 521, H 129711 12813' H5" X 4.147 XD, D . 1.45r I AM hpf, D.6274' PERFORM= BASIOJRY I IEF LOM FES -148A-1324 an 0511002 AMIE AT ROW 27 lg 1316/1 NSW War b Prodwkan CM for Itializbalpirf dala SUE B DEERVAL 4M 00Sql DALE I 7 6 13186 • 13210 0 GOO VCR 7 12 13210- 13300 0 0027/02 I 7 6 13300 - 11120 0 0703002 7 6 134.151 0 GOMM 7 6 13354 - 13314 0 0&271 I • Ma .11 . 1410 LFR, 12_64 =RIM VANI-ACE, 1, •,-! s w 1 /69 ' 4 4 a . : 0 1 4 Al S2 Opf,113. 3 A5r . , DATE Fel BY CO DATE REV BY COMEMIS II NORIFIS1AR ISAMU BM WARM. COUPLET= 1 t173 Kg IMIRP.0 WELLFDI LOOMENCOFFECIEIE WELL mau 07x1m2 BE AID PERK 0025•08 RCITIVC GLV 00 (05/16 A 06/14021. BRET Ili I kt20170 060102 BE AM PERFS 0624811 VIRRP,C ORIIVANG COFFEL11COR API Mx 50020-23041-00 12/2042 BE LFDA1E0 MI PIM 06/05 VARRIC POWS (0&27- VIM) SEC 11, T1 3PL RI 3E, 1 100 FR A 642* FEL 11,0405 RILI PEW FORAM 02 wham ALCM SSW SAFETY NOM Mame WFR %WEE COFFECTICN (00 15412) El Eaploradon (Alaska) Page 12 of 13 . • PERFORATING PROCEDURE Ver 1.2, Rev 10/21/01 Well: NS07 API #: 50-029-23081-00 Date: 01-10-13 Prod Engr Lea Duong Office Ph: 907-564-4840 H2S Level: Home Ph: 0 Cell/Pager: 720-951-7238 CC or AFE: ANSPERFS WBL Entries IOR Type Work Desciption E Perforate 13,384' MD to 13,398' MD 250 Well Objectives and Perforating Notes: These perforations will be added post gel/squeezecrete to obtain standoff from the gas contact. • Reference Log Tie in Log Add 0 feet Log: CCL/GR/2" PJ 2006 PEX to the tie-in log to be on Date: 8/26/2008 5/10/2002 depth with the reference log. Company: HALT SLB Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Reftperf . 13,384' - 13,398' 13,384' - 13,398' 14' 6 Random 60° Ivishak APE Requested Gun Size: 2" Charge: 2006, PowerJet Omega, HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating NA Preferred Amount of Drawdown/Suggestions to Achieve Drawdown NA Last Tag: 13,389 ft SLMD on 2/12/2010 Est Res. Pres. @ 11,100 MD is 5,106 psi • Perforation Summary Summary Dist Well: NS07 Town: Date: API #: 50-029-23081-00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Based on Ref Log Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U 0 / B / U 0 / B / U 0 / B / U 0 / B / U 0 / B / U 0 / B / U 4 • • Perforation Attachment ADL0312799 Well Date Perf Code MD Top MD Base TVD Top TVD Base NS07 8/1/02 APF 13186 13210 10983 11005 NS07 6/27/02 PER 13210 13240 11005 11032 NS07 6/26/02 PER 13240 13270 11032 11060 NS07 6/26/02 PER 13270 13300 11060 11088 NS07 7/30/02 PER 13300 _ 13320 11088 11107 NS07 8/27/08 APF 13334 13354 11120 11139 NS07 8/26/08 APF 13354 13374 11139 11158 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • I * I Casing Summary ADL0312799 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade LINER 740 4 -1/2" 12.6# 13Cr8( 12789 13529 10631 11305 8430 7500 13Cr80 LINER 1780 7" 26# L -80 11196 12976 9344 10795 7240 5410 L -80 PRODUCTION 11371 9 -5/8" 47# L -80 44 11415 44 9517 6870 4760 L -80 SURFACE 3715 13 -3/8" 68# L -80 44 3759 44 3356 5020 2260 L -80 TUBING 12765 4 -1/2" 12.6# 13Cr8( 40 12805 40 10645 8430 7500 13Cr80 • • • Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS07 PACKER 11196 7" Top Packer 9344 NS07 PACKER 12755 4 -1/2" Top Packer 10601 NS07 PACKER 12789 5" Baker ZXP Top Packer 10631 r IFS = A MJL1 5-1/8" 510 — NOTES: WELL REQUIRES A SSSV. = ABB VG113 5l8 MKJLTiBOWL 5 07 '"•4 -1/2" CHROMETBG & LNR""" ACTUATOR ACTUATOR BAKER KB. ELEV = 56.1' BF. ELEV = 40.2' (CB 15.9') 1606' H 13 -3/8" DV Tool _KOP = 50' Max Angle = 42° @ 10452' D a t u m MD = 1 2 7 0 3 ' • I 2032' H 41 /2' SSSV w /HXO SLVN NIP, ID = 3.813" I Datum TVD = 10500 SS 113 -3/8" CSG, 68#, L -80 BTC, ID = 12.415" H 3759' 1 GAS LIFT MANDRELS Minimum ID = 2.4" 12803' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 5189 4526 33 SMOR CM/ BK -2 0 05/18102 OFFSET WLEG (12774' SLM) 1 6512 5631 33 SMOR DMY BK -2 0 06/14/02 ITOP OF LNR H 11196' J `t 11196' H9-5/8" X 7" BKR LNR TOP PKR, ID = ? 1 11217' 1- -19 -5/8" X 7" BKR LNR HGR, O = ? I 19-5/8" CSG, 47 #, L -80 BTM-C, ID = 8.681" 1 1415' 1 H I--A • 12715' 1— 4112" FIBER OPTIC TRANSDUCER, ID = 3.958" 12721' ELM I 12734' H4-1/2" HES X NIP, ID = 3.813" I z ' 1 12755' H7" X 4-1/7' BKR PERM PKR, ID = 3.875" I ' 1 12780' H4-1/2" HES X NIP, ID = 3.813" I 12789' HT X5" BKR LNR TOP PKR, ID =? I I TOP OF 4-1/7' LNR H 12789' j 12791' 4-1/2" I-ES XN NIP, ID = 3.725" 2 I ' 12782' ELM 4-12" TBG, 12.6#, 13CR -80 VAM -ACE, —1 12804' I I 12803' —17" X 5" BKR LNR HGR, ID = ? I .0152 bpf, 10 = 3.958" 12804' H4-12" WLEG, ID = 3.958" I 12774' SLM H OFFSET WLEG, ID = 2.4° (see 06/15/02 WSR) I 7" LNR, 26# L -80 Hydri1 521, H 12976' 12813' H5" X 4 -1/2" XO, ID = 3.958" I .0383 bpf, ID = 6.276" PERFORATION SUMMARY ■ REF LOG: PEX- HRLA -DSI on 05/1 0/02 ANGLE AT TOP PERF: 23° @ 13186' Note: Refer to Production DB for historical pert data I SIZE SW INTERVAL (MD) Opn/Sgz DATE 2" 6 13186 - 13210 0 08/01/02 2" 12 13210 - 13300 0 06/27/02 2' I 6 13300 - 13320 0 07/30102 2" 6 13334 - 13354 0 08/26/08 2' 6 13354 - 13374 0 08/27/08 I PBTD 13440' 1 4-1/2" LNR, 12.6#, 13CR -80 VAM -ACE, H 13529' I MAW* 0152 bpf, ID= 3.958" :.........AV DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 05118102 EMF INITIAL COMPLETION 02/23/12 PJC DRAWING CORRECTIONS WELL: NS07 11/27/07 WRR/PJC WELLHIY LOC CORRECTIONS PERMIT No: "2020770 06/25/08 RCT /PJC GLV CO (05/18 & 06/14/02) - API No: 50- 029 - 23081 -00 06/28/08 WRR/PJC DRAWING CORRECTIONS SEC 11, T13N, RI3E, 1109' FSL & 642' FEL 09/05/08 WRR/PJC PERFS (08/27- 27/08) 02/17/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) C~ J BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~~~~,?`~h*~~~4~.~e;-r C., 44.3 ~!J~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 i ~- ~tE~~~VE SAY ~ ~ 2o1a .. .i~il~Gar;~or~s.0~m-ss~o~ ~;. ~nchoraa~ Subject: Corrosion Inhibitor Treatments of Northstar D~` ©~ Dear Mr. Maunder, ~ _ Ns ©~ Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) .~~ Date Northstar 4/20/2010 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NSO8 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 'Not measured due to rig proximity. ate: 02-22-2010 Transmittal Number: 93130 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. Tf you have anv auestians_ please contact Toe Lastuflca at (9071564-4091 Delive Contents Bottom SW Name Date Contracto Run To De th De th Descri tion MEMORY MULTI-FINGER CALIPER LOG RESULTS NS07 02-12-2010 PDS 1 0 13406 SUMMARY CD-ROM -MEMORY MULTI- . FINGER CALIPER LOG NS07 02-12-2010 PDS RESULTS SUMMARY MEMORY MULTI-FINGER CALIPER LOG RESULTS NS16A 02-11-2010 PDS 2 0 14380 SUMMARY CD-ROM -MEMORY MULTI- FINGER CALIPER LOG NS16A 02-11-2010 PDS RESULTS SUMMARY f :-~. f f" please Sign and Return one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center BPXA AOGCC ~,"~' ' cy _3~c~ DNR Murphy Exploration ~- j ri'" :~~~% MMS David Fair Christine Mahnken Corazon Manaois Ignacio Herrera Doug Chromanski -, -3 " __ Petrotechnical Data Center LR2-1 900 E: Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • Memory Multr-Finger CaliRer Log Results Summary Company: BP Exploration (Alaska), Inc. Well: NS-07 Log pate: February 12, 2010 Field: Northstar Log No.: 7386 State: Alaska Run No.: 1 API No.: 50-029-23081-00 Pipet Desc.: 4.5" 12.6 Ib. 13CR-80 VAM-ACE Top Log Intvl1.: Surface Pipet Use: Tubing & Liner Bot. Log Intvll.: 13,406 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the HES XN-Nipple @ 12,782' (FEND). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing and liner logged appearto be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate slight to moderate buckling, increasing in severity with depth from 2,500' to 12, 700'. 4.5" TUBING & LINER -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18°~) are recorded throughout the tubing and liner logged. 4.5" TUBING 8~ LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing and liner logged. 4.5" TUBING ~ LINER -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: T. Atkinson & M. McGuiness ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281} 565-1369 E-mail: PDSC~memorylog.cam Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 • Correlation of Recorded Damage to Borehole Profile Pipe 1 4.5 in (0.5' - 13403.6') Well: NS-07 Field: Northstar Company: BP Exploration (Alaska), Inc. Country: USA Survey Date: February 12, 2010 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 4 0 ~~ ~. ---~, ~- 095 100 4188 GLM 2 GLM 1 150 6312 v ~ E ,~ ~ ~ ._ Z ~ 200 8436 Q. ~o v p 250 10525 300 12612 317 13404 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 317 • i PDS Report Overview ~, S,~ Body Region Analysis Well: NS-07 Survey Date: February 12, 2010 Field: Northstar Tool Type: UW MFC 24 Ext. No. 214040 Company: BP Exploration (Alaska), Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st C. Waldro Tubing: Nom.OD Weight Crade & Thread Nom.ID Nom. Upset Upper len. lower len. 4.5 ins 12.6 f 13CR-80 VAM-ACE 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1 % 10"/° 20% 40% 85% 85% Number of'oints anal sed total = 333 pene. 190 135 3 0 3 2 loss 252 79 2 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 1 1 0 0 0 0 Damage Profile (% wall) ~ penetration body rnetal loss body 0 50 100 0 97 GLM 2 GLM 1 193 2 93 Bottom of Survey = 317 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. ,Nominal LD.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint No. Jt. Depth (Ft) Pc~n. Ilt~x~t (~I1,S.j Pen. Body (Ins.) Pen. % Metal loss `;~~ Min. -.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 0 u 0.01 ~ I 3.95 PUP 1 4 U 0.01 ~ 1 3.93 1.1 47 t) 0.01 2 I 3.96 PUP 2 51 a 0.00 1 I 3.94 3 93 U 0.00 1 I 3.94 4 135 t) 0.00 1 1 3.94 5 177 U 0.00 1 I 3.94 6 220 tt 0.01 ~~ 3.93 7 261 t) 0.00 I I 3.95 8 304 tl 0.00 1 I 3.95 9 346 U 0.00 I I 3.93 10 388 t) 0.01 3.96 1 1 430 U 0.01 3 3.91 12 472 a 0.01 s _' 3.93 13 514 a 0.00 1 i 3.95 14 557 tt 0.01 3 ? 3.93 15 598 0 0.00 1 1 3.93 16 641 U 0.00 1 1 3.92 17 682 t t 0.00 1 1 3.93 18 724 tt 0.01 ~ ' 3.91 19 766 a 0.01 3 ? 3.92 20 808 i) 0.00 i 3.94 21 850 t) 0.01 Z t 3.94 22 892 U 0.00 I I 3.93 23 935 l) 0.01 3.95 'r 24 976 U 0.00 i 1 3.94 25 1019 U 0.01 ~ 3.94 26 1061 O 0.01 Z I 3.94 27 1103 t) 0.00 1 I 3.93 28 1145 t) 0.01 393 29 1187 U 0.00 i I 3.94 30 1229 U 0.00 I i 3.94 31 1272 t) 0.00 I 1 3.93 32 1314 U 0.00 I 1 3.93 33 1356 t) 0.01 2 I 3.91 34 1398 U 0.00 I 1 3.92 35 1440 (t 0.01 i ? 3.92 36 1482 n 0.00 1 1 3.92 37 1524 t) 0.01 3 Z 3.95 38 1566 t) 0.01 2 1 3.91 39 1608 i? 0.00 1 I 3.92 40 1650 t) 0.00 1 1 3.92 41 1692 tt 0.00 1 I 3.93 42 1734 i) 0.01 Z 1 3.92 43 1776 t) 0.01 ~' I 3.93 44 1818 t) 0.00 1 1 3.92 45 1861 l) 0.00 I i 3.93 46 1903 (~ 0.01 3 ~' 3.93 47 1945 ~) 0.00 I I 3.96 47.1 1987 ~ ~ 0.00 ! i 3.94 PUP _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint No. Jt. Depth (Ft.) I'c~n. UI>u~i (Ins.) Pen. Body (Ins.) Pen. %~ Mcl,rl Loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47.2 1997 i ~ 0 U U 3.81 4.5" SSSV w HXO SLVN Ni le 47.3 2002 U 0.05 18 ? 3.95 PUP Shallow ittin . 48 2010 U 0.01 2 1 3.94 ' 49 2053 t) 0.01 Z 1 3.96 ' 50 2095 ~? 0.00 1 1 3.93 51 2137 i? 0.00 1 1 3.95 52 2179 a 0.01 ~3 _' 3.92 53 ' 221 ~? 0.01 _' 3.95 54 2260 ~ i 0.00 1 i 3.92 55 2301 U 0.01 2 I 3.95 56 2342 i~ 0.00 1 1 3.96 57 2384 (1 0.00 1 1 3.95 58 2426 n 0.01 3 z 3.94 59 2467 i? 0.01 2 1 3.94 Sli ht Bucklin ' 60 2508 i? 0.00 1 1 3.96 61 2550 U 0.00 1 1 3.96 62 2592 a 0.01 1 I 3.94 63 2634 i) 0.00 1 1 3.94 64 2676 O 0.00 1 I 3.93 5 2718 a 0.00 1 1 3.92 Sli ht Bucklin . 66 2760 i? 0.01 3 ? 3.93 67 2803 c? 0.00 1 I 3.92 68 2845 U 0.00 1 I 3.96 69 2887 U 0.00 I 1 3.92 70 2929 i? 0.00 1 1 3.93 71 2971 i? 0.00 1 I 3.93 Sli ht Bucklin . 72 3013 U 0.00 1 I 3.93 73 3055 i? 0.01 3 ~' 3.91 74 3096 ~ ? 0.00 1 ! 3.93 75 3138 i? 0.01 ' 3.96 76 3180 t? 0.00 1 1 3.92 77 3222 i~ 0.01 2 I 3.94 Sli ht Bucklin ; 78 3264 ~) 0.00 1 I 3.91 79 3306 ! i 0.01 3 Z 3.91 80 3348 U 0.00 1 1 3.91 81 3389 t? 0.00 1 1 3.96 82 3431 i? 0.00 1 1 3.94 83 3474 t? 0.01 3 3.95 84 3515 i? 0.01 3 3.94 Sli ht Bucklin . 85 3558 i ? 0.02 ~> ~-t 3.96 ~ 86 3600 U 0.00 1 I 3.95 87 3642 i? 0.01 2 I 3.94 ' 88 3684 t) 0.00 1 I 3.95 89 3726 a 0.00 1 I 3.94 90 3768 (t 0.00 I 1 3.96 91 3810 i? 0.01 3 _' 3.95 Sli ht Bucklin . 92 3852 ~? 0.00 1 1 3.96 93 3894 t? 0.00 1 1 3.96 94 3936 c? 0.00 1 1 3.91 95 3978 t? 0.01 3 1 3.94 ' Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: 6P Exploration (Alaska), Inc. Nominal 1.D.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint )t. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) L)pset Body °~ Loss LD• Comments (%wall) (Ins.) (Ins.) `~, (Ins.) 0 50 100 I ~ ~~ I SZna I ~ ~ I n n~ I I ~ I~ a~ I ~ 128 5391 (1 0.01 3 ~' 3.91 129 5433 (~ 0.00 1 1 3.92 130 5475 U 0.00 I 1 3.93 131 5517 I; 0.00 1 I 3.91 132 5558 t~ 0.01 ? 1 3.91 Bucklin _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Cornpany: BP Exploration (Alaska), Inc.. Nominal I.D.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint No. Jt. Depth (ft.) Pc~n. UL~sei Ilnt.j Pen. Body (Ins.) Pen. °4~ Mclal I os~ `;4> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 143 6017 U 0.01 3 3.92 144 6060 U 0.00 I I 3.92 145 6101 U 0.01 3 1 3.92 Bucklin . 146 6143 i? 0.00 1 1 3.92 147 6186 t ? 0.00 1 I 3.91 148 6228 t? 0.00 1 1 3.93 149 6270 U 0.00 1 I 3.92 150 6312 t) 0.00 1 I 3.91 151 6354 t) 0.00 1 1 3.92 Bucklin . 152 6396 U 0.01 ? I 3.91 153 6438 () 0.01 ~ 3.90 153.1 6480 U 0.03 11 E~ 3.91 PUP 153.2 6487 U 0 U t? N A GLM 1 Latch ~ 6:00 153.3 6499 t? 0.01 ~~ ! 3.94 PUP 154 6507 U 0.01 _' 3.93 155 6550 i? 0.00 I I 3.94 156 6592 t? 0.00 I I 3.91 Bucklin . 157 6634 t? 0.00 1 I 3.92 158 6676 i) 0.01 ? 1 3.91 159 6718 i) 0.00 1 1 3.93 160 6760 t1 0.00 1 1 3.92 161 6802 U 0.01 3 2 3.94 162 6844 t ? 0.01 3 ? 3.91 163 6887 (1 0.00 1 1 3.91 Bucklin . 164 692 8 t l 0.00 I ! 3.94 165 6971 ! ? 0.01 ~ 1 3.91 166 7012 t? 0.01 i _' 3.93 167 7054 t? 0.00 1 I 3.92 168 7096 a 0.00 1 1 3.89 169 7138 U 0.00 I 1 3.91 170 7180 t) 0.01 3 3.92 Bucklin . 171 7221 t1 0.00 1 I 3.90 172 7263 U 0.00 1 1 3.89 173 7305 U 0.00 1 1 3.92 174 7345 O 0.01 3 ? 3.91 175 7387 t? 0.00 1 1 3.89 176 7430 t? 0.00 I 1 3.94 177 7472 c? 0.00 I 1 3.92 178 7514 U 0.01 ~ ~' 3.92 Bucklin ` 179 7556 c) 0.01 5 ~ 3.92 180 7598 (? 0.01 3 ? 3.91 181 7640 ~) 0.00 I 1 3.91 182 7682 l) 0.00 1 I 3.94 183 7724 a 0.00 1 I 3.91 184 7766 O 0.01 3 ~ 3.95 a 185 7808 t) 0.00 1 I 3.90 186 7850 + ~ 0.00 1 I 3.92 Bucklin . 187 7892 ~ ! 0.00 1 I 3.92 188 7934 a 0.01 3.92 189 7976 U 0.01 I 3.92 _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACL Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint No. Jt. Depth (Ft.) I'c~n. t_ 1psc~t {Ins.) Pen. Body (Ins.) Pen. %> Mctal I o5s °> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 190 8018 (t 0.00 1 1 3.92 191 8061 U 0.00 1 I 3.92 192 8100 t) 0.00 1 I 3.91 193 8142 ! ? 0.00 1 i 3.92 194 8184 ! t 0.01 ' 3.92 ` 195 82 6 U 0.00 1 i 3.91 ucklin . 196 8268 i) 0.00 I I 3.91 197 8310 t? 0.00 1 1 3.90 198 8352 O 0.00 1 I 3.92 199 8394 U 0.00 1 1 3.92 200 8436 t) 0.00 1 I 3.91 201 8478 U 0.00 1 I 3.92 202 8520 O 0.01 2 1 3.94 203 8562 t) 0.00 1 1 3.92 Bucklin . 204 8604 €? 0.00 1 i 3.92 205 8644 C~ 0.00 1 I 3.89 206 8686 ~) 0.00 1 1 3.92 207 8728 tt 0.00 1 1 3.91 208 8770 c) 0.00 1 I 3.91 209 8812 t? 0.00 I 1 3.92 210 8854 t ~ 0.00 1 1 3.92 Bucklin . 21 1 8896 t) 0.00 I I 3.91 212 8936 (t 0.00 1 1 3.91 213 8978 (~ 0.00 1 I 3.92 214 9017 t) 0.00 I I 3.92 215 9059 . t 0.01 ~' 1 3.93 ' 216 9102 i) 0.01 ? 1 3.91 ' 217 9142 t t 0.00 I 1 3.91 218 9184 U 0.01 2 1 3.92 Bucklin . 219 9226 0 0.00 1 1 3.92 20 9268 ~) 0.01 ~~ ~' 3.92 221 9311 U 0.01 ~ ' 3.91 222 9352 t) 0.01 3 _' 3.92 223 9395 (~ 0.00 1 1 3.91 224 9437 a 0.00 I 1 3.92 225 9478 U 0.00 1 1 3.91 226 9521 U 0.01 3 2 3.92 Bucklin . 227 9563 O 0.00 1 1 3.92 228 9605 tt 0.01 2 1 3.91 ' 229 9647 U 0.00 1 1 3.92 230 9689 +) 0.01 3 2 3.92 231 9732 (? 0.01 2 1 3.92 ' 232 9773 +~ 0.01 ~' I 3.91 ' 233 9814 ! t 0.00 1 1 3.92 234 9857 ~? 0.00 1 1 3.91 Bucklin . 235 9899 t? 0.00 1 1 3.92 236 9938 a 0.00 1 I 3.92 237 9979 O 0.00 1 I 3.92 238 10021 ti 0.00 1 I 3.92 239 10063 a 0.00 1 t 3.90 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint Jt. Depth I'c~n. Pen. Peen. Metal Min. Damage Profile No. (Ft.) Upset Body %~ I oss LD• Comments (%wall) (Ins.) (Ins.) "~ (Ins.) 0 50 100 1 I 1 Z84 11947 l) 0.01 l i 3.91 285 11988 ~? 0.00 1 I 3.94 ~Rh ~ ~n~n n n rn ~z ~> ~ as 287 12068 (1 0.01 ; Z 3.93 Bucklin . 288 12110 a 0.01 3 3 3.92 Penetration Body Metal Loss Body Page 6 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf 13CR-80 VAM-ACE Well: NS-07 Body Wall: 0.271 in Field: Northstar Upset Wall: 0.271 in Company: BP Exploration (Alaska), Inc. Nominal LD.: 3.958 in Country: USA Survey Date: February 12, 2010 Joint No. Jt. Depth (Ft.) I'cn. OI~sc~l (Ins.) Pen. Body (Ins.) Pen. %, Mc~l~~l loss ,, Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 290 12194 a 0.00 1 I 3.92 I I 291 12236 a 0.00 1 1 3.96 292 12278 U 0.00 1 1 3.95 293 12319 t+ 0.00 I I 3.92 Bucklin . 294 12361 !) 0.00 1 I 3.95 ~ ~ 295 12404 U 0.01 2 1 3.91 296 12446 U 0.01 2 1 3.96 297 12487 l) 0.00 1 1 3.92 298 12530 ~) 0.00 I I 3.93 299 12571 0 0.01 2 1 3.96 300 12612 U 0.01 ; 2 3.92 301 12654 ~) 0.00 I 1 3.94 Bucklin . 301.1 12696 l) 0.01 2 1 3.94 PUP ~ 301.2 12705 t) 0 U u 3.96 4.5" Fiber O tic Transducer 301.3 12711 !) 0.00 1 i 3.92 PUP 301.4 12714 U 0.00 1 1 3.93 PUP 301.5 12725 U 0 0 U 3.81 4.5" HES X-Ni le 301.6 12727 O 0.02 t3 ~ 3.93 PUP 301.7 12737 !) 0.01 .1 ? 3.93 PUP 301.8 12747 0 0 U i) 3.88 7" x 4.5" Baker Perm Packer 301.9 12751 O 0.01 _' I 3.93 PUP 302.1 12761 U 0.01 _' 1 3.94 PUP 302.2 12773 U 0 U U 3.81 4.5" HES X-Ni le 302.3 12775 (1 0.00 1 1 3.92 PUP 302.4 12782 U 0 0 ~~ 3.73 4.5" HES XN-Ni le 302.5 12786 i) 0.02 t3 ~t 3.92 PUP 302.6 12795 t) 0 ~) t) 3.96 4.5" WLEG 302.7 12797 O 0 i) ! i N A 7" x 5" Baker Liner To Packer 302.8 12811 u 0 r) i) N A 7" x 5" Baker Liner Han er 302.9 12818 t~ 0 t) U 3.96 5" x 4.5" X-Over 303 12820 U 0.00 I I 3.92 To of 4.5" Liner 304 12862 t1 0.00 1 1 3.94 305 12903 i ~ 0.00 1 1 3.92 306 12945 O 0.01 ~ ? 3.94 307 12986 U 0.00 1 i 3.94 308 13028 t) 0.00 1 i 3.93 309 13069 i) 0.01 3 ~ 3.92 310 13111 ~) 0.01 2 I 3.93 311 13153 U 0.21 76 4 3.92 Perforations. 312 13194 ~) 0.24 89 c3 3.89 Perforations. 313 13236 O 0.25 92 11 3.93 Perforations. 314 13278 U 0.18 6i' II 3.85 Perforations. 315 13315 i' 0.20 7Z s 3.75 Perforations. 316 13363 ii 0.03 11 I 3.87 Lt De o its. 317 13404 i i 0.02 ti I 3.91 Penetration Body Metal Loss Body Page 7 WELLHEAD= ABB-VGI13-5 ACTUATOR = BA KB. ELEV = 56.1' BF. ELEV. - 40.2' (CB 15.9') KOP 50' Max Angle = 42° @ 10452' Datum MD = 12703' Datum TVD = 10500 SS 13-3/8" CSG, 68#, L-80 BTC, D =12.415" 3759' Minimum ID = 2.4" @ 12803' OFFSET WLEG (12774' SLM) TOP OF 7" LNR -~ 11196' ~9-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" ~ N ~ O ~ SAFET~TES: ***4-1 R" CHROME TBG ~ LNR*** 1606' 13-3/8" DV Tool 2032' 4-1/2" SSSV w/HXO SLVN NIP, D = 3.813" GAS LIFTMAI~R~S ST MD TVD DE1l TYPE VLV LATCH PORT DATE 2 1 5189 6512 4526 5631 33 33 SMOR SMOR DMY DMY BK-2 BK-2 0 0 05!1$/02 06/14/02 11196' --~ 9-5/8" X 7" BKR LNR TOP PKR, D = ? 11217' 9-5/8" X 7" BKR LNR HGR D = ? 12715' (12721' ELM) ~ 4-112" FIBER OPTIC TRANSDUC~, D = 3.958" 12734' 4-1 J2" HES X NIP, D = 3.813" 12755' 7" X 4-1/2" BKR PERM PKR D = 3.875" 12~ 4-1/2" HF-S X NIP. ID = 3.813" ~TOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM-ACE, .0152 bof. D = 3.958" 7" LNR, 26# L-80 Hydril 521, .0383 bpf, ID = 6.276" P~FORATION SUMMARY REF LOG: PEX-HRLA-DSI on 05/10/02 ANGLEATTOP FERF: 23° @ 13186' Note: Refer to Production DB for historical pert data SQE SPF NTERVAL (MD) Opn/Sqz DATE 2" 6 13186 - 13210 O 08/01/02 2" 12 13210 - 13300 O 06/27/02 2" 6 13300 - 13320 O 07/30/02 2" 6 13334 - 13354 O 08/26/08 2" 6 13354 - 13374 O 08/27/08 PBTD 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE, .0152 bpf, ID = 3.958" 1j 2789' 1~ 7" X 5" BKR LNR TOP PKR, D = ? I 12791' 127$2' ELM 4-1/2" HES XN NIP, D = 3.725" 12803' 7" X 5" BKR LNR HGR, ID = ? 12$04' 4-1/2" WLEG, D = 3.958" 12774' SLM OFFSET WLEG, ID = 2.4" (see 06/15/02 WSR) 12813' 5" X 4-1/2" XO, D = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 05/18/02 EMF INITIAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CORRECTlO W~L: NS07 07/03/02 EMF ADD P6~FS 06/25/08 RCT/PJC GLV C!O (05/18 & 06/14/02) P6~MIT No: 1020770 08/09/02 EMF ADD PERFS 06/28/08 WRR/PJC DRAWNG CORRECTIONS API No: 50-029-23081-00 ' 12/20/02 EMF UPDAT® KB NFO 09/0510$ WRR7PJC PERFS (08!27- 27108) SEC 11, T13N, R13E, 1109' FSL & 642' FEL 11/04/05 BJM NEW FORMAT 07/06/06 WRR WLEG CORRECTION {06/15/02) BP Exploration (Alaska) ABB-VG15-1/8" SKSI /8" MULT~OWL SKSI • • by BP Exploration (Alaska) Inc. ~~ ;Y ` ~' Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ;,~ ~~~ ~~~~ May 26, 2009 I~~~a CAI _~~ 1~11~ n~li~sion ~~l~~~r~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ Q ~'1 333 West 7th Avenue ~~ Anchorage, Alaska 99501 n~ 1' Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ ~"(~-~ Andrea Hughes BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) X' "~~~ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 * na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5!3/2009 *Not measured due to rig proximity. AFL ~uti o ~ 2oos _ STATE OF ALASKA ~~ ALA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ' " Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ r Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' Exploratory ~~ 202-0770 3. Address: P.O. Box 196612 Stratigraphic S@rVICe 6. API Number: Anchorage, AK 99519-6612 50-029-23081-00-00~ 7. KB Elevation (ft): 9. Well Name and Number: 56.1 KB ~ NS07 8. Property Designation: 10. Field/Pool(s): ADLO-312799 ~ NORTHSTAR Field/ NORTHSTAR OIL Pool 11. Present Well Condition Summary: Total Depth measured 13529. feet Plugs (measured) None true vertical 11305.02 - feet Junk (measured) None Effective Depth measured 13484 , feet true vertical 11262.26 feet Casing Length Size MD TVD Burst Collapse Surface 3715 13-3/8"68# L-80 43 - 3759 43 - 3356 4930 2270 Production 11371 9-5/8"47# L-80 44 - 11415 44 - 9517 6870 4760 Liner 1780 7" 26# L-80 11196 - 12976 9344 - 10795 7240 5410 30 7500 Liner 740 4-1/2" 12.6# 13CR80 12789 - 13529 10 1 - 11305 84 6 3 ~ y , 4f !'~ ( nyy ~~'4~r MAY Y1~~ ~~~ ~~ ~~ (~~~V Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 12803 0 0 - Packers and SSSV (type and measured depth) 4-1/2" C.amco WRDP-1 SSSV 2032 7" Top Packer 11196 7" 13Cr80 Packer 12756 4-1/2" Top Packer 12789 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3137 76448 550 919 Subsequent to operation: 3333 80205 777 931 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~' Development ~; - Service f~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil `'. - Gas WAG ~' GINJ ~ WINJ ~~~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-271 Contact Robert Younger Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date 9/8/2008 `~ ~ 2~~8 ~R_ i Form 10-404 Rued 04/2006 ~~ i j ~ ~ ,{ ~ ~ C ~~ ~~~ ~ ~ ~~~8 Submit Original Only ~~~ NS07 202-0770 PERF ATTACHMENT • Sw Name Operation Da Perf Operati Meas Depth ' Meas Depth I Tvd Depth Tc Tvd Depth Base NS07 6/26/02 PER ' 13,240. 13,270. 11,032.44 11,060.33 NS07 6/26/02 PER _ 13,270. 13,300. 11,060.33 11,088.39 __ NS07 _ 6/27/02 PER __ 13,210. 13,240. 11,004.73 11,032.44 NS07_ 7/30/02 PER ~ __ 13,300. 13,320. 11,088.39 11,107.15 NS07 8/1/02 APF 13,186. 13,210. 10,982.69 11,004.73 NS07 _ 8/26/08 APF 13,354. 13,374. 11,139.13 11,157.98 NS07 ' 8/27/08 APF 13,334. 13,354. 11,120.31 11,139.13 _ 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 ~ NS07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/25/2008:':SPOT EQUIPMENT & START RU FOR PERFORATING. ':CONTINUED ON 8/26/08 8/26/2008 ***JOB CONTINUED FROM 25-AUG-2008*'`* CONTINUE JOB PREP, RIG UP ELINE TO PERFORATE, ONE INTERVAL WITH 2 RUNS OF 20' 2" PJ 2006 RUN #1 RE-PERFORATED INTERVAL 13354'-13374'. POOH. SAFETY STAND DOWN. "**JOB CONTINUED ON 27-AUG-2008*"'` 8/27/2008 **"JOB CONTINUED FROM 26-AUG-2008*** PERFORATE INTERVAL 13334'-13354': W ITH 2" PJ 2006, W ELL LEFT FLOWING, IA/OA OPEN TO GAUGES, SWAB SHUT. TAGGED TD AT 13435' DEPTH CORRECTED TO SLB PERF RECORD DATED 26-JUNE-02. ***JOB COMPLETE WELL CONTROL GIVEN BACK TO OPERATIONS'`'`* FLUIDS PUMPED BBLS 0 NO FLUIDS 0 Total • ~ ~~ }~ SARAH PAL/N, GOVERNOR r ~... ~ d._. ~J ~.J ~e..-. ~ ~ ~...~ .A 1. ~5~ OIIt ~ ~ 333 W. 7th AVENUE, SUITE 100 COAT5ERQA`i'IO1Q COMM155IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration Alaska Inc. ~~~ AU ~ ~ 2000 PO Box 196612 Anchorage AK 99519-6612 Re: Northstar Wield, Northstar Oil Pool, NS07 ~f Sundry Number: 308-271 ~ ~ 0 ~b Dear Mr. Younger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. ~^ ~ Chair DATED this `~ day of August, 2008 Encl. Q~1`'~ • STATE OF ALASKA v ALASKA OIL AND GAS CONSERVATION COMMISSION aU~ ~ ®ZQQ~ I r ~~ APPLICATION FOR SUNDRY APPROVA , ~n AAC ~s ~Rn 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ Wai r ~ Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni^ Exploratory ^ 202-0770 . 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23081-00-00' 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: NS07 - Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ~ ADLO-312799 " 56.1 KB ' NORTHSTAR Field / NORTHSTAR OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13529 - 11305.02 ~ 1348 4 - 11262.26. NONE NONE Casing Length Size MD TVD Burst Collapse Surface 3715 13.-38/" 68# L-80 44 3759 44 3356 4930 2270 Production 11371 9-5/8" 47# L-80 44 11415 44 9517 6870 4760 Liner 1780 7" 26# L-80 11196 12976 9344 10795 7240 5410 Liner 740 4-1 /2" 12.6# 13Cr80 12789 13529 10630.7 11305 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 4-1/2" 12.6# 13Cr80 40 - 12803 Packers and SSSV Type: 4-1/2" Camco WRDP-1 SSSV Packers and SSSV MD (ft): 2032 7" Top Packer 11196 7" 13Cr80 Packer 12756 4-1/2" Top Packer 12789 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/11/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Younger Printed Name e Younger Title Production Engineer Signature Phone 564- 5392 Date 7/28/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~g ' oG Plug Integrity ^ BOP Test ^ Mechanical Int egrity Test ^ Location Clearance ^ Other: Subsequent Form wired: Si ~FL_ AUG 0 5 2008 APPROVED BY ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: r Form 1 - 03 Revised 06/2006 Submit in Duplicate NS07 202-0770 PFRF ~TT~(~HMFNT U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base NS07 6/26/02 PER 13,240. 13,270. 11,032.44 11,060.33 NS07 6/26/02 PER 13,270. 13,300. 11,060.33 11,088.39 NS07 6/27/02 PER 13,210. 13,240. 11,004.73 11,032.44 NS07 7/30/02 PER 13,300. 13,320. 11,088.39 11,107.15 NS07 8/1/02 APF 13,186. 13,210. _ 10,982.69 11,004.73 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 • .., ~.. . .i a • ~ FILE COPY ~~ ~~ >e ,.i ~- .- ! •' •' PERF4RATIaN RECORD & JEVI/ELRY LOG ~ I '' ~ 2" PJ HSD GUNS.- 6SPF W Q 26-JUNE-2042 _ _ . ~, Z w ~ ~ 1109' FSL & 642' FEL - Elev.: KB. a ~ ~ ~ '~ ~ z SURFACE LOCATION. G.L. 15.9 ft m m ~ -3 O D.F. 56.26 ft _ _ ~ ~ F O h o 6' Q ~ Permanent Datum: MSL E{ev.: 0 ft u s z - z ,= z m ~ Log Measured From : RDF 56.3 ft above Perm. Datum Drilling Measured From: RDF ~ • ~ ~ - E ~ API Serial No. .SECTION TOWNSHIP RANGE ~ ° o °' $ m ~ ~ ~ U 50-029-23081-00 11 -- 13N 13E L in Date 26,1un-2002 ~_ Run Number ONE _ Depth Driller Schlumberger Depth 13432 ft ,. _ Bottom Log In#erval ~ 13395 ft ~ •..-- -~ Top Log I nterval 12650.ft __ __ __ __ _ ~ _ _ ~ ~ Casing-F.i~id Type DIESEL /SEA WATER ~ ., _ Satin' ''~ _..-. . Dens' _ - _.....__._._ F1uid Level -_. BIT/CASING(CUBING STRING 'Bit Size 6.125 in . From 12976 ft , _ To 13529 ft ________.- Casin~/Tubin Size 4.500 in ,-.. Wei ht 12.61bm/ft _ Grade L-80 From ft _.. To 13529 ft - _, _ Maximum Recorded Temperatures - _ __,_ Logger On Bottom Time 26,1un-2002 12:30. _ Unit Number Location 4101 PRUDHOE BAY _ • PERFORATING PROCEDURE ADW ~~..~..~ Well: NS07 API #: 50-029-23081-00 Date: 07/29/08 Prod Engr Robert Younger Office Ph: 5645392 Home Ph: 677-2599 Cell Ph: 830-4920 ............................................ CC or AFC: NSFLDWL07 Detail Code: Description: Drift to TD with Dummy Gun, Perforate ......................................................................................................................................... WBL Entries Ver 4.0 46,04,0, H2S Level: .................................................................. None Anticipated IOR Type Work Description 250 S Drift to TD with Dummy Gun -Last tag 07/10/03 250 E Perforate 13,334'-13,374' MD Well Objectives and Loaaina Notes: The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist due to scale. The proposed perforations are an attempt to increase production by adding 40' of perforations closer to the Oil Water Contact. Please note that 2" guns will be used due to 06/14/02 LIB to 12774' that shows 4.5 TBG OVERLAPING TIE BACK SLEEVE -min ID appears to be -2.40" based on 06/15/02 Drifts. . Please note that the perforations will be dependent on the drift information. In the event scale is encountered a bullhead acid job will be performed to mitigate any scale. Please contact Bob Younger with any questions, comments, or concerns - 564-5392 (w); 830-4920 (c); 677-2599 (h). Attachment: Tie-in Log with annotated perforations. Reference Log Tie in Log Add/Subtract feet Log: 'EX-HRLA -DSI ............................. Perf & Jewelry Log ............................. from the tie-in log to be on Date: 5/10/2002 6/26/2002 depth with the reference log. ............................. Company: Schlumberger .............................. Schlumber~er Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Re/Ipert - 13,334' - 13,374' 40' 6 60° 0 Ivishak AdPelf - ........... ......... ............................. . . .. - .............................. ................... ............. .................... . . 0 .......................... ................... ....................................................................................... ..... . . . ........... ......... ............................. ......... ...... ..... . . .............................. .................... ............... .................... . . .. .. 0 .......................... ................... ....................................................................................... .. . . . . . . . 0 Gas Jetting Expected? .No At what Depth? N/A Requested Gun Size: .2" Charge: .2006 PJ .............................. Desired Penetration: 18:6 Entry Hole Diam: 0:2 Is Drawdown Necessary/Desired/Unnecessary During Perforating NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Describe below how to achieve drawdown (check w/ Pad Operator to see i/necessary piping is installed) (e.g. N2 LiR, Hardline Lilt Gas, Gas Lift, Flow Well, BackFlow Through Drain or Hardline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tie in to Jewelry ~ ..............................MD Tie in using: ...................... .......................................................... ......................................................................................... Minimum ID: 3.725 in Min ID Type: 4:5°.XN.NiPPIe Ca 12,791 'MD Please note that min ID appears to be -2.40" based on 06/15/02 Drifts. WLEG Depth: 12:803 ft MD Casing Size: 4:5 in 12.6# 13-CR Liner Est Res. Pres. ~ . .......... 13,372 MD -11100' SS -5100 psi Last Tag: .13.390 ff SLMD on 7/10/2003 ............................... Well: NS07 Perforation Summary Date: API #: 50-029-23081-00 On-Site Prod Engr: General Comments: PBTD O/B/U - O I OP System Version: 10G0-3 ~. MCM . ' SHM GUN 10C0-306 SAFE OCO-306 PGGT-A 1000-306 PIP 8UMMARY Time Mark Every 60 S Gamma Ra G p (GAPI) 100 Casin Collar Locator CCL Shitted Casin Collar Locator ~ 10 3000---°"~TenslLB~ NS) -,__ SUSPEC~'ED JEWELRY FROM DRILLERS TALLY DISCREPANCY-NOTED B~TyyEEN WELCBORE ELaUIPMENT REPORT 12700 MAN C F X-NIP PKR XN-NIP NO-GO 12800 M.EG r SUSPECTED JEWELRY FROM URILLENS TALLY ~ TREE _ WELLHEAD = ABB-VGI 13-5 ACTUATOR = BAKER KB. ELEV - 56.1' BF. ELEV - 40.2' (CB 15.9') KOP _ 50 Max Angle = 42° @ 10452' Datum MD = 12703' Datum ND = 10500 SS 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 3759' Minimum ID = 2.4" @ 12803' OFFSET WLEG (12774' SLM) TOP OF 7" LNR 11196' ~ 9-5/8" CSG, 47#, L-80 BTIVt-C, ID = 8.681" ~ N ~ ~ ~ S NOTES: ***4-1 /2" CHROME TBG &LNR*** ~~~60~ 13-3/8" DV Tool e' ,, 2032' ~--i4-1/2" SSSV w/HXO SLVN NIP, ID = 3.813" CAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 5189 6512 4526 5631 33 33 SMOR SMOR DMY DMY BK-2 BK-2 0 0 05/18/02 06/14/02 11196' ~-19-5/a" X 7" BKR LNR TOP PKR, ID = ? 11217' 9-5/8" X 7" BKR LNR HGR, ID = ? 12715' (12721' ELM) ~ 4-1/2" FIBER OPTIC TRANSDUCER, ID = 3.958" 12734' ~ 4-1/2" HES X NIP, ID = 3.813" 12755' -~ 7" X 4-1 /2" BKR PERM PKR, ID = 3.875" 12780' 4-1/2" HES X NIP, ID = 3.813" ITOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM-ACE, .0152 bpf, ID = 3.958" 7" LNR, 26# L-80 Hydril 521, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: PEX-HRLA-DST on 05/10/02 ANGLE AT TOP PERF: 23° @ 13186' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2" 6 13186 - 13210 O 08/01 /02 2" 12 13210 - 13300 O 06/27/02 2" 6 13300 - 13320 O 07/30/02 PBTD 4-1/2" LNR, 12.6#, 13CR-80 VAM-ACE, .0152 bpf, ID = 3.958" 12{ 789' I-17" X 5" BKR LNR TOP PKR, ID = ? 12791' 12782' ELM 4-1/2" HES XN NIP, ID = 3.725" 12803' 7" X 5" BKR LNR HGR, ID = ? 12804' 4-1/2" WLEG, ID = 3.958" 12774' SLM OFFSET' WLEG, ID = 2.4" (see 06/15/02 WSR) 12813' 5" X 4-1/2" XO, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 05/18/02 EMF INITIAL COMPLETION 11/27/07 WRR/PJC WELLHD/ LOCATION CO_RRECTIC 07/03/02 EMF ADD PERFS 06/25/08 RCT/PJC GLV C/O (05/18 & 06/14/02) - 08/09/02 EMF ADD PERFS 06/28/08 WRR/PJC DRAWING CORRECTIONS 12/20/02 EMF UPDATED KB INFO 11/04/05 BJM NEW FORMAT 07/06/06 WRR WLEG CORRECTION (06/15/02) ABB-VGI5-1/8" 5 /8" MULTIBOWL 5K NORTHSTA R WELL: NS07 PERMff No: 2020770 API No: 50-029-23081-00 SEC 11, T13N, R13E, 1109' FSL & 642' FEL BP Exploration (Alaska) Northstar Oil Spill Response Rate emails . . Subject: Northstar Oil Spill Response Rate emails From: Dave Roby <dave_roby@admin.state.ak.us> Date: Thu, 10 May 2007 08:14:15 -0800 To: Jody Colombie <jody_colombie@admin.state.ak.us> Jody, a.o~-···rrft Attached are a series of emails for the files related to establishing the oil spill response rate for the Northstar field. The emails state that NS-30 will be used to determine the response rate but according to a phone call I received from Mr. Bob Tisserand with the DEC on May 9th they have decided to use well NS-7 to establish the response planning standard rate (the rate for both NS-7 and NS-30 are contained within the email trail). Mr. Tisserand stated that the emails were sufficient and at this time no letter is required. Thanks, =~CANNED MAY 1 0 2007 Subject: Northstar Production rates From: Dave Roby <dave_roby@admin.state.ak.us> Date: Thu, 22 Feb 2007 14:27:27 -0900 To: Robert L Tisserand <robert_tisserand@dec.state.ak.us> CC: "Jane Williamson, PE" <jane_williamson@admin.state.ak.us> Bob, I believe you said that BP was question the rate to use for the Northstar response planning standard. Jane Williamson, the other reservoir engineer in the office and the one who actually handles Northstar, put together the following information on individual well production rates at Northstar during the past year. ~Q# NS-30 Annual average daily production Year Endoil STBD water, Total Liquid, , STBD STBD 2006 6270 820 2006 6437 7 7090 6440 Not a whole lot of difference between the just oil rate of 6,437 BPD for NS-30 and the total liquid rate of 7,090 BPD for NS-07, unless 6,500 or 7,000 BPD is a threshold that automatically requires an increase in response preparedness. Thought you might be interested. Let me and/or Jane now if you have any further questions. 1 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . 9 7 -7 3- 2 David Roby <dave roby@admin.state.ak.us> Reservoir Engineer Alaska Oil and Gas Conservation Commission Subject: RE: Northstar Production rates From: "Tisserand, Robert" <Robert_ Tisserand@dec.state.ak.us> Date: Thu, 22 Feb 2007 14:38:15 -0900 To: Dave Roby <dave_roby@admin.state.ak.us> Hi Dave. Thanks for the information. I appreciate the discussion you and your co-workers had on this topic. Regards, Bob From: Dave Roby [mailto:dave_roby@admin.state.ak.us] Sent: Thursday, February 22,20072:27 PM To: Tisserand, Robert Cc: Jane Williamson, PE Subject: Northstar Production rates Bob, I believe you said that BP was question the rate to use for the Northstar response planning standard. Jane Williamson, the other reservoir engineer in the office and the one who actually handles Northstar, put together the following information on individual well production rates at Northstar during the past year. NS-07 NS- 30 Annual average daily production Year Endo"l STBD water, Total Liquid, I , STBD STBD 2006 6270 820 2006 6437 7 7090 6440 Not a whole lot of difference between the just oil rate of 6,437 BPD for NS-30 and the total liquid rate of 7,090 BPD for NS-07, unless 6,500 or 7,000 BPD is a threshold that automatically requires an increase in response preparedness. Thought you might be interested. Let me and/or Jane now if you have any further questions. 2 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . Subject: Northstar SRPS From: Dave Roby <dave_roby@admin.state.ak.us> Date: Thu, 19 Apr 2007 11:08:21 -0800 To: Robert L Tisserand <robert_tisserand@dec.state.ak.us> Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 BOPD, however this well was not completed until April 2006 (the rate would only be 4,856 BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 BOPD (if based on an entire 365 day year) . My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this well. But, I will defer to your guidance since it is your program that will be affected by how the average daily rate is determined. Regards, David Roby <dave roby@admin.state.ak.us> Reservoir Engineer Alaska Oil and Gas Conservation Commission Subject: FW: Northstar SRPS From: "Tisserand, Robert" <Robert_ Tisserand@dec.state.ak.us> Date: Wed, 25 Apr 2007 11:33:33 -0800 3 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . To: Dave Roby <dave_roby@admin.state.ak.us> Hi Dave. Here are the emails that I talked about. Bob From: Tisserand, Robert Sent: Monday, April 23, 2007 12:44 PM To: 'roby@admin.state.ak.us' Subject: FW: Northstar SRPS Good afternoon Dave. Please take a read of these emails and email to me the total barrels produced by NS- 30 and the number of days produced. Thank you, Bob From: Miner, Lydia Sent: Monday, April 23, 2007 12: 13 PM To: Tisserand, Robert Subject: FW: Northstar SRPS could you please find out from AOGCC the total barrels produced by NS-30 and the number of days produced? (in other words, how did they come up with their average?) Thanks. From: Breck Tostevin [mailto:Breck_ Tostevin@law.state.ak.us] Sent: Friday, April 20, 2007 3:25 PM To: Wilson, Craig; Miner, Lydia Subject: RE: Northstar SRPS How many barrels did NS-30 produce in total? »> 'Wilson, Craig" <Craig_Wilson@dec.state.ak.us> 4/20/20073:19 PM »> I'll give Breck the last word, but here's my take: The key here is "the maximum producing well". This term was derived from the statutory requirement for RMOD as defined at AS 46.04.030(r)(3), that is, "the maximum and most damaging oil discharge". The RMOD has been determined to be the maximum producing well. The RPS is based upon RMOD, which is the maximum producing well. The requirement of "annual average daily oil production volume" was introduced as a method to normalize flow rates and account for wells going on and off line. During discussions around the Phase 1 revisions to the RPS the producers expressed concern that the highest production day of a given well was not indicative of it's long-term threat. They argued that a well could flow extremely high during testing or some other condition, and then 4 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . produce at a lower rate during normal operation. Therefore the concept of averaging daily production flows over a longer time period was introduced, to handle offline and non-routine operational flows. But the "annual" period of time was introduced strictly to smooth out the production data and to handle days of no production, not to set an age requirement on a well. I would posit that if, in the department's discretion, there is sufficient past data to determine the "annual average daily oil production volume" for NS-30, and NS-30 is the "maximum producing well" in absolute terms for the previous calendar year, then it doesn't matter that there is not a full year's worth of data. Eight months is enough data to ascertain with reasonable confidence what the average daily flow rate is. Craig -----original Message----- From: Miner, Lydia Sent: Thursday, April 19, 2007 1:49 PM To: Wilson, Craig; AG Office: Breck Tostevin Su~ect:RE:NorthstarSRPS Hi Craig and Breck - I was going to send this back to AOGCC but thought I'd run it by you first, in case you can make the argument that a different well should be used. Our regulation states that the response planning standard (RPS) for a production facility is based upon the annual average daily oil production volume for the highest producing well at the facility (18 AAC 75.434(e). "Annual average daily oil production volume" is defined at 18 AAC 75.900(162) as the highest annual volume produced by a well at the facility during the previous calendar year divided by the number of days in the year, epxressed as barrels per day. So while the more conservative (and preferable) approach would be to use NS-30 and its 8 months of production and a higher RPS, I believe we must do our best to comply with the regulation as written, so we should use NS-7. I know BP will shove back on anything to get the RPS lower so I'm loath to get into a fight with them if you think I can't win. The difference is nearly 800 bbls/day so I'd like to get it right! Thanks. Lydia ----~Original Message----- From: lìsserand, Robert Sent: Thursday, April 19, 2007 11:52 AM To: Miner, Lydia Subject: FW: Northstar SRPS Hi Lydia. What are your thoughts? 5 of 11 . 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . Bob -----Original Message----- From: Dave Roby [mailto:dave roby@admin.state.ak.usl Sent: Thursday, April 19, 2007 11:08 AM To: Tisserand, Robert Su~ect:NorthstarSRPS Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 BOPD, however this well was not completed until April 2006 (the rate would only be 4,856 BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 BOPD (if based on an entire 365 day year). My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this well. But, I will defer to your guidance since it is your program that will be affected by how the average daily rate is determined. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 Subject: RE: FW: Northstar SRPS 6 of 11 . 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . From: ''Tisserand, Robert" <Robert_Tisserand@dec.state.ak.us> Date: Wed, 25 Apr 2007 11:50:05 -0800 To: Dave Roby <dave_roby@admin.state.ak.us> Thank you Dave for your response. Bob From: Dave Roby [mailto:dave_roby@admin.state.ak.us] Sent: Wednesday, April 25, 2007 11:46 AM To: Tisserand, Robert Subject: Re: FW: Northstar SRPS Hi Bob: NS-30 produced for 251 days during 2006 and produced a total of 1,772,620 bbls of oil, which yields an average daily production rate of 7,062 bbls of oil per day. Also, if I remember correctly the DEC regulations for response planning standard volumes also take into consideration whether or not the wells at the facility are artificially lifted. NS-30, and all wells at Northstar, are naturally flowing and not on any form of artificial lift. Hope this helps. Do you need a formal letter to follow up on this, or is this email sufficient? s Tisserand, Robert wrote: Hi Dave. Here are the emails that I talked about. Bob From: Tisserand, Robert Sent: Monday, April 23, 2007 12:44 PM To: 'roby@admin.state.ak.us' Subject: FW: Northstar SRPS Good afternoon Dave. Please take a read of these emails and email to me the total barrels produced by NS- 30 and the number of days produced. Thank you, Bob From: Miner, Lydia 7 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . Sent: Monday, April 23, 2007 12:13 PM To: Tisserand, Robert Subject: FW: Northstar SRPS could you please find out from AOGCC the total barrels produced by NS-30 and the number of days produced? (in other words, how did they come up with their average?) Thanks. From: Breck Tostevin [mailto:Breck Tostevin@law.state.ak.usl Sent: Friday, April 20, 2007 3:25 PM To: Wilson, Craig; Miner, Lydia Subject: RE: Northstar SRPS How many barrels did NS-30 produce in total? »> "Wilson, Craig" <Craiq Wilson@dec.state.ak.us> 4/20/20073:19 PM »> I'll give Breck the last word, but here's my take: The key here is "the maximum producing well". This term was derived from the statutory requirement for RMOD as defined at AS 46.04.030(r)(3), that is, "the maximum and most damaging oil discharge". The RMOD has been determined to be the maximum producing well. The RPS is based upon RMOD, which is the maximum producing well. The requirement of "annual average daily oil production volume" was introduced as a method to normalize flow rates and account for wells going on and off line. During discussions around the Phase 1 revisions to the RPS the producers expressed concern that the highest production day of a given well was not indicative of it's long-term threat. They argued that a well could flow extremely high during testing or some other condition, and then produce at a lower rate during normal operation. Therefore the concept of averaging daily production flows over a longer time period was introduced, to handle offline and non-routine operational flows. But the "annual" period of time was introduced strictly to smooth out the production data and to handle days of no production, not to set an age requirement on a well. 1 would posit that if, in the department's discretion, there is sufficient past data to determine the "annual average daily oil production volume" for NS-30, and NS-30 is the "maximum producing well" in absolute terms for the previous calendar year, then it doesn't matter that there is not a full year's worth of data. Eight months is enough data to ascertain with reasonable confidence what the average daily flow rate is. Craig -----Original Message----- From: Miner, Lydia Sent: Thursday, April 19, 2007 1:49 PM To: Wilson, Craig; AG Office: Breck Tostevin Subject: RE: Northstar SRPS Hi Craig and Breck - I was going to send this back to AOGCC but thought I'd run it by you first, in case you can make the argument that a different well should be 8 of 11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . used. Our regulation states that the response planning standard (RPS) for a production facility is based upon the annual average daily oil production volume for the highest producing well at the facility (18 AAC 75.434(e). "Annual average daily oil production volume" is defined at 18 AAC 75.900(162) as the highest annual volume produced by a well at the facility during the previous calendar year divided by the number of days in the year, epxressed as barrels per day. So while the more conservative (and preferable) approach would be to use NS-30 and its 8 months of production and a higher RPS, I believe we must do our best to comply with the regulation as written, so we should use NS-7. I know BP will shove back on anything to get the RPS lower so I'm loath to get into a fight with them if you think I can't win. The difference is nearly 800 bbls/day so I'd like to get it right! Thanks. Lydia -----Original Message----- From: Tisserand, Robert Sent: Thursday, April 19, 2007 11:52 AM To: Miner, Lydia Su~ect:AN:NorthstarSRPS Hi Lydia. What are your thoughts? Bob -----Original Message----- From: Dave Roby [mailto:dave roby@admin.state.ak.usl Sent: Thursday, April 19, 2007 11:08 AM To: Tisserand, Robert Su~ect:NorthstarSRPS Hi Bob: I have two quick questions for you. 1) Should the highest production rate well be based on one that flowed for the entire year, or could it be one that came on production during the calendar year? 2) Should the average daily rate be calculated by taking the production for the year and dividing it by a full 365 days, or should the average rate be based only on days the well was actually producing? The reason I ask is that during calendar year 2006 the well at Northstar with the highest average daily flow rate (based on days on production) was NS-30, which produced at an average rate of 7,062 SOPD, however this well was not completed until April 2006 (the rate would only be 4,856 9 of 11 5/10/200711:00 AM Northstar Oil Spill Response Rate emails . . BOPD if its production were applied to the entire year). The highest producing well that produced for the entire year was NS-7, which produced at an average rate of 6,332 BOPD (based on the 361 days it actually produced) or 6,263 SOPD (if based on an entire 365 day year). My thoughts are: 1) That the rate should be based on actual producing days since it is a better indication of how the well could actually produce and will not result in a reduced SRPS rate if the facility is temporarily shut in for a maintenance or repairs, and 2) That a well that is still on production at the end of the year that had produced for at least 8 months (2/3 of the year) could be used since there would be sufficient production data to indicate the true performance of this well. But, I will defer to your gUidance since it is your program that will be affected by how the average daily rate is determined. Regards, Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 David Roby <dave roby@admin.state.ak.us> Reservoir Engineer Alaska Oil and Gas Conservation Commission A h d M Content-Type: message/rfc822 ttac e essage C E d" 7b' ontent- nco mg: It A h d M Content-Type: message/rfc822 ttac e essage ". Content-Encodmg: 7blt h d M Content-Type: message/rfc822 Attac e essage " Content-Encodmg: 7bit A h d Content-Type: message/rfc822 ttac e Message ". Content-Encodmg: 7blt 10 of11 5/10/2007 11 :00 AM Northstar Oil Spill Response Rate emails . . Content-Type: message/rfc822 Attached Message Content-Encoding: 7bit 11 of 11 5/1012007 11:00 AM bp . RECEIVED . Date 05-04-2007 Transmittal Number:92888 MAY 0 8 Z007 Alaska 011 & Gas Cons. CommIssion d Ô d - 0-:;'''7- Ancho!'age BPXA WELL DATA TRANSMITTAL :tF ISlör 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 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 '9 2007 STATIC TEMP / PRESSURE NS24 02-15-2007 PDS ,u~E n MAY ( 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 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 04-1 0-2007 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 IU('.. t""II 07 -23-20û6 PDS JEWELRY LOG / CD ROM 1'1 V It:. DEPTH CORRELATION NS16 08-20-2006 PDS STATIC SURVEY CD ROM Petrotechnica1 Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . 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 04-1 0-2007 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 Petrotechnical Data Center Attn: Kristin Dirks Chistine Mahnken Ignacio Herrera Doug Chromanski Petrotechnica1 Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ------------------ BP Inc. !VS-07 North Star North Surface - Befora RIH 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 9.0 9.5 10.0 AVERAGE Time 53.75 53.78 53.37 53.79 53.01 53.30 53.35 53.31 53.20 52.87 53.16 52.86 52.51 52.90 52.50 52.75 52.66 52.55 52.16 52.15 52.16 52.95 Curren Wellhead Pressure Wellhead Inner Annulus Pressure Outer Annulus Pr Pressure 3621.01 3621.03 3621.05 3621.08 3621.09 3621.11 3621 . 1 3 3621 . 15 3621.16 3621 17 3621.19 3621.20 3621.21 3621.22 3621.23 3621.24 3621.26 3621.27 3621.27 3621.28 3621.28 3621.17 3611 N/A o o Date: Start time: 16:02:00 2006 Data 60 55 50 45 40 0 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 3625 3623 3621 « 00 0... 3619 3617 3615 0 2 3 4 6 7 8 9 10 Page 1 ------------------- Inc. BP !VS-07 North Star North 1 WDss Mil == 13,3291 Date: 2006 Start time: 18:56:00 0.0 256.34 5115.71 1.0 256.33 5115.74 Data 2.0 25637 5115.77 3.0 256.34 5115.79 260 4.0 256.34 5115.82 258 5.0 256.38 51 5.83 6.0 256.37 51 5.85 u. 256 7.0 256.38 5115.87 å! <! 8.0 256.39 51 5.88 c 254 9.0 256.42 5115.89 10.0 256.42 5115.90 252 10 256.39 5115.91 12.0 256.43 5115.92 250 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 13.0 256.43 5115.93 14.0 256.42 5115.94 Minutes 15.0 256.44 5115.94 16.0 256.46 5115.95 7.0 256.47 5115.96 Pressure Data 18.0 256.46 5115.96 5120 19.0 256.48 5115.97 5115 20.0 256.48 5115.97 5110 21.0 25648 5115.98 22.0 256.48 5115.98 5105 « 23.0 256.47 5115.99 ø 5100 0... 24.0 256.47 5115.99 5095 25.0 256.48 5116.00 5090 26.0 256.50 5116.00 27.0 256.51 5116.00 5085 28.0 256.49 5116.00 5080 29.0 256.49 5116.01 0 :2 4 6 8 10 12 16 18 20 22 24 26 28 30 30.0 256.49 5116,01 AVERAGE 256.43 5115.92 Page 2 - - - - - - - - - - - - - - - - - - - BP Inc. !VS-07 North Star North 1 Mil == 13,275' Date: 2006 Start time: 1 Pressure 0.0 254.70 5099.21 0.5 254.70 5099.21 Data 1.0 254 72 5099.21 1.5 254.69 5099.21 260 2.0 254.72 5099.21 258 2.5 254.69 5099.21 3.0 254.69 5099.21 u. 256 3.5 254.66 5099.22 å! (1/ 4.0 254.69 5099.21 c 254 4.5 254.68 5099.22 50 25469 5099.22 252 5.5 25469 5099.22 6.0 254.68 5099.22 250 2 3 .4 5 6 7 8 9 10 11 12 13 14 15 6.5 254.65 5099.22 7.0 254.64 5099.22 Minutes 7.5 254.64 5099.22 8.0 254.68 5099.22 8.5 254.64 5099.22 Pressure Data 9.0 254.65 5099.22 5120 9.5 254.64 5099.22 5115 1 254.64 5099.22 5110 10.5 254.68 5099.23 11.0 25464 5099.23 5105 <I: 11.5 5099.23 ii5 5100 i:!. 2.0 254.67 5099.23 5095 12.5 254.64 5099.23 5090 13.0 254.67 5099.23 13.5 254.61 5099.23 5085 14.0 254.64 5099.23 5080 14.5 254.64 5099.23 0 2 3 4 5 6 12 13 14 15 15.0 254.64 5099.23 254.67 5099.22 Page 3 ------------------- BP NS-07 North Star North Inc. Mil == 13,221' Date 2006 Start time: 19:41 :00 0.0 251.55 5091 .22 0.5 251.54 5091.22 Data 1.0 251.52 5091.21 .5 251.52 5091.21 260 2.0 251.51 5091.21 258 2.5 251.50 5091.21 3.0 251.50 5091.20 u. 256 3.5 251.50 5091.20 å! <! 4.0 251.50 5091 .20 c 254 4.5 251.47 5091.20 5.0 251.50 5091 19 252 5.5 251.48 5091. 6.0 25148 5091 . 19 250 0 2 3 4 5 6 7 8 9 10 11 12 13 14 15 6.5 251.50 5091. 9 7.0 251.47 5091.19 Minutes 7.5 251.47 5091.19 8.0 251.50 5091. 8 25147 5091.18 Pressure Data 9.0 251.47 5091 . 18 5120 9.5 251.47 5091.18 5115 10.0 .47 5091 .18 5110 10.5 251.45 5091. 8 11.0 251.45 5091.18 5105 « 11.5 251.43 5091.18 ii) 5100 c.. 12.0 251.45 5091.18 5095 12.5 251.45 5091.18 5090 13.0 251.42 5091.17 13.5 251.43 5091.17 5085 4.0 251.42 5091 17 5080 14.5 251.45 5091.17 0 2 3 4 5 6 8 9 10 11 12 13 14 15 15.0 251.45 5091. 7 251.48 5091.19 Page 4 ------------------- BP NS-07 North Star North Inc. TVDss MD. == 167 Date: 2006 time: 20: 12:00 0.0 252.36 5084.84 0.5 252.36 5084.84 Data .0 252.36 5084.84 .5 252.33 5084.85 260 2.0 252.34 5084.85 258 2.5 252.36 5084.85 3.0 252.36 5084.85 u. 256 3.5 252.36 5084.85 å! <:II 4.0 252.39 5084.85 c 254 4.5 252.34 5084.85 50 252.34 5084.85 252 5.5 252.34 5084.85 252.39 5084.86 250 2 3 7 8 9 10 12 13 5 6.5 252.37 5084.86 7.0 252.37 5084.86 Minutes 7.5 252.36 5084.86 8,0 252.37 5084.86 8.5 25236 5084,86 Pressure Data 9.0 252.39 5084.86 5120 9,5 252.39 5084.87 5115 10.0 252.37 5084.86 5110 0.5 252.34 5084.87 1 .0 252.36 5084.87 5105 « 1 .5 252.37 5084.87 iñ 5100 !l. 12.0 252.40 5084.87 5095 12.5 252.39 5084.87 5090 13.0 252.41 5084.87 13.5 252.39 5084.87 5085 14.0 252.37 5084.88 5080 14.5 252.37 5084,88 0 2 3 4 5 6 8 9 10 11 12 13 14- 15 15.0 252.39 5084.88 AVERAGE 252.37 5084.86 Page 5 - - - - - - - - - - - - - - - - - - - BP Inc. !VB 07 North Star North Mil== Date: 2006 Start time: 20:44:00 Press 0.0 251.32 5090.96 0.5 251.31 5090.96 Data 1.0 251.28 5090.96 1.5 251.30 5090.96 260 2.0 251.28 5090.95 258 2.5 251.30 5090.95 3.0 251 .28 5090.95 u. 256 3.5 251.27 5090.95 å! <! 4.0 251.28 5090.95 c 254 4.5 25127 5090.95 5.0 251.23 5090.95 252 5.5 251.26 5090 95 6.0 251 .27 5090.95 250 0 2 3 4 5 6 7 8 9 10 12 13 14 5 6.5 251.23 5090.95 7.0 251.25 5090.95 Minutes 7.5 251.25 5090.95 8.0 251.22 5090.95 8.5 251.23 5090.95 Pressure Data 9.0 251.25 5090.95 5120 9.5 251.23 5090.95 5115 10.0 251.25 5090.95 5110 10.5 251.23 5090.95 11.0 251.23 5090.95 5105 « 11.5 251.22 5090.95 ø 5100 0... 12.0 251.22 5090.95 5095 12.5 251.22 5090.95 5090 3.0 251.19 5090.95 13.5 251.23 5090.95 5085 14.0 251.22 5090.95 5080 14.5 251.18 5090.95 0 2 3 4 5 6 8 9 10 12 13 14 15 15.0 251.23 5090.95 VERAGE 251.25 5090.95 Page 6 - - - - - - - - - - - - - - - - - - - BP Inc. NS-07 North Star North Surface - After POOH Date: 2006 Start time: 22:13:00 Pressure 0,0 43.21 3621 . 1 3 0.5 43.05 3621.29 Data 1.0 42.89 3621 .45 1.5 42.71 3621.61 60 2.0 42.50 3621.75 2.5 42.44 3621.87 55 3,0 42.26 3621.98 u. 3.5 42.29 3622.06 g> 50 4.0 42.05 3622.13 c 4.5 42.06 3622.18 45 5.0 41.90 3622 21 5.5 41.86 3622.23 6.0 .80 3622.23 40 6.5 0 2 3 4 5 6 7 8 9 41.70 3622.21 7.0 41.70 3622.19 Minutes 7.5 41.66 3622.15 8.0 41.61 3622.11 8,5 41.56 3622,05 Pressure Data 9.0 41.47 3621.98 3625 9.5 41 .45 3621.91 10.0 41.36 3621.83 3623 AVERAGE 42.07 3621.93 3621 <I: æ 1:1. 3619 Wellhead 3611 Wellhead N/A 3617 Inner Annulus Pressure 0 Outer Annulus Pressure 0 3615 0 2 3 4 5 7 8 9 10 Minutes Page 7 ------ ------- - - - - - - BP Inc. !VS-07 North Star North Downhole Overall Date: 2006 Start time: 18:24:00 End time: 21 :00:00 Data 260 258 u. 256 ¡:: ¡ III c 254 252 250 00 00 300 500 700 900 1100 1300 1500 Minutes Pressure Data 5120 51 5 5110 5105 « æ 00 Il. 5095 5090 5085 5080 -100 100 300 500 900 1100 1300 1500 Page 8 · lIt1j¡j Ip( A STATE OF ALASKA _ ALA~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ~ Stratigraphic D Stimulate [] Other. D WaiverD Time Extènsion[] Re-enter Suspended Well D 5. Permit to Drill Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 202-0770 D 6. API Number: 50-029-23081-00-00 9. Well Name and Number: Exploratory Service 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 56.1 KB NS07 8. Property Designation: ADL-312799 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTH STAR OIL Pool Total Depth measured 13529 feet Plugs (measured) None true vertical 11305.02 feet Junk (measured) None Effective Depth measured 13440 feet true vertical 11220.44 feet Casing Length Size MD TVD Burst Surface 3715 13-3/8" 68# L-80 44 - 3759 44 - 3355.63 4930 Production 11371 9-5/8" 47# L-80 44 - 11415 44 - 9516.57 6870 Liner 1780 7" 26# L-80 11196 - 12976 9344.3 - 10794.79 7240 Liner 740 4-1/2" 12.6# 13Cr80 12789 - 13529 10630.7 -11305.02 8430 Collapse 2270 4760 5410 7500 Perforation depth: Measured depth: 13186 - 13210 13210 - 13300 13300 - 13320 ~,l f; ,_ Z,' True Vertical depth: 10982.69 - 11004.73 11004.73 - 11088.39 11088.39 - 11107.15 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 12803 Packers and SSSV (type and measured depth) 4-1/2" Cameo WRDP-1 SSSV 7" Top Packer 7" Baker 13Cr80 Packer 4-1/2" Top Packer 2032 11196 12755 12789 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft M.4 Y 1 6 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 7291 6850 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 57510 1024 106 51893 949 69 15. Well Class after proposed work: Exploratory Development I;?' 16. Well Status after proposed work: Oil ~ Gas D WAG Tubing pressure 925 988 Service x Contact Sharmaine Vestal WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sharmaine Vestal Title Data Mgmt Engr Signat~.~ Form 10-404 Revised 04/2004 ~ o R i'J Phone 564-4424 Date 5/9/2006 Submit Original Only .. e e NS07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SOMMARY 4/2/2006 ***Heat Seawater/Diesel, load uprights*** *** Job Continued Next Days WSR*** 4/3/2006 ***Continued from previous WSR*** T/I/O=3600/100/0 Assist SLB Pump Crew (Acid Treatment) - Pumped tubing w/69 bbls 100* diesel following acid pickle. Operations flowed pickle back. Pumped tubing w/69 bbls 110* diesel following acid treatment. Turned well over to operations for 4 hr soak. Final WHP's=700/vac/vac *** Job Complete*** 4/3/2006 acid treatment; pump treatment as per program. notify well tender to leave shut in four hours before flowback. FLUIDS PUMPED BBLS 138 Diesel 5 Meth 65 12% acid 194 2% KCL 130 seawater 532 TOTAL e e z.·r·····" co ',. " ",... ¡t~ · ", " ' MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ) I(ñ)~' ~ 9[!Æ' kr' rr;r IE ~\\ 1,\ ûJ\ rl¡ ¡~ [ÜJ Li' U Lb "OJ \ ¡~r il'. ! I~ [ I I 9 i \ 11 U' ,~I,I nl~i'{7 /;,t,rT\\ :I!: i I II ',\ I I" Ii' ~ì ILl i(\~ '\ / p::.~ '\ ; J ....;¡:-J \\....:1 FRANK H. MURKOW5KI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH 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 .10;)..- 017 Re: Northstar Field, NS07 Sundry Number: 306-057 ". ,. r ~ ¡. "11:~' ' f~ f" r ~' ',' 0 01 [, :.:; ,( l\ it~r; ;{'..ä Ir' 1'1 ' .> ~''"J. ~ ~,!, Q; \oj V, ~Ù . 'J "';J.......... , ""'" U 6,,-'<,,:) 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 ~z.-ciay of February, 2006 Enc!. bp ) ) .~. .\If.'II, .......~ ~AP~ ~..- ~..~ .....~ ~..... .'i!'.~'\" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 15, 2006 RECEIVED FEB 1 7 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Alaska Oil & Gas Cons. Commissiol Anchorage Re: Sundry Notice for NS07 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS07 well. This well has exhibited decline and historical analysis of formation water indicates the formation of CaC03 scale is likely. NS07 has a track record of positive responses to annual acid stimulations since August 2003. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid · Flowback Sincerely, Robert Younger Production Engineer BPXA, ACT, Northstar 1. Type of Request: STATE OF ALASKA .... ALl-. k OIL AND GAS CONSERVATION COMMIt,bN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Developm ent It) Stratigraphic 0 rtCuE:.1 V t:.U FEB 1 7 20U~ Abandon [J Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend U Repair well 0 Pull Tubing 0 Alaska Oil & Gas Cons. \' Änr.h~r~;'1e Perforate U Waiver U Other U Stimulate 11] Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 202-0770 Anchorage, AK 99519-6612 7. KB Elevation (ft): Service D 6. API Number: 50-029-23081-00-00 9. Well Name and Number: 56.1 KB NS07 8. Property Designation: ADL-312799 10. Field/Pools(s): 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): 13529 11305.02 13440 11220.44 None None Casing Length Size MD TVD Burst Collapse Surface 3715 13-3/8" 68# L-80 44 3759 44 3356 4930 2270 Production 11371 9-5/8" 47# L-80 44 11415 44 9517 6870 4760 Liner 1780 7" 26# L -80 11196 12976 9344.3 10795 7240 5410 Liner 740 4-1/2" 12.6# 13Cr80 12789 13529 10630.7 11305 8430 7500 Perforation Depth MD (ft): 13186 - 13320 Perforation Depth TVD (ft): 10982.69 - 11107.15 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 40 - 12803 Packers and SSSV Type: 4-1/2" Camco WRDP-1 SSSV 7" Top Packer 7" Baker 13Cr80 Packer 4-1/2" Top Packer 12. Attachments: Descriotive Summary of Proposal e Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Packers and SSSV MD (ft): 2032 11196 12755 12789 13. Well Class after proposed work: Exploratory D Developm ent eJ Service 0 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ¿:;'e~ou5er...---- Title Production Engineer Signature II/v ~ Phone 564-5392 Date COMMISSION USE ONLY Date: 15. Well Status after proposed work: Oil eJ Gas 0 Plugged D WAG 0 GINJ 0 WINJ 0 Abandoned 0 WDSPL 0 Commencing Operations: 3/1/2006 Prepared by Sharmaine Vestal 564-4424 Robert Younger 2/15/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ..30 G,. - 0 5 '" Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS BFL f E8 .2 3 2006 APPROVED BY THE COMMISSION Date: 'Jr''/,~'' of; Submit in Duplicate TREE = ABB-VGI5-1/8" 5K' ) P\¡VEU..I-!EA.O = ABB-VGI13-5IS"' MUl. TBOWl5K:>4: " ~~~i~~:~==~~::::~:==~:-""--"'-'-' . - . 56.1:' ~ BE 8.81 = 40.2' (CB 15.9') ! iKOP = ,----_.,-"...- ~~~_.,~:~gie = 42 @ 9876' ! Datum f¡¡() = LDatum WD= 113-3/8"' CSG, 68#, L-80 BTC, D= 12.415" H 3759" ~ ~Minimum ID =2.4" @ 12803' ~OFFSET WLEG (12774' SLM) I TOP OF 7" lNR Ii 11196" 1 .1S, ~9-5l8" CSG.47#. L-80 8TM-C, D=S.681" 1-1 11415' ~ I TOP OF 4-112"' LNR 1-1 4-1f2"TBG.12.6#.13CRVAM.ACE, :-1 .0152 opf, 10 = 3.958'" I ¡ r lNR, 26# l-80 Hydril 521, D = 6.276" 1-1 12789" 12803" 12976" PERFORA T10N SUMMARY REF lOG: PEX-HRlA-DSlon 05/10/02 ANGLE AT TOPÆRF: 2311 @ 13186' ! INlTI.A.l ÆRF - CHARGE: 2006 POWERJEf, HMX, 6 SPF ~ ÆNETRA llON: 18.6", HOLE: 0.2·, AiASE: 60 DEG. i Note: Refer to A"oduction DB for historical perf data SIZE SPF INlERVAL (W) OpnlSqz DATE 2'" 6 13186 - 13210 0 08/01/02 ,2- 12 13210 - 13300 0 06127/02 2* 6 13300 - 13320 0 07130/02 NS07 - - I ~ ~ 8t. A . ~ L . ~ ~ ~ IRHD l-t 13440" ~ J.~ j4-1/2- LNR, 12.6#. 13CRVAM-ACE >-i 13529" ~ i .0152 bpf. D = 3.958· DATE 05118102 07/03,;02 GSð09i02 ; 220i!02 ~ 1 :04/05 , ~ R£V BY EMF EMF eE e.t= BJM ~ INTIAL COM PLEfION ADD PERFS ADD PERFS UPDA lID KB NFO NEW FORMAT DATE REV BY - -- - - ...."... ~~ìNOTES:*-4.1J2n CHROME TBG & LNtr'* =-----4 1606" 1-1 13-3/S" OV Tool I 2032" 1-14-1/2" SSSV w!HXO SLVN NIP, 10 = 3.813" I .. GAS LFT MANDRElS ST MJ NO DEV lYPE VLV LA TŒI FURf! DATE 2 5189 4526 33 1 6512 5631 33 8.. l 12715" H4-1/2" FlBffi OPTIC TRANSDtJCER, 0=3.958"' I 112721' ELM H4-112" FBEROPT1ClRANSDUCER, D=3.958" I 12734' H4-1i2" XNP, 10=3.813"'1 I 12755" Hr X4-1J2"' PKRI I 12779" H4-112"XNP. D=3.813"1 I 12791" H4-1/2"' XN NP, 10= 3.725"'1 .. I 12803" H4-1/2" WLEG. D- 3.958"1 112774" SLM HOFFSEfWLEG, 10=2.." (see 06/15/04 WSR) 1 H 8.MD TT NOT LOGGED? I COfvM:NTS NORTHSTAR WELL: NS07 PERMIT No: '2020770 API No: 50-028-23081-00 BP Exploration (Alaska) ... _ STATE OF ALASKA _ ALAŠ- OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVEB DEC 1 G 2M, ~ ~ 'n 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 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 0 4. Current Well Class: Development R' Stratigraphic 0 Exploratory Service Stimulate [] "'~ uao ""III'" Waiver 0 Time Extension 0 Anchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0770 6. API Number: 50-029-23081-00-00 9. Well Name and Number: 56.1 KB NS07 ADL-312799 11. Present Well Condition Summary: 10. Field/Pool(s): Northstar Field/ Northstar Oil Pool 8. Property Designation: Total Depth measured 13529 true vertical 11305.02 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 13484 true vertical 11262.26 feet feet Surface Production Liner Liner Length Size MD TVD Burst Collapse 3715 13-3/8" 68# L-80 44 - 3759 44 - 3355.63 4930 2270 11371 9-5/8" 47# L-80 44 - 11415 44 - 9516.57 6870 4760 1780 7" 26# L-80 11196 - 12976 9344.3 - 10794.79 7240 5410 740 4-1/2" 12.6# 13Cr80 12789 - 13529 10630.7 -11305.02 8430 7500 Casing Perforation depth: Measured depth: 13186 - 13320 True Vertical depth: 10982.69 - 11107.15 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 12803 Packers and SSSV (type and measured depth) 4-1/2" Cameo WRDP-1 SSSV 7" Top Packer 7" Baker 13Cr80 Packer 4-1/2" Top Packer 2032 11196 12756 12789 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ço/íot:.J\jt\.fiq¡ nrr 9 l' ')nr!~} \.?~-\:¡U .,,:,!~ ~¡ç~\C' Ly L"" \;i~" b! ",_.. t...v v~ Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 42714 868 0 49990 . 987 0 15. Well Class after proposed work: Exploratory Development R' 16. Well Status after proposed work: Oil R' Gas OJ WAG 0 GINJ 0 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: RBDMS 8FL DEC 19 2DOd 305-171 Contact Sharmaine Vestal . . 13. Oil-Bbl 8346 9723 Tubing pressure 858 907 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x P",ted N,me Sh,,,,,,;,e V..Ia; . .~. r. .. Signatu~~~ Title Data Mgmt Engr Phone 564-4424 Date 12/13/2005 Form 10-404 Revised 04/2004 OR\G\NAL Submit Original Only + e e ~ NS07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/11/2005 Acid/Scale Inhibitor Treatment; Pumped 2 bbl meth spear, 12 bbls 12% HCL, 112 bbls fsw, 69 bbls diesel. Flowback pickle to flowback tank (193) bbls. Spear in with 2 bbls meth followed by 64 bbls 12% HCL w/1 0% L66 scale inhibitor; overflush with 87 bbls 2% KCL w/1 0% L66, 150 bbls KCL, 130 bbls fsw, 69 bbls diesel. Shut in well and let treatment soak for 4 hours. Bring well on to test separator and well clean up tank (500 bbls). Test well post clean-up. FLUIDS PUMPED BBLS 12 12% HCI 12% HCL, 10% L66, .6% A 161,4% A201, 4ppt A 179, 8ppt A 153, 50ppt L41, 64 .5% W54, .2% F103, 20ppt L58 4 Meth 242 Fresh SW 87 KCL w/1 0% L66 150 KCL water 138 Diesel 697 TOTAL ~' ?!Æ/~ ~ ~, . f I f1j ~ ¡ U¡i \ ..J Lu:., tr(l'¡ r?J~ r I' l f, II lUll ¡! \~I ) i /ì i, iì /;M'~\ (el] '~' "\/ ~~' , ß! ,J , ¡! : 1./ '¡ \ \, \, I [.' " : \ ,\,' I II 1 II, " i !' '\ \\ i, 1, 'i \ 'II , , '" -'~ ~')) I '1 ' '\ U ~,t-6 LrlJ Ql) 1\.1 /' ,~ ) ¿;<'tJ2 -0 7 7 FRANK H. MURKOWSKI, GOVERNOR AIfASHA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH 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 SCANNED .Hn 1 2,2005 Re: Northstar NS07 Sundry Number: 305-171 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decisio 0 Superior Court unless rehearing has been requested. DATED this II day of July, 2005 Encl. bp ) ) ... ,~t.,~. -......~ ~..~ ~40.:- ~40.:""" ~..~ ~..... · I'·~§\'" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 5, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS07 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS07 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, CrYLè/haJ j} ~~ / ~ ~ Mic~IJ. FrBh~p.E.· ~ Senior Petroleum Engineer BPXA, ACT, Northstar o R I h I ~II\ ! irJ6/t- 1/7IzøO<;; ) STATE OF ALASKA ) RECEIV ALASKA OIL AND GAS CONSERVATION COMMISSION ,JUt O'6cZOU:1 APPLICATION FOR SUNDRY APPRQY~&GasCons.Luh~hI~~. 20 AAC 25.280 Anchor"ll Operation Shutdown D Plug Perforations D Perforate New Pool 0 StratigraphicD Service D 9. Well Name and Number: NS07 ./' 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): 11249.6 13484 11206.2 S~ MD WD 1. Type of Request: Abandon D D D Suspend D D D Alter Casing Change Approved Program Repair Well Pull Tubing 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Development ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.10 KB 8. Property Designation: ADL-312799 11. Present Total Depth MD (ft): 13529 Casing Length PerforateD Waiver 0 Stimulate[K Time Extension D Re-enter Suspended Well D 5. Permit to Drill/Number: 202-0770 Other 0 / Exploratory D / 6. API Number / 50-029-23081-00-00 Plugs (md): None Burst Junk (md): None Collapse SURFACE INTERMEDIATE LINER PRODUCTION top bottom top bottom 3715 13-3/8" 68# L-80 44 3759 44.0 3355.6 11371 9-5/8" 47# L-80 44 11415 44.0 9516.6 6870 4760 1780 7" 26# L-80 11196 12976 9344.3 10794.8 7240 5410 740 4-1/2" 12.6# 13Cr80 12789 13529 10630.7 11249.6 8430 7500 Perforation Depth MD (ft): 13186 - 13210 13210 - 13300 13300 - 13320 Perforation Depth TVDss (ft): 10927 - 10949.0 10949 - 11032.0 11032 - 11051.0 Tubing Size: 4-1/2 " Tubing Grade: Tubing MD (ft): 12.6 # 13Cr80 40 12803 Packers and SSSV MD (ft): Packers and SSSV Type: 7" Top Packer 7" Baker 13Cr80 Packer 4-1/2" Top Packer 4-1/2" Camco WRDP-1 SSSV 12. Attachments: 11196 12756 12789 2032 13. Well Class after proposed work: Description Summary of Proposal ŒJ Detailed Operations ProQram 0 BOP Sketch 0 14. Estimated Date for Commencing Operation: /' Service 0 July 13, 2005 Exploratory 0 DevelopmentOO 15. Well Status after proposed work: Oil ŒJ / GasD PluggedD Abandoned 0 16. Verbal Approval: Date: WAG D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Michael Francis ~A ~,J ~~)Vf~'~) p;- if '-- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Contact Michael Francis Title Phone Petroleum Engineer 564-4240 6/29/05 Sundry Number: 3OÇ-17/ Location Clearance D RBDMS BFL .JUL 11 2005 BY ORDER OF ¿ i( THE COMMISSION Date: 7(1/1 () Ic~4c4. Form 10-403 Revised 11/2004 o RIG I N A 1-- SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi ) F' ' 133/8" DV Tool at 1606'MD 133/8", 68#/ft, L-80, BTC @ 3759' MD 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 11415' MD 4.5" X NIPPLE, @ 12734' MD 3.813" ID 4.5" X NIPPLE, @ 12779' MD 3.813" ID 4.5" XN NIPPLE, @ 12791' MD 3.725" ID 4.5" WLEG, @ 12803' MD 3.958" ID 7", 26#/ft L-80, Hydril 521 @ 12976' MD PffiFŒA TlO'J SLMv\ðo.RY REf LOG: FÐ(-HRlA-DSI (5/10/2002) AN3LEATTOPF£RF: IIbte: Refer to Ffoduction DB for historical perf data ~1itial F\Jrf - Olarge: 2006 FbwerJet, HMX; F\Jnetralion: 18.6"; I-ble: .2"; A1ase: 60 deç¡ 6 spf x2 runs SIZE SFF 1N'l"mJ AL M) 1N'l"mJ AL TVD q¡n/Sqz 2 12 13210' -13300' 11018' - 11045' Opn 2 6 13300'·13320' 11101'-11120' Opn 2 6 13186' -13210' 10996' - 11018' q¡n / PBTD @ 13440' TD @ 13529' NS07 / )KB. ELEV = 56.1' KB-BF. ELEV = 40.2' BASE FLANGE ELEV = 15.9' '1 1/2" SSSV @ 2032' MD w/ HXO SVLN nipple - 3.813" ID ~ .. 4 1/2" GLM,@ 5189' MD, 4528' TVD w/ 3.833¡' ID ~ 41/2" GLM @ 6512' MD, 5634'TVD w/ 3.833" I D . ¿- ~ - 7" LINER TOP @ 11196' MD V I 4.5" Fiber Optic Transducer 12715' MD, 10578' TVD 3.958" ID (10582' TVDe/m) B -;; _ 7" PACKER,13 Cr @ 12755' MD, ~- 10615' TVD ~ MIN ID 2.4" @12774' offset WLEG ~ 4.5" LINER TOP @ 12789' MD 1 E ~ .... DATE 6/27/2002 7/30/2002 8/1/2002 j - TAG 13407' ELMD (7/30/02) ~ 4.5",12.6#, 13Cr Vam Ace DATE REV. BY COMMENTS Northstar 5/14/03 EMF Updated Depth Values WFI I : N~07 5/3/02 EMF Update Depth Values, Perfs API NO: 500282308100 7/3/02 EMF Add Perfs 8/9/02 EMF Add Perfs BP Exploration (Alaska) 1 ?/?O/O? I::.Mt- Uodated KB Information STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~ ~ 1. Operations Performed: RepairWeliD PluQ Perforations 0 AbandonD Stimulate 1:&:1 OtherD Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionO Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 202-0770 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23081-00-00 7. KB Elevation (ft): 9. Well Name and Number: 56.10 NS07 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar Field 1 Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 13529 feet true vertical 11318.1 feet Plugs (measured) None Effective Depth measured 13484 feet Junk (measured) None true vertical 11275.1 feet Casing Length Size MD TVD Burst Collapse Liner 1780 7" 26# L-BO 11196 - 12976 9354.1 - 10807.6 7240 5410 LIner 740 4-112" 12.6# 13Cr80 12789 - 13529 10643.3 - 11318.1 8430 7500 Production 11371 9-5/8" 47# L-BO 44 - 11415 44.0 - 9526.7 6870 4760 Surface 3715 13-3/8" 68# L-80 44 - 3759 44.0 - 3355.6 4930 2270 Perforation deDth: Measured depth: 13186 -13210,13210 - 13240, 13240 - 13270, 13270 - 13300, 13300 -13320 True vertical depth: 10995.54 -11017.57,11017.57 -11045.29,11045.29 -11073.18,11073.18 -11101.24,11101.24 -11120 EO Tubing (size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 40 - 12805 RECE\V Packers & SSSV (type & measured depth): 4-112" BOT Perm Packer @ 12756 S£P 1 6 '2.G04 . 4-112" Camco WRDP-1 SSSV @ 2032 Coni. CommisSIon 4-112" Liner Top Packer @ 12789 ~\a,~a Oi\ &. GaS 7" Liner Top Packer 11196 ~"thO'8ge 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13186 - 13320 RBDMS 8FL SEPll&8 Treatment descriptions including volumes used and final pressure: 64 Bbls 12% DAD Acid @ 900 psig 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 10088 29.9 808 0 1010 Subsequent to operation: 10969 30.2 561 0 1104 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. ! OilŒ] 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. ISUndry Number or NIA if ~~ ~7mpt: Contact Garry Catron JWI( ~ ~~ Printed Name Garry Catron Title Production Technical Assistant Signature )j /. A.ÁI, (' h....... Phone 564-4657 Date 9/15/04 u Form 10-404 Revised 4/2004 OR\G\NAL . ,.-..., ~ NSO7 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/14/04 ACID I SCALE INHIBITOR TREATMENT: PICKLE TBG WI 17 BBLS 12% DAD ACID AND DISPLACE TO PERFS WI 107 BBLS SW AND 69 BBLS DIESEL. FLOWBACK PICKLE VOLUME OF 193 BBLS TO WELL CLEAN UP TANK. PERFORM MAIN TREATMENT: 64 BBLS 12% DAD WI SCALE INHIBITOR (20%) FOLLOWED BY 199 BBLS SW FOR DISPLACEMENTTo PERFS. LET SOAK 30 MINUTES. OVERDISPLACE WI 204 BBLS SW AND 63 BBLS OF DIESEL. ASK OPS FOR 4 HOUR SOAK TIME PRIOR TO POP. FLUIDS PUMPED BBLS 81 12% DAD Acid wI scale inhibition 510 Sea Water 4 Neat Methanal 138 Diesel 733 TOTAL Page 1 Permit to Drill 2020770 ~ G J J\,) ÀN~ "1. DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 )fJ'A-¿' {g ~ Ä~ ~ l- API No. 50-029-23081-00-00 Well Name/No. NORTHSTAR UNIT NS-07 Operator BP EXPLORATION (ALASKA) INC - ---_.------ MD 13529./ TVD 11318 /' Completion Date 6/26/2002./ Completion Status 1-01L UIC N Current Status 1-01L REQUIRED INFORMATION Mud Log Yes Samples No ~-~, Directional surve~ -- ------ ------ - - ----- ------ DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~. -------- ~g 0f11êrfo ratio n ~ I :ED C !~ ~C ~D ! i ¡~--.C I .+Log '~ ,~. c :6-9 Ûæg. ~- !~ I ~/ J...kú9 ~/- ~og ~ V11 048 See Notes Log Log Run Interval OHI -' Scale Media No Start Stop CH Received Comments 2 Blu 1 0 13529 Open 12/5/2002 \)\ ~ À,{j ~ "L- 5 Blu 13186 13320 Case 8/14/2002 2" PJ HSD Guns - 6 SPF 1 to 7 201 13544 Open 7/26/2002 LDWG Open Hole Edited Measurement While Drilling data 25 Blu 11418 11750 Open 617/2002 ~ Express Triple Combo See Notes V 1 056 See Notes / ). )-~ 1 See Notes 11424 12954 Open 6/21/2002 Stratigraphic Dip 0 13529 Open 7/11/2002/ormation Evaluation Data ASCII files 11424 12954 Open 6/21/2002 Structural Dip 12992 13480 ~ 1/31/2003 ~aJform-Express High Resolution Laterolog ~'1 056 See See Notes 5 Blu Directional Survey ~J 11558 Gamma Ray ~Log ~L09 LÞo'fñ1ation Tester ljléutron ~tion/ResistiVitY Neutron ~ma;Ray 0 13529 ;:>perr-~5122/2002 100 13546 Case 1/27/2003 '--~ 0 0 13529 Open 12/5/2002 13529 Open 12/5/2002 5 Blu 2 Blu Blu 25 Blu 25 Blu 2 Blu 25 Blu 25 Blu 5 Blu 13022 13424 Open 8/21/2002 11418 11750 Open 617/2002 ~m Express 11418 11750 Open 61712002 ÚoPfâtform Express 11418 11750 &-1/31/2003 Platform Express 11418 11?50 ~ 1/31/2003 ~ 12958 ~ 617/2002 12650 133~5~ 7/22/2002 ~J HSD Guns - 6 SPF ~GárnmaHay Jerforation )., CD J ~ ;JJ~ 1- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Permit to Drill 2020770 Well Name/No. NORTHSTAR UNIT NS-07 MD 13529 ~. 'Ù&Q~ '~ ;'-lcg- ~- ljÁ9 Rpt vtOg ~D C ~/ i VED C ~ ~ I : Log -;-tog- t~ÉD C I~ I (~ [jYð9- . Log ~/ ~ C ¡ Log '¡tog 0D : Log C 1VD 11318 - ------- Completion Status 1-01L Current Status 1-01L 25 Blu 7 to 7 1'4) LJ.28B 1 13543 Open 7/26/2002 25 Blu 7 to 7 ~13544 Open 7/26/2002 25 Blu 6 to 6 f'1.D ~ 13544 Open 7/26/2002 25 Blu 7 to 71þ'J) 12878 13544 Open 7/26/2002 25 Blu 1 11418 11750 Open 6/7/2002 25 Blu 6 to 6 ìVJ) 265 13544 Open 7/26/2002 0 13529 Open 5/22/2002 11750 ~e 1/31/2003 12982 ~ 6/13/2002 12958 Open 6/7/2002 Completion Date 6/26/2002 Density ~úfron ~n/Resìstívíty L.Øéi1sity Density ~ion/Resistivity Directional Survey ~nsity v11 076 Sonic /-- '---Sonic [/11056 See Notes [ßee"'Ñotes e-soñic Neutron See Notes ~0838 See. Notes See Notes OOOõé[¡on/Resisti"itY ~otes See Notes t...A0858 See Notes See Notes LtÓ869 Sonic Sonic -"- - ------- 2 Blu 11418 8432 25 Blu 11418 1 11424 1~- 0 25 Blu 11418 25 Blu 7 to 7 12881 5 Blu 12650 270 2 2 Blu ~Blu 2 Col J" q J 10'-1 À6~'" 5 Blu 2 Col 2 2 5 Col Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23081-00-00 UIC N Platform Express CpfgffÕrm Express -- \) 51 12954 Open 6/21/2002 f....FMllmages and Dip data 13529 Open 7/11/2002 LE--m:tô{ Well Report 11750 ~' '[uat12003 13543 Open 7/26/2002 13395 Case 7/22/2002 -jeWelry 12955 Open 6/7/2002 c.)?penHole LDWG Formatted edit Blu 11418 11750 ~' 1/31/2003 Platform Express Triple Combo 11418 11750 s;:;;- 1/31/2003 -Ptâtform Express 1 'jvÒ 11418 11750 Case 1/31/2003 [ßatfõrm Express Triple Combo ._~ Col 0 13529 Open 7/11/2002 Rig Monitoring 11260 12960 Case 5/18/2002 ¿).AS, DLlS, and PDS files of Processed DSI ÓJ26Ó 12960 ~/18/2002 (Best DT final result 13186 13210 Case 8/14/2002 2" PJ HSD Guns - 6 SPF 0-2438 13.512 Open 5/22/2002 Lâe$rDT Final Result 12438 13512 Open 5/22/2002 8432 12982 Case 6/13/2002 Permit to Drill 2020770 MD 13529 Well Cores/Samples Information: TVD 11318 Name Well Cored? ADDITIONAL INFORMATION Y / CJ Chips Received? Analysis Received? - ---- ---- --- Comments: --- - ---- ---- ---- ~ ~ --------- Compliance Reviewed By: -----.-- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2004 Well Name/No. NORTHST AR UNIT NS-07 Operator BP EXPLORATION (ALASKA) INC Completion Date 6/26/2002 Completion Status 1-01L Interval Start Stop Sent Received Daily History Received? Formation Tops !~ Current Status 1-01L Sample Set Number Comments &N ß/N Date: API No. 50-029-23081-00-00 UIC N -- 3 /~) ~ U,,--- bp ') \. ~~~ ,\~f.~itl. -...'"~ ~...~ ~.- -:..-- "Ar'~ ~'"... . ~~~~~\... "~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 :J-°:J.. -D 7 7 July 7,2004 I Winton Aubert Alaska Oil & Gas Cònservation Commission 333 West ih 'Avenue Suite 100 Anchorage, AK 99501 JUl 1 3 2004 Dear Winton: Re: Sundry Notice for NS07 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS07 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, c:la~~s~~ Senior Petroleum Engineer BPXA, ACT, Northstar OR\G\NAL ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~uL ":.1 ';11' 20 AAC 25.280 -~. di 2004 D Suspend D Operation Shutdown D D Repair Well D Plug Perforations D 0 Pull Tubing 0 Perforate New Pool D 4. Current Well Class: 1. Type of Request: Abandon Alter Casing Change Approved Program 2. Operator Name: VJ6Æ- 1114-/20°4 °7::> 7/ (<f--/~ fJ.~[ ?;,:::~ ;~I':'L :,:':":, ,,-';::"",',: ,;",,:,. ",'" :-':~ PerforateD wai,y~~p .." f\nn'ùlarDisposa~ D StimulateŒ] Time Extensio~D OtherD Re-enter Suspended Well 0 5. Permit to Drill N)Jmber: 202-0770 / 6. API Number // 50-029-23081-00-00 BP Exploration (Alaska), Inc. Length Development Œ] Exploratory D Stratigraphic D Service D 9. Well Name and Numb7r: NS07 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13484 11219.0 MD TVD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.10 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 13529 Casing Total Depth TVD (ft): 11318.1 Detailed Operations Program III Printed Name Signature Size Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 11196 12976 9354.1 10807.6 7240 5410 12789 13529 10643.3 11318.1 8430 7500 44 11415 44.0 9526.7 6870 4760 44 3759 44.0 3355.6 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 40 12805 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): 10995.5 11017.6 11017.6 11045.3 11045.3 11073.2 11073.2 11101.2 11101.2 11120.0 Packers and SSSV MD (ft): 13. Well Class after proposed work: BOP Sketch D 12756 2032 12789 11196 ExploratoryD DevelopmentŒ] ServiceD August 1 2004 15. Well Status after proposed work: Oil ŒJ GasO WAG D GINJD Liner 1780 Liner 740 Production 11371 Surface 3715 Perforation Depth MD (ft): 13186 - 13210 13210 - 13240 13240 - 13270 13270 - 13300 13300 - 13320 Packers and SSSV Type: 4-1/2" BOT Perm Packer 4-1/2" Camco WRDP-1 SSSV 4-1/2" Liner Top Packer 7" Liner Top Packer 12. Attachments: Description Summary of Proposal I)ZI 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Contact Michael Francis Title o/V..1v~aJ J ~~" ~~ £ . Phone ( '-. Commission Use Only Petroleum Engineer 564-4240 7/8/04 Conditions of approval: Notify Commission so that a representative may witness BOP TestO Mechanciallntegrity Test D Location Clearance 0 n. 2~. fIDtS BFt PluggedO AbandonedO WINJD WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Numger: Ý .30J./-;)t, Form 10-403 Revised 06/2004 '- BY ORDER OF THE COMMISSION Date: ~/~ OR\G\NAl SUBMIT IN DUPLICATE . . TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi 13 3/8" DV Tool at 1606'MD 13 3/8", 68#/ft, L-80, BTC @ 3759' MD 41/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-80 BTM-C @ 11415' MD 4.5" X NIPPLE, @ 12734' MD 3.813" ID 4.5" X NIPPLE, @ 12779' MD 3.813" ID 4.5" XN NIPPLE, @ 12791' MD 3.725" ID 4.5" WLEG, @ 12803' MD 3.958" ID - 7", 26#/ft L-80, Hydril 521 @ 12976' MD ÆRFæA TIQ\ SlJvTvIO-RY Rf3= LOG: ÆX-t-R.A-DSI (5/10/2002) Af'GLE AT TOP ÆRF: f\bte: Refer to Ffoduction DB for historical perf data nitial Fer! - O1arge: 2006 R:>werJet, H'v1X; Fenetration: 18.6"; I-ble: .2"; R1ase: 60 deg 6 spf x2 runs SIZE SFf INTHN AL M) INTHN AL lVD Q:>nISqz 2 12 13210'-13300' 11018'-11045' Opn 2 6 13300'-13320' 11101'-11120' Q:>n 2 6 13186' - 13210' 10996' - 11018' Opn PBTD @ 13440' TD @ 13529' ) DAlE 6/27/2002 7/30/2002 8/1/2002 NS07 ..4 . ¿- J B J. J ~ ~ . \KB. ELEV = 56.1' "¿B-BF. ELEV = 40.2' BASE FLANGE ELEV = 15.9' 41/2" SSSV @ 2032' MD, 1971' TVD wI HXO SVLN nipple - 3.813" ID 6.8PPG DIESEL FREEZE PROTECTION AT +/- 5000' TVD (5750'MD) .. 4 1/2" GLM @ 5189' MD, 4528' TVD wI 3.833" ID 4 1/2" GLM @ 6512' MD, 5634' TVD wI 3.833" ID ~ - 7" LINER TOP @ 11196' MD 4.5" Fiber Optic Transducer 12715' MD, 10578' TVD 3.958" ID (10582' TVDelm) -;¡ - 7" PACKER,13 Cr @ 12755' MD, .- 10615' TVD ~E ... MIN ID 2.4" @12774' offset WLEG 4.5" LINER TOP @ 12789' MD ¡- TAG 13407' ELMD (7/30/02) ~ 4.5",12.6#, 13Cr Yam Ace DATE REV. BY COMMENTS Northstar 5/14/03 EMF LJpdated LJepth Values WF~ ~ : NS07 5/3/02 EMF Update Depth Values, Perfs API NO: 500282308100 7/3/02 EMF Add Perfs 8/9/02 EMF Add Perfs BP Exploration (Alaska) 1 ?/?O/O? ~Mr Updated KB Information ) STATE OF ALASKA'} ALASkA OIL AND GAS CONSERVATION COMivII6SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D SuspendL:] Repair WellD Pull TubingC] Operation Shutdown 0 Plug PerforationsD Perforate New Pool D PerforateD VarianceD Stimulate !] Time ExtensionD Re-enter Suspended WellO Annular DisposalD OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development 00 ExploratoryD 5. Permit to Drill Number: 202-0770 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD ServiceD 9. Well Name and Number: NS-07 10. Field/Pool(s): Northstar 6. API Number 50-029-23081-00-00 7. KB Elevation (ft): 56.1 8. Property Designati ADL-2799 11. Present Well Condition Summary: I Northstar Total Depth measured 13529 feet true vertical 11318 feet Plugs (measured) Effective Depth measured 13484 feet Junk (measured) true vertical 11163 feet Casing Length Size MD TVD Burst Collapse Structural Conductor . Surface 3715 13-3/8" 68# L-80 44 3759 44.0 - 3355.6 5020 2270 Intermediate 11371 9-5/8" 47# L-80 44 11415 44.0 - 9526.7 6870 4760 Production 1780 4-1/2" 12.6# 13Cr80 11196 12976 10643.3 -11318.1 8430 7500 Liner 740 7" 26# L-80 12789 13529 9354.1 - 10807.6 7240 5410 Perforation depth: Measured depth: 13186' -13210', 13210' -13240', 13240' -13270', 13270' -13300', 13300' -13320' True vertical depth: 10995.54' -11017.57',11017.57' -11045.29',11045.29' -11073.18',11073.18' -11101.24', 11101.24' -11120' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40' -12805' MD Packers & SSSV (type & measured depth) 7" Baker Liner Top Packer @ 11196' MD /7" Baker Perm Packer @ 12756' MD 7" Baker Liner Top Packer @ 12789' MD /4-1/2" Otis BBE SSV @ 2032' MD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: (See Attachment) 9.: 13 Representative Daily AveraQe Production or Injection Data" . . Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure" Tûbing"PressÜre Prior to well operation: Subsequent to operation: 6800 11075 17,500 23,800 140 508 I ' ".. . ,', '731 1513 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentOO Service 0 Signature Michael J. Francis, P.E. Michael J. Francis ~~4ff~' 16. Well Status after proposed work: Operational Shutdown OilOO GasO WAG 0 GINJD WINJD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 303-220 D WDSPLD Copies of Logs and Surveys run - Daily Report of Well Operations - ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Senior Petroleum Engineer f~~'~ Phone 564-4240 Date 9/26/03 Form 10-404 Revised 4/2003 OR1G'NAL Ra~~~r~ 5t~ ~:" L U \..1.1 ') ') NS-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/13/2003 Pickle tubing with 5 bbls meth, 12 bbls 120/0 DAD acid (12.5% titration), 112 bbls SW, 69 bbls diesel, flowback 195 bbls to separator, 1550 ISITP, treated at 3 bpm, masx treat psi at 2900 psi. Pump main acid treatment per procedure, 3 bbls SW, 64 bbls DAD acid, 199 bbls SW, soak 30 min, 204 bbls SW flush, 69 bbls diesel. Shut in well for 4 hour soak, flow back. FLUIDS PUMPED BBLS 5 138 76 518 737 Methonal Diesel 12% DAD acid (titrated 12.50/0) Sea Water TOTAL Page 1 bp ) ) ,\tA~/. ~...~~''''~..... ~- ~...'" ..~ ~..... .'J'~\" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. 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 NS07 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS07 well. This well has exhibited a high rate of decline and analysis of formation water indicates the formation of CaC03 scale is likely. Additionally, CaC03 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, A cyI~4I ~ Mic~ ael J. Fr IS, R.E. ) Senior Petrole m Engineer BPXA, ACT, No . star ,0.£. : : r~ .; t? D i~ 3 0 RIG I ~\I A f. VJG¡\. f r~ J 2..001 ) STATE OF ALASKA ) ó)r;-;ý rf /!)~ ALASKA OIL AND GAS CONSERVATION COMMISSION Cyß (/I( , APPLICATION FORSUNDRY APPROVAL O( ,if) 20 AAC 25.280 1. Type of Request: D Suspend D Operation Shutdown D Perforate D VarianceD Annuar Disposal D Abandon Alter Casinq D Repair Well D Pluq Perforations D Stimulate[X Time Extension D OtherD ChanQe Approved Proqram D Pull Tubinq D Perforate New Pool D Re-enter Suspended WellD 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): RKB 56.10 8. Property Designation: ADL-312799 3. Address: 4. Current Well Class: Development ŒI ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: NS07 ,/ 10. Field/Pool(s): 5. Permit to Drill Number: 202-0770 /' 6. API Number r 50-029-23081-00-00 Northstar I Northstar 11. Total Depth MD (ft): 13529 Casing PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11318.05 13484 11162.93 Size MD TVD Length Conductor Surface 3715 13-3/8" 68# L-80 Intermediate 11371 9-5/8" 47# L-80 Liner 1780 7" 26# L-80 Production Liner 740 4-112" 12.6# 13Cr80 Perforation Depth MD (ft): Perforation Depth TVD (ft): 13186' . 13320' 10995.5' - 11120.0' Packers and SSSV Type: 7" Baker Liner Top Packer /7" Baker Perm Packer 7" Baker Liner Top Packer /4-1/2" Otis BBE SSV 12. Attachments: Description Summary of Proposal D Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 8/11/2003 Date: top bottom top bottom Plugs (measured): Junk (measured): Burst 5020 6870 7240 8430 Tubing Size: Tubing Grade: 4-1/2" 12.6# 13Cr80 Packers and SSSV MD (ft): 11196 /12756 /12789 / 2032 Collapse 2270 4760 5410 7500 Tubing MD (ft): 40 - 12805 13. Well Class after proposed work: ExploratoryD Developmentl!] 15. Well Status after proposed work: Oil[!) GasD PluggedD AbandonedD WAGD GINJD WINJD WDSPLD Perpared by S. Copeland 564-4424 Plug Integrity D BOP TestD Mechanciallntegrity TestD Location Clearance D Other: Subsequent Form Required: 40,-/ 44 44 11196 12789 - 3759 - 11415 - 12976 - 13529 44.0 - 3355.6 44.0 - 9526.7 9354.1 - 10807.6 10643.3 -11318.1 Service D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patty Hill Printed Name Patty Hill < 1 Title - Production Engineer Signature ~ tÁd~~ !11,- Phone 564-4346 Date 8n/03 "--' cYommission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 313. A;~ Lî Approved by: C, -----"~/2 n, ,. . , .COMMISIONER (1 ~~O '""' i ,--' . . , ~ ¡ J ' (' . , , .. t\ . l) t ~\\j /' ; Form 10-403 Revised 2/2003 RBDMS SF L ,AU 11 Z003 BY ORDER OF THE COMMISSION J~0. 'j ':: ì .', J ~r;6 SUBMIT IN DUPLICATE b:p ) ) Date: 01-27-2003 Transmittal NU11lber:926 I 3 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 Log Run Depth NS07 05-06-200~ SCH 1 11418 ~n77 'NSOt 05-06-2002 SCH 11418 ( NS07 05-06-2002 SCH 11418 V NS07 05-06-2002 SCH 11418 / NS07 05-06-2002 SCH 1 11418 /' NS07 05-06-2002 SCH 11418 SCH Bottom Depth Log Type 11750 GAMMA RAY LOG; MERGED COPY; PLATFORM EXPRESS; TRIPLE COMBO SSTVD; MERGED COPY; 11750 PLATFORM EXPRESS; NEUTRON/DENSITY; MERGED COPY; 11750 PLATFORM EXPRESS; TRIPLE COMBO; MERGED COPY; DIPOLE SONIC; MERGED COPY; 11750 PLATFORM EXPRESS; HIGH RESOLUTION LA TEROLOG TOOL; '12494 DEPTH DETERMIN A TION LOG; 11750 --- 11750 ""í NS24 12-23-2002 ~t'B ..fln(r V NS24" 12-20-2002 V v NS18, 12-31-2002 ANA 0 16865 MWD SURVEY REPORT; a(')rl.- J t/ I v 'HARDCOPY/DISKETTE; NS22 . 12-12-2002 ANA . 0 '12486 MWD SURVEY REPORT; c7~~~ / HARDCOPY/DISKETTE; NS24 12-20-2002 ANA 1 0 "12607 MWD SURVEY REPORT; ~":11.o1 v HARDCOPY/DISKETTE; /Ý7/¡~~~--V~- ~ NS;2-1 /'1 ~B9-O-i."~./l.-- ,~,_:~"----L::--z-~--v ~~oo:lQIt1RRMI:r~ ./ l' j/ MODIFY; ./ 1 '1795 SCH 11 350 12590 REPEAT FORMATION TESTEr~; ~d ~!~~py of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVED Petrotcchnical Data Center LR2-1 900 E. Bcnson Blvd. PO Box 196612 Anchorage, AK 99519-6612 JAN 3 1 2003 AI- Oii & Gas Cons. Commi8lion And1nge b:p ) ) Date: 12-5-2002 Transmi~tal Number:92602 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the POC at 564-4091. --... SW Name Date Contractor NS06 06-07-2002 SPERRY SUN () ""ì NS06 rt ~NS06 ./ v 06-07 -2002 SPERRY SUN V' ./' 06-03-2002 SPERRY SUN I 05-15-2002 SPERRY SUN v' 05-15-2002 SPERRY SUN ý' 05-15-2002 SPERRY SUN NS07 ~ NS07 0 ( BNS07 r1), NS08 - ~ NS08 ~NS08 NS12 C -NS12 -... , ~NS12 ro NS14 II' 03-10-2002 SPERRY SUN 03-10-2002 SPERRY SUN 03-10-2002 SPERRY SUN 06-27 -2002 SPERRY ./' SUN 06-27-2002 SPERRY / SUN / 06-27-2002 SPERRY SUN ~ q~-l)é~~:OÒ2-"; SÞÊRRY / SUN ÒO NS14 02-09-2002SP'ERRY -,¡ SUN \ Õ NS14n.~<::; 02~09-2002;~¡"SPEHRY; ~ " ./ " !>""ii" """', ,/ SUN NS15 04-13-2002 SPERRY ~ SUN 8' NS15 .,/ 04-13-2002 SPERRY ~ / SUN Cã Top Log Run Depth 100,101, 201 200,300, 400 100,101, 201 200,300, 400,401 100,101, 201 200,300, 400,401 100,200, 201 300,400, 500 100,200, 201 300,400, 500 100,200, 0 300,400, 500 1,2,3,4 201 1,2,3,4 201 1,2,3,4 201 100,200, 201 300 100,200, 201 300 100,200, 201 300 1,2,3,4 201 1,2,3,4 201 1,2,3,4 201 100,200, 201 300,400, 500 100,200, 201 300,400, Bottom Depth Log Type , 13396.9 MUD LOG - 5" - MD ~OG 13396.9 MUD LOG - 2" - TVD¡LOG 13396.9 MUD LOG - 2" - MD LOG 13529 MUD LOG - 5" - MD ~OG 13529 MUD LOG - 2" - TVD¡LOG 13529 MUD LOG - 2" - MD LOG 12030 MUD LOG - 5" - MD LOG 12030 MUD LOG - 2" - TVD: LOG i 12030 MUD LOG - 2" - MD LOG 13135 MUD LOG - 5" - MD LOG 13135 MUD LOG - 2" - TVD LOG 13135 MUD LOG - 2" - MD LOG 13020 MUD LOG - 5" - MD LOG 13020 MUD LOG - 2" - TVD LOG 13020 MUD LOG - 2" - MD LOG 15370 MUD LOG - 5" - MD LOG 15370 MUD LOG - 2" - TVD LOG Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 ,) d09-0 -¡ J Date: 01-27-2003 J 155~ Transmittal Number:92613 bp ) 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 NS07 05-06-2002 Top Contractor Log Run Depth Bottom Depth Log Type SCH 1 11418 11750 DIGITAL DATA; MERGED COPY; CD ROM ~ r~~/ ~:;;g~eturn one copy of this transmittal. Thank You, James H. Johnson Petrotechnícal Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg M.B3-6 Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) Attn: Bob Gage (Murphy Exploration) ; . RECEIVED JAN 27 2003 AI-a Oit & Gas Cons. ColM1e8ion Andtcnae Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ;bp ) ) Date: 12-5-2002 Transmittal Number:92602 BPXA WELL DATA TRANSMITTAL 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 f' ./ SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUDLOG-2"-TVDLOG ( ./ SUN 'ð 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, v"" 300,301, 400,401 ~NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUDLOG-2"-TVDLOG -..... SUN 200,201, . 300,301, rcr / 400,401 ~NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 2" - MD LOG SUN 200,201, ~ / ~ 300,301, 400,401 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 5" - MD LOG '"::)--. v SUN 300 ~ NS24 08-24-2002 SPERRY 100,200, 201 12127 MUDLOG-2"-TVDLOG ~ 'NS24 v SUN 300 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - MD LOG 0). I SUN 300 ~~g~n one copy of this transmittal. Thank You, . RECEIVED James H. Johnson Petrotechnical Data Center DEC 05 2002 Ken Lemley MB3-6 AI.. at & Gal Coni. CoInmiIIion Esther Fueg MB3-6 AIKttcßþ Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (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 COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well OIL 0 GAS 0 SUSPENDED 0 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4171' FNL, 643' FEL, Sec. 11, T13N, R13E, UM (asp's 659834, 6030881) At Top Producing Interval 462' FNL, 1425' FEL, Sec. 15, T13N, R13E, UM (asp's 653808,6029183) At Total Depth 418' FNL, 1551' FEL, Sec. 15, T13N, R13E, UM (asp's 653681,6029224) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 56 feet ADL 312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 04/18/2002 05/09/2002 08/01/2002 Add Perfs 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13529' MD / 11318' TVD 13484' MD / 11275' TVD YES [2] No 0 22. Type Electric or Other Logs Run GYRO, MWD, LWD, DIPOLE SONIC, FMI, DEN, RFT, GR, DIR, RES, PWD, NEU 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 201' 44' 3759' 44' 11415' 11196' 12976' 12789' 13529' ABANDONED 0 CASING SIZE WT. PER FT. GRADE X-56 L-80 L-80 L-80 13Cr80 20" 13-3/8" 9-5/8" 169# 68# 47# 26# 12.6# 7" 4-1/2" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) Perfs TVD Gun size 13186' - 13210' 10996' - 11018' 2" 13210' - 13300' 11018'-11101' 2" 13300' - 13320' 11101' - 11120' 2" SPF 12 12 12 27. Date First Production 06/ 30/ 2002 Date of Test 8/3/2002 Hours Tested 4 hrs Test Period -> Calculated Flow Tubing 816 psi 28. Casing Pressure 24-Hour Rate> Brief description of lithology. porosity, fractures, apparent dips and presence of oil. gas or water. Submit core chips. SERVICE 0 HOLE SIZE 20" 16" 12-1/4" 8-1/2" 6-1/8" Classification of Service Well 7. Permit Number 202-077 / 302-239 8. API Number ~OP"""""'JW"""''''' 50-029-23081-00 :, tOCA) ~~'\'~1,' 9. Unit or Lease Name ~ ~~~~) ~ Northstar Unit '~,¡.'~..'..', ,~l'J~:, ,.,"'''' ,'".IóIJ".i, 10. Well Number i¡" ~¡¡;¡'r'. ,~ ., NS07 """'~""~"~''!I'''.'':<:':''':;~''%)' 11. Field and Pool Northstar Unit 15. Water Depth, if offshore 16. No. of Completions N/ A feet MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2032' MD 1545' (Approx.) CEMENTING RECORD Driven 654 sx PF 'L', 469 sx Class 'G' 737 sx Econolite, 806 sx Class 'G' 485 sx Class 'G' 112 sx Class 'G' AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 12805' 25. SIZE 4-1/2", 12.6#, 13Cr80 PACKER SET (MD) 12756' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED GAS-MCF 29.5 GAS-MCF CORE DATA RBDMS 8Ft PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) ESP Production for OIL-BBL 21024 OIL-BBL Form 10-407 Rev. 7-1-80 WATER-BBL 0 WATER-BBL CHOKE SIZE GAS-OIL RATIO 1.411 OIL GRAVITY - API (corr) RflHVEO OCT 0 4 2002 m\SS\Of\ A'as\œ. O\~& Gas Cons. Com N Anchorage nr:T ? I 2(i¡r¡? CONTINUED ON REVERSE SIDE Submit in duplicate Ii Ii \ t1 ~ ;\ ~ ¡~ : ¡ \\" ~; iJ ~ \,1 L~ 29. ) GEOLOGIC MARKERS NAME MEAS.DEPTH TRUE VERT. DEPTH Top of Schrader Bluff 72921 62931 Top of Kuparuk 10362' 8727' Kuparuk 'C' 10783' 9043' Top of Miluveach 113451 9471' Top of Kingak 119601 99501 Top of Sag River 12930' 10767' Top of Shublik 130481 1 08721 Top of Ivishak 13146' 1 0960' 31. LIST OF ATTACHMENTS 32. I hereby certify that the following is true and correct to the best of my knowledge. S;gned~~o~JL~ Title engmeer Technical Assistant INSTRUCTIONS 30. ) FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECEIVED OCT 0 4 2002 Alaska OI~& Gas Gems. eommtsslon J\nohorago Date 9/23/2002 Prepared by DeWayne R. Schnorr 564-5174. 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 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 . ". . Î'" ~ .~. 1 I 07/29/2002 07/30/2002 08/01/2002 08/02/2002 08/03/2002 08/04/2002 08/06/2002 08/10/2002 07/29/02 07/30/02 08/01/02 08/02/02 08/03/02 08/04/02 ') ') NS07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG; SSSV C/O OR STROKE PERFORATING: PERFORATING PERFORATING: PERFORATING PERFORATING: SSSV C/O OR STROKE PERFORATING: GEL TREATMENT; SSSV C/O OR STROKE PERFORATING: SSSV C/O OR STROKE PERFORATING: SSSV C/O OR STROKE PERFORATING: SSSV C/O OR STROKE EVENT SUMMARY PULL BBE SSSV. (SER# BB4-32) D/T W/ 111 2-1/8" DUMMY GUN TO 133791 SLM ADD PERF, 2" PJ 2006 HSD 6SPF GUNS, SHOOT INTERVAL (13300' TO 133201) TWICE FOR 12 SPF, WIRELlNE STUCK IN FLOWTUBES NEAR COMPLETION OF SECOND RUN. INJECT TANNER GAS INTO FLOW TUBES. CLOSE BOTTOM SET OF RAMS, BLEED PRESSURE FROM LUBRICATOR. RAMS HOLDING. EQUALIZE PRESSURE B/W LUB AND WELLBORE; WIRE FELL FREE. DROP 501 AND POOH. SUSPECT HYDRATES AROUND WIRELlNE. RD LUBRICATOR AND RETURN WELL TO PRODUCTION. ***JOB IN PROGRESS*** NOTIFY PAD OPERATOR AND PROD CONTROL THAT WELL NEEDS TO BE SHUT IN. RIH W/2" 6 SPF PJ/2 1/8" WEIGHT/ CCU HEAD AND PERF INTERVAL FROM 131861-13210. GOOD SHOT INDICATION AT SURFACE. RIH W/ SAME STRING AS ABOVE AND PERF THE SAME INTERVAL W/ THE SAME GUN CONFIGURATION. GOOD SHOT INDICATION AT SURFACE. NOTIFY PAD. OPERATOR OF SHUT IN STATUS. SET 4.5" BBE SSSV , (SER # NSB-13) @ 20011 SLM PERFORM CLOSURE TEST, 2700 PSI DOWN TO 2400 PSI, TEST GOOD. RETURN WELL OPERATOR OK TO PUT ON PRODUCTION. PULLED BBE SSSV SERIAL # NSB-13, VALVE FAILED DUE TO BALANCE & CONTROL LINE COMMUNICATION. RETURN WELL TO PRODUCTION TO BE POP OVERNIGHT TO WARM UP, WILL SET SSSV TOMORROW. SET 4.5" BBE SSSV @ 20011 SLM, SER# BB4-15, PERFORM CLOSURE TEST 2750 PSI DOWN TO 2450 PSI, ENDING PRESS 2450 PSI15 MIN. TEST GOOD NOTIFY OPERATOR OF WELL STATUS, RETURN TO PRODUCTION. 08/06/02 08/10102 BBLS 10 10 ) ) NS07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TROUBLE SHOOT SSSV, PULL SSSV SER # BB4-15 ( FUNCTION TEST GOOD AT SURFACE) , RETURNED WELL TO PRODUCTION. NOTIFY OPERATOR OF WELL STATUS. WILL RESET VALVE, AFTER HES, RESEARCHES PROBLEMS WITH VALVES NOT OPERATING PROPERLY AFTER BEING SET. SET 4.511 BBE SSSV (SER# BB432) @ 20021 , PERFORM CLOSURE TEST FROM 2750 DOWN TO 2450 PSI, GOOD CLOSURE TEST RID. NOTIFY DSO OF WELL STATUS. (HES REP TO MONITOR SSSV FOR REST OF THE DAY) Fluids Pumped PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 6 TESTS) TOTAL ADD PERFS 08/01/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 211 PJ, 6 SPF, RANDOM ORIENTATION. THESE INTERVALS WERE PERFORATED TWICE --- TOTAL SHOTS PER FT WAS 12 SPF. 131861 - 132101 133001 - 13320' :blP ') ') Datt,. Gv-21-2002 Transmittal #92565 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Bottom SW Name Date Contractor Log Run Top Depth Depth Log Type NS07 05-10-2002 SCH 1 13022 13424 REPEAT FORMATION TESTER; ¥Oa-Oïl NS12 08-04-2002 SCH 50 12586 GAMMA RAY; :C>d...JJO CASING COLLAR LOCATOR LOG; c~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petro technical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) Attn: Buford Bates (Murphy Exploration) ',"',.:-i f", ""'."'G"C\~ ~.."",' "., !1",'--" .'-,,*" f~ ~ '. ÌI.L ,!j \. , 1-.. ' '",~,..'~ i", ~ 'f ~ '-r-'; J\ ! ~ 2 /. :( ~,{:"'" ""\. --.J ,<. ' \I., " -';~','.' :.' ';'~~:' J~'"i:C' ....".:¡;~)Jt~I/"i~1"," '~nch~;:' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 blP ') ) Date: 08-12-2002 Transmittal Number:92561 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 Bottom SW Name Date Contractor Log Run Depth Depth Log Type Ja.-Oi1 NS-07 07 -29-2002 SCH 1 13186 13320 PERFORATION RECORD ""\t NS-07 08-01-2002 SCH 13186 13210 PERFORATION RECORD \Oó-IO I NS-06 08-03-2002 SCH 70 11470 GAMMA RAY/COLLAR LOCATOR LOG Od.- Jc.. I NS18 08-02-2002 SCH SURVEY REPORT - PAPER NS18 08-03-2002 SCH FINAL SURVEY - DISC ~-' ll~ \~~ and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Oklanà Murphy Exploration (Alaska), Inc. Attn: Buford Bates DNR - Division of Oil & Gas Attn: Tim Ryherd ~I' .' J '" .' '. !' .~.:.t ~'t~' ~'~~¡., ,.. t ~~ F f:'" , ,. ,~.. ".~\~~ 1110:' ~. ~~f '" .~ ,-. J I ' iG '1 L1. ;!í\ " ~I"'. J 'T r J. MMS Attn: Doug Choromanski '~ ~' I'¡ .. . ~ . .. . ..:' ': ": . . ~~.,;\ ,; ,.... . \~~':: ~nr~)t BP - SSD - Terrie Hubble Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at sur1ace Development _X Exploratory- Stratigraphic- Service- Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) KB 56.1 7. Unit or Property name feet 1. Operations per1ormed: Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: 1109'FSL,642'FEL,Sec.11,T13N,R13E,UM At top of productive interval 455' FNL, 1422' FEL, Sec. 15, T13N, R13E, UM At effective depth 418' FNL, 1535' FEL, Sec. 15, T13N, R13E, UM At total depth 418' FNL, 1551' FEL, Sec. 15, T13N, R13E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 659834, 6030881) NORTHSTAR UNIT 8. Well number NS07 9. Permit number / approval number ", 202-077 " '10. API number ~50-029-23081-00 11. Field / Pool (asp's 653808, 6029183) (asp's 653694, 6029218) (asp's 653681, 6029223) NORTHST AR POOL 13529 feet 11318 feet Plugs (measured) Production Liner measured 1 3484 feet Junk (measured) true vertical 11275 feet Length Size Cemented Measured Depth True Vertical Depth 654 sx PF 'L', 469 sx 201' 201' 201' 20" Class 'G' 3715' 13-3/8" 737 sx Econolite, 806 sx 3759' 3356' Class 'G' 11371' 9-5/8" 485 sx Class 'G' 11415' 9526' 1780' 7" 112 sx Class 'G' 12976' 10808' Effective depth: Casing Conductor Sur1ace Sidetrack Liner R E', ",'" r ! \ P 11~' .,. It r ~il Perforation depth: measured 13210' - 13320' It I V' 0 /" (jf'l{)2 ,r'\V.J 0 CUI true vertical 110181 - 11120' Tubing (size, grade, and measured depth) 4.5", 12.6# , 13CR80 Vam-Ace @ 13529' MD Alaska Oil & Gas Cons ,)':j,",,,. Anchoraoe Packers & SSSV (type & measured depth) 7" Packer, 13 Cr @ 12755' MD; 4.5" Liner Top Packer @ 12789' MD 4.5" BBE SSSV @ 2032' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 12057 26364 0 11828 26796 0 16. Status of well classification as: Prior to well operation Subsequent to operation (7/31/02) 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil_X Gas - Suspended- 17. I meby certify, tha\the ~r.~gOing is true and correct to the best of my knowledge. AlJ~ C~l.'~ Title: Production Technical Assistant Garry Catron' Casinq Pressure 0 0 Tubinq Pressure 764 847 Service - Date 3/ (p/oz- Form 10-404 Rev 06/15/88 . O~\G\NAL Prepared by Garry Catron 564-4657 SUBMIT IN OUPLlCATE ~ 7/29/02 7/30/02 8/2/02 8/3/02 8/4/02 BBLS ) ') 8-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY Pull SSSV and Conduct Static Bottom Hole Pressure Survey. Perforate interrval133001 - 133201 with 2" Schlumberger HSD guns at 12 SPF, 60 degree phasing and random orientation. Set 4.511 BBE SSSV at 2001' SLM. Pull SSSV due to balance and control line communication. Re-set 4.511 BBE SSSV at 20011 SLM. FLUIDS PUMPED None TOTAL Page 1 -) ) Date: 06-26-2002 Transmittal Number:92527 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 Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS07 04/18/2002 SCH 7 12878 13544 VISION DENSITY NEUTRON - TVD f' NS07 04/18/2002 SCH 7 12881 13543 VISION DENSITY r' NEUTRON - MD Q NS07 04/18/2002 SCH 1 - 7 303 13543 VISION RESISTNITY - MD , 3 NS07 04/18/2002 SCH 6 265 13544 VISION RESISTNITY - TVD ra NS07 04/18/2002 SCH 1-7 201.5 13544 LDWG FORMAT - DISC ~Re0rn 9:~e;¿ransnùttlli. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley BP - Ester Fueg "AOGCC Attn: "Howard()ld!an:(1)¡~11~¡ Murphy Exploration (Alaska), Inc. Attn: Buford Bates DNR - Division of Oil & Gas Attn: Tim Ryherd RECEIVED MMS Attn: Doug Choromanski JUL 26 2002 Alaska Qf¡ & Gas Cons. Cornmiuion And1cnge Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp July 25, 2002 ) ) ..\t .~~I. -......~~ ,.~...- ~4!.:- ~4!.:-- ..~ ~..... ."$~\" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: r, t:~ t:¡ ~;~ ~ \', !.f ~ [":~.,~ r;;." ~:~ ~~~;;:..,' ~'~"t. f~ "J ~\:':Î~~: ,::~t; JUL 252002 Alaska Qn.& Gas Gons. Commissjgn ." AnchQragQ Re: Sundry Notice for NS07 to Add Perfs (Ivishak) / SP Exploration Alaska, Inc. proposes to add perforations to increase production to Northstar to meet plant compacity. The expected net oil benefit is 4,000 SOPD. r lOR The procedure includes the following major steps: 4,000 Type Slickline Electric Line Slickline Last Test: Max. Deviation: Perfs: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: SHT & SHP: Work Desciption Pull SSSV, Drift/tag wI dummy gun Perforate 441 of Ivishak 13186 - 13210 and 13300 -13320 MD Run SSSV / July 22, 2002 - SOPD 12459, Gas 27128, FTP 765 psi. 42 deg @ 10,452' MD Max Dog Leg: 6.9 deg/100' @ 50' MD 13186' - 13210' and 13300' - 13320' MD 3.725" at XN nipple @ 12791', see schematic 13407' MD SLM. 06/15/02 Stroke SSSV 07/24/02 0 PPM, none expected. Schlumberger PEX-HRLA-DSI 05/10/02 2540 F & 5175 psi a @ 13379' MD Please call (Alex Yancey 564-5092, hm: 522-2539, cell: 301-3019) if there are any questions. Background Data: Well: NS-07 Tree: ABB-VGI13-5/8" x 4-1/2" 50 ksi Tubing: 4.5", 12.6 ppf, 13Cr-80, Vam Ace Tubing Tail: NA - monobore SSSV Nipple: HRQ SVLN @ 2032' MD, 4.562" ID (angle at SVLN = 30.84°) GLM: 4-1/2" x 1-1/2" GLM w/ sheared valve at 6,512' MDrkb. 2nd GLM at 5,189' MD Packer: Baker S-3 @ 11,755' MD, 3.875" ID Min ID: 4.5" XN Nipple @ 11,792' MD, 3.725" ID Surf Casing: 13-3/8" L-80 @ 3,759' MD (68#/ft.) Intermed. Csg: 9-5/8" L-80 @ 11,415' MD (47#/ft.) Drilling Liner 7" L-80 @ 11,196' - 12,796' MD (26#) Prod Liner: 4.5" 13-Cr-80 12,789-13,529' MD, liner top ZXP packer, Flex Lock liner hanger (12.31 #/ft) 13,440' MD 42 deg @ 10,452' MD Max Dog Leg: 6.9 deg/100' @ 50' MD Production Fluids Diesel to :1: 3,887' MD, Seawater below Diesel to :1:1900 ft MD, mud below 13,186' - 13,210' MDrkb and 13,300' - 13,320' MDrkb, PEX-HRLA-DSI logged 05-10-2002; Perf/Jewerly Log 06-26-2002 Est. 5185 psi @ 11,100' TVD SS. EMW = 9.0 ppg PBTD: Max Deviation: Tubing Fluid: IA Fluid: OA Fluid: Proposed Perforations: Reservoir Pressure: WH Pressure: H2S ppm: Current Status: ) ) API: 50-029-23081-00 'I'" Max if all NS Formation gas - 4000 psi none expected I Producing. Sincerely, ~ff~~ Alex Yancey Alaska Consolidated Team Petroleum Engineer ) ) iNGÆ- $' D~ 7/ZIP!OL- '7{U /01/ 7)Z¿; /°2- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Alter casing - Repair well - Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1109' FSL, 642' FEL, Sec. 11, T13N, R13E, UM At top of productive interval 455' FNL, 1422' FEL, Sec. 15, T13N, R13E, UM At effective depth 418' FNL, 1535' FEL, Sec. 15, T13N, R13E, UM At total depth 419' FNL, 1551' FEL, Sec. 15, T13N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 201' Surface 3715' Intermediate 11371' Liner 1780' Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service- (asp's 659835, 6030881) (asp's 653808, 6029183) (asp's 653694, 6029218) (asp's 653681,6029224) 13529 feet 11 31 8 feet 13484 feet 11275 feet Plugs (measured) Junk (measured) Re-enter suspended well - Time extension - Stimulate - Variance - Perforate _X 6. Datum elevation (OF or KB feet) RES 56.1 feet 7. Unit or Property name Other - NORTHSTAR UNIT 8. Well number NS07 9. Permit number I approval number 202-077 ./ 10. API number 50-029-23081-00 11. Field I Pool NORTHST AR POOL Size Cemented Measured Depth True vertical Depth 654 sx PF 'L', 469 sx 201' 201' 20" Class 'G' 13-3/8" 737 sx Econolite, 806 sx 3759' 3356' Class 'G' 9-5/8" 485 sx Class 'G' 11415' 9526' 7" 112 sx Class 'G' 12976' 10808' Perforation depth: measured 13210' - 13300' true vertical 11018' - 11101' Q~L~:{~~~ n \. " ~,... iL. !I r..,',. ~'.".''iI. r:: H~..¡ ,JUL 252002 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth 4.5", 12.6# , 13CR80 Vam-Ace @ 13529' MD Packers & SSSV (type & measured depth) 7" Packer, 13 Cr @ 12755' MD; 4.5" Liner Top Packer @ 12789' MD 4.5" BBE SSSV @ 2032' MD 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: August 1, 2002 16. If proposal was verbally approved Oil_X Name of approver Date approved Service 17. I hereby certify t t the foregoing is true and correct to the best of my knowledge. Signed %/ ¿~ Alex Yancey 64-5092 /~a--~ Title: NorthStar Petroleum Engineer BOP sketch - Gas- Suspended - Date ~~ Prepared by Garry Catron 564-4657 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- Approved by order of the Commission OnglOal Signed By Cammy Qechsli Taytor Form 10-403 Rev 06/15/88 . I Approval nO~{~.1 ~g '-/07 Commissioner Date /ßv/ó:;L ORiGINAL SUBMIT IN TRIPLICATE bp ') ') aO~-017 Date: 07-22-2002 Transmittal Number:92547 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 Log Run Depth Bottom Depth Log Type NS07 07-22-2002 SCH 1 12650 13395 PERFORATION RECORD & JEWELRY LOG; &-~~ 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 . (~ or-' ,1,. ~ r- ¡~""I ~t~?: f~ ~\,.'r'. ; ll1-:~I,.), JUL :_~ 'I ',' ..' ~ '-:'. :,mm~r \ ,", ':,~' .h,I~'~~\.""'~ Petrotechnica1 Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ') ) Date: 06-21-2002 Transmittal Number:92524 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 Bottom t' SW Name Date Contractor Log Run Depth Depth Log Type \' NS07 05-06-2002 SCH 1 11424 12954 STRUCTURAL DIP 1 :240 Ç) , NS07 05-06-2002 SCH 1 11424 12954 STRATIGRAPHIC DIP 1:24 tõ <] NS07 05-06-2002 SCH 1 11424 12954 DISC - *FMI IMAGES * é{) / \.K_~ ~ ~~ Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates RECEIVED DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski ~J1..)¡\j 2 1 2002 Alaska Oii & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date: 07-10-2002 Transmittal Number:92539 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' t' 9 sw Name ~ NS 07 ið \IS 07 Date 05/18/2002 05/18/2002 Media PAPER DISC Title END OF WELL FORMATION EVAL. DATA -# / ~, >~82 ~et~:o~nùtt~. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates MMS Attn: Doug Choromanski RECE\VED JUL 11 2002. A1Ø80\1 & Gas Cons. Com_ion Anct\Q(8Q& DNR - Division of Oil & Gas Attn: Tim Ryherd Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) "\ Date: 06-13-2002 Transmittal Number:92517 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 Bottom SW Name Date Contractor Log Run Depth Depth Log Type ~ Ci).-o71 NS07 05-1 0-2002 SCH 2 8432 12982 GEOFRAME PROCESSED INTERPRET A TION C¡ÞJ57 B 1-01 04-05-2001 SCH 1 7850 8383 TEMP SURVEY GAMMA RAY CCL ~ 60o°-r-!. Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates DNR - Division of Oil & Gas Attn: Tim Ryherd RECE\VED JUN 1 3 2002 MMS Attn: Doug Choromanski Alaska Œ1 & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) PERFORATING PROCEDURE CC or AFC: NSWWEL107 Detail Code: Description: :þ.:~)($.$.:$.y.ï.ç,9.:~:~!:~§ï.:Aþþ'g~Ef.B~D...?§.?Y..::::::::::::::::::::::::::............................................................................................, WBL Entries Work Desciption Pull SSSV, Drift/tag wi dummy gun Log GR/CCUUSIT/CBL, Perforate 44' (Bottom shot @ 13320'MD) Run SSSV / Well: NS07 ................................................................, Date: 07/23/02 API #: 50-029-23081-00 ..................,.,.,.......,.......,...,.,.. Prod Engr .~~~~.Y~~.~.~.Y................. .............................................,.................." lOR Type S E S 4,000 ') Ver 4.0 06/04/01 Office Ph: 564-5092 ................,.....,.....................,.,....,...... Home Ph: 522-2539 .......................................................... Pager: ..................~.~.~.~.~g.~..~.................. H2S Level: Oppm Well Objectives and Loaaina Notes: Run GR/CCL, PBTD thru Jewelry for Tie In log. Correlate with Schlumberger PEX-HRLA-DSllogged 05-10-2002. Perforate well. Run SSSV. SSSV Nipple @ 2032',4.562" ID (HOLE ANGLE AT SVLN IS 31 DEGREES), Baker S-3 Packer @ 12,755' MD, 3.875" ID Attachment: Well bore Schematic, directional data. Reference Log I Tie in Log Log: p.~.?5~t!B~~.:.Q.S .p.~.~!.~.~~.~.I.!Y.. Log Date: 5/10/2002 6/26/2002 Company: :$.~b!:~ri):þ'~~;:: :$~6!~ri):þ.~:~~i~r Depths (from-to) Depths (from-to) Feet ........t~..J.§§.:......' - ......1..~J.gJ.Q.~.... ............................... - ""."""".""''''..'''''''' .....?4~. ......J.~...~.Qq.'....... - ....J..9....~.?9..:.... ............................... - ................................ .....?9..:.... SPF 6 6 ,................................. "'0""""""""""""" .............................., ........,.........,............ .,.......,...,.,.,.....,-."..... .......,.......,.,.......,.,.. ...,...,.,.,...........,....... ,...,...,.,.,.....,...,.,.,..." ,.............,.....,...,.,....... .........................,.... ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ......,.....,................." Gas Jetting Expected? No At what Depth? ,......................,........ Requested Gun Size: .......?.':..!::I.§q....... Charge: ....?9.9.~..p'~.!..!j.~X... Desired Penetration: ..................?.?..'.'................. Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wi Pad Operator to see if necessary piping Is installed) (e.g. N2 Lift, Hard/ine Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hard/ine) Tie in to Jewelry @ Minimum ID: Tail Depth: MD """"":3':725'''''''' in :::::::I?;:~:9.~:::::::: ft M D Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ Last Tag: 13407' SLM ft MD on .........,..................... ....~f.~.?!.?9.9.?.. Well: Date: NS07 Perforation Summary API #: 50-029-23081-00 ~,~.. ---.. _n -~ -.' -"" .......................................................... General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Feet SPF Orient. Add/Subtract ........Q......... to the tie-in log to be on depth with the reference log. feet Orient. Random ..........,.,.............. Random ,...............,.,.,....., Phasing ...ß.9.~...... 60° Zone AdlRellperf ..,.IY.i.~.~.~.~..........................A.qP..~.Œ...,.................... ....Iy'i.~.~~.~............,.............A.qp..~.Œ...............,........ 0 0 0 0 0 ..........,................ ............................................................,...............,..........' ","""""'''''''''''''''''''''''''''''''''''''''''''''''''''',...,.......,...,...,." .,.,...........,...,....... "',,,,,,,,,,,,,,,,,,,,,,,, ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,'.',,,,,,,,,,,,,,,,,,,,,,,,,,........................ N/A '...................... Entry Hole Diam: ..........9.:~~::.......... ..~.<?:.............................................................................................,........................................,............................, ............................................................................,",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.',,,,,,,,,,...................,............,......., :::::::::::::::1;$.::::8N.::NIp.p.:(~::::::::::::::"'."'"".@""::jg:;7.~t::";MD"."""".'"""""""""""""""""........ 4.5 in 12.6# 13-CR Liner ::::J~;~!.$.::::: MD is .................?1.t~.9..psi On-Site Prod Engr:. PBTD Phasing Zone Aperf/Reperf 00 00 0 ~ - 7" PACKER, 13 Cr @ 12755' MD, .- 10615' TVD . !~ TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi ') NS07 13 3/8" DV Tool at 1606'MD ..... 13 3/8", 68#/ft, L-80, BTC @ 3759' MD ..4 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT ~ 9-5/8" 47# L-80 BTM-C @ 11415' MD M .,4- 4.5" X NIPPLE, @ 12734' MD 3.813" ID 4.5" X NIPPLE, @ 12779' MD 3.813" ID 4.5" XN NIPPLE, @ 12791' MD 3.725" ID - 4.5" WLEG, @ 12803' MD 3.958" ID - B- , E 7", 26#/ft L-80, Hydril 521 @ 12976' MD J. ÆRFORA TION SUfIIMA RY REF LOG: PEX.HRLA-DSI (5/10/2002) ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2006 PowerJet. HMX; Penetration: 18.6'; Hole: .2"; A1ase: 60 deg 6 spf x2 runs SIZE SPF INTERVAL M) INTERV AL lVD Opn/Sqz DA TE 2 12 13210'.13300' 11018'.11045' Opn 6/27/2002 PBTD @ 13440' TD @ 13529' J DATE 3/19/02 5/3/02 7/3/02 COMMENTS "'NSO/ tJroposed Update Depth Values, Perfs Add Perfs REV. BY BMH EMF EMF ~ I ~ .. "fIGINAL KB. ELEV = 55.77' rŒ-BF. ELEV = 40.07' CB. ELEV = 15.7' 4 1/2" SSSV @ 2032' MD, 1971' TVD wi HXO SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 5000' TVD (5750'MD) .. 41/2" GLM @ 5189' MD, 4528' TVD wi 4.62" ID 4 1/2" GLM @ 6512' MD, 5634' TVD wi 4.62" ID T\. - 7" LINER TOP @ 11196' MD 4.5" Fiber Optic Transducer 12715' MD, 10578' TVD 3.958" ID (10582' TVDelm) MIN ID 2.4" @12774' offset WLEG 4.5" LINER TOP @ 12789' MD 4.5", 12.6#, 13Cr Vam Ace Northstar WELL: NS07 API NO: 500282308100 BP Exploration (Alaska) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-077 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 î---~~ 50-029-23081-00 4. . j XMN.Er~;J>" . L~~g~~~~~,~~~?~~~~~~c. ii, T13N, R13E, UM ,I,f ~.'",~" ¿~,<:'.'),' ,2.,.,', ','.,;,!,"\.::,J'éÃ~ã~'~, :',' '.', , 9. ~n~~~~~a~~i~ame At to,P of produc~ive interval i ~ VEJj.If' --, ~ Y~":i. 4818 NSL, 1425 WEL, SEC. 15, T13N, R13E, UM ~ ~IæJ' tSu~, ' ..".'" '~' 10. Well Number At total depth 1-' ',.. ,..I! " ; , ,.,,:g. NS07 4861' NSL, 1551' WEL, SEC. 15, T13N, R13E, UM -..,,,,,,,,-,,,,,,,~. ,( i1tt_,~',.,,:'#: '\ \, ,/)\: . _/~ ,_f.,- 11 Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. . Northstar Unit RKB = 56.1' ADL 312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/18/2002 5/9/2002 6/26/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13529 11318 FT 13484 11275 FT 1m Yes 0 No 22. Type Electric or Other Logs Run GYRO, MWD, LWD , DIPOLE SONIC, FMI, DEN, RFT , GR , DIR , RES, PWD , NEU 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 169# X-56 Surface 201' 2011 Driven 13-3/811 68# L-80 44' 3759' 1611 654 sx PF 'L', 469 sx Class 'G' 9-5/8" 47# L-80 44' 11415' 12-1/4" 737 sx Econolite, 806 sx Class 'G' 7" 26# L-80 11196' 12976' 8-1/2" 485 sx Class 'G' 4-1/2" 12.6# 13Cr80 12789' 13529' 6-1/8" 112 sx Class 'G' Classification of Service Well 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2032' MD 1545' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 6 SPF MD TVD SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 12805' PACKER SET (MD) 12756' 25. MD TVD 13210' - 13300' 11018' - 11101' r' t'" r I \ ¡ c r1, t t\,,,.. C, ~ 'i)' t L} 26. ACID, FRACTURE, CEMENT SQUEezE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 295 Bbls of Diesel. q'i "1 { no:o? !: I. ! n L ,,,-,. <3_.1 -- -- ...... 27. Date First Production June 30, 2002 Date of Test Hours Tested 7/2/2002 4 Flow Tubing Casing Pressure Press. A ,a$ka OB & Ga~; Gens. Gmmmss\On Ancnorayla. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 14324 OIL-BBL GAs-McF 17.32 GAs-McF WATER-BBL 3.56 WATER-BBL CHOKE SIZE GAS-OIL RATIO 1.245 CALCULATED 24-HoUR RATE OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. Form 10-407 Rev. 07-01-80 0 {~ i G ! r\J I~ L R 8 OMS SF l Jll '8 2æf>mit In DUPlica~e ç (;P ') 29. Geologic Markers Marker Name Measured Depth Top of Schrader Bluff 7292' Top of Kuparuk 10362' Kuparuk C 107831 Top of Miluveach 11345' Top Kingak 11960' Top of Sag River 12930' Top of Shublik 13048' Top of Ivishak 13146' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 6293' RFT was ran, log will be supplied with details. 8727' 9043' 9471' 9950' 10767' 10872' 10960' If" .f'."".. r".,...." ~ I¡""'~ r" l.\....... \:., :~.. ~ ~ J \ I' " I E[) Ii IJ 'J (:: ~;¡nn? '(... ....,... --- 'I",) 'I.~... ,U l.: ,'..." :Alaska oa ~~. Guns. Commission A!lchoraqø Summary of Daily Drilling Reports, Surveys, Post Rig Summary and Leak-Off Integrity Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~AAÌ.Jl.. .J ~ Title Technical Assistant NS07 202-077 Well Number Permit No. / Approval No. Date 67. {a..o?-.. Prepared By Name/Number: Sandra 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Legal Name: NS07 Common Name: NS07 Test Date 4/21/2002 5/2/2002 5/8/2002 LOT LOT FIT Test Type Test Depth (TMD) 3,794.0 (ft) 11,460.0 (ft) 12,976.0 (ft) BP EXPL.ORATION Leak-Off Test Summary Test Depth (TVD) 3,687.0 (ft) 9,562.6 (ft) 10,808.0 (ft) AMW 8.60 (ppg) 10.40 (ppg) 9.25 (ppg) Suñace Pressure 850 (psi) 2,520 (psi) 1,920 (psi) Leak Off Pressure (BHP) 2,497 (psi) 7,686 (psi) 7,113 (psi) EMW 13.04 (ppg) 15.47 (ppg) 12.67 (ppg) .~ .~ Printed: 5/20/2002 3:16:37 PM ) ') BP EXPLORATION Operations Summary Report Page 1 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 4/16/2002 Spud Date: 4/16/2002 End: 4/16/2002 00:00 - 08:00 8.00 MOB P PRE Move Rig to accept rig. Accepted at 0800 hrs on 4/16/02 08:00 - 00:00 16.00 MOB N WAIT PRE Prepare rig for move to NS-7 -- waiting for power from Hiline to perform NS10 kill. 1) C/O single gate to hydril, and reorient spacer spool to allow BOP scaffolding to clear the wellhouses. 2) Lay herculite & rig mats. 3) Turn tubing spool on stack. 4) Clean rig. 5) Weld hinges in cellar. 6) Moved rig 25' to south. 7) Put herculite over the top of NS8 & 9 wellhouses. 8) Clean well house in cellar. 9) Empty & clean L pit to install 12" equalizers. 1 0) Blow down & tear down lines from piperack. 11) Building berms 4/17/2002 00:00 - 06:30 6.50 MOB N WAIT PRE Continue preparing rig for move. G & I completed killing NS-10 w/11.2 ppg mud. 06:30 - 11 :00 4.50 MOB N WAIT PRE Blow down lines from piperack to rig. Disconnect lines. 11 :00 - 16:00 5.00 MOB N WAIT PRE PJSM - Move rig & level w/ shims. Note: Necessary to manuever around NS10 wellhouse which is 12.5' above pad level but shimmed to provide clearance betweeen wellhouse and tree. 16:00 - 20:00 4.00 MOB P PRE Connect service lines to piperack. PJSM - Hook up new injection line & weld brackets on side of rig. 20:00 - 22:00 2.00 MOB P PRE N/U riser. 22:00 - 00:00 2.00 MOB P PRE Clean up around NS-15 & P/U HWDP & stand back. 4/18/2002 00:00 - 01 :30 1.50 MOB P PRE P/U & stand back HWDP. 01 :30 - 03:30 2.00 DRILL P SURF M/U BHA # 1 to clean out conductor. 03:30 - 04:30 1.00 DRILL P SURF Pre-spud meeting, review 0-7 drill. Fill conductor w/ mud. Leak detected on riser clamp / o-ring. Calibrate rig gas monitoring system. 04:30 - 06:45 2.25 DRILL N RREP SURF Tighten clamp on riser to try & repair leak to no avail. Slide rig floor 6" towards piperack to get riser into vertical position which alleviated problem. 06:45 - 07:30 0.75 DRILL P SURF Clean out conductor & drill to 241'. Note: Spud well @ 0700 hours on 4/18. (See Rig Move in Remarks Section) 07:30 - 11 :15 3.75 DRILL N WAIT SURF Circulate & RIU Schlumberger for gyro. Difficulties getting power to Schlumberger. 480V drops on piperack not functional due to a bad breaker. Parts on order. Wired Schlumberger directly into 1600 amp breaker available by Halliburton transformer. (near miss - see remarks) 11:15-12:00 0.75 DRILL P SURF RIU sheave in derrick & run gyro. 12:00 - 15:00 3.00 DRILL P SURF Drill to 330' & run gyro. 15:00 - 18:00 3.00 DRILL P SURF POH & P/U BHA # 2. 18:00 - 00:00 6.00 DRILL P SURF Drill & slide from 330' to 780'. Run gyros. 4/19/2002 00:00 - 02:00 2.00 DRILL P SURF Drill & slide from 780' to 1100'. Pump sweep. 02:00 - 02:45 0.75 DRILL P SURF Run gyro. Gyro & MWD data correlating per JORPS criteria. Printed: 5120/2002 3:16:44 PM '') ) BP EXPLORATION Operations Summary Report Page 2 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 4/16/2002 Spud Date: 4/16/2002 End: Date From - To Hours Task Code NPT Phase Descri ption of Operations 4/19/2002 02:45- 03:15 0.50 DRILL P SURF LID sheave & E-line out of derrick. R/D Schlumberger. 03:15 - 12:00 8.75 DRILL P SURF Drill & slide from 1100' to 1750'. Pump sweep. 12:00 - 00:00 12.00 DRILL P SURF Drill & slide from 1750' to 3008'. Pump sweep. 4/20/2002 00:00 - 08:45 8.75 DRILL P SURF Drilling f/ 3008' -- 3774' md (TD of 16" surface hole). Note: TD picked by Sperry Sun and confirmed with Anchorage Geologist. 08:45 - 11 :00 2.25 DRILL P SURF Pump sweep and circ and cond mud in preparation to run casing. Note: Rotate and reciprocate pipe during conditioning. 11 :00 - 11 :30 0.50 DRILL P SURF Monitor Well, Pump Dry Job, Blow down Top Drive, standpipe and bleeder. 11 :30 - 13:30 2.00 DRILL P SURF POOH with drill pipe to 1006' md. Note: Wiped stands 4 and 21 based on drilling these intervals -- hole in good shape. 13:30 - 14:00 0.50 DRILL P SURF POOH with HWDP to 216' md -- inside 20" conductor. Note: Wiper trip not necessary based on hole condition -- decision to LD BHA and run casing. 14:00 - 16:30 2.50 DRILL P SURF Lay Down BHA #2 Note: Top stab had some clay and next stab had less -- about average for a surface hole bha. 16:30 - 17:30 1.00 DRILL P SURF Service Top Drive Note: Clean Rig Floor of BHA components and drilling mud. 17:30 - 19:00 1.50 DRILL P SURF PJSM -- RU Frank's Tool and Casing Tools. 19:00 - 00:00 5.00 DRILL P SURF PJSM -- RIH with 13-3/8" 68# L80 Btrc Surface Casing (60 of 92 total joints in the hole). 4/21/2002 00:00 - 02:45 2.75 CASE P SURF Run remaining 13 3/8" casing & land w/ mandrell hangar. (Jts. 61 - 92) Note: Casing S/O wts. 80K to 1 OOK on jts. 64,65 & 66. 2,563' to 2,685' Casing S/O wts. 95K to 125K on jts. 74 - 78.2,972' to 3,177'. Jt. 90 stacked up & would not go down. P/U & run back down only to lose 5'. Retried P/U & run back down & lost additional 5'. Was finally able to work down without pumping. Last 3 joints stacked up, but not as bad as joint 90. 02:45 - 03:30 03:30 - 06:30 0.75 CASE P 3.00 CASE P SURF SURF UD Frank's fill up tool & M/U HOWCO cement head & x-over. Circulate & condition mud in preparation for cement job. PJSM for cement job during circulation. 06:30 - 09:30 3.00 CEMT P SURF Note: No significant cuttings at shakers throuhout circulation. Pump 5 bbls. of water & test lines to 3,000 psi. Pump 484 bbls. of 10.7 lead cement & 97 bbls. of 15.8 tail cement. Displace cement w/ 25 bbls. of clean up water & 525 bbls. of 9.0 ppg mud. 09:30 - 10:45 1.25 CEMT P SURF Printed: 5/20/2002 3:16:44 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E HÖurs Task Code NPT Phase 4/21/2002 09:30 - 10:45 1.25 CEMT P SURF 10:45 - 13:30 2.75 CEMT P SURF 13:30 - 15:30 2.00 CEMT P SURF 15:30 - 16:30 1.00 WHSUR P SURF 16:30 - 17:00 0.50 BOPSUR P SURF 17:00 - 20:00 3.00 BOPSURP SURF 20:00 - 22:30 2.50 BOPSURP SURF 22:30 - 23:00 0.50 BOPSUR P SURF 23:00 - 00:00 1.00 DRILL P SURF 4/22/2002 00:00 - 04:45 4.75 CASE P SURF 04:45 - 05: 15 0.50 CASE P SURF 05: 15 - 09:30 4.25 CASE P SURF 09:30 - 12:00 2.50 CASE P SURF 12:00 - 12:30 0.50 CASE P SURF 12:30 - 13:30 1.00 CASE P SURF 13:30 - 15:00 1.50 CASE P SURF 15:00 - 16:30 1.50 DRILL P INT1 16:30 - 17:00 0.50 DRILL P INT1 17:00 - 17:30 0.50 DRILL P INT1 17:30 - 18:00 0.50 DRILL N DFAL INT1 18:00 - 19:30 1.50 DRILL N DFAL INT1 19:30 - 20:00 0.50 EVAL N DFAL INT1 20:00 - 21 :30 1.50 DRILL N DFAL INT1 21 :30 - 22:30 1.00 DRILL N DFAL INT1 22:30 - 23:30 1.00 DRILL N DFAL INT1 23:30 - 00:00 0.50 DRILL N DFAL INT1 4/23/2002 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 03:00 1.00 DRILL P INT1 03:00 - 00:00 21.00 DRILL P INT1 Start: Rig Release: Rig Number: 33E Spud Date: 4/16/2002 End: 4/16/2002 Note: Bumped plug @ 95% pump efficiency. UD cement head & blow down lines. Drain stack, remove casing elevators, UD landing jt, change out bails & install 5" elevators. Clear & clean rig floor. Nipple down surface riser. N/U tubing spool & test to 1,200 psi & hold for 10 min. PJSM on setting BOP's on tubing spool. N/U BOP. Install turn buckles, kill & choke lines. Install Koomey lines, both sections of riser, & mousehole. Function test BOP's. PJSM - Install bushings & floor track. PJSM - C/O MWD pressure sensor on top of stand pipe. Completed cleaning all pits. P/U test jt, floor valves, & test BOP's. Test to 250 low/4500 high & hold for 5 mins. Pull test plug, set bowl protector, & blow down mud lines. PJSM - P/U bias tool & test. OK. P/U remaining BHA & shallow test MWD. OK. RIH - tag cement @ 3,665' & clean out to 3,675'. Tag up on cement plugs @ 3,675'. Finish drilling to float collar @ 3675.5'. Test casing to 3,600 psi w/9.0 ppg mud & hold for 30 minutes. OK. Note: Discuss well control w/ rig crews & review 01, 02, & 05 drills. Drill out shoe track from 3675.5' to 3758'. drill rat hole from 3758' to 3774'. Drill 20' of new hole to 3794' Condition mud & circulate. Change over to new mud. 8.6 ppg. Conduct LOT to 13.0 ppg EMW. Condition mud & circulate. Pump dry job. Monitor well & blow down top drive & kill line. POH to HWDP - monitor well. Shallow test MWD - blow down lines. Handle BHA # 3 & UD MWD. Handle BHA # 4 & M/U MWD & shallow test. OK. Continue M/U BHA # 4. RIH wi DP. PJSM - Cut & slip drilling line. Service top drive & drawworks. RIH Drill per directional plan with Rotary Steerable from 3794' to 6609'. Notes: 1. Pumping hi-vis sweeps every 400' md (or as needed). 2. Spent 1 hr. and 40 minutes un balling bit -- bit balled up while drilling bottom 40' of SV3 (clay) from 4443' -4483' md (3914' - 3945' tvd). Pumped 25 bbl15 ppb walnut sweep, then 25 bbl 50/50 mud water with 15 ppb walnut and 1 ppb SAPP, then break connection and add vis cup SAPP with no apparent results. Adjusted drlg parameters from 80-180 rpm and WOB from 0-25K (Hycalog cautioned against stacking too much weight) and shut off pumps and rocked bit on bottom -- again with no apparent results. Checked mudlog comparison with Printed: 5/20/2002 3:16:44 PM ) BP EXPLORATION Operations Summary Report Legal Well Name: NS07 Common Well Name: NS07 Spud Date: 4/16/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Description of 4/23/2002 03:00 - 00:00 21.00 DRILL P INT1 NS14 lithology and noted SV2 sand within 15 '. Increased WOB to 20K and drilled ahead at -15 fph -- hit SV2 sand and bit unballed. Drilled ahead while adding fresh Condet, Clayseal and BDF263 to combat bit balling. Conclusion: treat for clays and clean up in sands -- in this depositional environment with the repeating sand, siltstone, clay sections, the bit should not stayed balled long provided we are careful to not stack too much weight and bake the ball on the bit. 3. Well is tracking NS14 lithology very close. 4/24/2002 00:00 - 18:00 18.00 DRILL P INT1 Directionally Drill 12.1/4" Hole with rotary steerable from 6,609 ft to 8,221 ft> ( 7,883 MD , 6790 ft TVD for Colville). No Drag, No Losses. Wiper trip point decided on TVD depth/ lithology. Pumping sweeps every 400 ft, ECD steady @ 9.8 ppg. Just wiping bottom 30 ft of each stand. P-rates higher than breakeven threshold for roundtripping for new bit according to offset data on last 500 ft drilled. Decreased RPM to 130 from 160 due to surface harmonics shaking Top Drive components- downhole shocks minimal. 18:00 - 19:00 1.00 DRILL P INT1 Sweep hole clean while RPM @ 150 and working pipe. X 150% bottoms up. 19:00 - 19:30 0.50 DRILL P INT1 Take survey. Flowcheck. Pump dry job. 19:30 - 23:30 4.00 DRILL P INT1 Make wiper trip back to 13.3/8" Shoe. Hole OK Back to 6,324 ft. Pulling tight back to 6,038'. Pump out of hole to 5,350 ft @ 300 GPM/ 600 psi, 10-25 klbs overpull. Unable to dry pull. 23:30 - 00:00 0.50 DRILL P INT1 High LEL alarm triggered in cellar area combined with observations of fluid release ( see remarks). Well Shut in and rig evacuated. Northstar ERT mobilised with SCBA and declared rig clear @ 0040 hrs. Courtesy call made to AOGCC @ 0100 hrs to inform the of ram closure and false alarm- rechecked sensor- OK. 4/25/2002 00:00 - 00:30 0.50 DRILL P INT1 Rig Declared Clear @ 0040 hours and stand. Work Pipe and circulate well- OK. Bit @ 5,350 ft. 00:30 - 05:00 4.50 DRILL P INT1 Continue with wiper trip back to 13.3/8" shoe @ 3,758'. Unable to dry pull Assembly. Pump out @ 300 GPM/ 600psi with 10-25 klbs overpull and occaisonal packing off if assembly pulled too fast. 05:00 - 06:30 1.50 DRILL P INT1 Circulate hole clean at 13.3/8" shoe while working pipe. Pump X 2.5 bottoms up. until shakers cleaned up. 06:30 - 10:00 3.50 DRILL P INT1 Inspect Top Drive and derrick for any loose objects after the harmonics issue. Align rig. 10:00 - 13:00 3.00 DRILL P INT1 RIH- Hole good until 6,143 ft.Ream wash from 6,143' to 6,225 ft ( Bottom Ugnu) and 6,500 to 6,650 ft. Continue to RIH- Hole good. 13:00 - 13:30 0.50 DRILL P INT1 Break circulation & set rotary steerable. 13:30 - 00:00 10.50 DRILL P INT1 Drill from 8224' to 9150' pumping hi vis weighted sweeps every 400'. 4/26/2002 00:00 - 05:00 5.00 DRILL P INT1 Drill 12.1/4" Hole from 9150' to 9560'. No Drag, No Losses. ECD steady. 05:00 - 05:30 0.50 DRILL P INT1 Down link rotary steerable. 05:30 - 06:30 1.00 DRILL N RREP INT1 Locking Nut from a solenoid valve fell from Top Drive. Inspect Printed: 5/20/2002 3:16:44 PM ) Legal Well Name: NS07 Common Well Name: NS07 Spud Date: 4/16/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Houts Task Code 4/26/2002 05:30 - 06:30 1.00 DRILL N RREP INT1 Top drive and replace solenoid valve. Continue to visually inspect Top DRive ach stand down and continue to make the rigfloor a no go zone while the surface harmonics is a conscern. 06:30 - 12:00 5.50 DRILL P INT1 Drill from 9560' to 10035'. Raising Mud weight to 10.2 ppg and prepaing properties for HRZ and Kuparuk. HRZ @ 9,897 ft MD, ,8373 'TVD Top Kuparuk 10,395 8754' 12:00 - 12:30 0.50 DRILL P INT1 Lubricate rig & service top drive. 12:30 - 00:00 11.50 DRILL P INT1 Drill 12.1/4" Rotary 8teerable from 10035' to 10620'. No Drag, No losses. Placed Non Rotating sleeve in at 10,135'. Helped Harmonics considerably for another 300-400 ft. ( Indicates "node" may be at a depth of 300-500 ft mD. Top of Kuparuk "c" @ 10,787' MD, 9047' TVD 4/27/2002 00:00 - 13:30 13.50 DRILL P INT1 Drill 12.1/4" Hole with Rotary Steerable system from 10,620 ft to 11,048'. No Drag, No Losses. P-rate average declining in Lower Kuparuk. 5-30 ftIhr average ( 50-70% lower than offsets for comparable lithology). Vary parameters with no improvement. Last two stands averging 20 ftIhr . Make decision to make bit trip based on economics of a wiper trip to the shoe for casing and on the remaining footage required versus the projected improvement of P-rate for new bit. Maximum gas 1287 units @ 10,763' MD 13:30 - 15:30 2.00 DRILL P INT1 Circulate 130% bottoms up until shakers clean- no gas. 15:30 - 16:00 0.50 DRILL P INT1 Flowcheck well and Pump Dry job. 16:00 - 21 :00 5.00 DRILL P INT1 POH to shoe. Hole is slick with no tight spots. Monitor well @ shoe for 10 minutes. Okay 21 :00 - 22:00 1.00 DRILL P INT1 Continue POH to HWDP. 22:00 - 22:30 0.50 DRILL P INT1 Monitor well. Losses @ 6 - 10 bbls. per hour. 22:30 - 23:00 0.50 DRILL P INT1 Continue POH to BHA. 23:00 - 00:00 1.00 DRILL P INT1 Handle BHA # 4. Bit Hammered. In gage but no cutting structure. 4/28/2002 00:00 - 02:00 2.00 DRILL P INT1 Continue to lay down BHA # 4- Rotary 12.1/4" Assembly. Bit Hammered but in gauge. 02:00 - 04:00 2.00 DRILL P INT1 Make up BHA # 5- Packed hole assembly with rebuilt Hycalog D8141. Loss to hole = 4 bbls over 4 hours. 04:00 - 05:00 1.00 DRILL P INT1 Make up HWDP and Jars. Surface test MWD- Fine. 05:00 - 06:00 1.00 DRILL P INT1 Slip and Cut 102 ft of drilline. 06:00 - 07:00 1.00 DRILL P INT1 Inspect and servive Top Drive. 07:00 - 12:00 5.00 DRILL P INT1 RIH. No problems. Some ledges @ 9,155', 9,817' and 10,097'. A little tight tthrough top of Kupuruk from 10,476' to 10,515'. 12:00 - 13:00 1.00 DRILL P INT1 Stage up Pumps gradually and fan" bottom of hole to pre-empt any junk issues from previous bit run. 13:00 - 18:30 5.50 DRILL P INT1 Drill from 11048' to 12 1/4" TD @ 11440' MD. Consulted wi Anchorage Geologist for TD determination. 18:30 - 20:30 2.00 DRILL P INT1 Pump hi-vis weighted sweep w/ barofiber & nut plug. Circulate 1 1/2 X B/U. Shakers indicated hole was clean. Spotted 8 drums of torque trim on bottom & in the open hole to aid in running casing. 20:30 - 21 :00 0.50 DRILL P INT1 Monitor well - pull 2 stands - monitor well. Okay. Pump dry job Printed: 5/20/2002 3: 16:44 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 4/16/2002 Spud Date: 4/16/2002 End: 4/28/2002 20:30 - 21 :00 0.50 DRILL P INT1 & blow down lines. 21 :00 - 00:00 3.00 DRILL P INT1 POH. Work tight spots @ 10909', 10330',9650',9610'.9448'. Tight spots to 40K over in the above listed areas, but was able to dry wipe through & clean up. Pulled smooth for the remainder of the trip. 4/29/2002 00:00 - 02:00 2.00 DRILL P INT1 POOH to 13.3/8" shoe @ 3,758'- hole good. 02:00 - 02:30 0.50 DRILL P INT1 Flowchgeck. POOH to HWDP. 02:30 - 04:00 1.50 DRILL P INT1 Lay down 12.1/4" Packed hole assembly. 04:00 - 05:30 1.50 DRILL P INT1 Attempt to pull wear ring- no go. Flush- no go. Unable to J into wear ring. 05:30 - 07:00 1.50 CASE P INT1 Install 9.5/8" Rams in top cavity while mobilisng Tristate Spear and hand. 07:00 - 08:30 1.50 CASE N SFAL INT1 Spear into Wear ring and pull free. The Wear ring had some damage to the J-slot- damage from a BHA/ Bit? 08:30 - 09:00 0.50 CASE P INT1 Test Rams to 3000 psi/1 0 mins 09:00 - 11 :00 2.00 CASE P INT1 R/U to run 9.5/8" and install Franks tool. 11 :00 - 11 :30 0.50 CASE P INT1 PJSM for running 9.5/8" 11:30-12:30 1.00 CASE P INT1 Make up Shoetrack and check floats- OK. 12:30 - 16:00 3.50 CASE P INT1 Run 9.5/8" Casing, BTC, L-80, 47Ib/ft. Run to 13.3/8" Casing shoe @ 18 jts/ hr. Seepage losses- 2-5 bbls/hr. 16:00 - 16:30 0.50 CASE P INT1 Circulate casing contents @ 7 BPM/ 500 psi. 16:30 - 00:00 7.50 CASE P INT1 Continue to run 9.5/8" Casing to 11,240 ft @ midnigh. Taking some weight 10,990 ft but still making good progress. 4/30/2002 00:00 - 01 :00 1.00 CASE P INT1 Continue to run 9.5/8" and land the casing @ 0100 hrs- 277 joints run. No losses while running casing. Little difficult getting last three joints down- making progress with each slack off. Down weight 150-200 klbs. Up weight 400 klbs. 01 :00 - 01 :45 0.75 CASE P INT1 Rig down Franks Tool and R/U Cement head and cement lines. 01 :45 - 05:00 3.25 CASE P INT1 Circulate 150% bottoms up staging pumps gradually up to 10 BPM/ 735 psi. Loosing 20-30 bbls/hr. Hold PJSM for cement job while pumping. 450 units on bottoms up. 05:00 - 08:00 3.00 CEMT P INT1 Mix and Pump 50 bbls weighted spacer, 425 bbls ( 737 sxs) Lead @ 11.2 ppg and 165 bbls Tail ( 806sx) @ 15.9 ppg. Drop Top Plug. 08:00 - 09:30 1.50 CEMT P INT1 Displace Cement with 25 bbls water and 815 bbls Mud @ 9 BPM. Observe cementing lifting and bump plug ( 95% efficiency) to 2100 psi.( 500 psi over final pumping pressure @ 4.5 BPM. Spacer observed at surface just prior to bump. Total losses while cementing/ displacing 30 bbls. 09:30 - 10:30 1.00 CASE P INT1 Back out landing joint and lay down same. 10:30-11:30 1.00 CASE P INT1 Unable to pump down stack- lines to trash pump frozen. Work issue while changing out bails and RIU to run 9.5/8" Pack-off. 11 :30 - 13:30 2.00 CASE P INT1 Drain Stack and install 9.5/8" pack-off. Problems energising seal- fix pump- Energise whiile rigging up lines to pump down 13.3/8" x 9.5/8" annulus. 13:30 - 14:30 1.00 CASE P INT1 Pump down annulus- formation broke down at 1700 psi= 19 ppg EMW @ 13.3/8" shoe ( cement setting> 8 hrs since started mixing lead). Injection pressure stabilised at 2 BPM/ 850 psi. 14:30 - 15:30 1.00 CASE P INT1 Test Pack-off and cleanup tools in cellar. Prepare to change out 9.5/8" rams to pipe rams. 15:30 - 16:30 1.00 CASE P INT1 Work on ram change. 16:30 - 17:00 0.50 CASE P INT1 PJSM for 9-5/8" x 13-3/8" annulus cement sqz. Printed: 5/20/2002 3:16:44 PM ') ) BP EXPLORATION Operations Summary Report Page 7 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 4/16/2002 Spud Date: 4/16/2002 End: 4/30/2002 17:00 - 20:00 3.00 CASE P INT1 PT cement and HB& R lines to 3000 psig- Good. Open up to 9-5/8" x 13-3/8" Annulus. Come on line w/ HOWCO pump w/ SW @ 2 bpm w/1 000 psig Pump press. Pump 70 bbls Water Spacer @ 2 bpm wi 940 psig. Batch up cement. Pump 75 bbls of 15.7 ppg Type C Cement. Switch to mud. Displace cement wi 36 bbls of 10.2 ppg mud pumped by HOWCO. Switch to diesel displacment w/ HB & R at 2 bpm wi 1600 psig P. press. Steady increase in pump pressure to 2 bpm w/1900 P. pressl 1540 lAP. Pump press backed off to stabilised injection rate of 2 bpm @ 1725 psig (1550 lAP) after 50 bbls diesel pumped. Continue w/ planned displacement of 130 bbls bbls diesel FP. SD and monitor fall-off on lAP to 600 psig. SI and RD HB & R. General Clean up and prepation work for BOP test ongoing. 20:00 - 20:30 0.50 CASE P INT1 Continue change out of pipe rams to 5" x 2-7/8" variables. 20:30 - 21 :30 1.00 CASE P INT1 RD down cementing manifold--clear and clean cellar. 21 :30 - 22:30 1.00 CASE P INT1 Run test plug and rig up to test BOP's w/ sea water. 22:30 - 00:00 1.50 CASE P INT1 PT BOPE stack. AOGCC Witness, J. Spaulding, waived witness @ 18:00 hrs on 4/29/02. 5/1/2002 00:00 - 02:00 2.00 CASE P INT1 Continue BOP Test. 02:00 - 03:00 1.00 CASE P INT1 BID choke and kill lines. Pull Test Plug-- Set wear ring. 03:00 - 03:30 0.50 CASE P INT1 Clear and clean rig floor. 03:30 - 05:00 1.50 CASE P INT1 Service Top Drive & Draworks. Weld pipehandler brace. 05:00 - 08:00 3.00 CASE P INT1 PJSM for BHA#6 MU. MU BHA and Load source. 08:00 - 09:30 1.50 CASE N HMAN INT1 Decision to lay down ADN made in morning meeting. Stand back drill collars. Remove source and lay down ADN. 09:30 - 10:00 0.50 CASE P INT1 MU HWDP & Jars. 10:00 - 10:30 0.50 CASE P INT1 Shallow Test MWD- good. BID lines. 10:30 -16:00 5.50 CASE P INT1 RIH to 10890' w/ BHA #6. 16:00 - 18:00 2.00 CASE P INT1 Wash down from 10890 ft md to 11328' md (Tag Plug).Stringer @ 11 ,274ft. 18:00 - 19:00 1.00 CASE P INT1 Circulate and condition mud for casing test. 700 GPM/ 3240 psi MWin=MWout= 10.3 ppg. 19:00 - 20:00 1.00 CASE P INT1 Pressure Test 9-5/8" casing to 4050 psig for 30 mins. 11.25 bbls Pump/ Return. Discuss well control- Stripping (D6) operations. 20:00 - 21 :00 1.00 CASE P INT1 D-6 Drill- Stripping. 21 :00 - 22:00 1.00 CASE P INT1 PJSM- Cut and Slip 102' of drilling line. 22:00 - 00:00 2.00 CASE P INT1 Drill out shoe track from 11328 ft-md to 11416' ft-md. 50 fUhr @ 3 Klbs WOB. Taking it easy with the bit. 5/2/2002 00:00 - 01 :00 1.00 CASE P INT1 Drill out cmt and 20' of formation to 11460' md. 01 :00 - 01 :30 0.50 CASE N DFAL INT1 MWD quit. Try to come on-off pumps and rattle tools to get I Printed: 5/20/2002 3:16:44 PM ) Legal Well Name: NS07 Common Well Name: NS07 Spud Date: 4/16/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E From-To CÖde....NPT 5/2/2002 01 :00 - 01 :30 0.50 CASE N DFAL INT1 back signal back. Didn't work. 01 :30 - 02:30 1.00 CASE P INT1 CBU. Condition mud for LOT. Magnets have retrieved approximately 3 Ibs of metal shavings mixed with fairly large shale cuttings- probably due to cutting structure on PDC reamer. MWin= MWout=10.4+ ppg 02:30 - 04:30 2.00 CASE P INT1 Extended Leak off test. Test was conducted twice w/ LO occuring at approximately 2520 psig (15.4 EMW). 7 bbls pump, 6.7 bbls returned. 04:30 - 05:00 0.50 DRILL P LNR1 Wash to 11460' md. PJSM on Spike bleed to increase MW to 12.7 ppg. 05:00 - 10:30 5.50 DRILL P LNR1 Bleed in 17 ppg spike mud and condition mud system to 12.8 ppg. Working pipe in open hole- hole extremely ratty, packing off, stalling assembly. Dry Pulling- 40 klbs overpulls. 10:30 - 13:00 2.50 DRILL P LNR1 Drill ahead 9-7/8" hole from 11460'- 11552' md. To establish if assembly could drill hole prior to pullling out for MWD failure. Parameters steadied out. Average ROP 45 fph. 13:00 - 14:00 1.00 DRILL P LNR1 CBU condition mud for TOH. Hole conditions smoothed out. 14:00 - 18:30 4.50 DRILL N DFAL LNR1 POOH for new MWD. 18:30 - 20:00 1.50 DRILL N DFAL LNR1 Handle BHA#6. Lay down MWD. 20:00 - 20:30 0.50 DRILL N DFAL LNR1 PU BHA #7. Same as BHA #6 wI new MWD. 20:30 - 21 :30 1.00 DRILL N DFAL LNR1 Shallow Test BHA#7. MWD working -- however, wrong reference frames. Need to POOH and reprogram tool. 21 :30 - 22:30 1.00 DRILL N HMAN LNR1 POOH. Handle BHA#7. 22:30 - 23:00 0.50 DRILL N HMAN LNR1 Reprogram MWD & Test - good. 23:00 - 00:00 1.00 DRILL N DFAL LNR1 RIH w/ BHA#7. 5/3/2002 00:00 - 04:00 4.00 DRILL N DFAL LNR1 RIH wI BHA#7 on 5" DP. 04:00 - 04:30 0.50 DRILL N LNR1 Take ECD baseline @ 11420' md. ECD baseline = 13.61. 04:30 - 06:30 2.00 DRILL P LNR1 Ream f/11430'- 11552' md (50 rpm/675 gpm). Ratty Hole. 06:30 - 00:00 17.50 DRILL P LNR1 Drill ahead 9-7/8" intermediate hole from 11552'-11870' md. Inclination in: 39.07--- Inclination out: 39.17** Azimuth in: 292.72 --- Azimuth out: 282.8 ** ** Note survey taken at 01 :08 on 5/4/02 Steering Time: 70% Rotating Time: 30%. Rotating Parameters: Avg Rot ROP= 60-70 fph. Flow: 680 gpm. SPP on 3800 wI 18 k torq. SPP off 3600 psig. WOB= 10k. ECD= 13.51. ROp while sliding 20-30 ftIhr. No Drag. 5/4/2002 00:00 - 01 :00 1.00 DRILL P LNR1 DRill ahead 9-7/8" hole through Miluveach to just above the Kingak from 11870' to 11933' md. 01 :00 - 03:00 2.00 DRILL P LNR1 Circulate surface to surface fiber/walnut hull sweep. Sweep brought back some excess. Circulate 14000 strokes total to clean and condition mud from 12.5-12.6 to 12.7 ppg. 03:00 - 04:00 1.00 DRILL P LNR1 SID pumps, BID lines, and monitor well--stable. Short trip from 11933' to 9-5/8" casing shoe at 11415' md. Hole in good condition no overpulls. RIH to btm. 04:00 - 12:30 8.50 DRILL P LNR1 Drill ahead 9-7/8" hole from 11933' md to 12345' md. Drilling parameters: 100 rpm/ WOB= 8K1 Torque (on/off) = (20-21 Kl18K)/ Flowrate= 640 gpm w/ 3850 psig PP. 12:30 - 13:30 1.00 DRILL N RREP LNR1 Pump #1 broke. SID and work pipe. 13:30 - 00:00 10.50 DRILL P LNR1 Drill ahead 9-7/8" hole from 11,933' to 12,785'. No drag. ECD Printed: 5/20/2002 3:16:44 PM ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary. Report NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E Spud Date: 4/16/2002 End: 4/16/2002 5/4/2002 13:30 - 00:00 From- To HoLlrs Task Gode NPT Phase 5/5/2002 00:00 - 04:30 04:30 - 06:00 06:00 - 08:30 08:30 - 11 :00 11 :00 - 12:30 12:30 - 14:00 14:00 - 14:30 14:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 23:30 5/6/2002 23:30 - 00:00 00:00 - 05:30 05:30 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 14:00 14:00 - 14:30 14:30 - 20:30 10.50 DRILL P LNR1 4.50 DRILL P LNR1 1.50 DRILL P LNR1 2.50 DRILL P LNR1 2.50 DRILL P LNR1 1.50 DRILL P LNR1 1.50 DRILL 0.50 DRILL 5.50 DRILL 1.50 DRILL 1.50 DRILL LNR1 LNR1 LNR1 LNR1 LNR1 P P P P P 0.50 DRILL P LNR1 0.50 EVAL P 5.50 EVAL P LNR1 LNR1 2.50 EVAL P LNR1 0.50 EVAL P 0.50 CASE P 0.50 CASE P 4.50 CASE P LNR1 LNR1 LNR1 LNR1 0.50 CASE P 6.00 CASE P LNR1 LNR1 hitting 14.2 ppg at times- fine tune flowrate, mud properties to stay under the hard line. No drag on connections. No splinters while drilling. Parameters steady. P-rate 40-60 ftlhr. Drill ahead 9.7/8" hole from 12,785 ft to 12,976 ft. Parameters steady. ECD hitting hardline of 14.2 ppg at times, average 13.9 ppg. No splinters. No drag. Top of Sag @ 12,930 ft MD, 10,770 ft TVD, 46 ft rathole into Sag. Sweep Hole clean @ 650 GPM/ 3950 psi. "Rest" BHA on bottom while rotating @ 100 RPM and periodically reciprocate without rotation ( every 20 minutes). Minimise Shale damage with "wobbly" bit. Make wiper trip to 9.5/8" shoe @ 11,415 ft. Hole good. Minor "tugs" @ 12,236',12,208' and 12,158'. Sweep Hole again @ 650 GPM/ 3950 psi following same practice as earlier to get higher RPM. Shakers cleaned up quick after bottoms up ( 5% splinters) pot black product cocktail. Final mudweight 12.8 ppg. POOH to 9.5/8" shoe @ 11,415'. Minor tugs @ 12,457' and 12,392'. Cut and slip drilling line @ shoe. Pump dry job. Blow down. Drop 2.5" drift rabbit. POOH standing back 5" DP. LD HWDP. LD BHA #7. Flush tools w/ fresh water. BiUReamer graded: 1-3-WT-A-X-I-CT-TD. Clear and clean rig floor. PJSM on SWS wireline RU for OH logs. RU SWS wireline for OH logging runs. W/L logging run #1 (SONIC/ FMI- 92' overall length). Caliper indicates the overall avg of hole in gauge. However, some ledges and undergauge hole were logged. Just below shoe approximately 30' of 18-22" washout. No drag with logging out of hole. Change out logging tools. W/L logging run #2 (Density-43' overall length). Set down on ledge @ 11760' md. 1700 Ibs drag PU. POH with 400-600 Ibs drag. Talk w/ Anchorage and decision made not to try second run. Rig Down SWS W/L. Rig up 7" equipment for running liner. PJSM for running 7" liner. MU and Bakerlock 8-3/8" reamer shoe jt and float collar. MU Baker landing nipple jt. Check floats. Run 44 Jts total 7" 26# Hydril 521 liner. MU torque was 12900 ft-Ibs. Liner hanging wt= 11 OK Ibs. MU liner hanger and packer w/ HRD liner running tool for rotating liner. Circulate liner vol @ 50 spm and 200 psig. RIH w/ 5" DP to 9-5/8" shoe- fill DP every 10 stands. Printed: 5/20/2002 3:16:44 PM Legal Well Name: NS07 Common Well Name: NS07 Spud Date: 4/16/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Hoürs 5/6/2002 14:30 - 20:30 6.00 CASE P LNR1 20:30 - 21 :30 1.00 CASE P LNR1 Circulate DP volume. Take rotating parameters: 10 rpm -6000 ft-Ibs torque Rot Wt= 225 K-Ibs / SOW= 210 K-Ibsl PUW= 250 K-Ibs. 21 :30 - 22:30 1.00 CASE P LNR1 RIH wI stand #117 5" DP and liner to 12912' md with 0-10 Ibs drag. 22:30 - 00:00 1.50 CASE P LNR1 PU single to wash down @ 12919'md.. PU off slips and attempt to wash down. Slack off 100m Ibs - unable to go down. Attempt to break circulation at 0.5 BPM. Pressure up to 1000 PSI-unable to cir. PU to neutral wt. Attempt to rotate, torque up to 22,000 fl-Ibs. - Unable to rotate. PU to 325m Ibs. while holding 650 PSIi pump pressure. Let set. Pressure slowly bleeding off. Maintain 650 PSIi and slowly establish cir. Bring pump up in stages to 70 SPM and 960 psi. Start rotating at 15 RPM and 14m ft-Ibs torque. Slowly work single down with 5-10m Ibs drag, 14-16m ft-Ibs torque, 70 SPM & 950 PSI. PU last single to wash & rotate to TD. 5/7/2002 00:00 - 02:30 2.50 CASE P LNR1 Wash last single down with 3.8 BPM, 650 PSI, 16-20M ft-Ibs torque and 5-10 weight on shoe. String would take weght and torque up. No change in pump pressure. 02:30 - 03:00 0.50 CASE P LNR1 PU Cement head. and cir/rotate to TD (strap showed 5' deeper then drill depth). Final parameters: PU 275M Ibs, SO 225M Ibs, Rot String Wt. 260M Ibs, Torque 17500 ft-Ibs @ 10 RPM & Pump pressure 1000 PSI & 8 BPM 03:00 - 03:30 0.50 CASE P LNR1 Circulate at 8 BPM & 1000 psi. Conduct PJSM 03:30 - 05:30 2.00 CEMT P LNR1 Pump 5 bbls 13.2 ppg Alpha Spacer. Pressure test cement lines to 4500 psig. Pump remaining 45 bbls Spacer. Mix and pump 129 bbls (485 sks) of 15.9 ppg Premium Cement. Drop 2.25" pump down plug. Pump 1 bbls water (1 bbls cemt on top of plug). Isolate and clean up cement lines. Displace w/ Mud @ 7.5 bpm while rotating 5 rpm w/ torque 18-20K ft-Ibs. Slow rate to 4 bpm w/187 bbls pumped. Latch plugs and see good pressure lift while cont to rotate. At 230 bbls displacement see torque and pressure increases (21 K ft-Ibs and 2200 psig). Quit rotating and continue displacement w/ 1250 psig PP. Bump plug @ 258 bbls and 3034 stks and pressure up to 3250 psig. Slack off 55 K and pressure up to 4250 psig. Bleed down and check floats- good. PU 9'. Set liner top packer w/ 50K Ibs down while rotating 10 rpm. 05:30 - 07:00 1.50 CEMT P LNR1 PU and sting out w/1 000 psig. Pressure increasing. PU an additional l' and circulate at 200 spm while reciprocating running tool. See cement at 5800 strokes and estimate approx 40 bbls cement returned to surface. 07:00 - 08:30 1.50 CEMT P LNR1 Monitor well. RD cementing head. UD singles. Pump dry job. BID lines. 08:30 - 14:30 6.00 CEMT P LNR1 POOH w/ HRD liner running tool. Printed: 5/20/2002 3:16:44 PM ) Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Start: Rig Release: Rig Number: 33E 4/16/2002 Spud Date: 4/16/2002 End: Hours Task Code N PT 5/7/2002 14:30 - 15:00 0.50 CEMT P LNR1 Inspect and LD running tool. 15:00 - 15:30 0.50 CEMT P LNR1 Set test plug & RU to test BOP stack. 15:30 - 20:30 5.00 CEMT P LNR1 Test H2S and Gas Monitors. Test BOP stack. AOGCC Representative- Lou Grimaldi witnessed test. 20:30 - 21 :30 1.00 CEMT P LNR1 Pull test plug and set wear ring. 21 :30 - 23:00 1.50 CEMT P LNR1 PJSM. MU BHA #8 - 6-1/8" Bit 1 4-3/4" 0 deg PDMI Slim pulse MWDI and ADN. 23:00 - 00:00 1.00 CEMT P LNR1 MU HWDP and RIH w/ BHA#8. 5/8/2002 00:00 - 01 :30 1.50 CEMT P LNR1 Continue RIH w/ BHA #8. 01 :30 - 02:00 0.50 CEMT P LNR1 Shallow test MWD- OK. 02:00 - 06:30 4.50 CEMT P LNR1 RIH w/ BHA#8 on 5" DP to 12801' md. 06:30 - 07:00- 0.50 CEMT P LNR1 Wash down to 7" Landing Collar @ 12891' md. No cement stringers. 07:00 - 08:00 1.00 CEMT P LNR1 Circulate to even Mud Wt of 12.5 ppg. 08:00 - 09:00 1.00 CEMT P LNR1 Pressure up to 3000 psig w/1 00 strokes and record on chart for 30 mins. Good Test. PJSM on well control and mud swap. 09:00 - 14:00 5.00 CEMT P LNR1 Drill out plug and L. C. at 12891' md (2hrs). Drill cmt to 12928' and begin mud displacement to 9.2 ppg. Drill Fe @ 12932' md. Drill shoe at 12973' md. Drill ahead 6-1/8" hole to 12996' md- 20' of new formation. 14:00 - 14:30 0.50 CEMT P LNR1 Perform FIT to 12.65 EMW w/1920 psig and 9.25 MW. 14:30 - 00:00 9.50 DRILL P PROD1 Drill ahead 6-1/8' production hole. 5/9/2002 00:00 - 07:00 7.00 DRILL P PROD1 Drilling from 13190' - 13500' md. 07:00 - 08:00 1.00 DRILL N HMAN PROD1 Plant tried to start LP compressor w/ no notification to rig. Lost high-line power. Rig started generators and lined up to back-feed power to G & I. 08:00 - 09:45 1.75 DRILL P PROD1 Drill ahead from 13500' - 13529' md. 09:45 - 12:00 2.25 DRILL P PROD1 Circulate sweep surface to surface. Monitor well. 12:00 - 13:00 1.00 DRILL P PROD1 Short trip to 7" shoe. Max pull 335K- Ibs. RIH to btm for circulate and condition. SOW= 245 K. 13:00 - 15:00 2.00 DRILL P PROD1 Circulate and condition hole for logs and 4-1/2" liner run. 15:00 - 15:30 0.50 DRILL P PROD1 POOH to shoe. Monitor. 15:30 - 16:30 1.00 DRILL P PROD1 Slip and cut 102' drilling line. 16:30 - 17:00 0.50 DRILL P PROD1 Pump dry-job and drop 2-3/8" hollow steel rabbit. 17:00 - 19:30 2.50 DRILL P PROD1 POOH for E-line OH- Logs. 19:30 - 22:00 2.50 DRILL N RREP PROD1 A retaining ring (2.5" OD x 0.625" deep x 0.25" thicknessl WT= 1.25 oz- aluminum) fell to rig floor. Shut operation down- pump across top of the hole. Perform zonal derrick inspection. The retaining ring appears to came from light at 110' level in derrick. Light was removed. 22:00 - 00:00 2.00 DRILL P PROD1 POOH for E-line OH-Iogging runs. 5/10/2002 00:00 - 01 :00 1.00 DRILL P PROD1 POOH. Stand Back 5" DP. 01 :00 - 02:00 1.00 DRILL P PROD1 Change to 4" equipment. POOH. Stand Back 4" DP. 02:00 - 03:00 1.00 DRILL P PROD1 LD 4" HWDP. 03:00 - 05:00 2.00 DRILL P PROD1 PJSM on UD of BHA #8 w/ source. UD BHA #8. Flushing Tools w/ fresh water. 6-1/8" Bit grade: 2-6-BT-G E-I-WT-TD 05:00 - 05:30 0.50 DRILL P PROD1 Clear and clean rig floor. 05:30 - 08:30 3.00 EVAL P PROD1 PJSM for SWS W/L rig up. Get Electrician to supply power to pipe rack for E/L unit. Printed: 5/20/2002 3:16:44 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Front-To Hours Task Codé NPT Phase 5/10/2002 05:30 - 08:30 3.00 EVAL P PROD1 08:30 - 15:30 7.00 EVAL P PROD1 15:30 - 00:00 8.50 EVAL P PROD1 5/11/2002 00:00 - 01 :30 1.50 EVAL P PROD1 01 :30 - 03:30 2.00 CASE P PROD1 03:30 - 06:00 2.50 CASE P PROD1 06:00 - 07: 15 1.25 CASE P PROD1 07:15 - 10:00 2.75 CASE P PROD1 10:00 - 11:30 1.50 CASE P PROD1 11 :30 - 13:00 1.50 CASE P PROD1 13:00 - 13:15 0.25 CASE P PROD1 13:15 - 20:00 6.75 CASE P PROD1 20:00 - 20:30 0.50 CASE P PROD1 20:30 - 22:00 1.50 CASE P PROD1 22:00 - 23:30 1.50 CASE P PROD1 23:30 - 00:00 PROD1 0.50 CASE P 5/12/2002 2.75 CASE P PROD1 00:00 - 02:45 02:45 - 04:45 2.00 CEMT P PROD1 04:45 - 06:30 1.75 CEMT P PROD1 Start: Rig Release: Rig Number: 33E Spud Date: 4/16/2002 End: 4/16/2002 Test Tools. Logging run #1- HRLA-Density-Neutron-DS Logging run #2- RFT (20 data points). Finsih running RFT -- RD Schlumberger Wireline Unit. Note: Successful on 17 of 20 sets. Prejob and RU to run 4-1/2" Chrome Liner. RIH with 17 jts of 4-1/2" 12.6# Chrome Vam Ace Liner. Prejob -- RD bales and set back tong, RU 2-7/8" handling equipment. RIH with 2-7/8" inner string and 4-1/2" x 7" liner hanger/packer. RIH with 1 jt of 4" dp and Hole Volume. RD liner running tools and clean floor. RiH with liner on 4" dp. Switch over to 5" handling equipment. RiH with liner hanger/packer on 5" dp -- fill pipe every 10 stands. PU cement head and one joint of 5" dp and set back with tugger. CBU (6750 strokes). Run into open hole with liner, tag bottom and space out. Note: Hole in good shape -- liner went to bottom with no problems. Last circulated and conditioned openhole prior to POOH for logs on 5/9 @ 1500 hrs (Mud static in openhole for 55 hours prior to establishing circ for cement job -- bu mud was in great shape). Establish Circulation and Prepare for cement job and tour change. Rig up manifold to cement head. Stage up circulation rate from 0.5 bpm to 7.5 bpm w/1454 psig. PJSM for Cement Job. HALCO break circulation and pump 5 bbls spacer. HALCO test lines to 4500 psig. Pump remaining 30 bbls 10.5 ppg Alpha Spacer. Follow w/30 bbls 15.9 ppg Premium Cement. Wash up lines. Precharge lines w/ vise KCL water w/ rig pump. Drop top dart, and displace with 20 bbls Vise KCL water w/ rig pumps followed by drilling 9.3 mud at average displacement rate of 7 bpm. Bump plugs 2465 strokes(97%- 206 on HALCO-off today) to 3500 psig. Set Hanger. Bleed off check floats- good. Rotate 20 rounds to right to release liner running tool. Pressure up to 1500 psig and disengage seals and circulate max rate for 25 bbls. Slow pumps and set liner top pkr. Repeat to confirm. Define reciprocating length. Circulate out spacer, vise KCL, and cement at max rate. Estimate 10 bbls cement returned. Printed: 5/20/2002 3: 16:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E HoUrs Task COde NPT Phase 5/12/2002 4.50 CEMT P PROD1 06:30 - 11 :00 11 :00 - 14:00 3.00 CEMT P PROD1 14:00 - 14:30 0.50 CEMT P PROD1 14:30 - 22:00 7.50 CEMT P PROD1 22:00 - 00:00 2.00 CEMT P PROD1 5/13/2002 00:00 - 00:45 0.75 CEMT P PROD1 00:45 - 03:00 2.25 CEMT P PROD1 03:00 - 03:45 0.75 CEMT P PROD1 03:45 - 07:00 07:00 - 09:00 3.25 RUNCOrvP 2.00 RUNCOrvP COMP COMP 09:00 - 10:00 10:00 - 18:00 1.00 RUNCOrvP 8.00 RUNCOrvP COMP COMP 18:00 - 00:00 6.00 RUNCOM\J WAIT COMP 5/14/2002 00:00 - 00:30 0.50 RUNCOM\J WAIT COMP 00:30 - 14:30 14.00 RUNCOrvP COMP 14:30 - 15:30 1.00 RUNCOrvP COMP Start: Rig Release: Rig Number: 33E Spud Date: 4/16/2002 End: 4/16/2002 Rig down Cement Head. Prep pits and G&I for Casing wash. Decision made not to Pressure Test Liner Top (neg or pos) until cement has sufficient compressive strength. Start installing desander modifications and VETCO GRAY- Reorientated Wellhead. PJSM for Caustic wash and SW displacement. Start casing wash treatment. Pump 50 bbls caustic sweep, followed by 50 bbls dirt magnet, and 50 bbls high vise spacer. Displace w/123% of hole volume w/ SW to 76 NTU value. Monitor well for 30 minutes. No flow- negitive test- good. POOH. Stand-back 5" DP. LD 4" DP in well and derrick for summer. LD liner running tool and 2-7/8" FOX tubing. Tools is in good shape. RD 2-7/8" Equipment and liner running tools. PU Test joint and pull wear ring. RUN VETCO GRAY Wellhead Junk Catcher Sub. Flush stack-- Recovered mud, wall cake and cuttings in catcher sub -- no metal (pictures sent to town). Close blind rams. HALCO PT Liner Lap to 4200 psig for 30 mins w/ 8.5 ppg SW in wellbore. PJSM for completion run RU. Rig up handling equipment to run 4-1/2" completion. PJSM. PU WLEG, 'XN', 'X" nipple Assembly. Bakerlock connection and MU to Baker PKR Assembly. MU 'X' nipple Assembly. MU 'Weatherford PT Mandrel Assembly. MU 1-JT of 4-1/2" 12.6# 13CR80 Vam-ACE tubing. PT Weatherford mandrel. RIH w/79 joints of 4-1/2" 13CR80 Vam-ACE completion. Note: Experienced higher make up torque with 4-1/2" Vam Ace connection than previous wells. Consulted Vam Ace technical representative in Houston, TX and discussed findings with BP Anchorage Drilling Team. See Remarks Section for Details. ISLAND lost power and fuel gas to rig. Rig was not able to supply power to Weatherford spooling unit with cold start. Plant is two-blocked can't keep EGEN running to power air compressors for instrument air. MU Floor safety valve and monitor well. Finally, able to get fuel gas valve open to rig. However, 480 volt breaker to pipe-rack will not throw. Still on standby at midnite while plant electrician trouble shoot problem. Continue waiting while electrician provides power to the pipe rack to power the spooling unit. Resume RIH with 4-1/2" 12.6# 13CR80 Vam Ace tubing wiht fiber optic line -- Ran joints 80 - 254. MU SVLN -- Pressure Test. I Printed: 5/20/2002 3: 16:44 PM ') BP EXPLORATION Operations Summary Report Page 14 of 15 Legal Well Name: NS07 Common Well Name: NS07 Spud Date: 4/16/2002 Event Name: DRILL +COMPLETE Start: 4/16/2002 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 33E Rig Number: 33E Höurs Task Code NPT Phase Description of Operations 5/14/2002 15:30 - 20:00 4.50 RUNCOI\tP COMP RIH with 4-1/2" 12.6# 13CR80 Vam Ace tubing with fiber optic line and 2 control lines -- Ran joints 254-303. 20:00 - 00:00 4.00 RUNCOI\tP COMP Space out and land the tubing hanger. Notes: 1. Lay down joints 302 and 303. Install 3' space out pup below joint 301, MU tubing hanger and install fiber optic and control lines. RIH and land tubing hanger -- necessary to use EZ Torque and tugger in attempt to center tubing hanger and keep off ledges. 5/15/2002 00:00 - 03:00 3.00 RUNCOI\tP COMP R/U surface lines to test tubing & U-tube. 03:00 - 04:15 1.25 RUNCOI\tP COMP Pump 25 bbls. of sea water wI 2 bbls. of corrosion inhibitor down 9 5/8" X 4 1/2" annulus. Chase with 30 bbls of sea water to diplace below the GLM. 04:15 - 07:45 3.50 RUNCOI\tP COMP Pump 315 bbls. of 13 degree diesel down 9 5/8" X 41/2" annulus @ 1.5 BPM. Note: Held Pre-Job Meeting and Filled out NAD Fluid Transfer Permit. 07:45 - 09:45 2.00 RUNCOI\tP COMP Test 9 5/8" X 13 3/8" annulus to 3500 psi & hold for 30 min. Note: Used Diesel for test fluid and blew down all diesel in surface lines to bleed trailer. 09:45 - 12:00 2.25 RUNCOI\tP COMP Drop ball & rod. Set packer and test tubing to 4,200 psi & hold for 30 min. Bleed tubing pressure off to 2,600 psi & test annulus to 4,200 psi & hold for 30 min. Bleed pressure off annulus to 3,500 psi and tubing to O. Shear RP valve in GLM @ 6504'. 12:00 - 13:00 1.00 RUNCOIVN DFAL COMP Attemp to U-tube without success. 13:00 - 14:00 1.00 RUNCOIVN DFAL COMP Troubleshoot: Pump down annulus to ensure communication with tubing. OK. Attempt to pump down tubing to ensure communication with annulus unsuccessful. Pressure on tubing immediately. Sheared RP valve acting as check valve. 14:00 - 16:00 2.00 RUNCOI\tP COMP Pump 135 bbls. sea water down annulus until 1 00 % diesel returns from tubing. Shut down pumps and allow diesel to U-tube. Bled back an additional 38 bbls. Note: Final estimates on freeze protection Calc 5750' or 87 bbls of diesel inside tubing based on DH Pressure Tool. Calc 3887' or 208 bbls of diesel in 9 5/8" X 4 1/2" annulus. 16:00 - 16:30 0.50 RUNCOI\tP COMP UD tanding jt. & set BPV 16:30 - 17:30 1.00 RUNCOI\tP COMP Top off annulus w/18 bbls of diesel from trip tank. RD lines. Note: Release Rig from NS07 @ 1730 hrs on 5/15/2002. Operations suspended to move rig and provide access to the slickline unit to repair the SSSV on the NS08 well. Plan to return to NS07 afterward and ND stack, NU and Test Tree. 5/18/2002 00:00 - 04:00 4.00 RUNCOI\tP COMP ND BOPE Stack. Note: Non process leak occured when <1 cup of diesel spilled over API ring when BOP was separated from the Tubing Spool. 04:00 - 08:30 4.50 RUNCOrvP COMP Terminate Cidra and SSSV control lines. Printed: 5/20/2002 3:16:44 PM ') Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS07 NS07 DRILL +COMPLETE NABORS NABORS 33E Date From- To Hours Task Gode NPT Phase 5/18/2002 04:00 - 08:30 4.50 RUNCOIVP COMP 08:30 - 10:30 2.00 RUNCOIVP COMP 10:30 - 12:00 12:00 - 17:30 1.50 RUNCOIVP 5.50 RUNCOI\.IJ\J COMP SFAL COMP 17:30 - 20:30 3.00 RUNCOI\.IJ\J COMP Start: Rig Release: Rig Number: 33E Spud Date: 4/16/2002 End: 4/16/2002 Notes: 1. Service Drawworks and Top Drive -- Grease Crown 2. Load Anadrill Tools on rig floor while installing motors and BHA in pipeshed for next well. NU Tubing head adapter and tree. Note: Slip and Cut 102' of drill line in preparation for the next well. RU S-10 lubricator and pull BPV and install TWC. Problems setting TWC: 1. Change out lubricators due to leaking packing gland on S-10. 2. Damaged O-Ring on large lubricator due to misalignment -- Move Rig 1.5' north to better align. 3. Replace O-Ring on lubricator. 4. Attempt to set TWC -- unable to get off TWC with setting tool. Decision to Test Tree without getting off TWC since plan to pull TWC and installing BPV for rig move. 5. Lesson Learned -- After evaluating the problem with TWC, it was determined that the setting rod was not hydraulically lifted a sufficient distance to clear the threads and reach the slot in the profile which would allow the the setting pin to disengage -- need 1-1/4" minimum and only went 3/4". In future ensure that rod is marked with paint stick prior to pulling to ensure the rod is pulled the 1-1/4" necessary to pull the pin into the slot. Lost Time Breakdown: Actual lost time attributable to TWC release problem was 1-1/2 hours. Time lost to S-10 packing gland leak was 2 hours. Time required to move rig 1.5 feet north was 1/2 hours. RU the hydraulic lubricator was 1 hour. Re-run the TWC is 1/2 hours. Test Tree to 5000 psi for 15 minutes. Pull TWC, Set BPV, RD lubricator and install the tree cap. Release Rig for Move to NS06 at 2030 hrs on 5/18/2002. Printed: 5/20/2002 3:16:44 PM ) ') Well: Field: API: Permit: NS07 Northstar Unit / Northstar Field 50-029-23081-00 202-077 Rig Accept: 04/17/02 Rig Spud: 04/18/02 Rig Release: 05/18/02 Drillin~ Ri~: Nabors 33E POST RIG WORK 06/14/02 PULL DBV, B&R, PULL RP AND SET DGLV, PULL RHC PLUG, RIH WITH 2 7/8" DG TO 12774' AND COULD NOT GET PAST. MADE COUPLE MORE ATTEMPTS TO GET PAST TIGHT SPOT WITH NO LUCK. RIH WI 3" LIB TO 12774 AND IMPRESSION SHOWS 4.5 TBG OVERLAPING TIE BACK SLEEVE. DISCUSS WITH RIG REP AND WILL TROUBLESHOOT SOME MORE IN AM, ATTEMPT TO SEE WHAT SIZE DUMMY GUN WILL GO THRU TIE BACK SLEEVE. 06/15/02 RIH WITH 2.25" TAPERED SWAGE TO TD AT 13407' NO PROBLEMS POOH.RIH WITH 2.50" TAPERED LIB TO 12,774' AND GOT IMPRESSION OF TIE BACK, ID APPEARS TO BE 2.40". RIH WITH 2.125" DUMMY GUN AND MADE IT THRU RESTRICTION WITH LITTLE HESITATION TO TD AT 13407' POOH. (DISCUSS OPTIONS WITH TOWN ON RUNNING 2" GUNS) 06/26/02 RIH WI 2" HSD 2006 PJ GUN - 6SPF. LOG GRICCL JEWELRY LOG TIE IN PASS ONE- CCL FOR SUBSEQUENT RUNS. DOUBLE PERFORATE INTERVAL FROM 13270'-13300'. PERFORATE FIRST OF DOUBLE PERFORATIONS FROM 13240'-13270', NO CHANGE IN WHP- 750 PSI. RIG BACK FOR NIGHT. 06/27/02 RIH W/2" HSD 2006 PJ GUN - 6SPF, RANDOM, 60 DEGREE PHASING. CCL FOR TIE IN. DOUBLE PERFORATE INTERVAL FROM 13210'-13300'. TAG 13442'. FINAL WHP 1050 PSI. 06/29/02 SET 4.5" BBE SER # BB4-32, @ 2001' SLM PERFORM CLOSURE TEST, 1500 PSI DOWN TO 100 PSI FOR 15 MIN. ENDING PRESS 100 PSI TEST GOOD. ANADRILL SCHLUMBERGER Survey report Client..... ............ ..: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Northstar Well. . . . . . . . . . . . . . . . . . . . .: NS07 API number...............: 50-029-23081-00 Engineer. . . . . . . . . . . . . . . . .: M. Leafstedt RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 33 E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent... . . . . : na DF above permanent.......: 40.36 ft ----- Vertical section origin---------------- La tit ude (+ N / S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ---~- Platform reference point--------------- La ti tude (+N / S-) . . . . . . . . . : - 9 9 9 .25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 256.13 degrees ***All MWD surveys D-Mag corrected*** [(c)2002 Anadrill IDEAL ID6_1C_l0] 9-May-2002 15:12:57 Spud date.. . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey... ....: MD of last survey........: Page 1 of 6 18-APR-2002 09-May-02 149 0.00 ft 13529.00 ft ~' ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date......... ...: 21-Apr-2002 Magnetic field strength..: 1150.31 HCNT Magnetic dec (+E/W-).....: 26.48 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 mGal 1150.31 HCNT 80.93 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.48 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 -- ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 173.00 ------ ------ Incl angle (deg) ------ ------ 0.00 0.68 0.89 2.38 2.69 2.67 2.27 2.14 2.21 2.20 3.15 3.54 4.43 5.37 7.32 10.05 10.95 13.64 14.53 13.71 14.52 16.43 18.37 21.25 23.09 25.93 29.21 31.93 33.66 36.22 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 0.00 211.29 220.79 239.61 239.51 230.14 234.51 233.37 235.82 236.41 241.03 240.15 242.72 241.18 238.12 236.96 239.92 241.90 237.62 237.34 236.22 228.40 225.88 226.67 232.15 235.59 234.16 234.25 235.64 237.15 ------ ------ 0.00 50.00 50.00 50.00 23.00 57.00 61.00 71.00 91.00 92.00 90.00 26.00 89.00 91.00 93.00 69.00 26.17 95.09 94.89 93.95 94.20 95.04 95.09 94.83 94.08 94.74 94.66 93.61 94.84 95.37 [(c)2002 Anadrill IDEAL ID6_1C_10J 230.00 291.00 362.00 453.00 545.00 635.00 661.00 750.00 841.00 934.00 1003.00 1029.17 1124.26 1219.15 1313.10 1407.30 1502.34 1597.43 1692.26 1786.34 1881.08 1975.74 2069.35 2164.19 2259.56 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 99.99 149.97 172.95 229.89 290.83 361.78 452-.71 544.64 634.55 660.50 749.29 839.95 932.38 1000.58 1026.31 1119.21 1211.25 1302.36 1393.72 1485.32 1576.05 1665.26 1752.39 1838.59 1922.49 2003.08 2082.81 2160.98 9-May-2002 15:12:57 -------- -------- Vertical section (ft) -------- -------- 0.00 0.21 0.74 2.05 3.02 5.50 7.90 10.43 13.64 16.97 20.98 22.44 28.43 35.96 45.80 55.67 60.21 79.76 101.89 123.61 145.28 168.38 193.23 221.11 252.82 289.20 330.01 374.17 422.07 473.48 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 -0.25 -0.80 -1.62 -2.14 -3.67 -5.28 -6.88 -8.88 -10.86 -13.01 -13.76 -16.70 -20.36 -25.59 -31.20 -33.69 -43.50 -55.14 -67.46 -80.05 -95.60 -114.96 -137.16 -160.19 -183.30 -208.52 -236.37 -265.86 -296.06 0.00 -0.15 -0.56 -1.71 -2.59 -4.76 -6.83 -9.04 -11.86 -14.80 -18.40 -19.72 -25.16 -32.01 -40.86 -49.64 -53.70 -71.41 -91.34 -110.66 -129.88 -149.83 -170.65 -193.88 -220.86 -252.62 -288.43 -327.04 -369.10 -414.60 Page --------------- --------------- Total displ (ft) At Az im (deg) --------------- --------------- 0.00 0.30 0.98 2.36 3.36 6.01 8.63 11.37 14.82 18.35 22.53 24.04 30.20 37.94 48.21 58.63 63.39 83.62 106.69 129.60 152.56 177.74 205.76 237.49 272.83 312.11 355.91 403.52 454.88 509.45 0.00 211.29 215.05 226.56 230.47 232.40 232.32 232.72 233.16 233.73 234.73 235.10 236.42 237.54 237.94 237.85 237.90 238.66 238.88 238.63 238.35 237.46 236.03 234.72 234.05 234.04 234.13 234.14 234.24 234.47 2 of 6 ----- DLS (deg/ 100f) 0.00 1.36 0.49 3.13 1.35 0.77 0.72 0.19 0.13 0.03 1.08 1.51 1.02 1.04 2.13 3.96 4.01 2.86 1.44 0.88 0.91 2.97 2.19 3.05 2.94 3.35 3.53 2.91 1.99 2.83 Srvy tool type TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD ------ ------ Tool qual type ------ ------ .--- - ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth ( ft) 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 -------- -------- 2353.79 2448.60 2543.09 2638.73 2733.52 2829.83 2924.64 3022.64 3117.92 3212.86 3307.22 3402.77 3496.66 3592.14 3687.90 3705.57 3876.13 3971.52 4067.49 4163.26 4257.98 4353.35 4449.33 4545.35 4641.35 4736.87 4829.50 4926.01 5021.16 5117.70 ------ ------ Incl angle (deg) ------ ------ 37.79 38.23 38.00 38.59 39.34 38.34 36.99 36.83 37.97 38.68 38.02 36.38 34.52 34.45 34.27 34.42 34.89 35.11 35.77 35.98 35.94 35.48 35.25 35.03 35.36 35.67 35.33 33.91 33.04 32.93 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 237.19 238.44 236.89 237.34 236.17 232.09 230.48 229.23 230.24 229.28 232.92 230.14 232.03 232.48 231.34 232.03 231.95 230.22 230.98 231.26 230.29 230.91 230.92 228.72 227.68 226.54 226.85 226.80 230.02 232.25 ------ ------ 94.23 94.81 94.49 95.64 94.79 96.31 94.81 98.00 95.28 94.94 94.36 95.55 93.89 95.48 95.76 17.67 170.56 95.39 95.97 95.77 94.72 95.37 95.98 96.02 96.00 95.52 92.63 96.51 95.15 96.54 [(c)2002 Anadrill IDEAL ID6_1C_10] -------- -------- TVD depth (ft) -------- -------- 2236.23 2310.93 2385.27 2460.34 2534.04 2609.07 2684.12 2762.48 2838.17 2912.65 2986.66 3062.77 3139.25 3217.96 3297.01 3311.60 3451.90 3530.04 3608.23 3685.83 3762.50 3839.94 3918.21 3996.73 4075.18 4152.93 4228.34 4307.76 4387.14 4468.12 9-May-2002 15:12:57 -------- -------- Vertical section (ft) --------- -------- 527.12 582.54 637.86 693.89 750.12 806.11 858.68 911.45 963.29 1016.03 1069.06 1121.58 1170.90 1220.33 1269.62 1278.69 1367.20 1416.76 1466.98 1517.84 1568.10 1618.33 1668.59 1718.12 1767.01 1815.53 1862.37 1910.19 1956.62 2004.25 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -326.81 -357.90 -389.10 -421.27 -453.96 -489.31 -525.53 -563.47 -600.87 -638.90 -675.67 -711.58 -745.79 -778.89 -812.22 -818.40 -878.13 -912.50 -947.82 -983.04 -1018.21 -1053.55 -1088.57 -1124.22 -1161.10 -1198.87 -1235.76 -1273.28 -1308.12 -1341.09 -462.25 -511.66 -560.94 -610.71 -660.56 -709.50 -754.70 -799.69 -843.85 -888.79 -934.33 -979.56 -1021.91 -1064.66 -1107.20 -1115.02 -1191.43 -1234.00 -1277.00 -1320.69 -1363.78 -1406.79 -1449.91 -1492.13 -1533.38 -1574.03 -1613.17 -1653.16 -1692.39 -1733.30 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 566.11 624.42 682.68 741.92 801.51 861.86 919.65 978.27 1035.92 1094.60 1153.04 1210.74 1265.11 1319.15 1373.17 1383.13 1480.08 1534.73 1590.31 1646.39 1701.96 1757.56 1813.07 1868.24 1923.38 1978.60 2032.10 2086.66 2139.00 2191.54 234.74 235.03 235.25 235.40 235.50 235.41 235.15 234.83 234.55 234.29 234.13 234.00 233.88 233.81 233.74 233.72 233.61 233.52 233.42 233.34 233.25 233.17 233.10 233.00 232.87 232.71 232.55 232.40 232.30 232.27 3 of 6 DLS (deg/ 100f) 1.67 0.94 1.04 0.68 1.11 2.85 1.76 0.78 1.36 0.98 2.49 2.46 2.30 0.28 0.70 2.36 0.28 1.07 0.83 0.28 0.60 0.61 0.24 1.34 0.71 0.77 0.42 1.47 2.08 1.26 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 -------- -------- Seq Measured # depth (ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 -------- -------- 5213.20 5308.48 5403.66 5498.61 5593.43 5688.39 5784.13 5878.69 5974.41 6070.16 6164.97 6259.35 6354.56 6449.85 6544.55 6642.36 6737.53 6833.07 6927.54 7022.75 7115.74 7212.31 7306.25 7400.82 7497.26 7590.58 7682.64 7779.09 7873.97 7968.11 ------ ------ Incl angle (deg) ------ ------ 32.75 32.74 32.50 32.33 32.54 32.89 33.65 34.25 34.29 33.99 33.77 33.66 33.46 33.08 32.82 32.76 32.72 32.87 32.52 32.34 31.66 31.58 31.54 32.14 32.64 33.07 33.43 33.79 34.62 35.52 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 235.55 237.71 240.17 243.13 243.74 243.26 242.26 242.08 240.39 239.46 238.29 236.78 235.09 234.11 232.97 232.96 232.65 231.88 231.10 230.29 230.27 229.62 229.19 228.64 230.36 233.26 234.95 237.97 243.73 250.83 ------ ------ 95.50 95.28 95.18 94.95 94.82 94.96 95.74 94.56 95.72 95.75 94.81 94.38 95.21 95.29 94.70 97.81 95.17 95.54 94.47 95.21 92.99 96.57 93.94 94.57 96.44 93.32 92.06 96.45 94.88 94.14 [(c)2002 Anadrill IDEAL ID6_1C_10] -------- -------- TVD depth (ft) -------- -------- 4548.36 4628.50 4708.68 4788.84 4868.86 4948.76 5028.81 5107.25 5186.35 5265.60 5344.31 5422.82 5502.16 5581.83 5661.30 5743.53 5823.58 5903.89 5983.39 6063.75 6142.61 6224.85 6304.89 6385.23 6466.67 6545.07 6622.06 6702.39 6780.88 6857.96 9-May-2002 15:12:57 -------- -------- Vertical section (ft) -------- -------- 2052.17 2100.75 2149.75 2199.02 2248.63 2298.71 2349.81 2401.05 2453.14 2504.74 2555.21 2604.86 2654.25 2702.88 2750.43 2799.13 2846.40 2893.72 2940.10 2986.21 3030.56 3075.99 3119.91 3164.27 3210.45 3256.58 3303.37 3353.63 3405.04 3458.41 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -1371.60 -1399.94 -1426.41 -1450.58 -1473.32 -1496.22 -1520.26 -1544.92 -1570.85 -1597.78 -1625.10 -1653.22 -1682.69 -1712.97 -1743.58 -1775.48 -1806.60 -1838.27 -1870.04 -1902.38 -1933.87 -1966.45 -1998.44 -2031.23 -2064.78 -2096.06 -2125.65 -2155.14 -2181.07 -2201.89 -1775.13 -1818.17 -1862.11 -1906.89 -1952.37 -1998.30 -2045.00 -2091.70 -2138.94 -2185.44 -2230.68 -2274.88 -2318.48 -2361.09 -2402.52 -2444.80 -2485.80 -2526.73 -2566.66 -2606.16 -2644.07 -2682.82 -2720.15 -2757.76 -2797.04 -2836.82 -2877.71 -2922.20 -2968.75 -3018.59 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 2243.30 2294.68 2345.65 2395.91 2445.90 2496.38 2548.18 2600.38 2653.80 2707.22 2759.87 2812.15 2864.75 2917.02 2968.53 3021.49 3072.95 3124.67 3175.65 3226.63 3275.81 3326.33 3375.35 3425.07 3476.60 3527.19 3577.66 3630.96 3683.82 3736.33 232.31 232.40 232.55 232.74 232.96 233.18 233.37 233.55 233.71 233.83 233.93 233.99 234.03 234.04 234.03 234.01 233.99 233.96 233.92 233.87 233.82 233.76 233.70 233.63 233.57 233.54 233.55 233.59 233.70 233.89 4 of 6 DLS (deg/ 100f) 1.88 1.23 1.42 1.68 0.41 0.46 0.98 0.64 1.00 0.63 0.73 0.90 1.00 0.69 0.71 0.06 0.18 0.46 0.58 0.49 0.73 0.36 0.24 0.70 1.09 1.75 1.08 1.77 3.52 4.44 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 ------ ------ I -. - ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 -------- -------- 91 92 93 94 95 8063.99 8156.24 8260.46 8354.85 8450.96 ------ ------ Incl angle (deg) ------ ------ 36.00 35.78 35.88 36.39 36.59 36.99 37.25 37.57 37.71 37.36 37.72 38.46 39.06 39.38 39.69 40.35 40.62 40.92 41.31 41.92 41.36 40.49 39.66 39.16 40.13 42.02 41.49 41.47 41.55 41.75 ------- ------- ------ ------ Azimuth Course angle length (deg) ( f t) ------- ------- 256.15 258.80 262.00 265.72 268.80 272.70 276.14 279.46 283.02 282.49 281.68 281.60 280.96 280.48 279.39 278.97 279.01 280.54 281.82 283.25 285.26 286.32 286.57 286.91 288.36 290.84 290.16 289.91 288.83 288.34 ------ ------ 95.88 92.25 104.22 94.39 96.11 94.90 94.66 94.93 94.88 94.80 94.32 96.13 95.04 97.47 92.81 96.11 95.33 95.30 93.65 95.16 93.36 102.31 94.32 95.82 93.73 95.93 95.06 94.87 96.20 95.42 [(c)2002 Anadrill IDEAL ID6_1C_10] 8545.86 8640.52 8735.45 8830.33 8925.13 9019.45 9115.58 9210.62 9308.09 9400.90 9497.01 9592.34 9687.64 9781.29 9876.45 9969.81 10072.12 10166.44 10262.26 10355.99 10451.92 10546.98 10641.85 10738.05 10833.47 -------- -------- TVD depth (ft) -------- -------- 6935.78 7010.52 7095.03 7171.27 7248.54 7324.55 7400.04 7475.45 7550.59 7625.77 7700.56 7776.22 7850.33 7925.84 7997.42 8071.02 8143.52 8215.70 8286.26 8357.40 8427.18 8504.48 8576.65 8650.69 8722.86 8795.18 8866.09 8937.17 9009.21 9080.51 9-May-2002 15:12:57 -------- -------- Vertical section (ft) -------- -------- 3514.33 3568.39 3629.21 3684.34 3740.40 3795.37 3849.59 3903.17 3955.61 4007.24 4058.92 4112.44 4166.30 4222.34 4276.39 4333.26 4390.29 4447.30 4503.08 4559.68 4614.39 4672.63 4725.04 4777.40 4828.38 4880.93 4933.18 4985.34 5038.66 5092.17 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -2217.79 -2229.52 -2239.68 -2245.62 -2248.35 -2247.60 -2243.19 -2235.36 -2224.07 -2211.32 -2199.29 -2187.32 -2175.69 -2164.22 -2154.03 -2144.17 -2134.50 -2123.94 -2111.99 -2098.27 -2083.01 -2064.77 -2047.59 -2030.07 -2011.94 -1990.78 -1968.61 -1947.08 -1925.93 -1905.72 -3072.27 -3125.05 -3185.18 -3240.50 -3297.58 -3354.38 -3411.32 -3468.44 -3525.25 -3581.58 -3637.77 -3695.86 -3754.21 -3814.76 -3872.95 -3933.96 -3995.10 -4056.42 -4116.83 -4178.52 -4238.64 -4303.13 -4361.37 -4419.62 -4476.61 -4535.96 -4595.26 -4654.29 -4714.44 -4774.54 Page --------------- --------------- Total displ (ft) At Az im (deg) --------------- --------------- 3789.12 3838.84 3893.79 3942.55 3991.13 4037.77 4082.77 4126.37 4168.20 4209.23 4250.91 4294.62 4339.09 4385.92 4431.66 4480.35 4529.56 4578.83 4626.97 4675.76 4722.81 4772.86 4818.10 4863.56 4907.94 4953.60 4999.18 5045.15 5092.66 5140.82 234.18 234.49 234.89 235.28 235.71 236.18 236.67 237.20 237.75 238.31 238.84 239.38 239.91 240.43 240.92 241.41 241.89 242.36 242.84 243.34 243.83 244.37 244.85 245.33 245.80 246.30 246.81 247.30 247.78 248.24 5 of 6 ----- DLS (deg/ 100f) 3.28 1.70 1.80 2.39 1.92 2.50 2.21 2.15 2.30 0.50 0.65 0.77 0.76 0.45 0.82 0.74 0.28 1.09 0.99 1.19 1.55 1.09 0.90 0.57 1.43 2.60 0.73 0.18 0.75 0.40 ----- 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 --- -------- -------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 -------- -------- 10929.09 10980.52 11012.22 11105.82 11200.21 11296.52 11376.72 11578.43 11673.98 11770.66 11862.49 11960.78 12055.34 12150.23 12247.42 12342.48 12435.94 12530.43 12626.46 12718.20 12812.33 12907.11 13005.23 13102.44 13195.34 146 13292.20 147 13388.21 148 13452.27 ------ ------ Incl angle (deg) ------ ------ 41.99 41.41 41.07 40.37 39.25 38.05 37.06 39.09 40.29 39.49 39.18 38.17 37.01 35.90 34.41 33.12 31.87 30.90 30.51 29.77 28.76 28.41 27.99 26.47 23.41 ------- ------- ------ ------ -------- -------- Azimuth Course angle length ( deg ) ( f t ) ------- ------- 287.70 288.31 289.26 290.23 291.41 293.16 293.90 290.10 285.67 282.57 280.34 279.96 280.37 280.00 279.35 278.95 279.80 279.41 280.30 279.99 280.98 281.76 281.98 281.35 285.52 20.49 288.57 19.17 290.52 18.12 292.56 Projected to TD 149 13529.00 17.25 294.00 ------ ------ 95.62 51.43 31.70 93.60 94.39 96.31 80.20 201.71 95.55 96.68 91.83 98.29 94.56 94.89 97.19 95.06 93.46 94.49 96.03 91.74 94.13 94.78 98.12 97.21 92.90 TVD depth (ft) -------- -------- 9151.71 9190.11 9213.95 9284.89 9357.40 9432.61 9496.19 9655.00 9728.54 9802.72 9873.75 9950.49 10025.41 10101.74 10181.20 10260.22 10339.05 10419.71 10502.28 10581.61 10663.73 10746.96 10833.43 10919.86 11004.10 96.86 11093.93 96.01 11184.25 64.06 11244.94 76.73 11318.05 [(c)2002 Anadrill IDEAL ID6_1C_10J 9-May-2002 15:12:57 -------- -------- Vertical section (ft) -------- -------- 5146.36 5175.41 5193.00 5243.86 5293.55 5342.12 5380.95 5481.76 5533.64 5588.36 5640.97 5697.07. 5749.75 5801.23 5852.53 5901.15 5947.29 5992.42 6037.31 6079.39 6121.31 6162.33 6204.09 6244.23 6279.05 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- -1885.98 -1875.41 -1868.68 -1848.06 -1826.58 -1803.79 -1784.27 -1737.78 -1719.08 -1703.95 -1692.39 -1681.56 -1671.38 -1661.41 -1652.00 -1643.60 -1635.42 -1627.21 -1618.82 -1610.71 -1602.34 -1593.40 -1583.86 -1574.86 -1565.85 -4835.23 -4867.77 -4887.56 -4945.03 -5001.51 -5057.17 -5101.99 -5217.31 -5275.35 -5335.46 -5392.50 -5452.96 -5509.74 -5565.23 -5620.39 -5672.55 -5722.09 -5770.61 -5818.92 -5864.26 -5909.51 -5953.96 -5999.34 -6042.90 -6080.99 Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 5190.03 5216.55 5232.61 5279.07 5324.62 5369.23 5404.99 5499.11 5548.39 5600.95 5651.84 5706.35 5757.67 5807.93 5858.15 5905.87 5951.21 5995.64 6039.90 6081.44 6122.89 6163.49 6204.89 6244.74 6279.36 248.69 248.93 249.08 249.51 249.94 250.37 250.72 251.58 251.95 252.29 252.58 252.86 253.12 253.38 253.62 253.84 254.05 254.25 254.45 254.64 254.83 255.02 255.21 255.39 255.56 6310.13 -1555.30 -6115.61 6310.28 255.73 6337.32 -1544.42 -6146.30 6337.37 255.89 6354.01 -1536.91 -6165.35 6354.03 256.00 6372.59 -1527.71 -6186.77 6372.59 256.13 6 of 6 DLS (deg/ 100f) 0.51 1.38 2.25 1.01 1.43 1.69 1.36 1.54 3.22 2.22 1.58 1.06 1.25 1.19 1.58 1.38 1.42 1.05 0.62 0.82 1.19 0.54 0.44 1.59 3.80 3.24 1.54 1.93 1.27 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 ------ ------ Tool qual type ------ ------ -' -" bp O'}',"'::..' .. . - ~ NS07 Schlumberger Survey Report - Geodetic Report Date: 15-May-2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 256.130° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS07 TVD Reference Datum: KB Well: NS07 TVD Reference Elevation: 56.100 ft relative to MSL Borehole: NS07 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWI/API#: 500292308100 Magnetic Declination: +26.473° Survey Name I Date: NS07 / April 24, 2002 Total Field Strength: 57515.847 nT Tort I AHD I DOlI ERD ratio: 182.174° /7022.70 ft 16.184/ 0.62C Magnetic Dip: 80.932° -. Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: April24,2002 Location Lat/Long: N 7029 27.290, W 1484135.794 Magnetic Declination Model: BGGM 2001 Location Grid N/E YIX: N 6030881.770 ftUS, E 659834.580 ftUS North Reference: True North Grid Convergence Angle: +1.23172678° Total Corr Mag North.> True North: +26.473° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azlm I TVD I VSec I N/-S EJ.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6030881.77 659834.58 N 702927.290 W 14841 35.794 50.00 0.68 211.29 50.00 0.21 -0.25 -0.15 1.36 6030881.51 659834.43 N 70 29 27.288 W 148 41 35.799 100.00 0.89 220.79 99.99 0.74 -0.80 -0.56 0.49 6030880.96 659834.04 N 70 29 27.282 W 148 41 35.811 150.00 2.38 239.61 149.97 2.05 -1.62 -1.71 3.13 6030880.11 659832.90 N 70 29 27.274 W 14841 35.845 173.00 2.69 239.51 172.95 3.02 -2.14 -2.59 1.35 6030879.58 659832.04 N 70 29 27.269 W 148 41 35.870 230.00 2.67 230.14 229.89 5.50 -3.67 -4.76 0.77 6030878.00 659829.90 N 70 29 27.254 W 14841 35.934 291.00 2.27 234.51 290.83 7.90 -5.28 -6.83 0.72 6030876.35 659827.86 N 70 29 27.238 W 148 41 35.995 362.00 2.14 233.37 361.78 10.43 -6.88 -9.04 0.19 6030874.69 659825.69 N 70 29 27.223 W 148 41 36.060 453.00 2.21 235.82 452.71 13.64 -8.88 -11.86 0.13 6030872.63 659822.92 N 70 29 27.203 W 14841 36.143 -"' 545.00 2.20 236.41 544.65 16.97 -10.86 -14.80 0.03 6030870.60 659820.02 N 70 29 27.184 W 14841 36.230 635.00 3.15 241.03 634.55 20.98 -13.01 -18.40 1.08 6030868.37 659816.47 N 702927.162 W 14841 36.336 661.00 3.54 240.15 660.50 22.44 -13.76 -19.72 1.51 6030867.59 659815.16 N 702927.155 W 14841 36.375 750.00 4.43 242.72 749.29 28.43 -16.70 -25.16 1.02 6030864.53 659809.79 N 70 29 27.126 W 14841 36.535 841 .00 5.37 241.18 839.95 35.96 -20.36 -32.01 1.04 6030860.72 659803.01 N 70 29 27.090 W 14841 36.736 934.00 7.32 238.12 932.38 45.80 -25.59 -40.86 2.13 6030855.31 659794.29 N 70 29 27.039 W 14841 36.996 1003.00 10.05 236.96 1000.58 55.67 -31.20 -49.64 3.96 6030849.52 659785.63 N 70 29 26.983 W 14841 37.255 1029.17 10.95 239.92 1026.31 60.21 -33.69 -53.70 4.01 6030846.94 659781.62 N 70 29 26.959 W 14841 37.375 1124.26 13.64 241.90 1119.21 79.76 -43.50 -71.41 2.86 6030836.75 659764.12 N 702926.863 W 14841 37.896 NS07 ASP Final Survey.xls Page 1 of 5 5/15/2002-10: 06 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec I NI-5 EI.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1219.15 14.53 237.62 1211.25 101.89 -55.14 -91.34 1.44 6030824.68 659744.46 N 702926.748 W 14841 38.482 1313.10 13.71 237.34 1302.36 123.61 -67.46 -110.66 0.88 6030811.95 659725.40 N 70 29 26.627 W 148 41 39.051 1407.30 14.52 236.22 1393.72 145.28 -80.05 -129.88 0.91 6030798.95 659706.46 N 702926.503 W 14841 39.616 1502.34 16.43 228.40 1485.32 168.38 -95.60 -149.83 2.97 6030782.98 659686.85 N 702926.350 W 14841 40.203 1597.43 18.37 225.88 1576.05 193.23 -114.96 -170.65 2.19 6030763.17 659666.45 N 702926.160 W 1484140.816 1692.26 21.25 226.67 1665.26 221.11 -137.16 -193.88 3.05 6030740.48 659643.71 N 702925.941 W 14841 41.499 1786.34 23.09 232.15 1752.39 252.82 -160.19 -220.86 2.94 6030716.88 659617.24 N 702925.715 W 14841 42.293 1881.08 25.93 235.59 1838.59 289.20 -183.30 -252.62 3.35 6030693.10 659585.98 N 70 29 25.488 W 148 41 43.228 1975.74 29.21 234.16 1922.49 330.01 -208.52 -288.43 3.53 6030667.11 659550.72 N 70 29 25.239 W 148 41 44.282 .~. 2069.35 31.93 234.25 2003.08 374.17 -236.37 -327.04 2.91 6030638.45 659512.72 N 702924.966 W 14841 45.418 2164.19 33.66 235.64 2082.81 422.07 -265.86 -369.10 1.99 6030608.06 659471.31 N 70 29 24.676 W 148 41 46.655 2259.56 36.22 237.15 2160.98 473.48 -296.06 -414.60 2.83 6030576.89 659426.47 N 702924.378 W 14841 47.994 2353.79 37.79 237.19 2236.23 527.12 -326.81 -462.25 1.67 6030545.12 659379.49 N 702924.076 W 14841 49.396 2448.60 38.23 238.44 2310.93 582.54 -357.90 -511.66 0.94 6030512.98 659330.76 N 70 29 23.770 W 148 41 50.850 2543.09 38.00 236.89 2385.27 637.86 -389.10 -560.94 1.04 6030480.74 659282.17 N 702923.463 W 14841 52.300 2638.73 38.59 237.34 2460.34 693.89 -421.27 -610.71 0.68 6030447.50 659233.11 N 702923.147 W 14841 53.764 2733.52 39.34 236.17 2534.04 750.12 -453.96 -660.56 1.11 6030413.75 659183.98 N 70 29 22.825 W 14841 55.231 2829.83 38.34 232.09 2609.07 806.11 -489.31 -709.50 2.85 6030377.36 659135.82 N 702922.478 W 14841 56.671 2924.64 36.99 230.48 2684.12 858.68 -525.53 -754.70 1.76 6030340.18 659091.40 N 702922.121 W 14841 58.001 3022.64 36.83 229.23 2762.48 911.45 -563.47 -799.69 0.78 6030301.28 659047.24 N 702921.748 W 14841 59.325 3117.92 37.97 230.24 2838.17 963.29 -600.87 -843.85 1.36 6030262.94 659003.90 N 70 29 21.380 W 148420.624 3212.86 38.68 229.28 2912.65 1016.03 -638.90 -888.79 0.98 6030223.96 658959.79 N 70 29 21.006 W 148421.946 3307.22 38.02 232.92 2986.66 1069.06 -675.67 -934.33 2.49 6030186.23 658915.06 N 70 29 20.645 W 148 42 3.286 3402.77 36.38 230.14 3062.77 1121.58 -711.58 -979.56 2.46 6030149.36 658870.61 N 702920.292 W 148424.617 3496.66 34.52 232.03 3139.25 1170.90 -745.79 -1021.91 2.30 6030114.24 658829.01 N 702919.955 W 148 42 5.863 ~ 3592.14 34.45 232.48 3217.96 1220.33 -778.89 -1064.66 0.28 6030080.24 658786.98 N 70 29 19.629 W 148427.120 3687.90 34.27 231.34 3297.01 1269.62 -812.22 -1107.20 0.70 6030045.99 658745.18 N 70 29 19.301 W 148428.372 3705.57 34.42 232.03 3311.60 1278.69 -818.40 -1115.02 2.36 6030039.65 658737.49 N 7029 19.241 W 148 42 8.602 3876.13 34.89 231.95 3451.90 1367.20 -878.13 -1191.43 0.28 6029978.30 658662.38 N 702918.653 W 1484210.850 3971.52 35.11 230.22 3530.04 1416.76 -912.50 -1234.00 1.07 6029943.03 658620.57 N 702918.315 W 1484212.102 4067.49 35.77 230.98 3608.23 1466.98 -947.82 -1277.00 0.83 6029906.79 658578.34 N 702917.968 W 1484213.367 4163.26 35.98 231.26 3685.83 1517.84 -983.04 -1320.69 0.28 6029870.64 658535.42 N 702917.621 W 1484214.653 4257.98 35.94 230.29 3762.50 1568.10 -1018.21 -1363.78 0.60 6029834.55 658493.10 N 702917.275 W 1484215.920 4353.35 35.48 230.91 3839.94 1618.33 -1053.55 -1406.79 0.61 6029798.30 658450.86 N 702916.928 W 148 4217.186 4449.33 35.25 230.92 3918.21 1668.59 -1088.57 -1449.91 0.24 6029762.36 658408.51 N 702916.583 W 14842 18.454 NS07 ASP Final Survey.xls Page 2 of 5 5/15/2002-10:06 AM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim I TVD I VSec NI-S I El-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (01100ft) (ftUS) (ftUS) 4545.35 35.03 228.72 3996.73 1718.12 -1124.22 -1492.13 1.34 6029725.82 658367.07 N 70 2916.232 W 1484219.696 4641.35 35.36 227.68 4075.18 1767.01 -1161.10 -1533.38 0.71 6029688.06 658326.63 N 70 29 15.870 W 148 42 20.909 4736.87 35.67 226.54 4152.93 1815.53 -1198.87 -1574.03 0.77 6029649.43 658286.80 N 702915.498 W 1484222.105 4829.50 35.33 226.85 4228.34 1862.37 -1235.76 -1613.17 0.42 6029611.71 658248.46 N 70 2915.135 W 1484223.257 4926.01 33.91 226.80 4307.76 1910.18 -1273.28 -1653.16 1.47 6029573.35 658209.29 N 70 2914.766 W 1484224.433 5021.16 33.04 230.02 4387.14 1956.62 -1308.12 -1692.39 2.08 6029537.67 658170.83 N 70 2914.423 W 1484225.587 5117.70 32.93 232.25 4468.12 2004.25 -1341.09 -1733.30 1.26 6029503.83 658130.63 N 70 2914.099 W 1484226.790 5213.20 32.75 235.55 4548.36 2052.17 -1371.60 -1775.13 1.88 6029472.43 658089.47 N 70 2913.799 W 1484228.021 5308.48 32.74 237.71 4628.50 2100.75 -1399.94 -1818.17 1.23 6029443.17 658047.06 N 70 29 13.520 W 148 42 29.287 240.17 4708.67 2149.75 -1426.41 -1862.11 1.42 6029415.77 658003.70 N 70 29 13.260 W 148 42 30.579 .--- 5403.66 32.50 5498.61 32.33 243.13 4788.84 2199.02 -1450.58 -1906.89 1.68 6029390.65 657959.45 N 70 2913.022 W 1484231.897 5593.43 32.54 243.74 4868.86 2248.63 -1473.32 -1952.37 0.41 6029366.93 657914.47 N 702912.798 W 1484233.235 5688.39 32.89 243.26 4948.76 2298.71 -1496.22 -1998.30 0.46 6029343.05 657869.05 N 70 29 12.573 W 148 42 34.586 5784.13 33.65 242.26 5028.81 2349.81 -1520.26 -2045.00 0.98 6029318.01 657822.88 N 702912.336 W 1484235.959 5878.69 34.25 242.08 5107.25 2401.05 -1544.92 -2091.70 0.64 6029292.36 657776.73 N 7029 12.094 W 1484237.333 5974.41 34.29 240.39 5186.35 2453.14 -1570.85 -2138.94 1.00 6029265.42 657730.06 N 70 2911.838 W 1484238.723 6070.16 33.99 239.46 5265.60 2504.74 -1597.78 -2185.44 0.63 6029237.50 657684.15 N 70 29 11.573 W 148 42 40.091 6164.97 33.77 238.29 5344.31 2555.21 -1625.10 -2230.68 0.73 6029209.22 657639.50 N 7029 11.305 W 1484241.422 6259.35 33.66 236.78 5422.82 2604.86 -1653.22 -2274.88 0.90 6029180.16 657595.93 N 70 2911.028 W 1484242.722 6354.56 33.46 235.09 5502.16 2654.25 -1682.69 -2318.48 1.00 6029149.75 657552.97 N 70 2910.738 W 1484244.004 6449.85 33.08 234.11 5581.83 2702.88 -1712.97 -2361.09 0.69 6029118.57 657511.03 N 70 29 10.440 W 148 42 45.257 6544.55 32.82 232.97 5661.30 2750.43 -1743.58 -2402.52 0.71 6029087.08 657470.27 N 702910.139 W 1484246.476 6642.36 32.76 232.96 5743.53 2799.13 -1775.48 -2444.80 0.06 6029054.28 657428.69 N 70299.825 W 1484247.720 6737.53 32.72 232.65 5823.58 2846.40 -1806.60 -2485.80 0.18 6029022.29 657388.37 N 70 29 9.519 W 148 42 48.925 6833.07 32.87 231.88 5903.89 2893.72 -1838.27 -2526.72 0.46 6028989.75 657348.14 N 70 29 9.207 W 1484250.129 6927.54 32.52 231.10 5983.39 2940.10 -1870.04 -2566.66 0.58 6028957.13 657308.90 N 70 29 8.895 W 148 42 51.304 -' 7022.75 32.34 230.29 6063.75 2986.21 -1902.38 -2606.16 0.49 6028923.95 657270.10 N 70 29 8.576 W 148 42 52.465 7115.74 31.66 230.27 6142.61 3030.56 -1933.87 -2644.07 0.73 6028891.65 657232.89 N 70298.267 W 1484253.580 7212.31 31.58 229.62 6224.85 3075.99 -1966.45 -2682.82 0.36 6028858.25 657194.84 N 70297.946 W 1484254.720 7306.25 31.54 229.19 6304.89 3119.91 -1998.44 -2720.15 0.24 6028825.46 657158.21 N 70297.631 W 1484255.818 7400.82 32.14 228.64 6385.23 3164.27 -2031.23 -2757.76 0.70 6028791.88 657121.32 N 70297.309 W 1484256.924 7497.26 32.64 230.36 6466.67 3210.45 -2064.78 -2797.04 1.09 6028757.50 657082.77 N 70 29 6.979 W 148 42 58.079 7590.51 33.07 233.26 6545.01 3256.54 -2096.04 -2836.79 1.75 6028725.39 657043.70 N 70296.671 W 1484259.248 7682.64 33.43 234.95 6622.06 3303.37 -2125.65 -2877.71 1.08 6028694.91 657003.43 N 70 29 6.380 W 148430.452 7779.09 33.79 237.97 6702.39 3353.63 -2155.14 -2922.20 1.77 6028664.48 656959.59 N 70 29 6.089 W 148 431.760 NS07 ASP Final Survey.xls Page 3 of 5 5/15/2002-10:06 AM Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO I VSec I Nl-5 I EJ.W I DLS Northing I fasting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7873.97 34.62 243.73 6780.88 3405.04 -2181.07 -2968.75 3.52 6028637.56 656913.61 N 70 29 5.834 W 148433.129 7968.11 35.52 250.83 6857.96 3458.41 -2201.89 -3018.59 4.44 6028615.67 656864.24 N 70 29 5.629 W 148 43 4.595 8063.99 36.00 256.15 6935.78 3514.33 -2217.79 -3072.27 3.28 6028598.62 656810.92 N 70295.473 W 148436.174 8156.24 35.78 258.80 7010.52 3568.39 -2229.52 -3125.05 1.70 6028585.76 656758.40 N 70 29 5.357 W 148437.727 8260.46 35.88 262.00 7095.03 3629.21 -2239.68 -3185.18 1.80 6028574.30 656698.50 N 70 29 5.257 W 148439.496 8354.85 36.39 265.72 7171.27 3684.34 -2245.62 -3240.50 2.39 6028567.18 656643.33 N 70 29 5.198 W 148 43 11.123 8450.96 36.59 268.80 7248.54 3740.40 -2248.35 -3297.58 1.92 6028563.22 656586.33 N 70295.171 W 1484312.802 8545.86 36.99 272.70 7324.55 3795.37 -2247.60 -3354.38 2.50 6028562.75 656529.53 N 70295.178 W 1484314.473 8640.52 37.25 276.14 7400.04 3849.59 -2243.19 -3411.32 2.21 6028565.93 656472.51 N 70295.221 W 1484316.148 ~ 8735.45 37.57 279.46 7475.45 3903.17 -2235.36 -3468.44 2.15 6028572.53 656415.24 N 70295.298 W 1484317.828 8830.33 37.71 283.02 7550.59 3955.61 -2224.07 -3525.25 2.30 6028582.60 656358.21 N 70295.409 W 1484319.500 8925.13 37.36 282.49 7625.77 4007.24 -2211.32 -3581.58 0.50 6028594.14 656301.62 N 70295.534 W 1484321.157 9019.45 37.72 281.68 7700.56 4058.92 -2199.29 -3637.78 0.65 6028604.96 656245.18 N 70295.652 W 1484322.810 9115.58 38.46 281.60 7776.22 4112.44 -2187.32 -3695.86 0.77 6028615.67 656186.86 N 70295.770 W 1484324.519 9210.62 39.06 280.96 7850.33 4166.30 -2175.69 -3754.21 0.76 6028626.05 656128.28 N 70 29 5.884 W 148 43 26.236 9308.09 39.38 280.48 7925.84 4222.34 -2164.22 -3814.76 0.45 6028636.21 656067.50 N 70295.996 W 1484328.018 9400.90 39.69 279.39 7997.42 4276.39 -2154.03 -3872.95 0.82 6028645.15 656009.10 N 70 29 6.096 W 148 43 29.730 9497.01 40.35 278.97 8071.02 4333.26 -2144.17 -3933.97 0.74 6028653.69 655947.90 N 70296.193 W 1484331.525 9592.34 40.62 279.01 8143.53 4390.29 -2134.50 -3995.10 0.28 6028662.04 655886.58 N 70 29 6.287 W 148 43 33.323 9687.64 40.92 280.54 8215.70 4447.30 -2123.94 -4056.42 1.09 6028671.29 655825.04 N 70296.391 W 1484335.127 9781.29 41.31 281.82 8286.26 4503.08 -2111.99 -4116.83 0.99 6028681.93 655764.39 N 70296.508 W 1484336.905 9876.45 41.92 283.25 8357.40 4559.68 -2098.27 -4178.52 1.19 6028694.32 655702.43 N 70296.643 W 1484338.720 9969.81 41.36 285.26 8427.18 4614.38 -2083.01 -4238.64 1.55 6028708.29 655642.00 N 70 29 6.793 W 148 43 40.489 10072.12 40.49 286.32 8504.48 4672.62 -2064.77 -4303.13 1.09 6028725.13 655577.14 N 70296.972 W 1484342.386 10166.44 39.66 286.57 8576.65 4725.04 -2047.59 -4361.37 0.90 6028741.06 655518.55 N 70297.140 W 1484344.100 286.91 8650.68 4777.40 -2030.07 -4419.62 0.57 6028757.32 ,~/ 10262.26 39.16 655459.94 N 70297.312 W 1484345.814 10355.99 40.13 288.36 8722.86 4828.38 -2011.94 -4476.61 1.43 6028774.22 655402.58 N 70297.490 W 1484347.491 10451.92 42.02 290.84 8795.18 4880.93 -1990.78 -4535.96 2.60 6028794.10 655342.79 N 70297.698 W 1484349.237 10546.98 41.49 290.16 8866.09 4933.18 -1968.61 -4595.26 0.73 6028814.99 655283.03 N 70297.916 W 1484350.982 10641.85 41.47 289.91 8937.17 4985.34 -1947.08 -4654.29 0.18 6028835.24 655223.55 N 70298.127 W 148 43 52.719 10738.05 41.55 288.83 9009.21 5038.66 -1925.93 -4714.44 0.75 6028855.09 655162.97 N 70298.335 W 1484354.489 10833.47 41.75 288.34 9080.51 5092.17 -1905.72 -4774.55 0.40 6028874.00 655102.45 N 70 29 8.533 W 148 43 56.258 10929.09 41.99 287.70 9151.71 5146.36 -1885.98 -4835.24 0.51 6028892.43 655041.35 N 70 29 8.727 W 148 43 58.043 10980.52 41.41 288.31 9190.11 5175.41 -1875.41 -4867.77 1.38 6028902.30 655008.60 N 70 29 8.830 W 148 43 59.001 11012.22 41.07 289.26 9213.95 5193.00 -1868.68 -4887.56 2.25 6028908.60 654988.68 N 70 29 8.897 W 14843 59.583 NS07 ASP Final Survey.xls Page 4 of 5 5/15/2002-10:06 AM Grid Coordinates Geographic Coordinates Station ID MD tnet Azlm TVD VSec N/-S EI-W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (o/1QOft) (ftUS) (ftUS) 11105.82 40.37 290.23 9284.89 5243.86 -1848.05 -4945.03 1.01 6028927.99 654930.78 N 70 29 9.099 W 148441.274 11200.21 39.25 291.41 9357.40 5293.55 -1826.58 -5001.51 1.43 6028948.24 654873.85 N 70299.310 W 148 44 2.936 11296.52 38.05 293.16 9432.61 5342.12 -1803.79 -5057.17 1.69 6028969.83 654817.72 N 70 29 9.534 W 148444.574 11376.72 37.06 293.90 9496.19 5380.95 -1784.27 -5101.99 1.36 6028988.37 654772.49 N 70 29 9.725 W 148 44 5.893 11578.43 39.09 290.10 9654.99 5481.76 -1737.78 -5217.31 1.54 6029032.37 654656.21 N 702910.182 W 148 44 9.287 11673.98 40.29 285.67 9728.53 5533.64 -1719.08 -5275.36 3.22 6029049.82 654597.78 N 702910.365 W 1484410.995 11770.66 39.49 282.57 9802.72 5588.36 -1703.95 -5335.46 2.22 6029063.66 654537.36 N 702910.514 W 1484412.764 11862.49 39.18 280.34 9873.75 5640.97 -1692.39 -5392.50 1.58 6029073.99 654480.09 N 702910.627 W 14844 14.442 11960.78 38.17 279.96 9950.48 5697.07 -1681.56 -5452.96 1.06 6029083.51 654419.42 N 702910.733 W 14844 16.221 .~ 12055.34 37.01 280.37 10025.41 5749.75 -1671.38 -5509.74 1.25 6029092.4 7 654362.44 N 702910.833 W 14844 17.891 12150.23 35.90 280.00 10101.73 5801.23 -1661.41 -5565.23 1.19 6029101.24 654306.75 N 702910.930 W 1484419.524 12247.42 34.41 279.35 10181.19 5852.53 -1652.00 -5620.39 1.58 6029109.46 654251.41 N 702911.022 W 14844 21.147 12342.48 33.12 278.95 10260.22 5901.15 -1643.60 -5672.55 1.38 6029116.75 654199.08 N 702911.105 W 14844 22.682 12435.94 31.87 279.80 10339.05 5947.29 -1635.42 -5722.09 1.42 6029123.85 654149.38 N 702911.185 W 14844 24.140 12530.43 30.90 279.41 10419.71 5992.42 -1627.21 -5770.61 1.05 6029131.02 654100.70 N 7029 11.265 W 14844 25.567 12626.46 30.51 280.30 10502.28 6037.31 -1618.82 -5818.92 0.62 6029138.37 654052.23 N 702911.347 W 14844 26.989 12718.20 29.77 279.99 10581.61 6079.39 -1610.71 -5864.26 0.82 6029145.50 654006.72 N 70 29 11.427 W 148 44 28.323 12812.33 28.76 280.98 10663.73 6121.31 -1602.34 -5909.51 1.19 6029152.90 653961.31 N 7029 11.509 W 14844 29.654 12907.11 28.41 281.76 10746.96 6162.33 -1593.40 -5953.96 0.54 6029160.88 653916.67 N 702911.596 W 1484430.963 13005.23 27.99 281.98 10833.43 6204.10 -1583.86 -5999.34 0.44 6029169.44 653871.11 N 70 29 11.690 W 148 44 32.298 13102.44 26.47 281.35 10919.86 6244.23 -1574.86 -6042.90 1.59 6029177.50 653827.37 N 702911.778 W 14844 33.579 13195.34 23.41 285.52 11004.10 6279.05 -1565.85 -6080.99 3.80 6029185.69 653789.09 N 702911.866 W 148 44 34.700 13292.20 20.49 288.57 11093.93 6310.13 -1555.30 -6115.61 3.24 6029195.49 653754.26 N 7029 11.970 W 14844 35.719 13388.21 19.17 290.52 11184.24 6337.32 -1544.42 -6146.30 1.54 6029205.71 653723.34 N 702912.076 W 14844 36.622 13452.27 18.12 292.56 11244.94 6354.01 -1536.91 -6165.35 1.93 6029212.80 653704.14 N 702912.150 W 14844 37.183 13529.00 18.12 292.56 11317.87 6373.21 -1527.76 -6187.39 0.00 6029221.48 653681.91 N 702912.240 W 1484437.832 ~ NS07 ASP Final Survey.xls Page 5 of 5 5/15/2002-10:06 AM ) ') VERTiCAL SECTiON ViEW Client: BP Exploration Alaska Well: NS07 Field: Northstar Structure: Northstar PF Section At: 256.13 deg Date: May 15, 2002 Schlumberger 0 -"""-,-""""""",-""-,,,,--.,,0-,,-,,,,,,-,-,,,,,,-.,,,, ""-".-..--.......-.....--....-.......,.....-.-.... --.-...--.-.. '--"-"-'----"""-"-"'-""-'-"-"__"_'R ..-.-- (!I & 2000 ..~ .~". NSQ7 ¡.>~~ NSQ7 (P141S19 i I ! ! ........... .... Q)........... 4000 Q)...J '+-c/) 8~ 0 Q) C\J > II 0 .c c CO :;:~ ........0 ..c:""": 6000 .... CD Q.1O Q)........ om -~ CO u.¡..: .- Q) ta:: Q) > > Q) Q) 8000 :JW ~ I- 10000 12000 0 2000 4000 6000 I 8000 Vertical Section Departure at 256.13 deg from (0.0, 0.0). (1 in = 2000 feet) O~",,,,bP ''''/" '. -6000 I PLAN V:IEW Client: BP Exploration Alaska Well: NS07 Field: Northstar -5000 t 1000- Mag Dec ( E 26.47° ) True North ^ ^ ^ I r- rY: 0 Z 0 -1 000 I r- -2000 => 0 CJ) V V V -3000 ~ .r""-"""""'O""<--+,,, ¡(~ NS07 \~~ " /¡-~~ ",. '~.._.p / Þ- N807 (P14) 819 -6000 -5000 Structure: Northstar PF Scale: 1 in = 1000 ft Date: 15-May-2002 -4000 -3000 ,-_._" // ", ....J \~ t G . t ; " ¡ '\.. ./ '%o".'~.~-=«-~.-.-_tO':~,.,.....P"/~ -4000 «< WEST -3000 -2000 . -2000 EAST »> Schlumberuer -1000 0 1000 .--- 0 -1000 -2000 .~ -3000 -1000 0 ) aOd~ö11 ') Dat~: 06-07-2002 Transmittal Numbcr:92509 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact ITIe in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS07 05-06-2002 SCH 1 11418 12958 DIPOLE SONIC IMAGER; ./ NS07 05-06-2002 SCH 11418 11750 TRIPLE COMBO LOG; v NS07 05-06-2002 SCH 1 11418 11750 ARRAY INDUCTION LOG; V NS07 05-06-2002 SCH 1 11418 11750 DENSITYfNEUTRON LOG~ vi NS07 05-06-2002 SCH 1 0 12958 GAMMA RAY; V NS07 06-05-2002 SCH 1 270 12955 OH DIGITAL DATA CD ROM; V ~iJkr' - ) Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petro technical Data Center RECEIVED JUN C 7 2002 Alaska Oil & Gas Cons. Commisston Anchorage Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) l.ts~ Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski Pctrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) ) Date: 05-22-2002 Transmittal Number:92498 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. NS07 05-09-2002 ANA Top Log Run Depth Bottom Depth Log Type 2 13512 12438 DIPOLE SONIC LOG; (COLOR) CD ROM; 13529 MWD SURVEY; (HARDCOPY/DISKETTE) V SW Name Date Contractor NS07 05-10-2002 SCH ~Ûd -{)11 ~ / ~~~pD 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) L / S/f Attn: Buford Bates (Murphy Exploration (Alaska), Inc Attn: Doug Choromanski RECEIVED t..1 ."'1 2 r'. 2002 r..,~.. .... AlalkaOil & Gas Cons. Cornmisston Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 ) Date: 05-18-2002 Transmittal Number:92497 ) BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. 04-08-2002 SCH Top Log Run Depth Bottom Depth Log Type 1 11260 12960 DIPOLE SONIC; (COLOR LOG PRINT) DIGITAL DATA; (CD ROM) 15388 DIPOLE SONIC; (COLOR LOG PRINT) DIGITAL DATA; (CD ROM) 15180 ULTRA SONIC IMAGER; COLOR LOG) DIGITAL DATA; (CD ROM) SW Name Date Contractor ~~"oll NS07 05-06-2002 SCH NS15 IOð-054 I 14714 NS15 05-02-2002 SCH 14200 r- Lt C1 :) Please ign and Return ~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 MAY 1 8 2002 AlælœOiI & Gas Cons.I'~_8-: Anchorage VVlIU'''on Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 \ ) ') bp .,. -\".",. ~.:~ ~~. "'k~ ~... . jj'~~I\'" ". BP Exploration Alaska Inc. To: Tom Maunder - AOGCC Date: April 2, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS07 Sundry for Surface Casing Seat Change Mr. Maunder, Well NS07 is a proposed producer in the Northstar field. The well path has been designed to hit two important targets. The first is a Brookian play in the Coleville interval; the second is the Ivishak target of the Northstar reservoir. In order to reach both targets, NS07 will enter the NS10 Area of Review. The EPA permit NS10 Area of Review drilling requirements states "New wells within the area of review shall be constructed in accordance with the AOGCC Regulations Title 20-Chapter 25. Further, all wells in the area of review shall have casing cemented to the formation throughout the entire section from the base of the lower confining zone to the top of the upper confining zone". Therefore, cement will be brought from the 9 5/8" casing shoe to the top of the SV6 confining shale. This formation top is located inside the 13 3/8" casing. In order to both cement and freeze protect this annulus, a down-squeeze must be performed. It is requested the 13 3/8" casing seat be moved from the current plan of 3532' MD / 3175' TVD (approximately 150 ft. TVD below the SV6 marker) to 3700' MD /3314' TVD (approximately 40 ft MD below the SV5 marker). This will increase the certainty of which formation will break down during the down- squeeze, thus increasing certainty in formation coverage. Excessive gas is not at issue in this shallow sand. The maximum gas found in the SV5 sand since BP Northstar drilling began has been 45 units (seen in both NS13 and NS31). Please find attached the revised NS07 Well Plan Summary and proposed completion diagram. Please also find attached the mud logs from previously drilled Northstar wells. If you should have any questions or concerns, please contact Allen Sherritt @ 564-5402 as I will be on vacation beginning April 5th. Sin7cerÌ'.Y ¿J~ 7/f¡þd- Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 RECEIVED APR 3 ZOOZ AllilOiIiGasConl. COøuni88iOn ~ r ] r ¡: ~ i \ f STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL f kJ-L~{ "-~,. /-- -U .-" )(/J<:: 1. Type of Request: 0 Abandon 0 Suspend 0 Plugging 0 Time Extension 0 Perforate III Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other III Change Approved Program 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 5. Type of well: Œa Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Planned RKB = 56.0' 7. Unit or Property Name Northstar Unit 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. Well Number NS07 9. Permit Number 202-077 10. API Number 50- 029-23081-00 11. Field and Pool Northstar Unit 4. Location of well at surface 1109' NSL, 6421 WEL, SEC. 11, T13N, R13E, UM At top of productive interval 4741' NSL, 1430' WEL, SEC. 15, T13N, R13E, UM (As Planned) At effective depth N/A At total depth 4811' NSL, 1739' WEL, SEC. 15, T13N, R13E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED Perforation depth: measured APR true vertical 3 2002 AlaskaOiI&GaaCOnl.(ìpM1t8ØI ..... Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation April 16, 2002 16. If proposal was verbally approved Service Name of approver Contact Engineer Name/Number: Prepared By Name/Number: Sondra Stewman, 564-4750 "the best of my knowledge Title Senior Drilling Engineer i,I",'I' Conditions of Approval: Notify Commission so representative may witness ~~ \J\« ~ "-.\-'> ~.ç l{<J \ ö..O t\\. APproval No. 3 ~, I ~.¡ {' ~ Plug integrity - BOP Test - Loca'tion clearance -' r f l"~~\ ' ,.....) Mechanical Integrity Test --Original SitR,.'.' ~, ,.' form, '" ..r",eq"Uired 10- l\()'ì ""'>:>~ \\. <:~ '< \. 0.\ ~''''' ~'. ~' . C" Approved by order of the Commission Canytrf ~,!F~S!I.,." i ;~ I ,1\ I Commissioner Date IllJf/ Form 10-403 Rev. 06/15/88 U ~ \ ~ .,J ~ ~ \1 t~\\ -- Submit I '~(cate ) ) NS 07 SUMMARY DRilLING OPERATIONS Pre-Ria 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.) RiQ Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/- 40' MD below the top of the SV5 marker at approximately 3661' MD. Surface casing point has been picked at 3700' MD. POOH. 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 to 250/4500 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 a Leak Off Test. This will give a baseline pressure during the annular down-squeeze. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximately 11 ,550'MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.0 ppg at the top of Kuparuk. POOH. 9. RU Schlumberger. Run open hole Dipole Sonic and FMI (4 arm caliper). POOH and RD Schlumberger. 10. Make a clean 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 SV6 confining shale 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 packoft. Down-squeeze cement sufficient to cover the SV6 shale followed by a spacer and diesel to 2000' TVD for freeze protection. 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 cement. 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 12.2 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 12,910' MD. Intermediate casing point has been picked at 12,944' 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 12.2-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 7" shoe with 12.2-ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.1 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.1 ppg drill-in fluid. 18. Drill 6-1/8" production interval to the proposed TD at 13,590' MD. POOH. 19. RU Schlumberger E-line unit. Run open hole Dipole Sonic and FMI (4 arm caliper). POOH and RD Schlumberger. 20. Make a clean out run, it required, and condition the hole for a liner. POOH. 21. Run and cement the 4-1/2" 12.6# 13Cr liner with an inner string. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH. ) ) 22. Pressure-test the liner top packer and casing to 1500 psi (11.8 ppg equivalent) 23. Circulate to clean seawater (less than 80 NTU's) using spacers as per Baroid recommendation. 24. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). 25. POOH and prepare to run the 4 112" completion. 26. Run the 4 112", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 27. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +1- 2000' TVD (2119' 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 head 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 in the lower most GLM. 33. Pump corrosion inhibitor and heated diesel down the 4 112" x 9 5/8" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4508'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. MIRU Slickline. Install dummy valve in lower most GLM. Pull the ball and rod I RHC profile from 'XN' nipple below the new production packer. RDMO Slickline. 37. MIRU Schlumberger Wireline. Run USIT/CBL. RD Schlumberger Wireline. 38. Perforate -140' Ivishak formation between the Top Ivishak and OWC. 0 Perforate interval based on PE recommendation. 39. MIRU Slickline. Run SSSV. RDMO Slickline. 40. Install (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: April 16, 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 ) NS07 WELL PLAN SUMMARY ") i I Type of Well (producer or injector): Northstar Slot: Surface Location: Brookian Target: 400' Radius Target (top of SAG): 400' Radius Bottom Hole Location: I Producer NS07 1109' FSL, 642' FEL, Sec. 11, T13N, R13E, UM X = 659835 Y = 6030882 4192' FSL, 4285' FEL, Sec. 14, T13N, R13E, UM X = 656241 Y = 6028608 4741' FSL, 1430' FEL, Sec. 15, T13N, R13E, UM X = 653805 Y = 6029107 10,796' TVDrkb 4811' FSL, 1739' FEL, Sec. 15, T13N, R13E, UM X = 653495 Y = 6029171 11,345' TVDrkb I AFE Number: 1831309 I Estimated Start Date: 14/16/02 I Rig: I Nabors 33E I Operating days to complete: 142.2 I MD: 113,590 I I TVDrkb: 111,345 I 1 RKB/Surface Elevation: (a.m.sJ.) I Well Design (conventional, slim hole, etc.): I Modified Big Bore I Objective: Ivishak Producer with fiber optic surveillance control line Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS07 Producer 5175 psi @ 11,100' TVD 8.95 ppg 254 of @ 11,100' TVD Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20",169#, X-56 (pre-driven) I I I 56.0' / 15.9' I I I i ) MUD PROGRAM: ) ) Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3700' MD /3314' TVD (-40' TVD below top SV5). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec 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 TD *9.5 75 -100 20 - 35 >6 10 - 25 4 -10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer 12-1/4" Hole Section From Surface Casing Shoe to 11,550' MD /9645' TVD (-top Miluveach). Interval Density (ppg) PV YP Initial 8.7 - 9.3 10 - 16 20 - 30 Top HRZ 9.6 10 - 16 20 - 25 Top Kuparuk to Miluveach 10.0 10 - 18 20 - 28 Tauo API 1 HTTP FL 4-7 6-10 4-7 4-6/<12 4-7 4-6/<12 pH 8.5-9.5 8.5-9.5 8.5-9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8..1/2" Hole Section From Intermediate Casing Shoe to 12,944' MD /10,786' TVD (top of Sag) Interval Density (ppg) PV YP Miluveach & Kingak to top of Sag 11.8-12.2 10- 25 20 - 25 Production Hole Mud Properties: Seawater/CaC03 Drill..ln Fluid From Intermediate Casing Shoe to 13,590' MD /11,345' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 8 - 12 20 - 25 Tauo 4-7 API FL pH 4-6/ <10 8.5 - 9.5 1 6..1/8" Hole Section Tauo 4-7 APIFL 3-5 pH 8.5 - 9.5 NORTHSTAR SV5 GAS UNITS: Well NS08 NS09 NS10 NS13 NS14 NS27 NS29 NS31 Gas Units 6 to 30 10 to 20 15 to 30 15 to 45 20 to 40 10 to 30 10 to 30 10 to 45 ') DIRECTIONAL:(P14) KOP: Maximum Hole Angle: Close Approach Well: ) :t300' MD Cantenary curve 1°/100' to 2.75°/100' build :t40.1 ° Surface- 10' well spacing NS06 - planned well, not yet drilled. NS08 - closest point at 400' MD center-to-center distance is 9.64 ft. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1500'. Standard MWD surveys from +/-1500' to TD. Survey Program: SURFACE AND ANTI-COLLISION ISSUES: Well NS07 is 9.64 ft center to center from NS08 at 400' MD. NS07 is 8.06 ft center to center at 550' MD from the NS06 plan. Both wells pass the 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 NS05 NS06 plan NS08 NS09 NS10 NS11 NS12 NS13 NS14 NS15 NS16 NS18 NS20 NS21 NS23 NS24 NS25 NS26 NS27 NS28 NS29 NS31 NS35 Seal #A-1 Seal #A-2 Seal #A-2A Seal #A-3 Seal #A-4 Allowable Deviation (ft) 12.67 4.26 6.73 9.45 27.48 33.01 43.36 50.67 66.74 72.71 83.07 102.66 122.97 133.45 153.02 163.14 173.63 181.80 194.50 202.94 213.85 234.13 273.02 436.66 417.62 417.80 420.81 454.86 Depth (MD) 450 550 400 350 200 450 400 400 350 450 450 450 450 350 450 450 350 400 450 450 350 400 450 400 150 150 400 200 Precautions Pass major risk Pass minor risk 1 :200 Pass minor risk 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 major risk Pass major risk Pass major risk Pass major risk Pass major risk Pass major risk Pass major risk ) NS07 Program Supplement LOGGING PROGRAM: 16" Section: Drilling: Open Hole: Cased Hole: 12-1/4" Section: Drilling: Cased Hole: Open Hole: Cased Hole: 8-1/2" Section: Drilling: Open Hole: Cased Hole: 6-1/8" Section: Drilling: Open Hole: Cased Hole: InteQritv TestinQ: Test Point 13 3/8" Surface Casing 95/8" Intermediate Shoe ]" Drilling Liner Shoe ) GR/Directional - Gyro as needed Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) None None GR/Directional, Resistivity (real-time), Density/Neutron (recorded), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples from 9750' MDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Dipole Sonic (TD to surface shoe), FMI (4 arm caliper) None GR/Directional, Resistivity (real-time), Density/Neutron (recorded), PWD 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) Dipole Sonic (TD to Intermediate shoe), FMI (4 arm caliper) None G R/Directional, Resistivity/Density/Neutron (recorded) 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) GR, Resistivity, Density, Neutron, Dipole Sonic (TD to 7" shoe) USIT/CBL (after rig release) Depth Test Type 20' min from 13 3/8" shoe LOT 20' min from 9 5/8" shoe FIT 20' min from 7" shoe FIT CASINGrrUBING PROGRAM: Hole Size Casing/ Wt/Ft Grade Conn. Casing Tbg O.D. Length 20" 20" 169# X-56 WELD 200' 16" 13 3/8" 68# L-80 BTC 3700' 12 %" 9 5/8" 47# L-80 BTC-Mod 11550' 8 Y2" 7" 26# L-80 Hydril 521 1544' 6-1/8" 4-1 /2" 12.6# 13Cr Yam Ace 796' Tubing 4-1 /2" 12.6# 13Cr Yam Ace 12794' 7 EMW ** Used for injection pressure 13.5 ppg EMW Target 12.2 ppg EMW Target (dependant on final MW in 8 Y2" hole.) Casing Top M DrrVDrkb Surface Surface Su rface 11400'/9530' 12794'/10655' Surface Hole Btm M DrrVDrkb 200'/200' 3700'/3314' 11550'/9645' 12944'/10786' 13590'/11345' 12794'/10655' ) ) FORMATION MARKERS: TVDss MDrkb Pore Press. Comment Formation Top estimated (Psi) I (ppg EMW) Top Permafrost 1149 1216 542 8.65 Base Permafrost 1519 1617 708 8.65 SV6 - top confining zone 2950 3329 1352 8.65 SV5 - base confining zone 3226 3661 1476 8.65 Surface casing point 3314 3700 0 0.00 Set surface casing 40' in SV5 SV4 3521 4016 1609 8.65 SV2 - top upper injection zone 3930 4508 1793 8.65 SV1 - top major shale barrier 4320 4977 1968 8.65 TMBK - top lower injection zone - Top Ugnu 4642 5364 2113 8.65 WS1 - top Schrader Bluff - Base Ugnu 6194 7231 2811 8.65 CM3 - Base lower injection zone (top Colville) 6697 7834 3038 8.65 Geol target #1 7586 8932 3437 8.65 THRZ - Top HRZ 8441 10050 3822 8.65 BHRZ - Base HRZ 8560 10205 3876 8.65 Hydrocarbon bearing (mainly Top Kuparuk 8680 10362 4265 9.45 gas) Hydrocarbon bearing (mainly Kuparuk C 9002 10783 4428 9.46 gas) Set intermedate casing into the Top Miluveach 9432 11345 4333 8.83 top of the Miluveach Intermediate casing point 9589 11550 0 0.00 Intermediate logging point 9589 11550 0 0.00 Top Kingak 9912 11972 4690 9.10 Fault "52" - throw = 150' 10033 12125 Expected in upper Kingak Set drilling liner into top Sag River to cover Kingak. Top Sag River 10700 12910 5006 8.95 Hydrocarbon bearing. Intermediate casing point 10730 12944 0 0.00 Geol target #2 10740 12956 4992 8.94 Top Shublik 10788 13011 5047 8.95 Top Ivishak 10850 13083 5076 8.95 Oil - Water contact 11069 13336 5178 8.95 Top Kavik 11249 13544 5261 8.95 Total Depth 11289 13590 5280 8.95 Top Lisburne 11329 5438 9.19 tJossible lost circulation zone REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ) 3700' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 11550' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 206 - 9 5/8" x 12" 1544' 1-8 %" 1-7" 1-7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1-7" 1-7" 796' 1 - 4-1/2" 1 - 4-1/2" 40 - 4-1/2" x 5-3/4" 20- 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 12794' 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 HeadlTbg head 95/8",47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7", 26# L-80 Hydril 521 BBL reamer shoe HES Super Seal II Float Shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker HR running tool Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Vam Ace 4 %" ABB-VGI tubing hanger 4 %" ABB-VGI adapter flange 4 %" ABB-VGI 5-1/8" 5K Swab Valve w/ tree cap CIDRA mandrel and 0.25" fiber optic cable (w/4 %" cable clamps). 4 %" SVLN and 2 - 0.25" control lines 4 %" x 1" GLM with dummy valve installed 4 %" x 1" GLM with RP Shear valve installed 7" x 4 %" Baker 13 Cr packer S-3. 4 %" WLEG (w/o holes) 4 %" 13 Cr X nipples 4 %" 13 Cr XN nipple ) ') PERMAFROST: The 13-3/8" surface casing will be run approximately 1500' TVD below the permafrost to -3700' MD 13314' 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. CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 1375' 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: -2950' MD 1 Total Cement 1 Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 474 bbl I 641 sk I 2660 ft of 10.7 ppg Permafrost 'L' Cement. 4.15 disk, BHST 50° I BHCT 50°, TT = 6.0 hrs 96 bbl I 466 sk I 541 ft;j of 15.8 ppg Premium 'G' wi 2% CaCI2. 1.16 dIsk, BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 6033' of 12 1/4" open hole x 9 5/8" csg with 30% excess Lead TOC: At -3329' MD (3006' TVD) Tail: Based on 2188' of 12 %" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -9362' MD (8177' TVD) Down squeeze: Based on cement 650' inside the 13 3/8" shoe. The SV6 is at 3329'MD. Down squeeze TOC: At 3050' MD (2815' TVD) Stage 1: Total Cement 1 Spacer Preflush 20 bbls sea water Spacer 50 bbl Alpha Spacer wei~hted to 1.0 ppg over mud MW Lead 437bbl I 758 sk I 2456 ft of 11.2 ppg Econolite. 3.24 dIsk, BHST 210° I BHCT 130°, TT = 4.0 hrs Tail 159bbl 1775 sk I 891 ft;j of 15.9 ppg Premium 'G'. 1.15 dIsk, BHST 210° I BHCT 130°, TT = 4.0 hrs Down- 50 bbl 1296 sk I 281 fe of 15.6 ppg Permafrost "c" squeeze 0.95 dIsk, BHST 50° I BHCT 50°, TT = 2.0 hrs Casing 17" Drilling Liner Basis: Stage 1 : Slurry: Based on 1394' of 81/2" open hole x 7" csg with 50% excess + 150' 95/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -11400' MD (9530' TVD) Stage 1: Total Cement 1 Spacer Spacer 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Slurry 69 bbl I 252 sk I 378 ft;j of 15.9 ppg Premium 'G'. 1.50 dIsk, BHST 250° I BHCT 150°, TT = 4.0 hrs Casing 14-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 646' of 6 1/8" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 4 1/2" csg liner lap + 200' 7" csg x 4" drillpipe above TaL + 80' shoe joint. Slurry TOC: At -12794' MD (10655' TVD) Stage 1: Total Cement 1 Spacer Spacer 35 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Slurry 28 bbl I 102 sk I 153 ft;j of 15.9 ppg Premium 'G'. 1.50 dIsk, BHST 250° I BHCT 150°, TT = 4.0 hrs ) ) WEll CONTROL: ~ A Diverter waiver has been requested on well NS07. To date, BP has drilled ten development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. All ten 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: 1476 psi @ 3226' TVDss - SV5 . Maximum surface pressure: 1153 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Intermediate Section: . Maximum anticipated BHP: 4428 psi @ 9002' TVDss - Kuparuk IC' . Maximum surface pressure: 3528 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Drilling Liner Section: . Maximum anticipated BHP: 5006 psi @ 10700' TVDss - Sag River . Maximum surface pressure: 3936 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5280 psi @ 11289' TVDss - Total Depth . Maximum surface pressure: 4151 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) . 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 subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. 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 NS10 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 NS10 Class I Waste Disposal Well. ) ) 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 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS08 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. . . . . . . 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- 2002 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, an uninterrupted fault is possible in both the Schrader and the Upper Kuparuk (approximately 8900' TVDrkb), the possibility of losses exists. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone 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 69.2 bbls assuming an influx from the Kuparuk interval at -8736' TVD. This is the worst-case scenario based on a 10.0 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.0 ppg mud in the hole. . . . . . . ) ) DRilLING LINER SECTION: . Mudloggers will be rigged up throughout the entire section. The directional target has been designed to penetrate fault #52 at 10089'MD. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone 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 12.2 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 9.6 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 12.2 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 12.2 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. 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 (CaC03) 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 9.69 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 12.2 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. . . . . . . ) ') NS07 Ria-site Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS07 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 NS07 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 %" 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 .ì TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl5ksi NS07 - Proposed '\ 133/8" TAM Port Collar at +1-1600'MD 13 3/8", 68#/ft, L-80, BTC @ 3700' MD ... 4 1/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING 10: 3.958" CAPACITY: 0.01522 BBLlFT . 9-5/S" 4 7# L-SO BTM-C @ 11550' MD ¿. 4.5" X NIPPLE, @ 12744' MD 3.813" 10 4.5" X NIPPLE, @ 12764' MD 3.813" 10 4.5" XN NIPPLE, @ 12774' MD 3.725" 10 4.5" WLEG, @ 12784' MD ~ 3.958" 10 E:. .3 7", 26#/ft L-80, Hydril 521 @ 12944' MD ~ PBTD @ 13510' i TO @ 13590' DATE REV. BY COMMENTS BMH ""NS07 ""roposed 3/19/02 ~ V I ORIGINAL KB. ELEV = 55.9' KB-BF. ELEV = 40.2' CB. ELEV = 15.9' 1 1/2" SSSV @ 2000' TVD wi HXO SVLN nipple - 4.562" 10 6.8PPG DIESEL FREEZE PROTECTION AT +1- 3986' TVD (4508'M D) ~ 4 1/2" GLM @ 4500' TVD (5362' MD) w/4.62" 10 ~ 7" LINER TOP @ 11400' MD 4.5" Fiber Optic Transducer 3.958" 10 e; - 7" PACKER,13 Cr @ 12754' MD ~E ~ 4.5" LINER TOP @ 12794'MD ~ 4.5",12.6#, 13CrVam Ace Northstar WFI I: NS07 API NO: BP Exploration (Alaska) I SPERRY.SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company WELL NS08 COMPANY BP ALASKA LOCATION NORTH SLOPE, ALASKA LOGGING SERVICE ,-=== === == === === == LEGEND === ===- -.:::= === == == ) == 10,000 Units Total Gas in Air = 100 % = \ )000 ppm == I / NB New Bit NCB New Core Bit CKF Check for Flow NR No Returns CO Circulate Out LA T Log after Trip TG Trip Gas CG Connection Gas DST Drill Stem Test DC Depth Correction STG Short Trip Gas SVY Direc Survey ~ SIskre I" . . .. "" .1 ~""'"..'.'.'".""..'..~'.;.1 §'---'--.'g' §-~-§ I .. 11 .. 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(." 1('1 . ~ "., ~ r 3985.44' MO, 3809.75' TVD INC 26.21°, All 317.24° SL T: It - m gy, sft, amor, non calc, pyr, micr mic, vf gr sd. 4080.64' MO, 3895.17' TVD INC 26.17°, All 317.17° SL T : It - m gy, sft, amor, non calc, pyr, micr mic, vf gr sd, tr tuff. 4176.99' MO, 3981.51' TVD INC 26.54°, All 316.20° CL Y : md-dk gry, sft, amor, slty, ........-. carb specs, tr pyr, micr mic,. 4271.63' MO, 4066.18' TVD INC 26.54°, All 316.68° SO :wh, trnsl, trnsp, vf f gr, occ , crs, sb ang-sb rnd, p-m srt, uncons. 4367.14' MO, 4151.56' TVD INC 26.72°, All 314.95° SO :wh, trnsl, trnsp, vf f gr, occ crs, sb ang-sb rnd, p-m srt, uncons, glauc, carb specs. 4461.14' MO, 4235.36' TVO INC 27.15°, All 313.96° CL Y : md-dk gry, sft, amor, slty, carb specs, pyr, micr mic,. ='1 ~-.-- .1:.. I ~ ~ .~ :"1"., ~.- ~ ~~ -'''~' ". .,.~ ~:'~,:-~ ~"< i~' r]" " I ..,I'~"'J'''' ""'~~III> c::- SV1 _~~D 4(tJ L4~9' 02/2')/C2 .I?OOH Rotary Tool =a'lwe .þ. C1I C1I 0 ~,.., ~, ' = =-, ~~\f.-'~':"'. =, ::=,:,:,:".,::~,:,., =.:: ., ,- -- f:...,....-"...,~-~. .. . .-.....111.-' ,,'''' ..'-':..-:'...- -'- --'-,."-:."'-""~.,.. . ,,~.-~-:;::-l7~-:-~-: .". ~----.',..~,~.~'.;.'- ~, :-:..::..:-....-:.:.::;- ~7~~~ . -----...,-'...~...--.. --.J¡ ~h\'ts ~ :> ~ ~ II~II I " \ , 4555.35' MO, 4319.08' TVO INC 27.45°, AZI 314.21° . I,~~-----,...,~,~--:".- - - """:"",,--,,.'-'.--..-.. . ~-"""".~'';'''-'.';'--,.oI- . .......- ---,.-,,,-,.'.,,,,'.. It' I -",-............,.."n_..:_'...'- .þ. 0'> 0 0 .' :-:..::..:----.;.: 7~-::-~-:::: . .- - ~,_.......'--.._,..--~. ~::.. ----,--~",~- ~;.~,~.- ( I' ( - - --. ,',.-,...-..'-.. . ===--~--=::-"::'~7.;": .- ~-----"",~,,,,:';"";"...,- - - ~-,' 1.0"_'''_:'.--'. : =--:-----~~7':'7£-: .- ----~'~'---...........;"~ -- _._'-'...:.:...-...._.._... : ~-:------~~7':'7';:~ - ---""..............,'~~--".;;;'~,.~"~ .þ. 0'> C1I 0 - - --- '.'-:,'.- '.~',.. . ' ,': .. " ,,', . - ----'~'..--",-""",--,,,,- .. t 5 r:~ 4 CL Y : md-dk gry, sft, amor, slty, carb specs, pyr, micr mic,. . - - '--'-'-'.'~"""I'¡"""'¡':'~.'''''''¡''' .þ. -... 0 0 ~ " 'I - -- -¿r ~2 tlit~ " i\ ,:~ I~. ' .... ~ 4653.65' MO, 4406.25' TVO INC 27.60°, AZI 313.08° " , J , I ..:.... DGR Continoo GanYM R2~ '1J!:: r- Z :!WR Shallow EWR Phase ~ Gas Chromatograph 0 < -I < ::¡ -I ~ ~ EWR Deep Phase Res GC11n!vl C1 Av~ Lithology Trace 0 api 150 Q) ;;0 Cñ I ëñ J: m œ11111C4TŒjAIg ;;0 ::! ~ 0 ~ GC11nM C~Av~ :gMO@CO c 0 ." ROP Avg CJ) -:Þ ï » r- ;;o tj ~ Gas Max GClIn!vl Cî Av~ - œ1~CSTŒjft.g ~ï 0 0 m ï -I G') (j) m Avg Gas feet per hr -< -< c 500 0 FT 6---' 1---E. 0 400 100 1K 10K 100K 1M WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company WELL NS-13 COMPANY BP ALASKA LOCATION NORTH SLOPE, ALASKA 1== === == === === == LEGEND === ===- )= === == == == 10,000 Units Total Gas in Air = 100 % = 1,000,000 ppm == NB New Bit NCB New Core Bit CKF Check for Flow NR No Returns CO Circulate Out LA T Log after Trip TG Trip Gas CG Connection Gas DST Drill Stem Test DC Depth Correction STG Short Trip Gas SVY Direc Survey ~ Srdtre I.. ; , '..' 'I t.:-:':':':':':':':':':':':'.: þ""-'.-'.;-:1 ~.. -:"'-~=1.. I :: : :: :: ~::::::::::::~::::::::::~: ~-:-=-:-=-:-=;.¡ ¡:£==::, "tI !:: °< -I < 150 ~ ëñ Ô ëñ ~~ MD r C ~r O::r> G> r -< 0 6---' FT ~ . 'I 0 Gamma Ray api ROP Avg feet per hr --_!~ 'Sl'de ",-" ~':I ! .!> J- "f .c~ Rota,jQ '" ~ ~>? i~-( --~r "Side \~ - H ~'> ~ -<¡J l 500 ~oæce, 1J ...~~ ¡~ srew ~ ,/ ~¿ ." ~ ~ ~e 5 r \1 ~~ ---; : ~ ii 1t1 slldel J>! \ .~I I -C-~. I I i !--:::.- :! ..II ~ I - ¡. ~ ~ I I:~ i~1 I I ~JØ ! I I~ R0i'rfr! I I I I~ I I i I~ í ~ tE1"".-""--,'''''.''.'''....'-.----- Siltstone ... - - Z -I -¡ :x: m 0 ~ ... ::u 0 m Q iTI -< c -.~,-.-- -~-,--- ",,,,,,--''''~:~~I''''- ::~-=--~-:..:--=-~-=-~..: ~:-'~:--'~ ~'~:"'"""'r,~'~'- ~~,--~'~-:--,- -,~'--"- ...-',-'~',......-.- ::...-~~:-~~-::...~=~~~:: ~-_:_,-,---- -:~,--,,-, -_:-_'.~'" ..... -,.....................'--'~'......... -,'--'-,- I!-:---"-"-- 0 ~,--....~.--:-,_.... 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Lag Gas Hydrcbn Max ~~ -¡en zð GJ:E Lithology Trace 1m~0 L...,ø ""-il I.;Ü --. --,--". -ll.r ts ~ ,. .....-'" ,,¡ I ~ MD 2554.44', TVD 2533.75' INC 23.16, AZ1102.46 33Lr~ , ..,~ , . t " / 3)Lri~s MD 2649.09', TVD 2620.03' INC 25.41, AZI 99.96 ~ #0 r--" 21 . r+.s -l ~".J,...i:9 k MD 2743.96', TVD 2704.54' INC 28.61, AZ1102.18 22 ~r ~s I ~.""~Å I I~ I -H ,\1'. I . I MD 2840.14', TVD 2787.30' INC 32.60, AZ1103.30 -\ 't~~ ~> ~ ( '-, \... ~r I <~ Sl'dS? ~= Z~ ~ ~. ROœ~.d TOP SV~[ 31885 -(:--- ~~-- ;'r r- {~ ................~................._...................... 1~.1'.."""""'~._'. <,""" ( . ~ r,,-' {l £r fl ~..r I I~ i I ~, i i I. " I~~I~~! ~ 3~62'~J:~3QB'T\tPr ! i : I I ,I I ! ¡I! "I i! I , I ~ , : I, pto~ -0 RUN CtSIY: ~ Sfde Rot~-.e ; 0 0 0) N '~~-:........_-== -----....'_:-:-- -:----~ -"~-.-'- -,-'---,- .....--------- -~'~-,- ~--'-,~.. ~....-----'........'....----...... ,,'.----- ""~-'""",-- _.~-'-~----~ -~---. --_._'-". 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L. . r I~S- rf 1 ).. r i-:s 1 ~ l..ni:3 , 1.., I. ri~s 1 € .. rr.s l' .. ri".s ~ 1 .. "'~ I I I' ""~ .r~ ~ -....... -/"I ", '/ .~ " '! .'\ I I, I .~ \ . ~.. .-..... --...,.- MD 2936.35', TVD 2866.77' INC 36.00, AZ1103.37 MD 3026.91', TVD 2939.15 INC 37.89, AZ1103.12 MD 3123.22', TVD 3013.98' INC 40.12, AZ1103.25 MD 3218.35', TVD 3085.29' INC 42.76, AZ1103.27 MD 3311.68', TVD 3153.44' INC 43.43, AZ1103.95 MD 3343.35' TVD 3176.48' INC 43.25, AZI1 03.40 12107/01 ~.....,," .6<¡gin..O'¡lIing ~- 12.25" Hole ~~ 12/10101.~,- I ....".. i 1,;:'''' ~I'de".'-"-'._'-'-"---' <- sf JI ~t --Ç' -={ ;;. -Reta,:c I ..~~~ ~J ~ -c::: -:: \ ~)N'4 .I 4C3~p, ~694' TVO ~:<- ~ I ' _._~- F- , '"" Side ~~ -~~ ~ Rota':e') ¡I.... -ll. f \ I I t I ~ i l~ þ i I ~ ~ ii' -. I i IsI I-~ \ i 17"~1~ +I!~ i I. )~ ! : ~ - _._,--_. .~~~-=-~ ~,....--......'---..... --,-',-- --'---,. -----'---- -~~-- ~:~,--.._,.. 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J"i~8 , -N' Jri~5 i : t. fì~5 ~ 22 Lr~.s 2'<'- ri-:s " ~rt! . ..,,- ) ~ I 1 T ",.. - , ~,lr~s I' I ,I l~ I r~ '" I ~r r.s I I 'ì MO 3504', TVO 3294.61' INC 43.63, AZ1103.71 CL Y :It-med gy, sft, amor, slty, stky, tr v f gr sd. MO 3595.67', TVO 3362.30' INC 42.44, AZ1103.81 CL Y :It-med gy, sft, amor, slty, stky, tr v f gr sd. - SO :trnsp, trnsl, occ wh, v f - f gr, sb ang-sb rnd, sb spher, mod-w srt, uncons. MO 3692.17', TVO 3434.30' INC 42.74, AZ1103.43 CL Y :It gy, sft, amor, non calc, -.-..--- slty, stky, micr mic, tr pyr, tr v f gr sd. - SO :trnsp, trnsl, occ wh, v f - f gr, sb ang-sb rnd, sb spher, mod-w srt, uncons. MO 3783.23', TVO 3505.28' INC 44.10, AZ1103.68 CL Y :It gy, sft, amor, non calc, slty, stky, micr mic, tr pyr, tr v f gr sd. - SO :tmsp, trnsl, occ wh, v f - f gr, sb ang-sb rnd, sb spher, mod-w srt, uncons. 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I : I . .¡ ~~ril.s 1 ~I"'i~ ~ 1-3 li~s ~ j L r.s 'iI. :....,;, Lri~s 1 ðl Lr i :s :í. ~""'I". 2~)"'¡?~- ~ 20') :2 - ri~.s :':1 ~ri,,:s 3':" - rr.s 1.. ...rlS ~ I I S--C: ~5 ..1\ 1""""5 4: ~ ri"'.! , /" '\ ) ,~c I\. 48C --_..~.. , I I 1.1 I, "'. ''\ /" -.".-...,.... I MD 3977.94', TVD 3647.68' INC 44.78, AZ1103.82 CL Y :It gy, sft, am or, non calc, slty, stky, micr mic, tr pyr, tr v f gr sd. - SD :trnsp, trnsl, occ wh, v f - f gr, sb ang-sb rnd, sb spher, mod-w srt, uncons. MD 4074.08, TVD 3719.46 INC 43.44, AZ1103.90 CL Y :It gy, sft, amor, non calc, slty, stky, micr mic, tr pyr, tr v f grsd. MD 4168.47', TVD 3789.94' INC 45.11, 104.13 CL Y :It gy, sft, amor, non calc, slty, stky, micr mic, tr pyr, tr v f grsd. MD 4264.17', TVD 3861.40' INC 44.57, AZ1104.21 SL T: It -m gy, blky, amor, arg, sft, p cons, intbdd w cly & sd. MD 4354.67', TVD 3928.97' INC 44.12, AZ1104.52 MW 9.1, VIS 48, PV/yP 16/20 GELS 9/13, PH 9.0, CL 17,000 SD : wh, clr-trls, vf- f gr, md ip, sb ang- sb rnd, mod srt, uncons qtz, cht, pyr, slty mtx, nsofc.. MD 4455.59, TVD 4004.32, INC 45.32, AZI 103.71 y- '. ,...,.. ~~ Gamma Ray 0 api ROP Avg 500 feet per hr '."fI"'~ ',' I!'~,...... . '. . .---. . II II ::.:;.,:': II . ..;..~.- .. .'--:.' . . .-.'...- . . .~-=-.- ñ .. .......;..-. r "'0 :::¡ < ~:5 I ëñ 150 0 en MD 0 c en~ r:þ ~r g r -< 0 6---' FT ) .... . . ... --'---- -'---- -.........-'-'-.. . :. . .:,. .1 . e," .', e.. 8" '. . '.,- . "M ".' . I ~~'~ ~~:.: ,~.!... ~.. - 0,._'..- ....... ."..'-..-..-..... r- - - z -I -I ::I: m 0 ~ r- ::u 0 m Q rri -< c " la~ Gas ~~Dn Av~ Gas Chromatograph GCj InMC1 Avg - œ1~('ATŒjAg GC11nMCUvg - - GC11nlvl CJ Avg - œ11~CSTŒjAII 400 1001,K 1qK 10pK1M Lithology Trace Lag Gas Hydrcbn Max ~~ -I en -J: Zo (j)~ 1---€. 0 WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered, In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. I ~ - ~ tI i ,..: Iri Q N M - j 2ft ~ rh ('II 0 Z ... 0 5i ... .¡¡¡ ~ - .¡¡¡ ¡ € ..2'€ :5 ~:!3.9 ~ Company Rig Well Field : Northstar NS-10IWD-01 : Northstar : BP Alaska : Nabors No. 33-E w ~ I ~ ID j I ~ § Country : United States DOE Number: ~ C "0 8 £ j Latitude: 70° 29' 27.58" North Longitude: 148° 41' 35.82" East UTM Easting = 6,030,912.00 m UTM Northing = 659,833.00 m : Cellar Box Elevation: 15.57 ft 40.20 ft Above Permanent Datum Elev. K B 40.20 ft D F 40.20 ft GL 0.00 ft WD 39.00 ft Other Services ~ Permanent Datum ~ . Log Measured From: Kelly Bushing Drilling Measured From: Kelly Bushing .-. - .-MLl:lti~~t- .. Depth Logged Date Logged Total Depth MD Spud Date Job No.: AKAM00307 : 159.00 ft To 8,246.00 ft : 14-Dec-00 To 06-Jan-01 : 8,246.00 ft TVD: 6,513.28 ft : 13-Dec-00 Borehole Record (MO) From 159.00 ft 3,742.00 ft 8044.00 ft 0.00 ft Unit No. : 40087 Plot Type: Field Plot Date: 07-Jan-01 Borehole Record (MO) From Run No. Run No. Size 13.500 in 9.875 in 0.000 in To Size To 3742.00 ft 8044.00 ft 8246.00 ft 0.00 ft Casing Record (MO) Weight From 169.00 0.00 45.50 40.00 29.70 40.00 To 159.00 3726.00 8029.00 Size 20.000 10.750 7.625 c z w C) W ..J.!!l 0 .c E ~ en "C r:: ca tn r:: 0 ; ca 8S: e .c ..c « tn - 0 ..c E ~ en ~ æ 0 - 0 ..r:: ~ --I ill ill ."~' ~:"~'.: : : : : ll.ili 1lili .'~-.,~.:- ~~. 1W ¡ ~ ::::s :E "--- "8",- ". -- ~ E 0 8 ï: ns :E " c ~ ( ) c ~ " c ~ ( ) c ~ j iö' CiS CiS õ TTTff, II i q q fTfTT lWl ilill 1l1l1 - ............... 8_. .. ..8....-..8 ..8.8.8.8 . . -.. .a-.8.8.8 ...8.8.8 . . .-. ..-....e..- ~~ f~¡i' ~j8~1~ -g!~~-gi ~Ü:~~~5= s j ~ ~ ~ ,ê -ó- X m c 'e» c w ns 1ü c "'C ::s ::IE &Æ(/)~~~ ë 8 ~~ ~~~ ~~ ~ ð * e.g :8~,e~uæ óü:ü:(!5£,ã: Ó~~(!)=E.a: ~ ~ ~ 8 ~ ~ ~H~ ~-u- .--..........-. - (¡o-:-( '-'"-- - ~ ~ ! 0 i .s:::. 0 ~ ~ .s:::. :t CD ~ ñi J: ~ CD ~ i ~ § ~ -fTfTTlIlI ilill Q) E en en i ~ ~ ~ ! ~ +0-0 , õ ~ j :s j ~ I ti: œ ~ C u i j ~ ~ ~ ~+-:=~ ~~ ~~ j~ .$ j ~ ØF~ Ø~ð&1 ~~!~ ~1&1~~.~- æ¡~~ . ~ æ¡~ œ:Æ~i=ð ij~8ð~~i~i~i)l£ i~~~~~ co ...... CO C C) s:::: - .C C ~Æü~8~8~8~~~~~~~ Œ~~~~ TG Trip Gas U Gas Units \fIŒ Weigrt On Bit ~UI. ) II Gypsum I~ ':' ~l ') I ""-L.,-,,-,, I . VIla. Ç ~ ,''-',, 801 . BiILrnen I LOT I LeakoffTest I PIT I Pressure Integrity Test :!it!\ ünestone Gravel - - f}..1;.....¡....1i: F;~l"..::,..;~:::v/I SmJ Sa'!IiIJJre I. . . . .. ., ~""'.'."" "''.'''.'''.'~ §..-ã F."~"'~"9 ~-~~""'à I . ~ . .., . ,~, ,.., '."~~I."I.'.'."I~"I.' ~'-"~,~ .::...-::~-:;~~~~, ~~-~~ . . .. . .. ','.'.'.'.'.'.'.'.'.'.'.'.' ---... --- - ................-.. ---- Dolomite IIIIIIII111 I Anhydrite Gravel Silt Siltstone Clay Claystone Lignite Coal Limestone WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. U -u !:B c: °< --I --I < 150 ;U ëñ I I - °c ." 0 (f) ~~ m ï C ~ m 0 » --I G) ï -< 0 6--1 MD Ivv:L 0 Gamma Ray api Logging ROP Avg 500 feet per h r ~[ -. !~. ~~..~ ,,,,,,I! ~1(\:2I.1 i4'i~ul~ ..ï~.~;;._.~ , I:-- Sr.:~r ~1^1DL J Qm]no.B~ M 0.0"''¡''~ ..-? ~ c::= ~ ~ -!' ~I ~ íT I I I I I . I I I ;-.... ~ - --, r- - - Z -f -I :r:: m 0 ~ r- :;0 0 m G') -I -< ~ MAX GAS Gas Chromatograph C1 Avg - C4 Total C2 Avg - C3 Avg - C5 Total Lithology Trace ~~ -I en -:I: Zo G)::: lad (1æ f!,dID1A~ RESCALE x10 1-6 0 1K 100 1K 10K 100K 1M 1CKU'ITSO~ GAS - 1CC~ .... - . '. . . - MW 8.9, VIS 87, PV/yP 19/45, GELS 15/23, PH 8.5, CL 40K. GRAV : - v dk gry - blk, occ wh, w rnd, prly srtd, grdg from crs sd to pea sz gvl, lithic. . .' . '. - . . . . 200 : ::.:-:-= . ..:. .e . \: . - . ,... . \: 250 : ;: .\: . \: . ,... ... . '- . \: 300 : :-. ".. ........ I I I I I I ...-\: ....... ....... ....... . . . ~ ....... ! I . . . . '""" . . . ..... ....... . . . ~ ...--: 350 : : : :,:- I Ii I, ! I I 385.52' MD INC 1.84, All 7.6 , II I I . . . ...: . . . ~ ...-\: . . . --:: : t:r ~) ~'-C; ~ ¡:~ ~r- ~~~ ~ < ~- <-~. -"--f . ~- .~~ . "7 ~ =~ :;; J1U210C "'> --!;;; -ç-:~ ...- ~ ~ ;r-~ ),.1 ;¡- ~ ~~ §I I\~!I <ll~i, I I{' ~i r- I ~ I ...¡.. --;:::> I i L: - I I. '--i-..... ........ : . l L-~ I~~ I ~ ::-T 1- ~I ~ r .. .",. ..,.. . :e,:.,~ 400 :;;-:-: .~ ~, rC . ~ . ,'.\: . ".,.. . ¿ 450 :;. .c .',~ . ~ .. ' ,.. . \: .:,r .c 500 : ',:='" .':..: ... " ',,'''' . .,. - .' ,.' .. ",': .. . :,.' .. 8, ',', ... 550 ::: . ..e, .. .' .' - . .",- . "," . ',",' : 600 ::r= . 8,""";¡'" . . .-- .. it'.. ..... .. . "8, :: .',',. .,- . a,' '....... .." '.':: .' . '. .;,;.. 650 ::::: .' "",-';'¡" . '. .- . .'.";"" .:. ',.~ . ,8',"- . .._- . '. .- .'. '- ( 700 :::::= ',. . ;....,- . '. '. -- . -,"-.. . . a....- . . .-- . . '-- . . .-- . . .-- 750 :: ::.:: . . . -- . . .-- . . .-- 800 : : ~::;:: .. -~ . . -- . . -- . . -- 850 . . -- . . -- . . -- . . -- . . -- 900 : : =--= . . -- I) -'-'--'_.- --,'---- --'-~- .'-'---,- ..,----- --.--- --,~~,~- ....----- .._,---'. ----- _:_'-~-:- . . e, . .'. . . "8 "8 '. ", .W'" :"'-_,--....-.- - ~'.....--'-,- ---,--,- ------ ------ --'~'-~'- ----- -'---- ------ ----- ------ ----- ------ -- -- -- -- -- ------ ----- -- :: ï:'"1",,:,";-1- ----- ------ II ) ì 476.11' MD INC 1.82, AZI 6 GRAV : - V dk gry - blk, ace wh, w rnd, prly srtd, grdg from crs sd ta , pea sz gvl, lithic. 565.89' MD INC 1.6, AZ110.4 657.37' MD INC 1.39. AZI 358.3 GRAV : - v dk gry - blk, ace wh, w rnd, prly srtd, grdg from crs sd ta pea sz gvl, lithic. 746.00' MD INC 1.17, AZ1260.3 GRAV : - v dk gry - blk, ace wh, w rnd, prly srtd, grdg from ers sd ta pea sz gvl, lithic. 833.23' MD, INC 2.55, AZI 214.4 I I I II \1 MW 9.3, VIS 90, PVIYP 25/51, GELS 14/27, PH 8.5, CL 41 K ~ ~~> " ,-~ ~ 7> -- -: !-::_- ~ - ~ -:::::¡- ~ ~ ¿ ~r ~~ - '."-''''. '\ - ~ ~ ;> -- -r £ E ~ ~ ~ ~ ~ ~ I ...... :~ , ~ .". :...--. .',. -,- . . .. . -.;,. . . ..~ . . -- . . _.- . II -- 950 . . -- . .. -- .. . -- .. .. .'- . III -- .. .. -- .'. -- 1000 :::-...:= -- ... ..-- .. '. ..:-...: ., . .. ;"';"'- .. ,'. ,:.'--- .' .. ' . .: .:,.;:; ., 'It, II' -......- 1050:<:::"'-: .. -'.'.~;';' . '.'.. -'.... .. ".".'--- .",-,.:- ~,- .. ...-- . . . .' .. "8 .-..¡.~ .. '. ,.. 1100 :::~..::: .. ,II .. ....- .. .. .. .-- .. .. '. -'- .. . .. -'- .. .. '. ......- .'" .. -- .. .'. ...;..;..;.;...,. .. .. .. ..'-',- .:..,-~ .. '. '. -,- 1150 ::: :::.: .. .. .. -- .'. . --'. .. ". '. ...- .'.. .. -- .. .. .. .-- .. '.-. -- .. .. .. -- .. .. .. .-- .'.-. -- .. .. .. -- ') "''''''''-'--- ----- ------ -'-,~~- -,-.-.-'-- -~--~ -'-,----'~- -......~~.,... .._-'......,~,- -,-,......... -- -_._--- -~--o:o- -,-,-'-,,...... ------ --'---,- --,--- ....... - - ....,.:- -----.1'- -----,- ...----,-,~ --"--'-,- -'---.... -.....-'--- .--, - -....- --~'--- ----- --.:---- ~....,~~- ",,-,.-'-.-- .. .. .. . .. -,' 1200 :',: : ~= :.,',: : : : ':': . . . . ., -- . " " . . . . ...'..'.'. .'. " .'. -. . " . " . -- " " " . III . . " . . ,8 . -,.;... " . . " . . . ....... . .'.. .'-- . . '. . . ,_, .....':=: . " . " . -- 1250 :: : : : = . . . . . -. ..'..... .'..'.... ...'...'. ....... ....... .'...... ....... -- ....... ....... . " . . . -- . . . . .. . . . " " " -- . . " . . . . ....... . . . . . -. . . . . . -- . . . . . -- " . . . . '_, . . . . . -- ....... ....... ....... ....... -- ....... . . . . . -- 1300 : : : : : = : : : : : : : : : : : : =: I: : ! ! : ! ! : ....... " I " / ) II II II II " . . . " ,_, . . . . " -- -- ....... ....... ....... ....... . . . . " -- . . . . " -. " . . . . . . ....... ....... 1350. . . . . -'1 . :::::3::::::: . . " . . -- . . . " " " . ....... . . . . .-., " . . . . " . . . . . " -'-' " " . . . " " " " " " . -...., ----- " . " " " -. ------ " " . . " ~-:7------_-: . . " . " -- ----- 1400: : ~~-~---- " . \.--- " " " " " " " . " ------ " " " " " " " " " ,.--- " " " . " . " . " '\._-- . . " " " . " . " ~--- " " " " " . . " . .,.--- . " . " " " " " " '\._-- " " " . " " " . " ......--- " " . " " . " " " ,--- . " " . " " . . . ,::=---~~---- '~~ "1 932.53' MO INC 3.72, AZ1217.9 GRAV: - v dk gry-blk, occ wh, w rnd, prly srtd, grdg from crs sd to pea sz gvl. lithic. 1027.76' MO INC 5.88, AZI 211.0 CL Y : gy, dk gy; sli calc; slty; sft, plas; mudst; hydphyl. 1121 .34 M 0 INC 7.69, AZI 207.06 SO : wh, It gy, gy, dk gy, mky; m gr, v f gr; qtz; sub spher; sub rnd, sub ang; p srt; clr, trnsl, It gy; uncons; grnst; cl mtrx. 1215.21' MO, INC 8.89, AZI 206.08 SO : wh, It gy, gy, trnsl; f gr, v f gr; qtz; sub spher; sub rnd, sub ang; mod srt; clr, trnsl, It gy; uncons; grnst; cl mtrx. 1310.48' MO, INC 10.08, All 208.87 I , I CL Y : It gy, gy, dk gy; v slty; sft, plas; amph; bnded. 1407.83' MO INC 11.5, AZI 205.95 --;1 ~ :?:- /Sf '. ~ ¿-"", ~".",.."-" ~ ~"'"-""".,,,.,,-",,.., ::> / ~-"..,,- ~ ~ >.".."~ ~ ~ ~ <1 ? ~ ~ ~ r{ I c -sil Ir-- IT --. ~ I k--' ( ~i i~1 I ~# I~ 'I 1<<" i! .,.-t- n- , ~ : ;'1 i <-- 11 i ...',,,,,..... ".."",,,,,.,. '...,""",.." """'''.'.'''' ') . -,'''-''';'-_. J".,. ,it .'. . . "'.' ~-'~,.......',..',." ,." .'-,". '-~ ,"~I .:-.. ""--:,:-~~.....;.,~,,,,;,,~ 1450 : .:;:-~----";-~-:..-:.: ... ('""-_-.._-=':-.;...;_':_-;.; .'. ~-........_-'-'-:-... . .' ~-'~'~~~~,"" a:,. ,....~~~---==-....:-~~~-:.: e, .' a...:_.....-----~-:-- .-. ,.-~'~~~,~,..... -'-----'---- ",-, \.'''-;'~~:~'''''''--;';''' . . "'----~--_....- . ..t"~~-::-~.....~~~-.: ',',' ,,\.~--~~~:~~ 1500 : ;=::-----=1----4 .' ::..---~~--: :....-:..-.;....-:..-= . ---- .,,--~- . -'--.... . "~~~- -,-.,-- . ---',-" . !,~~'-.,..- ".~~~- 1550 : ::..---~ . _.---,-- .. ''''''~,-''' '"I~--'---:';' . -......'_.-- : ~~:-£-: !'8'-~,--~ ----.- "" - ~ -.-.."...'- -'-~,-- ._~,-~- -,-'--'-- -,--'...........~- ................-.-- .""',---'~- ""~'-,-'- --O:-~'-,-- """~'-,~,"" -'~"""-',-:- -~~,.-~ .',-~:.....,--.- -,._,-',-- -:,-.....,.'-,......- -'---,- .-,-- ~,....~- ~,......,--,'.......- 18!'----'~,'~,- -'-,......~,- -~~;--,......- ~',-,...-""¡'...... . -'......_-- ---_.:-- . "~~,--,'- -~-...,.~ -~--. .~'~'~~~ --,-'-- ." h_......'- . ,-..-~,~'- .,' .c..~~~-: 1600 :;;:':-.......-"':: ::-:-::-:-:1 .c..-:--= .... .... e,','. '. .,.'. "~I . """-'--- . ", r- --:--- .,~'~~:- ."--'--- ."~,~~",,,: -~~,'- . ',\.-,----- 1650 ::::..-=----= . ~-_-:.:: . .,---'-'......., .,,,,,,,,,,'~_'- . ,'"--.;........:.... ."...._-- . ~.....---~ . . ~-...:-..:: .'....,--- ...'.'... ..'...".. '. .. '., '. ". ,,,a '. - - - ''"' - ",,' - -----'. -'----'.......0.,.... ."'"e.,." ....'... e, :1,' '. :1, . '. ",. .' '. .. ,8 . . ',- .' III . '"..,,, ..'...,. ., 'I '. ..'.'. . .'....., .'.'....'. ----,--- -'-----,- --,..'~:---~ ------ -----,-- . ,--.,~~- --~-- . c...-----= =----..:-:-= 1700 ::-:-.¿-= :::-2:-£-£-:' ",.,8, '--.'- ~,~~~~ "..,-'- .. .. .. ,--- .. :" . ,.c:..-: . .. .. 'I_''''''¡' . .. .. ''-.....- .. '- '. ..'.c:..-: .'. .'1_- .'''. '~-~ ..,. ~~..;. 1750 :: : :.:--= . . .. '.c:..-: . .. .. 8_- . . . "...-. . . . '\..---= .. '. . 1_- . . . .,--- . .. .. '--- . . .'._- .. . . .,--- . . . .c:..-: - -, - - - ,,-, - ."....'.. ",'.". .,'. .'.'.'... . . . . .. .. ',a .'...... ..'....'. ......,. . ;'. '. .. '. . . .'.'..... ....... ....... ....... ....... ....... ....... .'...'..'. ....... ....... ....... 1800 : : : :.:---= ::::::: I ....... .. .. . .c-_-= . . . 8_- .. . . ~-- . . . .c-_-= .. . . 8_- . . .. .--- .. . . ~---: . . .. 8_- . . .. "..-- .. .. .. .c:..-: 1850 : : : :.:--= . .. .. .c-_-= . . .. 8_- . . . .--- . .. .. '--- . .. . .-- .. .. . .--- . . . --=---= . . .. .-- . . . ,,--- . . .. .c-_-= ....... ........ ....... ....... ....... ....... ....... ....... ....... ....... ....... ....... ----- ------ ....... ....... ----- ------ ----- 1900 : : : :.:----=: : : : : : : . ....... . . . '--- . . . .. . .. . . . . ---- . . . .. . . . . . . ."...-- . .. . . . . . . . . .c:..-- . If .. " . .. . . . . ---------- . . . ~---=-------_-:: . . . -.....------ . . . .-------- . . . .,------- -------- . . . '------- 1950: : : '---"-;-t--=--=----= I: : : ~ ====:~ II .... ~ NITS I \ I II I '" 1501 .19' M D INC 12.91, AZ1198.69 CL Y : It gy, gy, dk gy, brn; calc; v slty; sft, plas; amph; bnded. 1596.17' MD 13.85, AZ1198.91 CL Y : It gy, gy, dk gy, brn; calc; v slty; sft, plas; amph; bnded. 1690.01' MD INC 16.34, AZI 202.99 SD : wh, It gy, dk gy, blk, clr; vcrs gr, f gr; qtz, lit; sub rnd, sub ang; Ise; uncons; cht, pyr, qtz. 1784.56 MD INC 19.07, AZ1205.14 SD : wh, It gy, dk gy, blk, clr; vcrs gr, f gr; qtz, lit; sub rnd, sub ang; Ise; uncons; cht, pyr, qtz. 1879.16 MD INC 21.93 AZ1205.17 CL Y : It gy, gy, dk gy, brn; calc; v Ii slty; sft, plas; amph; bnded. II ~ \.... <. .~ .~ ........ r~~ ~~ ~ <.r ,~~-:~ -=> -:;,~_7>' ~ '-). . J ,,,......,,,,.....,....-.r7 ..,,<..;> ? ---~ ~~~ ..- ..., ...5 ---- ~._- ..' .?r: >, ~ .}- ----., ~' ./ ==~:-:> { , ~;- ~~ ~ < .-" --~ ~ 12l1élO'~ t. r ~ I ~~ III ' ~.I ~r I- :J <... 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I I I I I. ~~~I~l ~~--u G.A$ 1 < I ~~h"" ..): IlfJl :..:1~ }...~ I ' , I I ") I 1974.26 MO INC 27.25, AZI 207.78 SO : wh, It gy, dk gy, blk, trnsl, clr; sub spher; sub rnd, ang; v p srt; uncons; cht. 2067.11 MO INC 30.28, AZI 208.07 MW 9.3, VIS 67, PVIYP 19/43, GELS 15/28, PH 8.3, CL 39K. SO : wh, gy, dk gy, blk, choc, clr; crs gr, f gr; sub rnd, sub ang; v p srt; uncons; cht, pyr, qtz. 2162.61 MO INC 31.97, AZI 202.2 SO : gy, dk gy, blk, trnsl, clr; crs gr, v f gr; qtz, lit; sub rnd, ang; p srt; uncons; cht, pyr, qtz. 2256.19 MO INC 35.57, AZI 200.99 CL Y : gy, brn; sli calc; v slty; sft, pi as; amph. 2351.18 MO INC 39.03, AZI 202.21 SO : gy, dk gy, blk, tmsl, clr; crs I gr, v f gr; qtz, lit; sub rnd, ang; p I srt; uncons; cht, pyr, qtz. I: I 2446.19 MO INC 43.02, INC 201.95 I I -- ...... ~ ~' >- ~¿~ . >~ ¿SC ~ $ ~ c..".,...."...,.,., ~ :> "J. ;.- ~ v ~ ~ ? .> .-/ /,,,,,, .. J W¡pe. Tr~"___,-".~ " -. ~ /"" : .:.'.: .:.:. ~f-}:i::i:>:i: .. ,8.'.'.,-.:' /'.'"~',,'.,,,'.-:',.,~ ...'.," " '.' .. r- .',8 .. .:'".' .',. -, .',8,"'. ",~ ~ '.',,'. '. ."'.'., ,. ....,..-- .'. '. 'II '.".~~'~~O:-- - --....' ...,.:..-. -- " .. .. .. "~a "~, ---.;....;...;,~~-- 2500 :<: : .::: '.': =-:-:-:-:'7:-:'" .. -, ., ".." ',. ~ 8,','. .. ,'a "'., . .. " .. .. .... -- .. '. .. .. .. .. .. "? ~~ ~ ¿ -~~ ~ ) 1 ) ) ~1 ~~ \ 2e .NITS I \ \ 28..NITS ' / 37 .NITS ~ ./ " / ( 2850 : =----- ---- ~ 2900 : ~---- ~ I 1 ---- '.. ---- ç ---- ---- sj ---- ---- ---- ---- II I ---- ~ --_.- :, J I II i ,,"," I ---- .'..".. .,.-,.-..:..:. ..'.. ..'..'.'. ...'fI'.. .. .. .. " .. 8, ----,--~- .' .. .. .. .. .. ~......--:,,---:- ------. .... .,.,.',.~-~,~- .. .. .. '. .. ----'--,""'. .' .' .' .. .. .. -,---- ------- .,. . .,". .. -.;...'.......--'~'- 2550: ::: : :---------~...: . ..... =-~'7'I M'7' f"'I¡- .. .. .. ..'.. .. -. .. ,... .". '. '. '. .'. . .'. . - '. . ".' .' '. ... ,',. ....,.. ..,'....,. . ':. ..'.. . '. -... ", ,'. ' '. '... '. ,.. .. . . .. . ~ .~. .' '. . .' . " . ":'., .. .'. .~.. '.:.,. .".. " '. '. . . . - - '. '. ". '. '. 'II' . .. .,,'~ ":".,',',~~~'~:...:~ .'" . 8" .','. ~~~'::.....;.... 2600 . ... . . ----~,........ .. .'". '. .. ,'. ==-~-.;.,;..-~-::: .. .. ., ,.' 8,',., ....-.--'--~'-,.... . .. . " . :. ---'----,---'. .... .,.',':.'~~'~~'~ --'---~,~,~- .,'.':",' II,', II,. -";";'~--'~-- . .. '. .. . ,. ---'-'-,--- .' '. . .',.,"..~~~....,--:- .~. ...=-"7M,"~- . II .. .,.',.... - '. '. ,"'" ,.' .' .. :": :: : :' :,:, ',: ~-,:",: ",:' ,:,..: ,:,:..;: 2650 ::: : :: :.::: : :::: ',. .. .'."::',~., -,',. -, .'. .. . II ", '. ,- - - '. - .. ,'. II, '.' . '. ::::::s::: :::.: . .':. ,.' '.,. ---. '. ',. ....'. .'. ,.,'., "~~.,'.'8 .',. "','~ . . . . '.". .... . .'. '." .". -----~'~....~ ------'-- ~----- 2700::: :.~:':----""'~----...:' ;,..-.== 7ï: -=-;"11 ~ -'..... -. ., '. . '. '.. . ~- .' ',. '. .' '.'.. '. ---..,~ --:--,-- --------- -~,~,~,-~ --'---:--- -----,- -,,....------ " '. .. . - --,- . ....... 2750:: : : --- .". '. '. '.'.". -'- .. .. . II .,. .. -'---....,...-- -- '" - .. .. - -, - =---= .:.t...:...:.:..:....:- ---,--""""'" - -'- .. '. .. . . '. .. -- . .' .. .. ",. '. . . . . :....--" ., . ..... -----,---... ------- ---------- -------- 2800 : ~=--- ::-:-::-:-:.... . 'ì 2540.31' MO INC 45.97, AZI 200.60 SO : gy, dk gy, blk, trnsl, elr; ers gr, v f gr; qtz, lit; sub rnd, ang; p srt; uncons; cht, pyr, qtz. 2634.91' MO, INC 46.27, AZ1197.28 CL Y : gy, brn; sli calc; v slty; sft, pi as; am ph. 2727.53' MO INC 44.88, AZ1198.58 COAL: blk, brn; arg; v hd; ea; no bed. 2821.92' MO INC 46.13, AZ1199.06 CL Y : It - m gry/brn, sft, amor, sli - v slty,n - v sli calc, sdy wI abnt thn Sd strgs. 2917.75' MO INC 47.53, AZ1198.05 3012.5' MO ì <> ~ cr 3? '>:t '" -........- .... ~~ ¿ ("~ ,~ .. . -=5<'''.''.'.'''''.'''''--' /,.--~> <> ..)- -<~ '- -.. . .....{ ~'~ :~) -- I~ -......... ~.~ "- < l...) r -c::::- ~. _/ <\, "', .> <> ..>/ ~f "('::I ~ -=:::::: > ~. "'" ---'"""\.. ..oc;-- ~ <::ç ~ ~ r--- .r-\ ...:.. ~:~~¡ ~i' ~¡-ii i 0 -::;7" ...< ) """"þ ----""" -..., =-- " ,',", ',-.' ." ',.~,', " '.',',"'" ""'~," ','.r"I:!....'..', ."'.'.,T.' , ,',,',"""12 ',. ,." , ,-, ....-- "''' ~" .'" .-'-. -.......--.........- .'.~~- -:_-,- ".,. "'''','' "f"'.","."'. .". 3000 ",. :::--=---=:-~ --.;....;.- -. . . ,.--- --~ . . \.-=--_-:.---=----~ .- . .....--. -----,- ...' ~-,-~~,........~ --......-......,-~-- .,8.,:\.''''';'-- . . """-_,1 .--'..-...'. . II ,---:- .-..:--.....-- ., .,,";,,;,,,,- . . "--- ~ . " "--... . . ...----- :,:':':,r:-î~ I . ....' --t."'" " .' .,.,...,..-- ..,' C-_-=--:: ... '. .. .'" '. .. . ',""-'-:-. '.'. .",.-. "-'.11 ",. -,--- .' '.:\.-:Z-~-:''''':'''''~' ~',,'. '." :.' 31 00 "" "::;...---. ::'::: :: :,,:',: :,= .,". .,-:.'" ,1,.11 .',11.11,11_...,.... "'.'..",,. .,.".,....,-,- I'."..".:.,... .", ,.,-. ...........;.. .'. .-..-. ,. .-' '. , " --,- I '"'.' II '.. . :"".':" :. :,:,-,.,.,::L,',....,' "-,'~, ~:,.,-,.',',"~,-,..- : ::: ~-£I:=.-::-"-::- 3150: :::::....~ :::: ::: -,' .," ' .. ...;......;,,~ .'.' II 'II . -'. II II II II II -,.....,;' , II' 'II ,II 'II II- II' 'II .",.,..,.,.~~ II..'.,.'.. .... ..--.-.... II II II . -,~. II II II, II II, ..'.. :",:..:'.: =~~:.:~:~~': II '-11 'II "II ~-'-_.-.-._-- :' :: .: = ::~~~= 3200 " " ". ~-' ._-,.............. :":: :==-',~?-~, II II II 'II -- -'"",,,,"~'-'- II -.'". II --------'::'-,- -~, -- ...... - ..... - .. 11'11 II 'II .......~,~~ 11'11 II' II -:~'...... --' ..---.; ~,'- ... II .-._~:-- ~ :.'. ' II ::-,---,,>,' ',,", .,',11 11"- II '.,' II ,II -....-'. .11,' 'II" 11'1" ,II ,'II, ,I I .'.' II '" ~'- ,II II II .' II ' II ' II . II ".,._~,,,,,.,.,.,.'. 11,1 3250 : ": I.: : :;:-...; :' ,:: :': :.: ,:: .. II, .. II '" ~;.... II .. ..' II ',II II, II ..'.. .. .. --.. 'II .. II '. II II ,II :: ..: :.:' ~-=-: ": : ': ': ,:',: II . II .. --- .. .. .. .. II .. II .. '.. '. """-.. .. '. .. II .'. II ... II "'~- ,',.'" '. .. "'. .. .. II .. --- II II II II .. .. . .. .. . ..' II .-..... .. .. 'II II II II . .. II," ,II .'_....... II II, II .. II II II 3300 :': : : ::..-...: ,:. : .: :, ,: .: .': ---.. ,I .. . ,..'. --:.... . ., II . . . . --,a .'. . . '. ',a -..;.. . . . .. . . --- . . . . . . . -:--- . '. . . . . . ....... --- . . . . . . . =-- -::.: ..:... :...:.:..:-=- ------ 3350 : : : : -------- ------ -------- ------ -------- ------ -------- ------ -------- ------ -- ... Ii III .. .. --- . . . . . . . -- . . . . . . . ....... 3400 : : : : "=--...: : : : : : : : ..... ....... . . . . . -- . . . . . . . . . . . . -- . . . . . . . ..... ....... . . . . . -- . . . . . . . . . . . . -- . . . . . . . ..... ....... . . . . . -- . . . . . . . . . . . . --. . . . . . . ..... ....... 3450 : : : : : :-...: : : : : : : : ..... ....... . . . . . -- . . . . . . . . . . . . -- . . . . . . . . . . . . -- . . . . . . . . . . . . -- . . . . . . . . . . . . -- . . . . . . . ..... ....... . . . . . -- . . . . . . . . . . . . -- . . . . . . . . . . . . -- . . . . . . . 3500 : : : : "..=-. ," " " . "-" ~ -------- ------ -------- ------- --------- ------- --------- )" ,t '\ ({ r ~ 1; \~ ,! ~~ -~i f~ )~ ~ ) >~ '} ~\ ~~' l ~~ < II : I ! I ': INC 48.60, AZ1197.75 SO : clr, dk gry - blk, vf - c gr, ang - sub rnd, prly srtd, un cons in slty cly mtx, pred qtz, lith frags, sme cht. 3107' MO INC 49.09, AZ1197.82 SO : clr, dk med - dk gry, f - c gr, ang - sub rnd, prly srtd, uncons in slty cly mtx, pred qtz, lith frags, sme cht. 32202.62' MO, INC 49.01, AZ1197.69 CL Y : It - m gry/brn, sft, amor, sli - v slty,n - v sli calc, sdy wI abnt thn Sd strgs. 3297.76' MO INC 48.33, AZ1198.12 SO : clr, dk med - dk gry, gn, tr yel, f - c gr, ang - sub rnd, prly srtd, uncons in slty cly mtx, pred qtz, lith frags, tr cht 3390.90' MO INC 49.10, AZ1198.54 SO : clr, mlky, med - dk gry, gn, f - vc gr, ang - sub rnd, prly srtd, uncons in slty cly mtx, pred qtz, lith frags, tr cht tr coal frags. I [ 3485.83' MO INC 48.57, AZ1198.97 CL Y : It - m gry/brn, sft, sli - v ~Ihl n - \1 ~Ii r::llr ~('hl wi ::Ihnt thn ( - ~ ~ ~ :;:;r ? J~7/0( { ~ --¿ ~ -..r ~ \:! ~ ~ '''.''5 ..."",,.....,~'" \ ~ 1~ ~ =~~~~/~~':'l ~ ".. New 3it J Ii I C [v1X~C1 I eakloff 13.7 ppg F~I ~ ..~ ¡l ~~ j\ ~~ ~~<[ "R S ; . 'II" " . -::L. . w--~.,- .b:~~ . .'. . - --------- -,.....------- ------ < -"""_,--:_-~,- ""----~~ ..,..'....- -- -~:--...,...'~'~'~- -..---~'---- -----~'-'---- ---,--- -,---,'---- - --..,.:--'-",- 3550 :: ' : : ------...-- ..... ----'- - --'--. -'----,--- --"~'-.-'~ ---'---..-- .- --~,-....'" -....,--~~-~.. --'--'--'''''' _._--,_._--- --'-'-""'-"""!18" -"",,~,.......---.....- -----'_.~ -.... .._~..... .......-- ,- ~~~'......~,~ - -- -'- tIiIIII!""-....- III ".' III -----",~.....,~-- 3600 :.' :",:,,,,:'1~,"'~~~~~~~ ~~-~-',~:~- .". -,'. ._-'--.-"""'--- . .',. . -~--""'-''''''- . "'- . '" "'--~~~,~:.- 8, 8o, -. ., :::-..=..-~~~~-::: . ,'. ". '. --:-:i----'-'~- .' ...',. .,~~:~'~:~~ . .,.,.'~~'7~~~~-:-~ . '. '.'. -'-'---,---""'''' .,'. ,."".'-""~~'~'~~"~ ." ", '.'., ~~'~,~~~~-:: 3650 .... ----~-~.....,. ::',:,":',,: 2'~"~=S~::~ .' tII . '. -----_._._'-'.. ."',' .'. :.:;.-;:;-..;-~~~~ . . ",' -,-'-'--:--'-"- . " . '. -'---'-'---- .' ." Ii ... .:'-:--~,~,-~'~ ':I~ "~','.'. ==-~~-==-~-;..; . . . . -~-,_:--'-~",," . ...' '. :.:--~-=--=-~-~~; .' ",' ";"--~-~-..;- 3700 :.::: =::?¿-Ë:' . "," . .'~:~'-~'~~ . . . .. -----_....._'-'- ~~~~~~~E~~ ,"".',~ ::..:-~-:~-~:~ e.,' .. . ....._-~'......._.......- :'...:., ::::'-~'-£~?-3E1 3750 :.:.: :-_-----=---~-..:-..: ",. ===-~--_-:.:-~~---=-~ " . ""----.-------" .'. ~-=--=-=:~-.;-~ . '. --.....--.....--.- . " ~,......'--:~~,-~- . . -------~-'~""" ""'-~--~~'---- . I- .--~,----- .,... ---,-,-----'. "" -,-----......,..,~...-:,- --,'--.-'--,-- . .111 -....-----....-,....... 3800: : :-_--=-_....._-:.:----~ ----.....----- . " ..---....-..-........,- . '. ----'_._--- .-. --_._---- ---------- . " ----.-....-- . " --------- " . -'....._-----~ -----,-~-~- " , ---,-'---- " " ----------- " " ...------.- --------.. . . -------..,- 3850 : : =----=--=--..=-_-..=-..:r ---'------- . . -------- . . --------- . . -------- -----'---- . .. -------- . . --------- . . -------- --------.. . . -------- . . --------- . . -------- --------- -------- 3900: : :=~----=------:..-..:'. -------- . . . ~------ . . . 8_- ""'" - - - - - - . . .. ~-- .. . . . . . . . . . ~...: . .. .. .. . . . . . . ---- . - . . . . . . . . ~ -~"'=-:"":..1..!..:- . . . ~-~ - - - - - - . .. . .--- . .. .. . .. . . . . . ,--- . .. .. .. .. .. .. .. .. .. ~-~---- 3950 : : : :=;;:-- . . . . . . . . .. .. .. .. -- .. . . .. .. .. .. .. .. .. .. .. -- .. .. .. . .. .. .. .. .. .. .. .. -- .. .. .. .. .. .. . .. .. .. . .. -- .. .. . .. . . .. .. .. .. .. .. -~----- .. .. .. .. .. -.-.--- --------- .. .. . .. . ----...-.-- .. . .. .. .. --- ----., : : : : : :...:: : : : : : : 4000 : : : ~..:.:..:.:.:..:.:..:-.: . . . ~..:-~ . .... . . ~- .. .. . ~- . . .. .. ~-~---- .. .. ~- ... III .. .. " ... . . ---,...,.----- . .. ---~-- ---~----- -----...-._- .. .. ----....._---- .. .. -------- -- ---------- (~ \\ 1!~ _~f +~ ~ ~ i ~ ); """ -f \' ? \ ,.9 I I II .. ) "NITS \ ~,J \ \ / < (I 1 I I \ I I .)" I "', "'''''1''. .. ...,,1 ...,\AI..." '/¡,Jul "W, ""...,1." ".n. Sd strgs, easily hydrtd. 3581.79' MO INC 49.16, AZ1198.90 CL Y : It - m gry/brn, sft, sli - v slty,n - v sli calc, sdy wi abnt thn Sd strgs, easily hydrtd. MW 9.4. VIS 60. PVIYP 17/32, GELS 12/29, PH 8.3, CL43K 3666.88' MO INC 48.69, AZ1198.56 CL Y : It-m gry/brn,sft,sli-v slty,sl calc,sdy,easily hydrated. 3760.88 MO 3215.63 TVO INC 48.03, AZ1197.79 CL Y :It-med gry,gry/brn,sft,sl-v slty,sl calc,sme sdy,hydrated. 3855.54 MO 3279.23 TVO INC 47.54, AZ1197.88 SO : clr,mlky,lt-m gry,vf-f gr,ang-subrnd,poorly srtd,unconsol in slty mtx,pred qtz. SO : cltr,mlky,lt-m gry,vf-f gr,ang-subrnd,poorly srtd, unconsol in skty mtx.pred qtz. ¡ I 3950.41 MO 3343.62 TVO INC 46.98. AZ1198.59 CL Y :: It-m gry,lbrn,sft,sli-v clt\l mr"'~ ('<11(' crl\l ..,oll h\lrlr<ltorl ¿i\ ~ ~ J..::..... f ~ <~ t - <--., R ".."......-............."""-..".....} t 't ~ 1.-. t ~ ::::::-- <- ~ -::::::- R - ......., I ?J ~ .. 'C [' i:-t iL I I I I Ii? :~ ¡{ I ~ { ~ .':.,~:~ -.~r! ,.",~,.,'.,'~,',I I, :: ",..-,.- ~.:= .'. ~~~,.:-~,~,~~ :': ~~~':-,7':'~ - -:-- _.-:--.....'~' ~ 4050 :: :-_-..:,.-:.--:-::-:-.::-:-:- ,,'. ~-:..;....-~,---'.....- " '. -------,-'........ ", '. """,---~_...~'.... --~,---'-,--- . . "'-'--.....--- "'I --'~,'';" " . ----"""'-,""- .,. I ~~---==-~-:.:-~-:: " I," --.....,-----,--- .' . --,~~-,---.......- """""--------88Ii!8- . ..' , .......'.... --.."....;;"" -...;- 4100.. =--~------.. : ':, :,':'2-:~~''''3î-&:: W." 1,1_'_---_----- . "," "~---=-~~~~ "',',', "--'-,_"""~",, ... ,_:_--,~'--... . ',' '. ,.,..~~~'..,~I'!I'- I, . :", ~~-=~~-:-~-:.: . . . '-~'----~'.._~ :,':'.:,:',::S ---~:S~?:: 4150 :,: :"":":':-";--=;::.:-';:'7:~~ ----~ , . ~ ',,'~''';;'';';'~-....-,--- . I,'" ,:.-......--......'~:........ .' '. "~I ""'~'~,~~~'..-¡. -'-----,-:....'~,- ',,' ,. '~~---..;.;.~~'~.;.... " '. ".1_.__:_:--'---- .',.. . ,~~,~-----~~ I ----,--'-'-- .' '.", '. ..'~~,~~:~...,;,~~ . '. ',. '..... - -- - ..... '..... '- .. :..,::.,:',2-~'~~:~=~:~ 4200: .:< ;.;:-..,..----=--=.."'-----= --,.......--~-:-- .,--"--'-'¡'-",,,,'- . '. --,-'-----'-- . . -'--,------,-'-.,- ----------- . '. ---,..--'i....,¡-',--- . . --------- . . -~,--~~~~--'~ . . ~--~-:.:::.:-~-----~-:.: . . ----~......_-- . . -~-~,""~~~ ....,- ---:'-..... ---,~ ~- . . -'-""'-~""''''',-~ 4250:: =-..:-_-=--:..---....-.; ----,------'. . III 1 81"""'----'''''-,--,-- . . ----..--------- . . =------==---~..:-_~-== . . .'-~~~--- . . ....._-----'--- . . -:......--,~--,..,...-- . . ;-----=--==-~..........--~ . 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'-";"" . . ._--....._-,,~,-- . .'.---~-'- ------- . . . --- ,,,,,,," - - - - - - . . . --- . . .'. . . . ... ....... 4400 : : : ~---= : : : : : : : ....... --- . . . . . . . -- . . . . . . . ..."... -------- ------ -------- ------ -------- ::-~. :::-:::- 4450 : : : : --- . . . . . . . -- . . . . . . . ....... --- . . . . . . . -- . . . . . . . ....... --- . . . . . . . -- . . . . . . . -- . . . . . . . --- . . . . . . . :-_~ .:..; ..: .:..; ..: . -~-- 4500 : : : ~=--:.:::...--=--...:..:. -----. - - - -- . . . -------- . . .----------- . . .--.---...- - - ---....._---- . . . --------- . . . ------- --------- . . . ------- . . . --------- . . . ------- --------- ------- ,., ¡:;¡:;(\ . . . -------_.J . . . '-------- ---------- -------- . . . ---------- -~) ~/ ( r> ~ 1 ) Ii" \ L II I 11 ~' \, :;5ri~s '). , ~ - ''\ _J ) ~ X '- < \i;- ~ I I I 'ì ~"'y,IIIV\.l \JUIV,\JUy,VV\:;i1l IIYUltU\,;U. 4045.57 MO 3406.18 TVO INC 50.80, AZ1198.46 SO :clr-mlky,lt gry,vf-fn gr,ang-subang,mnr subrnd,mod-well srtd,unconsol,v slty cly mtx,pred qtz. 4140.12 MO 3465.80 TVO INC 51.02, AZI 201.01 CL Y : It gy; v slty; sft; calc"sdy,sticky,well hydrated. 4235.21 MO 3526.08 TVO INC 50.29, AZI200.72 CL Y : It gy,-gy brn-brn; v slty; sft"sticky; mnr calc"wlintrbd sdy stringers,well hydrated, sl-mod sol. CL Y : It gy,-gy brn-brn; v slty; sft"sticky; mnr calc"w/intrbd sdy stringers,well hydrated, sl-mod sol. 4328.76 MO 3586.45 TVO INC 49.34, AZI 200.45 4424' MO INC 51.25, AZI 201.24 SO :clr-mlky,lt gry,f - cr gr, ang-subang, mnr subrnd,mod-well srtd,unconsol,v slty cly mtx,pred qtz. III I CL Y : It gy,-gy brn-brn; v slty; sft"sticky; mnr calc"w/intrbd sdy stringers,well hydrated, sl-mod sol. 4520' MO INC 51.27, AZI 200.57 \i .--" R ( ~' .~ ~ { ) jJ --4 ~ c-- .g..."."._...~..... ,-- ) ii - ) --- \ ~. ?C;- k- ? L- - I ~ \ \1 , I -< 'I ~ i I *' 1!~ !. (t ' -s ::i: E:"):2§2§ "TvvV .",. . ~~" ;..,~"~,~,~ -~~--~,~-'"",,- ., .,'. .....---:----~ .-,. '. --'';;''''--'--'-,-,:-,- .,' '.:,.'. .::;-~-::;;:-~~-~-: _,,'°,. ". ..;..............----,-,-- . . . -'---,--,---..- .' .'.. -,~':----~~~:-- ... :,.;--~. 'r"C.,." . . .' ---'...... ., ,I ",. ", . . . '. :-~~..;..;.- .. e." . .'.. . .. 'I,,' - ~ ;.....-:..... ~ ""','-:- 4600: .=-----;-.-:-:-.-;-:"" c.:""-,~ ~:~ ,-,~,...,'. . -............... _.- .. ....---. . :, c:-=--~~---=--::: .. ----,----'-,-- .. ,......--~ ~,---- .. c.:-...;...---- ---" --...;....--:..:; .. ",,------:~,-,'--,-'- . '~---------~-:::;..~ . 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SD :clr-mlky,lt gry,cf-fn gr,ang-subang,mnr subrnd,mod-well srtd,unconsol, V slty cly mtx,pred qtz. 4801' MD, 3884.8' TVD INC 50.54, AZI 202.7 CL Y : It gry/brn, sft, v slty, gmmy, occ sdy strgrs, n-v sli calc, sli sol. 4897' MD, 3946.6' TVD INC 49.59, AZI 201.04 CL Y : It gry/brn, sft, v slty, gmmy, occ sdy strgrs, n-v sli calc, sli sol. CL Y : It - m gry/brn, slty - v slty, ace thn sdy strgrs, v sli calc, gmmy, sft. 4992' MD, 4008.35 TVD INC 49.97, AZI 202.32 I I I CL Y : It - m gry/brn, slty - v slty, I ace thn sdy strgrs, v sli calc, gmmy, sft. f) S-, '5> ¡~ ~ \oJ ....- R \ 't ."" > S . """"~"."",","'"'''''-''''.''' R '1 '2 1'2Efee ' ./ . ~r s"".-- t {S \ > í~ § 1QI I ~ [, -i. I I I , ¡ I I I R -'---"""'"~--~ :~." -'~. )':":'::,::',:"':,::".::,,..::: ~~,-==-~, .' ..:".':'....:'. . _.,'.---- ',.,,1,.1, . ,I," ::3:-:= ::::::: .. -,--~,- I, . "," I,: ~,' ..' '-'----~-::"'-:"', '... ,., :":,,:' ," .-,~" " .. '. '. '. .. 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I I ~\ ,{ I I I, "qr " " } /. \ " 5088' MO, 4069.9' TVO INC 49.55, AZI 201.68 CL Y : It - m gry/brn, slty - v slty, acc thn sdy strgrs, v sli calc, gmmy, sft. CL Y : med - It gry/grybrn, slty - v slty, acc thn sdy strgrs, v sli calc, tr carb specks, gmmy, sft. 5182' MO, 4130.87' TVO INC 49.61, AZI 200.82 CL Y : med - It gry/grybrn, slty - v slty, acc thn sdy strgrs, v sli calc, tr carb specks, gmmy, sft. 5275' MO, 4191.18' TVO INC 49.7, AZ1201.96 5370' MO, 4252.81' TVO INC 49.45, AZI 200.71 CL Y : med - It gry/grybrn, decr slty, v sli sdy i/p, v sli calc, tr carb specks, gmmy, sft. 5464.8' MO, 4313.86' TVO INC 49.89, AZI 201.87 CL Y : med - It gry/grybrn, slty i/p, decr sdy, v sli calc, v gmmy, sft. I SL T : It gry, v sft, v arg, carb specks, sli micr mica, v sli calc, v sli - mad sdy i/p, gmmy. 5559' MO, 4374.95' TVO ..1,", ."". 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"100 .:-~-=---=. . . . . . . :> . , ----- . . . . . . . . ~--...: . . . - . .. . . ""'-'----""----- . 1-"------- ..r -::--=--..::. :---=---=..: '~ ~. ( \ ~ \ ¡''is } .r.' I , ? / / ~ J . , I , \ ~ ~ 'l ( 'J" ) ' , "ì " II I, I I I I.. I I ~ I I ì I I \ I I I 11<, II'JL, 4~.¿4, ALl ¿U'I.¿ö 5653.77' MO, 4437.06' TVO INC 48.94, AZI 201.27 SO : clr, trnsl, sli frstd, It gry, vf - m gr, sb ang - sb rnd, mod - prly srtd, slty cly mtx, uncons, . SL T :: It gry-mnr gry brn,v sft,v arg,scat carb specks,sl calc,mnr micrmica,sl calc,sli-mod sdy,v stky-gmmy. CL Y : med - It gry/grybrn, slty ¡¡p, decr sdy, v sli calc, v gmmy, sft. 5749.32' MO, 4499.64' TVO INC 49.23,AZI 201.98 5843.32' MO, 4561.34' TVO INC 48.83, AZI 201.95 CL Y : med - It gry/grybrn, slty i/p, incr sdy, v sli calc, v gmmy, sft,sli-mod carb. 5937.40' MO, 4623.59' TVO INC 48.20, AZI 201.10 SO :: clr,trnsl,mnr frstd,lt gry,vf-f,pred sb ang-sb rnd,occ ang,prly-mod srtd,slty cly mtx,unconsol,mnr carb. 6031.76' MO, 4686.68' TVO INC 47.88, AZ1200.94 CL Y :It-med gry,gry brn,mnr dk gry,v slty,dec sdy,sli calc,mnr carb,sft,ptly sol,v stky-gmmy. I I, I MW 9.5, VIS 50, PVIYP 16/28, GELS 15/30, PH 9.0, CL 39000 6124.17' MO, 4749.06' TVO 1"1'" ...,. ^'" "...,. f'\"'t"\ ^^ -¿::;..-"-...- - J} ~ StortTria~ 1212710(5. 18r¿ ".....,."_...,.._..~ I,. ~ ~ --- <> <:;. ~ --1 ( ~h_- /5 ~() <s ~ f? ~'- - ~ -c::....... S ~ '~ , I lIJ -6 ~I-'_.. ."\ :~:,'~,".:":".,,:,"...:'. .. -=-";"','" ), .'.,",., ." " ,.,..,., ." ..,.r:...,...;..;. ..' ..'.. .. '.'. ..'"~"~:,,,,, - ~,~~---,-.;, ..' 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J :: : =---::==: -=- ::=; ---- ---------- .---------- ----------- . , ----- . . 8__-......__--- , . .-"..------ ---------. -",.,.---- . . '--~------- . . .~",.,.---- '", J < 7 ~) J.i~s ~.. sr~ 98) J li~s \ /. \ I \ \. ~, ~ ;:J ~ ç-/ " -" ) '---,; .... ~ .~ ~ ~'r -.::: ~ ~ I I ~ ¡';)JJ.i'~ -4 "...õi I II ! ,I I ~. ¡--= ( "1'1 '\ .~:- "ì .-- ....- 11~1v 4/.¿¿, ALl ¿V¿.LJ " SD :clr-trnsl-mlky,sme frstd,lt gry,vf-f,oCC med,sb ang-sb rnd,prly-mod srtd,slty cly mtx,unconson,carb i/p. " I ( 6222.54' MD, 4815.98' TVD INC 47.04, AZ1201.21 ( 6316.56' MD, 4880.20' TVD \ INC 46.80, AZI 200.91 ~ SD :clr,trnsl,vf-f gr,occ med,lt gry,ang-sub ang,sme subrnd,mod-well srtd,unconsol,pred qtz,sltycly mtx. \ I ( CL Y :It-med gry,gry/brn,sft,stky,v slty,mnr calc,mnr carb,sl-mod sol. '"'''''''''' 6411.89' MD, 4945.78'TVD ( INC 46.26, AZI 201.59 SD :clr-trnsl,lt gry,pred vf-f,occ '\ med,prly-mod srtd,slty,w/v slty stky cly mtx,sl-mod sol. .r 6505.23' MD, 5010.96' TVD INC 45.17, AZ1203.06 ~ \~ MW 9.5, VIS 46, PVIYP 15/22 GELS 11/27, PH 8.8, CL 41000 .. CL Y :pred It-med gry,sl-mod sol,micromica i/p,sl-mod abnt carb mat,sft,stky-gmmy,w/intrbd vf-f mod srtd ang-sb ang qtz sd. l, 6600.34' MD, 5079.27' TVD ......., .^...." ..-.-^....^^ ~ ~ <.> f ,~ .. -<::::- \ ,~ -c- "-:5 {,.~ ~- - -t~ ') - ~.~ """""'-"'1 ' ~~ i . -::::::=-- ' "". ~-'"'-'''-''' ç-') c?) ~-~~ ~~ ~ ~2: ~ '-~ ,?~ f? ~~ ~----21 <-; c S I ~13 ~ ! I I ~-,- :J01!' i, :~ Ii ! I ! ¡ I i !,r;-p" '¡: I ~ I ~- I I I I . I ) R s R s S 1212E/OC :1-,.,,".. ==, " """~ .O1§"'.' .', +--,..'.~ . .".'~;',"~::- .', .',',. ~,,~" ,J:,~,~,,~,~,,- I ---'~~-'~"~ .. ."....,-~....,,~,,-:--,-- .' . '''.. --,,""'- -:":"--..I-i'.:- ~,',. 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Il18o-. ---- . . . . . . . . . ---- . . . . . . . . .r:.:...---....: . . . . . . . . "'-' ---- . . . . . . . . I - --- . . . . . . . . .r:.=----..: . . . . . . . - . - - ff-=:~~~ . . ~ . . ~- .~'~ '\ ! ,. ----. " ... ~ '?1 I~~ ",---- " ".. \ \ J I ~ \ ~ 1 / , C ~ / ..:Þ 7 ') / .... "'\ ( { ( ..... r '\ ", ( \ " ''>-- / '''"- ? / ì ~ ¡ 41 ;~ ~ f .~l i, \ I '~ .1 I \.J...~~'n:s / I[ ~ i I ~ .J.:.: I $ \ ( I b.. INl,; 4j.Ul, ALl ;¿Uj.~;¿ 6695.80' MO, 5150.86' TVO INC 39.80, AZI 205.36 CL Y :med-dk gry,mnr It-med gry,sft-sl frm,sl-mod sol,stky ¡/p,sl calc,mnr micromica,scat carb mat,v slty-sdy. SO :clr-trnsl,lt gry,pred vf-f,occ med,prly-mod srtd,slty,w/v slty stky cly mtx,sl-mod sol. MW 9.4 VIS 49 6789.16' MO, 5224.8' TVO INC 35.43, AZI 203.44 SL T : It gry, arg, sli sdy i/p, carb specks, grdg to slty cly. CL Y : It gry - gry/brn, sft, slty ~ v slty, gmmy, carb specks, n - v sli calc. 6883.86' MO, 5303.84' TVO INC 31.4, AZI 207.22 SO :clr-trnsl,lt gry,pred vf-f,occ med,prly-mod srtd,slty,w/v slty stky cly mtx,sl-mod sol. MW 9.4+ CL Y : It - m gry/ grybrn, sft, stky, gmmy, mod - v slty, abnt vf sdy strgrs, n - v sli calc. 6979.60' MO, 5386.55' TVO INC 29.07, AZI 204.33 CL Y : It - m gry/ grybrn, sft, stky, gmmy, mod - v slty, abnt vf sdy strgrs, n - v sli calc. 7073,70' MO, 5469.23' TVO INC 27.98, AZI 201.30 SL T : It gry, arg, sli sdy ¡/p, carb specks, grdg to slty cly. MW 9.4 VIS 46 PVIYP 14/28 GELS 14/30 PH 8.5 CL 39K SO : clr, trnsl, frstd ¡/p, vf-f gr, sb ang - sb rnd, mod - prly srtd, occ carb specks, uncons in slty cly mtx, nsofc. .,"" j ;~ ~~ --r ~0 _::S- J StortTrp<t7~ ¡ r ..-"- ~~_. ¿--' t:. --- <--::z.... ,S ..$ l2--- ~~~== ~. ~ ~..,.,-" .::::::> ~ r-~ ~~ ~ "" ' ~(> ~" . I <- --: ~~ ~þ !~I: l~ ! I.J-.. 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'" 7262.06' MO, 5637.38' TVO INC 26.44, AZ1200.67 ( SO :clr-trnsl,frstd i/p,vf-f gr,occ m,pred ang-sb ang,sme sb rnd,prly-mod srtd,scat carb specks,unconsol in slty cly mtx. /'/' '\ ( 7356.04' MO, 5721.65' TVO INC 26.11, AZ1199.12 7450.34' MO, 5806.37' TVO INC 25.98, AZ1199.68 " < MW 9.5 VIS 45 I CL Y : It - m gry/ grybrn, sft, stky, gmmy, mod - v slty, abnt vf sdy strgrs, n - v sli calc. '\ 7544.26' MO, 5890.59' TVO INC 26.58, AZ1204.12 I <I \ Ii I CL Y : It - m gryl grybrn, sft, stky, gmmy, mod - v slty, abnt vf sdy strgrs, n - v sli calc. I 1. 7638.44' MO, 5974.89' TVD INC 26.46, AZI 204.59 ?--. ~ '< ~ ~ \ I ( ~ \ <;.. ~ 1 ~~ > ..,. -s. -4 ¡ ( ~-~- -<... ~ r-' 2' ?- =--$- r' '" ') r Bil #2 - L318', '56.3 h's. 1212910~6/01 ~ Set 715/~ CSG (à 8C 29' NEW -8F1it~ X I C. J. ~or L~I.T at 8034' M L.O.T.= 1~ ppg Er.JW ~ ~. i fl ~I ... I '"* ~ 1'1.1 ::: ~..'."..'. ~..:'.~:.I.,\...... :...:. :. :.:.: .~g..... ~"""""-l 8:'''''''''''___:'''.,'.'.8",8,.,'. 8,1 ~~-- 'e,'". ."'.'.,"'. . 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P\ (~~ I~ .......,..t.., .,............. 815~tt::ttt~~ :tttt::ttttttttt :~~~~:~~tt:j;~~~~~ .......,-... ~t~t~~::~-:-.. ~ ::::~_. :.: :.~ " ~II \ ,/ ) ') ," SD :clr,trnsl"mnr mlky,frstd ilp,vf-f gr,occ m,pre sb ang-sb rnd, mnr amts ang,prly-mod srtd,com carb specks,unconsol,wlslty It-m gry cly .. mtx. l I \ 7732.30' MD, 6058.88' TVD INC 26.56, AZI 203.41 CL Y : gry - gry/brn, sft, gmmy, stky, n - v sli calc, sli - v slty, acc thn sdy strgrs.. ( . f~ ~ \ SL T : It gry, arg, sli sdy ¡/p, carb , specks, grdg to slty cly. " , ) 7827.04' MD, 6143.74' TVD ~ INC 26.25, AZ1204.03 ~ ~þ \. \.. / ,j SD :clr, trnsl, It gry, tr mlky, frstd ¡¡p, vf-f gr, occ med, pre sb ang-sb rnd, prly-mod srtd, occ carb specks, ) uncons wlslty It-m gry cly mtx. ----- ~ \ 7920.13' MD, 6227.30' TVD ~ INC 26.06, AZI 201.95 C~ < MW 9.4, VIS 46, PVIYP 14/28 GELS 14/30, PH 8.5, CL 39000 'r 7986.52' MD, 6287.04' TVD INC 25.69, AZI 203.62 " " C.O. for E-Lags at 8044' MD --- MW 9.4, VIS 60, PV1YP 20/31 , GELS 12/24, PH 10.7, CL 38K 8065.35'MD 6357.8'TVD " INC 26.65 AZI 202.66 ..... SST : Itgy, wh, clr ip, vf-mgr, ì ang-sbang, msrt, pred vfri, mcmtd ¡p, uncons ip sme calct cmt 70% " qtz, 30% lith+cht frags, slty lams ¡p, nsafc.. ( 8159.62' MD 6440.44' TVD INC 30.79, AZI 200.17 II, SST: clr-fstd,wh, blk,tr Iygy, f-mgr, I cgr ¡p, ang-sbang,sme sbrnd, II I m-wsrt, pred vfri, uncons ¡p, chlky I II I calct, 60% qtz, 20% blk mgr cht I ) (silic coal) frags,20% lith+clky Is 371 -~N frags,nsofc. 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"............. 8217.35' MD, 6489.43' TVD INC 33.08, AZ1198.95 ~.~ I~~~"~'~ .~~~.~:: .:~~~~:~.: \ 8246.00' MD, 6513.28' TVD INC 34.20 , AZ1198.40 PROJECTED TO TO Rê:9" Gas Chromatograph m r r- Z MAX GAS Gamma Ray ""U "'U :::¡ ::¡ ;;uQ C1 Avg - 0< -I < -4 Lithology Trace 0 api 150 è5Cñ I I ::c m »ï C4 Total 0 ëñ O :xl -I en lad ~ f¥idI1A~ C2 Avg - enc " C ." -:I: -» m r r- :xI Zo C5 Total Logging ROP Avg ~ï m 0 » 0 m G)~ C3 Avg - -I G) r G') -4 m RESCALE x1 0 feet per hr -< -< c 500 0 6--1 MD 1--6 0 100 100 1,K 10K 100K 1 M ":~" ::':" .:.:..~::.".~,".. .. ~, .') DIRECTIONAL SURVEY REPORT BP Alaska Northstar NS-1 01WD-01 Northstar North Slope Borough Alaska United States AKAM00307 SURVEY INFORMATION PROVIDED BY ANADRILL SCHLUMBERGER Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogle~ (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/10 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 385.52 1.84 7.60 385.45 6.14 N 0.82 E -6.01 0.48 476.11 1.82 6.00 476.00 9.01 N 1.16 E -8.81 0.06 565.89 1.66 10.40 565.74 11.70 N 1.55 E -11.47 0.23 657.37 1.39 358.30 657.18 14.12 N 1.75 E -13.79 0.46 746.00 1.17 260.30 745.80 15.04 N 0.83 E -14.31 2.19 833.23 2.55 214.40 832.99 13.29 N 1.15 W -11.96 2.21 932.53 3.72 217 .90 932.14 8.92 N 4.37 W -6.73 1.19 1027.76 5.88 211.00 1027.03 2.30 N 8.78 W 1.04 2.34 1121.34 7.69 207.06 1119.95 7.38 S 14.10 W 12.00 2.00 1215.21 8.89 206.08 1212.84 19.49 S 20.15 W 25.48 1.29 1310.48 10.08 208.87 1306.80 33.40 S 27.41 W 41.08 1.34 1407.83 11.50 205.95 1402.43 49.59 S 35.77 W 59.20 1.56 1501.19 12.91 198.69 1493.68 67.84 S 43.19 W 78.89 2.23 1596.17 13.85 198.91 1586.08 88.65 S 50.27 W 100.85 0.99 1690.01 16.34 202.99 1676.68 111.43 S 59.07 W 125.27 2.88 1784.56 19.07 205.14 1766.74 137.66 S 70.83 W 153.98 2.97 1879.16 21.93 205.17 1855.34 167.64 S 84.91 W 187.03 3.02 1974.26 27.25 207.78 1941.79 203.01 S 102.62 W 226.41 5.71 2067.11 30.28 208.07 2023.17 242.48 S 123.55 W 270.79 3.27 2162.61 31.97 202.20 2104.94 287.14 S 144.44 W 319.99 3.63 2256.19 35.57 200.99 2182.72 335.51 S 163.55 W 372.00 3.91 2351.18 39.03 202.21 2258.27 389.01 S 184.76 W 429.55 3.72 2446.19 43.02 201.95 2329.94 446.79 S 208.20 W 491.89 4.20 2540.31 45.97 200.60 2397.07 508.26 S 232.11 W 557.85 3.29 2634.Q1 46.27 197.9~ 2462.65 572.61 S 254.63 W 625.98 2.02 ) , A TOTAL CORREC11ON of 26.93 lEG fROM MÀGNETIC NOR:TH TO TRUE Nt.,. ' ~ HAS 'BEelAPPUED HORIZONTAL DISPLAC8VENT IS R8.A11VE TO 11-IE W8.l. HEAD, HORIZONTAL DISPlACEMENI'(CLOSURE} AT 8217.35 FEET IS 4382.37 FEET ALONG 201.29 DEGREES (TRUE) 'l..-- -.-.-.. - _)5:37 W 2727.53 44.88 198.58 2527.48 635.41 S 692.03 1.57 2821.92 46.13 199.06 2593.63 699.14 S 297.09 W 759.30 1.37 2917.75 47.53 198.05 2659.19 765.40 S 319.32 W 829.11 1.65 3012.50 48.60 197.75 2722.51 832.47 S 340.99 W 899.47 1.15 3107.88 49.09 197.92 2785.28 900.83 S 362.98 W 971.15 0.53 3202.62 49.01 197.69 2847.37 968.96 S 384.86 W 1042.57 0.20 3297.76 48.33 198.12 2910.20 1036.94 S 406.82 W 1113.89 0.79 3390.96 49.10 198.54 2971.69 1103.42 S 428.85 W 1183.83 0.89 3485.83 48.57 198.97 3034.14 1171.05 S 451.81 W 1255.18 0.65 3581.79 49.16 198.90 3097.27 1239.41 S 475.26 W 1327.39 0.62 3666.88 48.69 198.56 3153.17 1300.16 S 495.86 W 1391.47 0.63 3760.88 48.03 197.79 3215.63 1366.90 S 517.78 W 1461.61 0.93 3855.54 47.54 197.88 3279.24 1433.64 S 539.25 W 1531.59 0.52 3950.41 46.98 198.59 3343.62 1499.82 S 561.05 W 1601.17 0.81 4045.57 50.80 198.46 3406.18 1567.79 S 583.82 W 1672.77 4.02 4140.12 51.02 201.01 3465.80 1636.85 S 608.60 W 1746.12 2.11 4235.21 50.29 200.72 3526.09 1705.57 S 634.80 W 1819.65 0.80 4328.76 49.34 200.45 3586.45 1772.47 S 659.92 W 1891.12 1.04 4424.39 51.35 201.24 3647.48 1841.27 S 686.13 W 1964.73 2.20 4520.13 51.27 200.63 3707.32 1911.06 S 712.83 W 2039.46 0.50 4615.13 50.43 199.95 3767.30 1980.16 S 738.38 W 2113.12 1.04 4707.70 51.14 203.08 3825.84 2046.87 S 764.69 W 2184.83 2.73 4801.06 50.54 202.70 3884.79 2113.56 S 792.84 W 2257.19 0.72 4897.39 49.59 201.04 3946.63 2182.10 S 820.36 W 2331.04 1.65 4992.97 49.97 202.32 4008.35 2249.91 S 847.33 W 2404.02 1.10 5088.27 49.51 201.68 4069.94 2317.34 S 874.57 W 2476.74 0.70 5182.29 49.61 200.82 4130.92 2384.03 S 900.50 W 2548.29 0.70 5275.45 49.70 201.96 4191.24 2450.14 S 926.40 W 2619.29 0.94 5370.49 49.45 200.71 4252.87 2517.53 S 952.72 W 2691.64 1.04 5464.32 49.89 201.87 4313.59 2584.17 S 978.70 W 2763.17 1.05 5559.08 49.24 201.28 4375.05 2651.25 S 1005.22 W 2835.29 0.83 5653.77 48.94 201.27 4437.06 2717.93 S 1031.18 W 2906.85 0.32 5749.32 49.23 201.98 4499.64 2785.05 S 1057.80 W 2979.06 0.64 5843.42 48.83 201.95 4561.34 2850.94 S 1084.37 W 3050.10 0.43 5937.40 48.20 201.10 4623.60 2916.43 S 1110.20 W 3120.50 0.95 6031.76 47.88 200.94 4686.69 2981.93 S 1135.37 W 3190.67 0.36 6124.17 47.22 202.23 4749.06 3045.34 S 1160.45 W 3258.85 1.25 6222.54 47.04 201.21 4815.98 3112.31 S 1187.13 W 3330.94 0.78 6316.56 46.80 200.91 4880.20 3176.40 S 1211.81 W 3399.61 0.35 6411.89 46.26 201.59 4945.79 3240.88 S 1236.88 W 3468.80 0.77 6505.23 45.17 203.06 5010.96 3302.69 S 1262.26 W 3535.60 1.62 6600.34 43.01 203.92 5079.27 3363.38 S 1288.62 W 3601.72 2.36 6695.06 39.80 205.36 5150.31 3420.32 S 1314.71 W 3664.25 3.53 6789.16 35.43 203.44 5224.83 3472.58 S 1338.48 W 3721.58 4.81 6883.86 31.40 207.22 5303.87 3519.73 S 1360.69 W 3773.58 4.79 6979.60 29.07 204.33 5386.58 3563.11 S 1381.68 W 3821.62 2.87 7073.70 27.98 201.51 5469.26 3604.48 S 1399.20 W 3866.52 1.84 7168.93 26.35 200.16 5553.99 3645.11 S 1414.67 W 3910.00 1.83 7262.06 26.44 200.67 5637.41 3683.91 S 1429.12 W 3951.39 0.26 7356.04 26.11 199.12 5721.68 3723.02 S 1443.28 W 3992.98 0.81 7450.34 25.98 199.68 5806.40 3762.08 S 1457.03 W 4034.36 0.29 7544.26 26.58 204.12 5890.62 3800.63 S 1472.54 W 4075.92 2.19 7638.44 26.46 204.59 5974.89 3838.94 S 1489.89 W 4117.91 0.26 7732.30 26.56 203.41 6058.89 3877.21 S 1506.92 W 4159.75 0.57 7827.04 26.25 204.03 6143.74 3915.78 S 1523.87 W 4201.85 0.44 7920.13 26.06 201.95 6227.30 3953.55 S 1539.90 W 4242.86 1.01 7986.52 25.69 203.62 6287.04 3980.26 S 1551.12 W 4271.82 1.23 8065.35 26.65 202.66 6357.79 4012.23 S 1564.77 W 4306.57 1.33 8159.62 30.79 200.17 6440.44 4054.41 S 1581.25 W 4351.85 4.57 8217.35 33.08 198.95 6489.43 4083.19 S 1591.46 W 4382.37 4.12 CALClJ.A'OON BASED ON W&1U\1 ClRVATlÆ PÆTHOD SURVEY COORDNA1ES RB.A11VE TO WBl. SYSTEM Kl:t"t::t<t:IŒ PONT 1VD VALUES GIVEN R8.A11VE TO DRIL.L.N; rÆASURBÆNT PONT vætr.AL. SECTDI RELAllVE TO VVEl.L tEAD VERT1CAL SEC110N IS COI\FUTED ALONG A ClOSURE OF :æt.29 DEGREES rrRUE1 SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company WELL NS-14 COMPANY BP ALASKA LOCATION NORTH SLOPE, ALASKA ~== === == === === == LEGEND === === -.:= === == == ) == 10,000 Units Total Gas in Air = 100 % = 1 ~OO ppm == NB New Bit NCB New Core Bit CKF Check for Flow NR No Returns CO Circulate Out LA T Log after Trip TG Trip Gas CG Connection Gas DST Drill Stem Test DC Depth Correction STG Short Trip Gas SVY Direc Survey LOGGING SERVICE ~JI ~RII:UII:ìll"5111IitE'!! .. ~ '. \.. .1;"".' I. . . . . . . ..1 ~""""""'''''''''''''''1 ~..- ..- .'g §---§ 1 .... ",.' " ~.. :.:.:.:':.:':.:':.:I:.:.:.:'._~~-'.."~:.. ,,~:~~~'. " '" ":',, "'",, :.'''.'''.1:.1:.1...1.". ..'::'7~-::-":'::'.. 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'\'l5 ~ CL Y : It- m gry, amor, stky, v slty grdg to sdy, micr mic. - SO ,-....,....... : wh, clr-trsl, blk, vf-f gr, ang - I sb ang, mod srt, uncons, cly mtx, noncalc, nsofc. ",. ...,_......... ,,_~(I !.ßI ... (1M:; , II ( 47 ... IIi.S CL Y : It- m gry, dk ¡p, amor, , stky, v slty grdg to sdy, micr mic & tf. - SO: wh, clr-trsl, blk, vf-f gr, ang - sb ang, mod srt, " uncons, cly mtx, noncalc, nsofc. 31 ni:!. \ 1 :X:\n1.s CL Y : It- m gry, It brn ip, amor, ".. /~" stky, v slty grdg to sdy, micr mic. - SO : wh, clr-trsl. blk. vf-f '" gr, ang - sb ang, mod srt, I uneons, ely mix. noneale, nsofc. ~...II~ I ~~ ...IILs ) CL Y : It- m gry, It bm ¡p, amor, stky, cly grdg to slty, micr mic. - SD : who clr-trsl, blk, vf-f gr, ) ang - sb ang, mod srt, uncons, cly mtx, noncalc, nsofc. ~) ... nr.s I ~r .J~ ~- 1\ .--. ~ , ...,. "'"'....-..--: ~,","" ~:C : t --~ nAil' .) ~ ~-.wO? ~ t ~,'~ -~~ ~ Î ~ ~..,r '-.'} ~ I, - ~ .,- t¡°":"'" I ~_I , -1. I~' I I . ' .,-...".,.-"'. ..-......--.. _lr ¿ /_..".. 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LO : ~~...:"~. .. .-"-~----:o- -._-- -'---_.. ,----81i!118---- _.- .. ---- ------ " :.=::--_---:-_~~-=: . ---....-~ -- . ---,- -----'. .. .~-~~.:.- --,-,-, --,--'-. a .. .-"~~-~ 0 N LO 0 LO ('f) LO ~ ~ II~ 2...ld:5 ~ CL Y : It- m gry, It brn ip, amor, stky, cly grdg to slty, micr mic. - SO : wh, clr-trsl, blk, vf-f gr, ang - sb ang, mod srt, uncons, cly mtx, noncalc, nsofc. r¡J ... íli:s , MW 9.2, VIS 52, PVNP 15/29 GELS 10/14/0, PH 7.5, CL 16K 1 '" ..- I ~~ ...1Ii:S ~ CL Y : It- m gry, It brn ¡p, amor, stky, cly grdg to slty, micr mic. - so : wh, clr-trsl, blk, vf-f gr, - md ¡p, ang - sb ang, mod srt, uncons, cly mtx, noncalc, nsofc. " ...4 ...Iìi:s ; ......... I .., \ ( ~ "7: ... Iìi:S '\ rJ "" ñ DGRCorrbinooGarrmaRa~ ï r- - 0 Shallow EWR Phase Res10 Gas Chromatograph '1J - _Z 0 0 api 150 ~ ~ :i:::; :£! ~ ~ ¡::: EWR Deep Phase Res GC11n!vl C1 Av~ - ~ Lithology Trace oC:MD 0 en 0 ~ =:!enO 10GC41'~C~A OC1~C4!i1.A¡g en» ï C r-::o z::I: - InlYl'v~ - - ROP Avg ~ r 0 ~ O!!l (j) ~ Lag Gas Hydrcbn Max GC1InMC~Avg - OC1~CSTliIAI9 ~ ~ 2} l~ Gas H~rcbnAvg - 500 feet per hr 0 6---' FT 1---E. 0 400 100 1 K 10K 1 OOK 1 M WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company WELL NS27 COMPANY BPÞLA9<A LOCATION NORTH SLOPE, ALASKA 1== === == === === == LEGEND === ===- )= === == == == 10,000 Units Total Gas in Air = 100 % = 1,000,000 ppm == NB NeNBit NC8 NewCaeBi CKF Check for Flow NR No Returns CO CiræleQt LAT lq¡*Trp TG Trip Gas æ Qrmixl<:Œ O8T DiStanTest IX; ~Conm1 STG SutTrp<:Œ SVY Direc Survey ~~~~I~~ SYSTEMS I r"'..I."".'I"~i I [::~::m::::m~~:] ~ SaIIIre I §-=~~ I I - f;.~':);t'l I{:.//~/ IIIIIIII111 I~.~:~' ~ ~. ;:;¡. I III ca,m ~ [II ~ ~ WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. Max Gas Gas Chromatograph "U c: c z 0 < -I < -I -I ;;0 ~ C1 Avg - 150 ;;0 U5 I Cñ ::1:0 m ::¡ en C2A C4TotalAvg ~ ~ MD þ2 C r:;õ Z Ô Avg Gas vg - - =<! ro » Om (j):E C3Avg - C5 Total Avg G) r (j)-I -< -< ~ RESCALE x10 - FT 1--6 0 100 100 1K 10K 100K 1M ..u.\. ":"""_--~-_-:-=--....:-_--~ I I . ---------- ------------ 0 Gamma Ray api ROP Avg 1 K feet per hr 0 6--1 WO B 20.30 -S ¡ RrM 30 :> SPP 12(0 GPM 64) ~ 13 3/8" CSG SET A h23~ ~:~".:: 5.5 P JG E~IW . ~ß-m/o' } ~~ C83CS TFA 1,037 ~tJ)2''37' MD N!iÐS386HPX -FA 1.031 ...aæ-xxxx' ~ D ? ... ¡ ~ ~ L t { ~ I Sl'de -Rctat'C>~ r Lithology Trace . I ,. I I ---------- --.---------- ---------- ------------ ----..------ ------------- ---------- ------------ ---------..- -( CL Y :It-m gy, vsft-sft,slty, tr v f gr sd, stky. ------------ ---------- ? 3:ID :.:-:..-.-:-=---= :....--=------= --..---------- \ ---------- --.---------- ----------- .t I' I MW 9.0 ,VS45 ,PV/YP 13/16 GELS 6/6, PH 9.2t- CL 50000 3278.91' MD, 32J5.78' TVD INC 10.87, AZ1184,07 ------------ ---------- ------------ ---------- ~-=---::~=-=-=-== ---------- ------------ ---------- 3m ~-_-=-:--= :....-_-=-:---:..:J \ ----------- --------- ----------- ----------'-- ----------- --------- ---------- --------- ----------- --------- ---------- --------- ----------- SD : clr, trnsl,wh,tn,dk gy, f-m gr,sb ang-rnd,m srtd,uncons,tr pyr,cht,no show. -------- 3fi) ---------- --------- ---------- -------- ---------- --------- ----------- --------- ---------- 3373.37' MD, 3348.40' TVD INC 11.83, AZ1181.34 -------- ---------- --------- ---------- -------- ----------- --------- 24D "':....---....:- -=---=---=---:.:1 ----------- --------- ----------- --------- ---------- --------- ---------- --------- \ I CL Y :It-m gy, vsft-sft,v slty, tr v f gr sd, stky. ----------- --------- I ! I I ---------- ---------- ---------- ---------- Jfl) =------=--=---=---=----= ---------- --------- ---------- --------- ---------- ---------- f')At::'O 0('\1 .an "1 A ....... "'" T\/n ------------ ---------- ----------- ., ~ "Sl'de ~ -Rctat: <~ - 'i~UB 1.0. ~ ~,,1 '50.'80 .sFP 1650 ~PM 80) , ;:::::.. 'pt'" - 'pi"""'.'"'''.''''''''.'''''''''''''''''''''''''''.''''''' 02(1,,1/0' Slide Rc tat ~ "",,,,,,.,,,,. -.."..... "...,..,,,...,,..., > ~ > ? "==\. ~ SI'de Rctat~ WOB 0-: ~ RrM 50-80. SPP 17(0 I GPM 80) ¿ ç ~ S Z- .¿ .~ ~ ~ ~ « -=, -.,> : '\.! ~< E~-~~=~ ---------- ----------- ---------- ----------- ---------- ----------- ---------- EJ ~---=--:':~-=--=-----=I ----------- --------- ----------- --------- ----------- --------- -----....----- ---------- ----------- --------- ----------- --------- ----------- --------- :mJ ----------- --------- --..--------- --------- ----------- --------- ---...--...----- --------- --~-..--------- --------- ---...-----.---- --------- ------..------ ------"'--- ...---------- --------- 33] ~---=--....: ~--------1 -------------- --------- ------------- --------- - - -. - -,..,.- - -,.-- -------- -------------- --------- ----------- --------- ----------- .--------- ----------- --------- E) ----------- -------- -...---------- ---------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- 3iO) ".=-----,.-....: ~-=- -=-----=1 ----------- ---------- ----------- ... ~,.--~--=- -: =-=--=---=--:.:: ......---------- ----------- ------------ ----------- ----------- ----------- ----------- --.---------- -----,...----- 37ff) =--,.---=-..=-,.-~,.----,.- -=- -:.: -.----,...----- ---------- --------------- ---.------- ------------ ---_---.0_----- ------------ ---------- ------------ ---------- ----------- ---------- ----------- ---------- :mJ =-,.--=----....:=--=--=-----=1 ----------- ---------- ----------- ---------- ----------- ---------- ----------- ---------- ----------- ---------- ----------- --------- ----------- ---------- :ffi) =-------....: ~------=-....: ----------- --------- ---------- ---------- ----------- ---------- ----------- ---------- ---------- --------- ---------- ---------- ---------- ---------- 1ID ~------=-=- -=------=-=1 ---------- -------- ----------- --------- ---------- --------- ---------- -------- ----------- --------- ----------- --------- ----------- -------- 1H) ----------- --------- ---------- --------- ---------- -------- ---------- -------- ---------- --------- ---------- --------- ---------- --------- ----------- --------- ----------- --------- , ~ , .-. ..... .~. t~ ) \ ~ I (I I (I ,!~~!. I, . ! I I J . I ... L~ I I- II' I I 1 \ I !I , I ì L ._"H_' . "'+OO.OV IVIU, ,,'+'+ I.~V I V U INC 11.24, AZ1184.84 CL Y :It-m gy, vsft-sft,V slty, tr v f gr sd, stky. 3563.20' MD, 3534.31' TVD INC 12.35, AZI179.92 SO :clr,wh,trnsl.dk gy-blk,f-m gr,sb ang-sb rnd,w srtd,uncons, qtz,tr pyr, cht, no show. 3657.83' MD, 3626.72' TVD INC 112.50, AZ1181.30 MW 9.0 ,VS 45,PV/YP 13/23 GELS 7/10, PH 9.0, CL 50000 3750.85' MD, 3717.61' TVD INC 12.06, AZ1179.24 CL Y :It-m gy, vsft-sft,v slty,grdn sltst,tr v f gr sd, stky. 3844.69' MD, 3809.32' TVD INC 12.41, AZ1180.42 CL Y :It-m gy, vsft-sft,v slty,grdn sltst,tr v f gr sd, stky. 3937.50' MD, 3899.97' TVD INC 12.37, AZ1178.35 CL Y :It-m gy, vsft-sft,v slty,grdn sltst,tr v f gr sd, stky. SI'de . Rc;,t.a.t 3 WOS 18-22 .HPM 50 SPP 18C 0 '(3"P'M" 78 5 Sl'de Rctat:! Sl"de Retate } "."¿~"""")"""'.""'.,..""" -~ ¡ I ( ~ ~ ~ I -.". i { { ~ <' ~ I f~ =--=--=-- -:L-=--_-_--= E-_-_-=--= --- ..----- 4aI) =-------==----=-----=) ---.-------- -------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- ----------- --------- 4ŒD ----------- --------- ----------- --------"""'--- ----------- --------- ---------- --..-----.- ------------ --------- ------------ ---------- ---------- ---------- ----------- -------- 41ffi ,------=':""-=------=1 -....--------- ----------- ---------- --------- -..--------- --------- ---------- --------- ---------- --------- ---------- --------- ---------- 41ffi =---=--= w.. - - --- -------'''"''----- --------- ---------- --------- .----------- --------- ---------- ---------- ---------- 4aD -- --------- .-------- --------- ------- --------- -------- --------- ------- ....----..---- ---..---- -----...---- 42D ------- 43D --== =- -=.=- -=- -=---=1 ---""""'-------- --------- ----------- -------- ----------- --------- ------------ --------- ----------- --------- ----------- -------- ---------- -------- 4JD ---------- --------- ----------- --------- ---------- ----- ---- ----- ---- ----- ---------- --------- ----------- -------- 4(1) ==--------=------=---=J ._---- ------ ---------- .----- ------ ---------- ----- ------ ---------- .----- ------ ---------- ----- ------ ---------- ----- ------ ---------- '----- ------ ---------- 44ff) ~---=-_-:..: =---------= .----- ------ ---------- ----- ------ ---------- .----- ------ ---------- .----- ------ ---------- ----- ------ ---------- .---------- ---------- '----- ------ ---------- 4ffi) :.:;;=-. ------=. =--------...:¡ ---------- ---- ----- ---- ----- ---- (~ \ I ( ~I -~) ---- ~ )) .~~rTR J f ~~\ITS ~ ~ , ~ ~! II I it{- )' I .k I 1""°""'" ( \ I < IIV , I '" 4031.54' MD, 3991.89 'TVD INC 12.08*, AZI176.04* CL Y :It-m gy, vsft-sft,v slty,grdn sltst,tr v f gr sd, stky. 4125.76' MD, 4083.94' TVD INC 12.55, AZI174.82 SO :Itgy, clr, blk, m-dkgy ip, f-mgr, ang-sbang, m-wsrt, uncons, 50% qtz, 30% lith frags, 20% f-mgr lig coal frags, slty cly mtx, tr xsm gravel frags, no show. 4219.82' MD, 4175.77' TVD INC 12.42, AZ1174.35 SO :orng, blk, It-dkgy, wh, m-vcgr, ang-sbang, m-wsrt, uncons, 60% qtz, 20% lith frags, 20% lig coal frags, slty intbds, cly mtx, no show. MW 9.1 ,VS 46,PV/YP 12/22 G~~ ~./g~' ~~, ~~6r.~~6p8B INC 11.56, AZ1181.42 CL Y :Itgy, gmmy, sol, hyd, v slty-grdg to clyy sltst, sme imbd sd gr, vsft. 4412.09' MD, 4364.03' TVD INC 11.43 , AZ1187.40 CL Y :Itgy, gmmy, sticky, hyd deer sol, vslty-slty, tr imbd sd gr, sme mic carb mtl ¡p, v sft . 4S0~ S~' Mn 44S~ SO' Tvn Sl'de == '~ta:t ~."'''' WOB o-e ..RPM 85 ",§,f P 1ge,o GPM 79j SI'de Sf- ORT TR P ,~ta~= "",,,.,, ''''',' "_..,,.. .... t' > - SI'de Rc tate ~ ~- \ ~ ~ ß ~ , f \ ~ -" .> -- ~ ~ ...s- ~ ~J ¿ ~ i I \.J I I\ <J,r Rct;: t~ I ~ "-L !, I - ~M- ~~¿!: ¡:: , , WO 80".. i .-1 i RF'M -50 I ~ SPP ~ 8CO GPM 795 " . .... Sl'de ~ .''':.:l1lI' <: ~ ~--"""1t----- :-~ T--=-"--=--= ----,- ----- ----- .----- ---- ----------- ----- ---- ----- ---- 4ffi) =-------=;----- ---- ------ ----------- --------- ------------ ----------- ----------- ---------- ----------- ---------- --.-------- ---------- 4ffX) ..=-------=---------=1 ----------.- ---------- ---------- --------- ------------ ---------- ----.-------- ---------- ----------- ---------- ---------- ----------- ------------ ---------- 4ffi) ::.:::_----==----=---=--= ----------- --------- ----------- ---~-,- ----- ----------- ---'------- ------------ ------------- ----------- ---------- _.._---------~- ---------- ---- ----- 4iUJ :::;::..------= ----- ---- ---- .. ---------- ----------- --------- ----------- --------- ----------- ---------- ------------ ---------- ----------- -.-.-------- 47!Ð ----------- ------------ ----------- --------- ---- ---"-'-- ---..- ...-.--- ------.--..- ---..-----..----- --------- ----- ------ ---------- ----------- --------- 48D :':---=-::':':""---=--=--=1 ---------- --------- ---------- ---------- ---------- --------- ---------- -------- ---------- --------- 4ffi) ---------- --------- ---., - -'" --------- =------== 4WJ ------- - -------- ------ ------- ------ ------- ------ m ------ ------- 5JD .:--=-----~ ------- ---- ------- ------- ------ ------- ¿J '( ~s --I 1"ÒT-ð-S' \ , ~ )4ì.1I\118 / J I \1 1, ~! .; III I III I I I III i \ \ J ) ,I :\ .-...-.-- ..._, . .--.-.... ..- INC 12.39, AZ1186.21 SO :Itgy,blk, vfgr, sme cgr, sbang, msrt,uncons + imbd in cly, abnt slty cly mtx, mic carb mtl, no show. 4597.17' MD, 4545.01' TVD INC 12.12, AZ1186.04 CL Y :It-mgy, gmmy, sticky, hyd, sli sol, vslty-slty, tr imbd sd gr, sme vfgr sd ip, sme mgr coal frags ip, v sft . 4693.54' MO, 44639.21' TVO INC 12.15, AZ1184.43 - CL Y :It-mgy, gmmy, sli sol, incr sticky, vslty, intbd sd,tuff ip, sme m-cgr coal frags, SD-blk,clr,brn,m-cgr,ang,tr pyr. . 4787.93' MO, 4731.59' TVD INC 11.58, AZ1183.32 MW 9.2 ,VS 41,PVIYP 11/18 GELS 9/13, PH 8.6, CL 47000 CL Y :It-mgy, gmmy, sli sol, incr sticky, vslty, intbd sd,tuff ip, sme m-cgr coal frags, SD-blk,clr,brn,m-cgr,ang,tr pyr. . 4881.67' MO, 4823.66' TVO INC 10.05, AZI176.04 SO :clr,trnsl,qtz,ltgy,blk, vfgr-mgr, sb ang- sb rnd,w srt,uncons + imbd in cly, abnt slty cly mtx, mic carb mtl, no show. 4976.00' MD, 4916.71' TVO INC 8.87, AZ1174.97 r:,l----- " )----- \ ¿~ ::-:: ,..~' :.::_----- ( SD :clr,trnsl,qtz,ltgy,blk, vfgr-mgr, [fi) :.:: =----=---=--= sb ang- sb rnd,w srt,uncons + imbd 51 de == ==-==-=-:::-== f in cly, abnt slty cly mtx, mic carb ;. - :::-...::.' . ~~ mtl, no show. ~ :::--= 7' HI\I' ~ \ ..;:::=-,".l :=-:,----- ,.# , 5071.57'MD,5011.13'TVD -> :-== \ I INC 8.93, AZ1183.96 ~ - :::-_-----, KC:tara -- r' 5100 -,~--==----=-----=I \ MW 9.2 ,VS 46,PV/YP 12/23 =--=:=--=--=-----= GELS 10/14, PH 8.4, CL 46000 ------- --------- r S =--;-------=--= } 5' =---= J' :=-:= CL Y :It-mgy, gmmy, sli sol, incr SI:Jie <'""'1 51!D =--- ,/ sticky, vslty, intbd sd,tuff ip, sme "'"""> =---= "-"-"- m-cgr tr coal frags,tr pyr . Rctat3 ..ç - , --- '-- =--= :.:- -=---=---=" \ 02112/0' C <' ==-==-==-=-== ~ \ ::::-~~- - - -- æD - --' .\ H 5165.63' MD, 5104.09' TVD ...~ J --- l INC 9.32, AZ1191.61 ~ ~ --------- ------- :-=-= :-==-==-=-=-=) ...... SD :clr,trnsl,qtz,ltgy,blk, vfgr-mgr, &H) :::-====-==-:::::-==: <'" ~b ang- sb rnd,w srt,uncon~ + imbd --------- '. In cly, abnt slty cly mtx, mlc carb :::--=:=--=-----=--= ~. \ mtl, no show. =---=-==-----=--= ''-tITS. h ~~-==-=-==-= : (,-~ ¿- ............ 5ID --- I' .l ) :< f ":":....----:::-"::---:"'-:::: ~~'-':52 U~Il[f. 5260.16' MD, 5197.45'TVD ~?~=f~~ I I INC 9.32, AZ1191.62 ~ --J:: ---------- ~ ~ ~~~~~~ (~, SD :clr,trnsl,qtz,ltgy,blk, vfgr-mgr, fiH) =------==--=--=----=: "-- \ ~b ang- sb rnd,w srt,uncon~ + imbd Rctata ~ =-----=-:::..:-_----=: ~ ' In cly, abnt slty cly mtx, mlc carb -------- "\ mtl, no show. --=-------- J ~ \ - =------=-----=--=--= 5ID ~~:~==~=~ 5 5353.05' MD, 528903' TVD , 1 'i, INC 9.94, AZ1186.55 -BRie I ~ - ¡'). r SD :clr,trnsl,qtz,ltgy,blk, vfgr-mgr, -- ~ sb ang- sb rnd,w srt,uncons + imbd WOB O-E ~ 5ij) ::::-. in cly, abnt slty cly mtx, mic carb RPM 75 :=- . ,'\ I mtl, no show. SPP 18('0 -- GPM 78; , ::=- ~. I \ II I~;' I ffiD - I~ I I 0 j I I ! ~ Gamma Ray 0 api ROP Avg 1K feet per hr .,. ""IJ !:: 0< -I < 150 ~ ê MD Ô ëñ SQ» r C ~ï 0» G) r -< 0 6--1 FT r- - - z .... .... ::I: m 0 ;;g r- ;;a 0 m G) .... -< ~ ~~ -¡en -:r: Zo G>~ ''','', .",,,. ,. ""' Max Gas Avg Gas ",,,,,,, "'",,.. ),.."" Gas Chromalograph C1 Avg - C2 Avg - C4TotalAvg C3 Avg - C5TotalAvg RESCALE x10 1-6 0 100 100 1~ 10K 100K 1M Lithology Trace SPERRY -SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company W3.L t\&L9 COMPANY BPÞLAS<A LOCATION NORTH SLOPE, ALASKA ) ~ , === === == === === == LEGEND === ';...._J === === == == == 10,000 Units Total Gas in Air = 100 % = 1,000,000 ppm == NB NewBt NCB NewCaeBi CKF Check for Flow NR No Returns CO cmtElli lAT Lo;¡*Ti1J TG Trip Gas CG QrmblGæ O3T IJiSlsnTest OC DeçAhCarW STG SntTi1JGæ SVY Direc Survey ~ I ~'."'."'.'.'.'..'.'..'."."H I t~~::~::::::::~t~ ~ :::J * Gamma Ray 0 api ROP Avg 1K feet per hr ? ~ -- f ~ :r - f!- Rotat'-l; > -- ~ WJS 5/~~O - ..> ~~f~~~f~o! ~ GPM70J '77 ~ 03/0e/0- \" - ;;-' SI de ? ~ 7~ Rotal. ---= ~ Side ~ > f .£ -::' >.""" ""'1.... .r- I Slide J i ~I I ~ - ! I ~ ¡ Rqtat9 ~ ~ Rotata Slide I ~ ') -Rßtat~ J SiItsb1e I E===~=~ I Clay "U c:: 150 ~ ~ ~:5 0 c MD 0 C/) !'E:Þ ï C =<!r 0» G> ï -< 0 6--1 FT \ ~ .- - - z -I -I ::t m 0 ;:g .- :;a 0 m G') -I ~ 21 ~~ie'~~ SYSTEMS NS-29 l¥1I I - f"L~L;':fJ lç/';:t<>1 11111111111 ~ Umestone ::uQ :þr -100 -:r Zo G>::E l.aJ Gæ ~ Mt< I::, ::. ~:. ::' '} ~. i. I t. ~ ,n . I II~ i-1m! ~ m- l PI! DoIorrite CL Y : It-~ gry, brn, sft, :mor, occ Gas Chromatograph GarlJ ,"&i, v !lt1, bMt, fltg c¡tl & cht. OC1ItJC1Ag OCIIiJŒI\g - ID~G¡~~ OC1ItJŒAg - ID~Œ¡~ Lithology Trace RESCALE x10 1--6 0 100 100 1 K 10K 100K 1 M =---= =------_-: 1æJ ----- --..---- -..---, ---...-"-- --- ---..---... ---- ---..--.- ..---..-. -..-"----.. -,--- ----- -,-- -..---...,-- ------ --'----- ---- ------ . 16] --- ------ --------- --- ------ --------- --- ------ --------- --- -,----- 1ffD --- ------ --------- --- ------ --------- --- ------ --------- 1700 -- ------ "-- ----- -- ------ ._------ -- ------ .-- ----- -- ------ "------- 175) -- ------ -------- -- ------ ,------- -- ------ '------- -- ------ 1aD --- 1ffi) Avg Gas . ~ . .~ ~ - _.~,....,. \ \ ~ (' 33 J~ T8 '\ ~ ~ f~ /... ~ t j ~I A't'g 03s- I ~( Hvd-dn ~ .~ Hj\1d:n "CS ) Avg Gæ . 0 ) ~ ~~ i --~ I 1\ ¡ CL Y : It-m gry, brn, sft, amor, mic carb spks, slty, bent, fltg qtz & cht. MW 9.4, VS 92, PVIYP 15/58 GELS 17/26, PH 8.6, CL 21000 1583.06' MD, 1536.20' TVD INC 27.30, AZI 318.39 , / ., CL Y : It-m gry, brn, sft, amor, mic carb spks, slty, bent, fltg qtz & cht, occ calc strgs. 1676.95' MD, 1619.09' TVD INC 28.69, AZ1318.40 . . ) / SO : clr-trnsl, dk gy, occ blk, vf-m gr, occ c gr, sb ang-sb rnd, pred p srtd, un cons, cht & qtz grs. 1770.22' MD, 1700.00' TVD INC 30.95, AZ1318.78 I i I \ I CL Y : It-m gry, brn, sft, am or, mic carb, slty, bent, fltg qtz & cht. 1864.99' MD, 1779.82' TVD INC 34.27. AZI 318.24 .!:. Side ~ '--- ~) -? R~tat~ ~ -S.I-tre ~ Rotat:! :> -81-d-e- ~ C ( - c'"' ~ "" .,.~,~,~.~,~~.~ ::' >-- --- l- C ',."",."".,,",,...,.? Side Ratata 1) ? Y ? Sl'de ~ -> 5 Rotat af¿ Sl'n.~ > ~~ ! ?>: i c::¿ [ I ¡ I ,f- i i I I > I i ~i I ~_I I ~llde, ;> ..1._-- <. ~ : 2100 1m¡ 1"---:- - - }~ JL-- ----- 1!ID am am .- -- - - ~"----- .- ----- ------ .- ----- 2100 zm .- . ------ :::-...:: =---=----=--_J .------- -- ------ ._------ -- ------ llÐ zm lID m > t f I, ) l ~ \ ( ~ r' ,~ \) .~ 47~1 TS \...., " 4~ J~ TS ~ \ 'il It\TS ~5t J~"S Y ") CL Y : It-m gry, brn, sft, amor, mie earb, slty, bent, fltg qtz & eht. 1959.76' MO, 1856.56' TVO INC 37.57, AZI 317.51 ( )UI " 2054.30' MO, 1929.67' TVO INC 41.10, AZI315.72 SO : elr-trnsl, dk gy, ace blk, vf-m gr, ace e gr, sb ang-sb rnd, pred p srtd, uneans, eht, qtz grs,oee pyr. /' 2148.59' MO, 2000.79' TVO INC 40.99, AZI 316.91 SO : elr-trnsl, dk gy, oee blk, vf-m gr, oee c gr, sb ang-sb rnd, pred p srtd, uneons, slty ely mtx, co eht, qtz grs,oee pyr. \ " ) /~ ~):::~: ~, ~ \ \ '. ,\ ~ t I I' 2242.90' MO, 2071.41' TVO INC 41.97, AZ1316.30 CL Y : It-m gry, brn, sft, amor, mie earb,vy slty, bent, fltg qtz & eht. ......... {. - ---- > '-l , r 2237.00' MO, 2141.33' TVO INC 41.97, AZI 317.43 I CL Y : It-m gry, brn, sft, amor, mie 1 earb, vy slty, bent, fltg qtz & eht. I ". ----- I 1(. ---- /11 ~ ----- ---- 1 I. I' 5 --- :~. ~ .; \ <.-:-? ~- t ~ .~ SI de .c:;:- - <""-;;> ? Kolata ..... WJB 1Gct55 .RrM 40 c-=- Spp 1400...1 ~ GPM 7~:'~ ~ ~ J r\Uli:ll:l .) 'SlUe --- <:: Kotat a <. ~ ~ ~"'-,."'.. -~ ~ > <' \".'''.'''..-... ,-5J ).T S~ ( ""'- <! I '<- slide ¿ --. t.- I~ Rttate, - ~ 5 , þl' I ~) >'"11. \ Ii 1 II ,~=... }I ) /' 2430.58' MO, 2210.71' TVO INC 42.33, AZI 317.49 SO : clr-trnsl, dk gy, occ blk, vf-m gr, occ c gr, sb ang-sb rnd, pred p srtd, uncons, slty cly mtx, co cht, qtz grs,occ pyr. - - ----- ) Avg Gas ' 0 ) 'L,tç 3as HIP d:1I1 ,,~ IL~ 3as lij(l tt'1I1 ~ ') Avg Gas . 01) ---- 24m ----- ----- ------ , ----- 2m ------" ", '\. l" 15J . ~ 1"S 2525.05' MO, 2280.30' TVO INC 42.78, AZ1318.41 ------ ----- "~ CL Y :m gry-gry brn,vf-gr, amor, 2ID '- ------ slty, sndy, carb mat, non calc. ----- \. ------ ----,- .- ------ ------ '- ------ j ~ am --- ------ \~ 2620.75 MO, 2351.05 TVO -------- INC 41.85, AZ1317.56 --- ------ SO : clr-trnsl, dk gy, occ blk, vf-m dID gr, occ c gr, sb ang-sb rnd, pred p ---- ---,--""- srtd, uncons, slty cly mtx, co, cht, --- ___0__- -------- qtz grs,occ pyr, wood, . --- ------ -------- --- ------ H' .N -5 -------- --- ------ -------- --- ------- "\ I"" I 2iUJ .~-- ---.-------.. (" j -- -----... ~ "------- I ;( 2715.34 MO, 2422.22 TVO INC 40.55, AZ1318.19 ,------- -\ -- ------ .------- -- ------ CL Y : It-m gry, brn, sft, amor, mic .------- 21ffi -- ------ carb,v slty, bent, fltg qtz & cht. .------- -- ------ -------- ~ am 2809.59 MO, 2493.64 TVO ( INC 40.92, AZ1317.11 -- ------ -- ----- -- ------ ------- ..- ------ {.. SO : clr-trnsl, dk gy, occ blk, wh-org ------- -- ------ ¡p, f-pred m gr, occ c gr, sb ang-sb ------- EJ -- ------ f rnd, pred p srtd, uncons, slty cly ------- -- ------ ------- mtx, cht, qtz grs. -- ------ ------- -- ------ ------- ~: I \ I ¡ , I ( I lID I ~, 2903.64 MO, 2564.77 TVO INC 40.81 AZ1316.36 t~ (( ) I I SO : elr-trnsl, dk gy, ace blk, arg ¡p, ~ <: f-pred m gr, ace e gr, sb ang-sb 51 'de am rnd, pred p srtd, uneans, slty cly ~. mtx, eht, qtz grs. ------- } ..- ------ ------- -- ---_._- ------- .Ro.t;:! t q "- ------- ------- .-.- ------ ------- ...- ------ ------- 2997.44 MO, 2635.06 TVO 3m ..- -----~ -:::: :-_-=-----~ j INC 42.12, AZI 316.26 ----------: ~ ~ -------,--- ...- ------ ------- -- ------ ------- CL Y : It-m gry, sft, amar, mie "- ------ ------- earb,v slty, bent, fltg qtz & eht, sm 3ID ..- -.----- ------- ..- ------ gravevgs. ------- ~ \, -- ----- ._-,- .?r. -- ------ --£ J - ------- -- ------ 3093.50 MO, 2707.03 TVO -- ----- 31m -- ------ INC 40.82, AZI 316.41 -- ------.., ..- ------ « -,- ----- -- ------ -- ----- ...- ------ ~l --~---- ..- ------ ~) ------- ...- ------ c....'" ------- ..- ------ { .Sf,de ~..."" ------- CL Y : It-m gry, sft, amar, mie 31!ìJ earb,v slty, bent, fltg qtz & eht, sm r.I grav evgs, abnt sd evgs. ------- Ratat g -- -,----- ,'( C- I (. < 3186.83 MO, 2777,35 TVO INC 41.41, AZI317.04 S 3ID <;. ~ .J' '~ t". 'S '~ SO : elr-trnsl, dk gy, ace blk, f-pred 1 m gr, ace e gr, sb ang-sb rnd, pred 3:1Ð ~ p srtd, uneans, slty ely mtx, eht, qtz I grs. ~ < ~ ~ -< 3283.44 MO, 2849.65 TVO ~ INC 41.68, AZ1318.07 '\. 3m .. I WOS ;i:40 r RrM SPP 1 0 I GrM7~ ~ slide ,~ if I SO : elr-trnsl, dk gy, ace blk, f-pred : I m gr, ace e gr, sb ang-sb rnd, pred I :mJ \ p srtd, uneans, slty ely mtx, eht, qtz O~/1Cli grs. '~ ¡ 3376.10 MO, 2918.72 TVO I I INC 41.94, AZ1317.79 ~~ I I '\- 'M) ) I I I r II I > " ~n '"lr-tm~1 rile ml n,,("' hlle f-nrøri --~1 ~ ~ ~> 2~ >- -.c- "-> -..,.. ,... ."'."" ....? --- ,~ - 0 Gamma Ray api ROP Avg 1K feet per hr ~ 3ß) 0 6--1 FT :31D :mJ :EJ E) 't7("(" "U c: 0< -1< 150 ::u ëi5 I- 0 c MD 0 C/) ~» r C -ir 0» -< G) r -< ï - - z ~ -I ~ m 0 ~ ï :;a 0 m G') -I -< g} < )) \ """'.., . VII "III"", un. ~1' v,,",v U"', I 1"'1 vu m gr, occ c gr, sb ang-sb rnd, pred p srtd, uncons, slty cly mtx, cht, qtz grs. 3469.88 MD, 2988.65 TVD INC 41.63, AZ1318.88 I t I~ CL Y : It-m gry, sft, amor, mic carb,v slty, bent, fltg qtz & cht, sm grav cvgs, abnt sd cvgs. 3564.32 MD, 3059.41 TVD INC 41.32, AZI 318.03 I' I "f"-" ,_.. ...0. ,- ... , ~\ v ~I Gas Chromatograph æ11tJC1f\g - OCHtJC1Ag - ro~G1~~ æ1ItJŒI\g - ro~Œ1~ Lithology Trace 0 ~~ -:r Zo G>::E l;g c:æ ~ M1x Avg Gas RESCALE x10 1--6 0 100 100 1,K 1qK 10,oK 1M WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. SPERRY.SUN DRILLING SERVICES LOGGING SYSTEMS A Haliburton Company WELL NS-31 COMPANY BP ALASKA LOCATION NORTH SLOPE, ALASKA Saoo Gamma Ray 0 api ROP Avg 500 feet per hr Sandstone ) ) === ~~~O~O~O=~~ts=;o7a~~a;~~i~~gO=~~ ~~;O,~~O=P~~~=== == ~~~~,~~ NB New Bit NCB New Core Bit CKF Check for Flow mil" NR NoReturns CO Circulate Out LAT Log after Trip ' MJ,'....t TG Tnp Gas CG Connection Gas DST Drill Sterrš~sk:lr-trsl w~ ~I r.tIß6ü1'. DC Depth Correction STG Short Trip Gas SVY Direc SUrUÖY. v f-m ~r, o;c ~I'~~I~~L~~ ang, mod srt, pred ucons in S~ ~1.~. ~"~'. ~'~ 1P.a"~fif;"(~,"f I 'I. 'i ,. i .. ,~,. ""I pip. . "l .. .l o. '" I ê==~=~ I Siltstone ." !:: 0< -1< 150 :;c ëñ I- 0 c: MD 0 (J) !:!2» r C =<!ï 0» G> r -< .- - - z -t -I J: m 0 ;g .- :;u 0 m (j) ¡; -< c 0 6---' FT - ,Vvvv ! ~~~T~ ~-i\ I : ~ ~ , "-- "'''''''''''':'''':;:?..- -- "'" -! ? SV5 ~. 3340' MD, 3::" G. ~ I --Ä~- I ( : ~. 305C il--t 11-1 :i--I :1-'- I i~: §~~~~ !:'::I""""==== IHI 1011 Ibl.""."".",.""""",.,."",." ~~~~ 'I'!:.:] F""--:""-":':--= iþE"'::=~=-=-= Il:d:::/!=---~...:..-:....-:--= t:_--rL.---=-~~-= I§t====~ 1~- ~----- I!-"""¡r---'-'- Ii----:¡ ¡::...-----=--= R~==3f~ 310C 315C '--.--'-'-'- :~~=----~~~-= 1::--::":""---=-"':""-= 1~-1""'---'-'- !--¡~_._-- 1E-3E-~==="':"== i!-:,~-'-'-'- :~~=~===~ ---------- ---------- ---- ----- ---- ----- ---- ----- ---- ----- ---- ----- ---- ----- 335C -=---_-:.--::.. ---- -----. ---- ----- ---- ----- ---- ----- ---- ClalSlone 1_ll!:I,~I;. ~.L , .~ "I:, . Limestone Lignite Lag Gas Hydrcbn Max ~~ -ten -I Zo Ci):;E 1---~ 0 ~"...I . ..J ! I , ~ >1 : I '" I 1 ,! ! Avg Gas ----- ')h..NTS ! : 1 I . Þ ,-NTS Gas Chromatograph GC11nMC1 Avg - GC1In!vlC2Avg -- GC1InMC4ToIal~ GC1InMC3Avg - œ1In~IA~ 100 1001K 10K 100K1M ; ¡ ._.~.. , ..... - ¡¡¡;:'"'''...''''''''''''''''''''''''''''''' ""''''''''''''''' ...-. ."".,..... '-i: '."""''''''''''''''.''''''''''''''''''''''''.''.'''.''' -f" - - - :) _."."...""'''-'''...'''...."...."''''''''''''',,...,,-,,~ Co- I .-!.~ VV10B 1 3/30 ~ ~ --.. 320C I~:?::::::-:::::-===-: .~~~ 154050 ~--~=j~~~ ¡' M 71 0 .~::=~~E:-="'::=-=== . 13 3/8" cs~ @ --1: ~~~==-:=-=-=-=-: """'depth 324~"-------- ~~ - o~lOk 325() ":--1===3~==~~ ~ i I ---------- , ~. ! I -=- --=---_-::.. :....--------= N~~~X-C 1 D~, 1 -=-------=- :....-:....---=----= Ro~e I. -=-_-:....---=- :....-----=---= LO:..t.....5.3 ---------- -~ -------.--- ~ . -=---:....-_-::..::-_------= ~ ---- ------ ~ 330C ::-=-=-=.-: ::::-=-=...::=-::: c:-> ---~ ;:s.-- ~- s. : I , i : i i 1 I I , I , i I! Iii i [I ¡ I i I " . I I ! : ì I I II~ I I I 1¡ : 1í I! :" ,I I', 'I I I \! ii I ! I I I I I I ~ I \ I :1 I .1 ' I ' ,, ) I : ill -l¡ ¡: 'I II i . i Ii : ill I, I! I: I! 1 , I 111* led Lithology Trace CL Y :It -m gry, sft, stky, v slty, bent, fltg qtz & cht. 3106.71' MD, 3103.41' TVD INC 0.22, AZI 80.77 CL Y :It -m gry, occ brn, sft, stky, slty, qtz & cht, occ glaun & pyr, non calc. MW 9.6, VS 54, PVIYP 54/17 GELS 14/19, PH 8.1, CL 22000 3177.82' MD, 3174.52' TVD INC 0.17, AZI 91.24 : CL Y :It -m gry, occ brn, sft, . stky, slty, qtz & cht, occ glaun & pyr, non calc. MW9.3, VS 39, PVIYP 14/13 GELS 5/11, PH 10.4, CL 21000 II CL Y :It-m gry, It brn i/p, sft, V : slty - slty, sdy i/p, v gmmy. ¡ 1,1 , . I: I I I I \ ~ , ~ I \ 3387.21' MD, 3383.88' TVD ~ ..,_.~~ ~ <:>, '/~ 1 C""... SV4: ~... F"':::-., .S6SE)!."1V D,3f~o' I./.g.-,,,._,...,,... ~... < ' ~ ".,...,.- -....-.-.;;;;::-."'¿ >-'<-- WOS 15/25 I ¡;II " ..( --..:....- ~~~ 18gS0 <~- ' G:>M 7.QO ( ~, )~ '-~ -;,:I ~ . ~ ~ ~ ~ G, -.. 1 l.-~ , 1 if : ,: ::....: ' .... 1 .£ : ----~; ~ ' ~' " ~~----_. ., -> : j> 1 ~ ~c:.,:. , - ) ~ ~ l ë- ~. !tio- ' ~-~---- - - . ....... 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""-- , !¡ ::---=__1 E-=~--~I 3400' :'=t~~Ê:=~~ 1------.-'-- 1-=-_-_-.:. ;:.----~-=--:-....: 345C ¡-=---_-.:.t- -=---=--= i'--- t---.-,-.- I---"""'t.r'-'-'-- i-==-=-=;-=-=-==--:--= l:- =-:::: S""""-:==""7-=--=---~ 1---: ¡----' I---,i'"'''''''''''''''''._''''"'"'-'~ -----.-,--.- ~][~~=; 350C ','","""" !:--:=-~ ~~ -:=-=-= .t~~~~~~ ~ ~ ~ : ' ------.-,-.-- I____!_---,-.-- ... §=~=~fE==~~ ',:~=~~~=~-= i'=--=- - -:j ::-----=-.-= 355C I:r:....-:.:-_--::; c..:-_-..=-~....:.--= ' ~~~t~=-== ! ~ ..4 '---- ---.-.-.- - " .1'"-'----;----'-'- :~~==~~~=f~71 360C C:---47;¡ ¡'~I ~~, ~.;" '~~I:, ~",~:,:,':~: ~----¡~I":l:;:/;.:)" ,-,/' JU;:"lt' :~','.IIII~' I ji- - -1r: .1: I~, i \~,: l' .,,"It IlIl ~--~IU','l!llfl',/' .11, III! ;IIIIII.II!I~I' 1==--=3::,"! ;.::[ ~,;:;¡: j:::::~: ::---4,1. 1111, "¡( ~:.,II: -, i~ll, I~I. l:-"--=-- - ~I, II~~! l . I. /, rII;, lit 1l1li:./111111 ~ 11---"11.1 1:'.~.lll 11111'111. Ilill 1~1 r:' --:1; l~l,l ,I~, I., III! ; .~:-_-,l,ill~~.lllll" .. ,i '1l1li1 ,; ::1" ' I~!: IL 1111", ~ I~II WIlli I1II 365C : i:--~ -:¡,~ ~, ¡:,'" ,,' ! '!'---'~Ifl C--=---~I lC-~--1K¡ ~~~i~~~:-=: ï--~iñ71 370C I=:-::-_--=f:::!' ~' ~--H-_._._- .~~~~ ._~----- ~--D=----_-:-_--= --\' .---.-.-- ~~ ~TITm: :-:......--:.:' 7,. -./ . f . ./. 380C -~-=--~---=-----= ~====~'-===~==~ ----.------ ----'-"';1----- ----"------ ----..----- ~--=----=-~----~----= -=------7---------= ----.,------ 385C ~-=~=~-=-=-== ~===~~=======~ ----.------ -=-------2-----~-=----= ~==~~==~~ '____- 390C -------..::l 375C" ~ " .J .. S - - .. "' ... '! ) II! ~ Ii 24 - N I $ I): , ' ~: )' ,: ,! , 1 ..._".1..... , \ .' ! i : : : : '~ " , J8 -NTS )~g Gas 100 LA GI,:;; I;ur .;Lrl~ L~ Gas Hïdrf~~ I Avg Ga 400 ! i , I III 11 II I I , Î t 1:31 H~/TS , ¡ I! ¡ ¡ II .. I I : ~ \. I T , Iii! : I I . - - I i ¡ , i ~: II . I I :! i I:" ! I I I I I !!! I ' : i : 1 I i ) i i "'i I: ~ 1 )i 1 ¡ )1 , ! I c '" I I I ¡ I : , I' I I ! , I : 1 : I INC 0.36, AZ 41.28 SO :wh, clr-trsl, acc blk, u f - v f gr grdg-silt, ang-sb rd, w srt, uncans qtz & acc cht, tr SST wI pyr cmt. CL Y :It-m gry, It brn i/p, sft, v slty - slty, sdy i/p, mic carb, mic mica i/p, v gmmy. MW 9.3, VS 53, PVIYP 16/26 GELS 718, PH 8.4, CL 58000 3587.8' MD, 3584.47' TVD INC 0.51, AZ155.12 GRAV :dk gry - blk, wh, v c- pea size pbls, pred w rnd, acc ang, uncans, cly mtx. 3671.78' MD, 3668.44' TVD INC 0.59, AZI 60.27 SO :wh, clr-trsl, acc blk, v c - m gr, grdg - gray ilp, acc f gr, ang - sb ang, acc rd, v prly srt, uncans qtz & cht, cly mtx, nsafc. 3766.60' MD, 3763.26' TVD INC 0.47, AZI 53.84 1 1 I I CL Y :It-m gry, It brn i/p, sft, v 1 slty - slty, sdy i/p, mic carb, . mic mica i/p, v gmmy. I' , 3860.78' MD, 3857.44' TVD INC 0.51, AZI 52.27 1 ! I : CL Y :It-m qry, It brn i/p, sft, v 1 .. L ~ ~ =-0_, ~ ""'::..-...- ~ ,'-~ ;-> ,"» : ! i'_~ ...- ; :;~ ~"'- r r--: c:;. !~' '-.L ~ ~V2 )j -4'0'5'2' MU, ~~ .'WU . .........,....... ..,...................................,............,............. Ii ~ j, . ,$- ~ , .> , .....................................~t..:............."........ <.:. ~ ' "''''~t ' " ~ . '" ' --~---~~ ).............~~.............. <. .. ..........._......:......_..._.............2._.__..~................... ~ ......__..~. ~ - ¡--=--=--= ~..... 1 \ > ......} 1 >~ [;! )~ ) 1 ~-= : L_._- -:.. ~ ':>\ ~ ~ :.t ~ -, ~ -.., '--1 I . - - ~- ~ ~ j'- ~ ~ <:- L...--.__..._I I-=-- }.: 1----1 I-:----~ ! '----..¡, i----- ! :~-----=j :-=----"":.:1 : j~=-~I 395C ;-=------:; þ~~==c. :~?~F----=-~-= ;-=---:'--='1 I__--i' ,I~~~,¡ 400~ 1.:::.:- -=--=, , . 1Ë!_.~_:...~ I'::. t...----=--~--= !~ ~--.-.--=--=-~ ig~~~ i~E=~~~ Ib"'---"""~ '1:::1 : ¡I--!, "_-1' :l-!i :[::;:1 ¡:=I I~i E! 1'-1 ~~! E' 405~ 410C 415C ¡::'I §I Si, t:'~~=~~~ 1=1 c:.::...--=--== w c- -=----=--=--= r-""":---.-'- ~r:--::-=--=..~ 11- ¡. - - _.__..- g~:::=:.= :-. - - - -,,--,,- 420C r"'!"" "--'-'-'- -11"""'---'-'- ~~E~~~ 425C I~-- ----,-,- 11---:=---- !~--=::----~~-~-= ',--1 . E-=-=! t=::. . !--- 1--- --- 430C"' --------- ---- ---_._- --------- ---------- --------- ---- ------ --------- ---- ------ --------- --------,-- -------_.- ---------,- --------- -------_._- --------- 435C ---------- --------- ---------- --------- ---------- --------- ---------- ----.:----- ---------- --------- ---------- --------- ---------- --------- ---- ------ --------- 440C ---------- --------- ---------- ----.----- ---- ------ --------- ---- ------ --------- ---------- --------- ---------- - 00 ~ N TS - . a ~ N TS ~: I I D II I! I( 1 II i 1 II : , 1 I . . II ¡ I I , I , , I I I I ~ I, , ' I ' . IÐ6 UrNITS 1 , Ii' I ~ 1 I; , , ' i II . , 1 1 i 1 ,: I 1 I :~ I 1 i I' (' ,I, , ' I! :( II " I ; i 1 Ii 1'1 I, I. I I ¡I : i 93 ~ N TS ; : I I I : 1 I I 1 i 1 ¡ i I , 1 slty - slty, šdy i/p, mic' carb, mic mica ¡¡p, sli gmmy. 3955.94' MD, 3952.59' TVD INC 0.56, AZI 61.23 SD :wh, clr~trsl, blk, grn i/p, v f - f gr, occ m gr, ang - sb rd, mod srt, uncons qtz & occ cht, slty cly mtx, nsofc. 4051.50' MD, 4048.15' TVD INC 0.37, AZI 57.90 SD :wh, clr-trsl, blk, grn ¡¡p, v f - f gr, occ m gr, ang - sb rd, mod srt, uncons qtz & occ cht, slty cly mtx, nsofc. 4143.31' MD, 4139.96' TVD INC 0.37, AZI 67.55 CL Y :It-m gry, It brn ¡¡p, sft, v slty - slty, sdy i/p, tr of coal frags, sli gmmy. 4236.98' MD, 4233.62' TVD INC 0.37, AZI 60.65 I CL Y :It-m gry, It brn i/p, sft, v i slty - slty, sdy i/p, tr of coal i frags, sli gmmy. 4330.53' MD, 4327.17'TVD INC 0.52, AZI 72.93 'ii . CL Y :It-m gry, It brn ¡¡p, sft, v , slty - slty, sdy i¡p, tr of coal . : frags, sli gmmy. \ : 1,1 I: Ii ¡ ? !. ì-.:.--. , " 1 : '. 1 SV1 ~- .. .zt:~51~''''rvl'O 4¿.17' ~\1. 0-"-.+'...' , 'J~ 1 ! -- t ~~ -U,l ~ ~ I..................."...........".....""....... ~ $- !OI::'''''''''.'.' ~ _\ :~~... .s. i, ...... ~~, ~ ?' ,.".. .. ....,- , <" ._.~ ' ¡~ : r < t. ,. þ- ,-""...._..",,,,--.,,,.,...,~,,.._,.._.... ~ ..{ ~3/91 ~I ~UGNU .. ,-- 4~.02' ~lJ, 4/~~ 1 I .~ WPB ?p ¡: RPM 81;) ~ "SPP 1450 -" :- .> GPM 750 ~ : , . <....., ) ,<- c-" -.., , ,- - 4- ~ ~ ~ " " 445C: ....... \------ i:.::... - "-..:, 1;...-=_-::..-::: 1--"".- b----~'- I~=~Ê::~~ I~~~=~~ ¡~:f~[:E=~ !---..--.....---.- I__._--.¡"'_........- _._.1.... j'"-"'-"'--''''''¡-----''- 450C :-~.:=:-= t7:..-=-::::-== . 1--_-1 ! ~___-:;' ¡ ¡i-==~~--~-~--= i_, ~_- -'---.-.,.... ¡ I=-::~~E-==-::= , :.::=---=:;t..-=---~-=--= 455'" I ,.;....._--"If,.____..- "'" I !----r----'-'- I ¡___...I,!,"",_""",-'_'-"'" I.. i":- -:..::.::j t"'"-=---=---= 1.1-----:1----'- !, i---~!¡-,___'_"- !1~=::jË=::::=~~ i~~[=3=3=~ 460C ; ¡.:----=.::. r:----=----= iif::~t=::=~~ .,t::-=::={. ,-=-:-:..=-== 1----1"-'---'- 1---.- "'--'-"-"- 11-::":'--:= I I";----i ,1-,---:'''' "",' "I'. . 1----: 465C :. ¡.:-...:..-_-:.! iê=~~~~ I' ,.1..- -~ -.... ,- -- -... ---- 1---:'-----,- 11:~:i:S~=;~i~~ ~ ¡:.:--=:jl i ,.,--*--.,' 4700 1.1-"" .._.. -, I !f~~~. ::.---=--=--:1 c--_-::....~~~ i~=~~~-:=-= ----:--_._.- :----~----,- I~_-_--=; :-_-~--:--_-: ----',--.-.-.- 475c-! ,-=--. --:----=:.:::.. -----=--= ----,---.-,-.- , " i-:=-=-=~!----- '---- ----¡----.-'- ------,--- ---_._--,-,-,- ------,-.-- ----',¡...-_._-- ------,--- ---- ---.-.-.- --_.....1,---'-'- 480C ---.=::_-------~ - ---.--.- - ---'--,'- ------,- ----,--- ------- 485C - ------ ------- - ------ ------- ------- ------- ------- -----'-- - ------ ------- l'O5 _NTS \ ~ I I ~ , , ,~. 0 ~ f'tJTS I I: ~: ! jl. I I I ..-. ' '163 HN~TS 1 I...,.. ~ L : i i I 1[ I II ' II , 1 I . '\1 i: i I l' ~165 ~r':J'TS ! 1 ¡ II , ¡ i !: 1 : I I ;'. 1 " ,','6 U~'IS Ii' I' ,L '<.. . ~:II_N ~S ...."..l+.,... ' " ,~: ,! ) 8Ù ",N T8 I I I 1 ' 1 ! , 490C .- , I '~ , ) . : '¡ ¡I ~ ! I 495C i : I : I ! 1 <J }I , 1::\ : ), 1 1 ' . :! !: ! I i I I ~ '\ II : il I : ) I 1 I i 1 1 , i I , I ì I ..._--J.... 4426.76' MD, 4423.40' TVD INC 0.27, AZI 98.87 CL Y :It-m gry, It brn i/p, pred hydrtd, sft,v slty, sltst i/p, tr lithic frags, sli gmmy, v-sft. 4519.86' MD, 4516.52' TVD INC 0.29, AZI 97.88 CL Y :It-m gry, It brn i/p, pred hydtd, v slty - slty, sltst i/p, tr of coal frags, sli gmmy, v soft. 4614.15' MD, 4610.81' TVD INC 0.15, AZ1122.78 MW 9.3, VS 46, PV/yP 16/26 GELS 6/10, PH 8.8, CL 56000 CL Y :It gry, It brn i/p, pred hydtd, v slty - slty, sltst i/p, sli gmmy, v soft. 4709.12' MD, 4705.78' TVD INC 0.15, AZI 88.06 SD :wh, clr-trsl, blk, grn i/p, v f L r- - f gr, occ m gr, ang - sb rd, I . mod srt, uncons qtz & occ cht II ,[ & pyr, slty cly mtx, nsofc. IIII i: ! I , I i I I I II I I i: I : SO :wh, clr-trsl, blk, m-f gr, I' i ang - sb rd, mod srt, uncons qtz, occ v c-pea size pebls,slty : cly mtx, mod calc ip, nsofc. i I '! 5, ( r- t'\ r", Gamma Ray "U c: . °< - < 0 apl 150 ~ Ci5 I ëñ -----._..--_0...-_----.__.___0___.__- ~ ~ MD ~ c ROP Avg ~ r 0 ~ G> -< 0 6---' FT 500 feet per hr r- - - z .... -I ::t m 0 ;g r- :;a 0 m G') ñI -< c )¡i ) :t, ; Lag Gas Hydrcbn Max Gas Chromatograph ;;c ~ GCllnlvl CI Avg - ~ en GCllnM C4 TotaJ Avg Z :r: GC11nlvlC2Avg - - - - - G) ~ - AV~GaS- GCllnlvlC3Avg - OC1InMC5Tolal~ : I ° I : I . i! '~8, .. N Tß Lithology Trace 1---6, 0 400 100 1~ 1qK 10~K1M WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. 3J1j SaI!tre iI!I ) I - r...,..., ;..,j.{";..II).?.:/:t';/'l....,:.,.:1111.111'11.11.11 r ' ;' I '.'" \< ' I' ", ,,"1."" "l ' , 11\ , I\t ~ I:: : : :: :] mtttm::tm:J ') t~~=~=~ ~~:?3 I ~ WARRANTY: Sperry-Sun Drilling Services will use its best efforts to furnish customers with accurate information and interpretations that are part of, and incident to, the services provided. However, Sperry-Sun Drilling Services cannot and does not warrant the accuracy or correctness of such information and interpretations. Under no circumstances should any such information or interpretation be relied upon as the sole basis for any drilling, completion, production, or financial decision or any procedure involving any risk to the safety of any drilling venture, drilling rig or its crew or any other third party. The Customer has full responsibility for all drilling, completion and production operation. Sperry-Sun Drilling Services makes no representations or warranties, either expressed or implied, including, but not limited to, the implied warranties of merchantability or fitness for a particular purpose, with respect to the services rendered. In no event will Sperry-Sun Drilling Services be liable for failure to obtain any particular results or for any damages, including, but not limited to, indirect, special or consequential damages, resulting from the use of any information or interpretation provided by Sperry-Sun Drilling Services. 1:] !:: r- Z MAX GAS Gas Chromatograph Gam ma Ray 0< --I < ::¡ -I ~~ C1 Avg - Lithology Trace 0 api 150 ;u Cñ I :J: m C4 Total ~ §;; TVO ~ ëñ O ;;U -I(J) lad ~ f¡prtnA~ C2 Avg - C "tI -J: r- ;;u Zo C5 Total Logging ROP Avg ~ï O :Þ 0 m G):;E C3 Avg - (j) r G') -I m RESCALE x1 0 1K feet per hr 06-1 -< -< c FT 1--6 0 1 K 100 1 K 10K 100K 1 M 1"""1 CONDUCTOR SET AT 1a9'I~O ...... 01 0 NR # 1 MX-:~1 TF~ I~!ir DFtLG 1:! 1/2" ,0 _E LC GGING OU- 0'":: ..GØNUblGt".QR AT 1125 .j"RS-"", 1/' 5/)1 '" ~~N GY~O AT 206' MD 0 , JJ % = 10 JJL .~ 0 ..... GRAV :: v gry-bl, ace grn, ace 10,'---'--- "I~ITS pnk,w rnd, prly srtd, grdg from crs . '.'.. .'.,'. sd to pea sz gvl. t . ..'. . '. .. ....... ..'..... - . ~ ,- - -.. ...'."... '" ....'..'. 01 .... ....... 0 .... ....... ....... ....... ....... 263.64' MO 263.6' TVD ....'... ....... INC 0.49* AZI127.40* 292.16' MD 292.2' TVD (¡.) INC 0.51* AZI125.69* 0 ... - SO : clr, trnsl, ace wh, ace grn, 0 ....... ....... f-med gr, p srt, sub ang-sub rnd, ........ uncons. ....... ....... (¡.) ... I 01 0 ... ....... ....... ....... I ....... 1!'ö¡)1 ...~... I I I I I j) ! 382.60' MD 382.6' TVD .¡::. ... INC 0.24* AZI11 0.67* 0 .... ....... GRAV :: varic dk gry-blk, wh, 0 ....... I> Itgy,w rnd, sme ang, prly srtd, grdg from crs sd to pea sz gvl, sme vcrs ....... <~ J- ."'.'.,..,,.' .." ~. -;:> 2- -,--~,.__._,- ~._- WfrB 15 R M 45 P 855 GPM 615 )i ~! <-1\ -- f1 r-I- .uCl. .þ. CJ1 0 CJ1 0 0 CJ1 CJ1 0 . . . . 0) 0 0 . . "" \I . . . .' . J ) .......... .'...... ..,..... ....... . . . .". '0. " " .'. .'... ....'... 8.......1 ....'.'.. "',,, " III " "," ..'..'..'. "III .'. -.,.,. ".." III " III " '. ~. . " " '. 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I I II I . -....- .-..1. .-. ...".... -- .- ì sd. 471.90' MD 471.9' TVD INC 0.24* AZI111.48* SD : blk,dkgry,clr,wh,m-cgr,sme fgr,ang-sbang, msrt, uncons, sme cly mtx, 20% coal+lith frags, 40% qtz, 40% qtzt frags, tr pyr wood, tr pyr .. 564.76' MD 564.8' TVD INC 0.74* AZI 316.36* GRAV :: dkgry,blk,wh,sm-m pea sZ,rnd,pred qtzt, sme qtz, sme pyr wood frags.. 655.76' MD 655.74' TVD INC 0.98* AZI 303.49* CL Y : Itgry, gmmy, hyd,sl slty,as mtx + intbds in bdd sd+ gvl, vsft.. 745.22' MD 745.19' TVD INC 0.94* AZI 308.07* CL Y : mgry, Itgry ¡p, vslty,xfgr sd ,sdy intbds,gmmy ip,sft. 835.52' MD 835.47' TVD INC 1.05* AZI 305.72* II SD : clr-opq, It-dkgry, blk, f-mgr,ang-sbang, wsrt, un cons, cly mtx ¡p, 40% qtz, 30% cht frags, 30% lith+coal frags, nsofc.. --~ </ .<:.> h 1/'25/')1 ~ "S~Ofn TR P 2C3' v1~ 2.5l.0.1/0' Cont Jìrilling S s R ~: ~ ~~.~ ~Fr:~šs~- CJ1 .'..... -------- 0 .,'.. ..',''',.~~~,---'- .". .,.'" ..::-'~--~~-~ .. .. . . ',. .. .- .", '- -, -' -. '.., .. .. ..'.. ".. -. '. .. ',. 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U:i-!=', I ) 'I I ,I I I I I I I I : I i ''f I I '4rli-S \1 I I 'ì 930.55' MD 930.50' TVO INC 0.23* AZI351.74* SD : clr-opq, It-dkgry,blk, mgr, ang-sbang, wsrt, uncons, incr cly mtx, 50% qtz, 20% cht frags, 30% coal+lith frags,nsofc.. 1025.67' MD 1025.62' TVD INC 0.27* AZI44.17* CL Y :mgrybrn, gmmy, hyd, VV slty-grdg to slst in cly form, xfgr sd, imbd wI + intbd wI sd, mica, mic carb specks, vsft. 1120.08' MD 1120.03' TVD INC 0.21* AZI40.52* SO : clr-opq, It-dkgry,blk, mgr, ang-sbang, wsrt, uncons, cly mtx, coal+lith frags,nsofc.. 1213.11' MD, 1213.06' TVO INC 0.30, AZI 32.17 CL Y :mgrybrn, gmmy, hyd, vv slty-grdg to slst in cly form, xfgr sd, imbd wI + intbd wI sd, mica, mic earb specks, vsft. 1307.41' MD, 1307.35' TVD INC 0.43, AZI 20.38 1401.20' MD, 1401.14' TVO INC 0.81, AZ1326.18 SD : clr, tmsl, It-dkgry, vf - m gr, sb ang - sb md, pr - m srtd, uncons slty cly mtx, pred qtz, lith frags, tr II wood & shell frags. II I 8 R 8 R ""~".."."'""."" 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'---- c.o (J1 0 . ~---- ----- ---- ----- . .,.--- ....... . c..---- ....... ....... . ,.--- ---- ~3 ~ NITS CG ',~ I\JTS 21 J~ II S CG 22 ~ ~ n s :G ¡ ~ ,ITS I I i'3.:: ~'inb i I i II :1 q~ 1~ j~l~ II I ( , \, (: \ .....-1111 \.," ) \ /' I' I \ I / '\ 1495.85' MO, 1495.77' TVO INC 1.40, AZI 313.90 SO : clr, trnsl, It-dkgry, vf - m gr, sb ang - sb rnd, pr - m srtd, uncans slty cly mtx, pred qtz, lith frags. 1589.94' MO, 1589.75' TVD INC 3.93, AZI 311.73 CL Y :It - m gry/brn, slty - v slty, Sd strgrs, acc carb specks, gmmy, sft. 1687.47' MO, 1686.85' TVO INC 6.69, AZIN 311.39 CL Y :It - m gry/brn, slty - v slty, Sd strgrs, acc carb specks, gmmy, sft. 1780.69' MO, 1779.31' TVD INC 7.96, AZI 308.85 SO : clr, trnsl, It-dkgry, vf - m gr, acc c gr, acc grdg to pea sz gvl, sb ang - sb rnd, pr - m srtd, uncans slty cly mtx, pred qtz, lith frags, tr wood. 1874.36' MO, 1872.00' TVD INC 8.81, All 306.94 SO : clr, trnsl, It-dkgry, vf - m gr, acc c gr, acc grdg to pea sz gvl, sb ang - sb rnd, pr - m srtd, uncans slty cly mtx, pred qtz' lith frags. 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CJ'I .-------- - 0 --------'.- -------- - 8__--__-- -- ¡ .-------- - -------- -- 8______-. - , r ./ ) I) CG 6 - ,ITS \ t, ) \1 3196.16' MO, 306.38' TVO INC 20.51, AZI 306.15 CL Y :m - dk gry/brn, slty - v slty, sli sdy, occ carb specks, v gmmy, sft. 3230.64' MO, 3158.44' TVO INC 20.24, AZI 306.17 N -a C r- Z MAX GAS Gas Chromatograph Gamma Ray ::¡ 0 C1 Avg - Lithology Trace 0 < -I < -I ~~ :t m C4 Total 0 api 150 ~ iTVO ~ ëñ 0 ::0 la¡ (ß f¥jd)1A~ C2 Avg "D z:1: - C r- ::o (j)o C5 Total Logging ROP Avg :< 0 » 0 m C3 Avg - ï G') -I ~ G') m RESCALE x1 0 feet per hr -< -< c 1K 0 6--1 FT 1--6 0 100 100 1K 10K 100K 1 M 8______-- -- .------_. - -------- ~- 8______- - 8______-- .. ) .-------- - w . =---_-:..--==-----:;,. : tV 0______--..- g :==-=-:..:::.~~-=-~: ' 8______---- ::-=-=-=-~7=-:: " ( ( ) ) ~~Á,~E : F !Æ~~,~~~] ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mike Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. . P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar Unit NS 07 BP Exploration (Alaska) Inc. Pemrit No: 202-077 Sur Loc: 1109' NSL, 642' WEL, Sec. 11, T13N, R13E, UM Btmhole Loc. 4811' NSL, 1739' WEL, Sec. 15, TI3N, RI3E, UM Dear Mr. Schultz: Please replace the transmittal letter that you received from our office on April 1, 2002 with this revision. The letter inadvertently stated that the agency had granted your waiver of the diverter requirements for NS 15. It should have stated NS07. The permit 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 permitting determinations are made. You have requested a waiver of the diverter requirements at 20 MC 25.035 (c). Your request for waiver of the diverter requirements is granted for NS07. Annular disposal has not been requested as part of the Permit to Drill application for Northstar 07. Blowout prevention equipment (BOPE) must be tested .in accordance with 20 MC 25 035. 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, Ú~ {)dwL' jt~t--< Cammy OOchsli Taylor Chair BY ORDER OF THE COMMISSION . DATED this 1st day of April, 2002 Nunc Pro Tunc cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) AlASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR ~7~~E :1 ~~~~~~~ 333 W. -pH AVENUE, SUITE 100 ANCHORAGE,. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Mike Schultz Senior Drilling Engineer . BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar Unit NS 07 BP Exploration (Alaska) Inc. Pennit No: 202-077 Sur Loc: 1109' NSL, 642' WEL, Sec. 11, T13N, R13E, UM Btmhole Loc. 4811' NSL, 1739' WEL, Sec. 15, T13N, RI3E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations 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 NSI5. Annular disposal has not been requested as part of the Pennit to Drill application for Northstar 07. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. 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, Cæ'1t~1Uf ~~L~ . ~~/ Cammy tbechsli Taylor() Chair BY ORDER OF THE COMMISSION DATED this 1st day of April, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 20" 16" 12-1/4" 8-1/2" 6-1/8" . STATE OF ALASKA ALASKA Oil ¡~D GAS CONSERVATION COMMISt 1J PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 56.0' 6. Property Designation ADL 312799 7. Unit or Property Name Northstar Unit 8. Well Number NS07 9. Approximate spud date 04/16/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13590' MD /113451 TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 40.1 0 Maximum surface 4151 psig, Attotal depth (TVD) 112891/5280 psig Setting Depth Top Bottom MD TVD MD TVD Sufrace Surface 2001 2001 Driven Surface Surface 35321 3175' 616 sx PF ILl, 466 sx Class IGI Surface Surface 115501 96451 758 sx Econolite, 775 sx Class 'GI 114001 95301 129441 107861 ,252 sx Class IGI 12794' 106551 135901 113451 102 sx Class IGI IIJ~ '2,þ1/0L I::J' ~ (d- \ 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1109' NSL, 6421 WEL, SEC. 11, T13N, R13E, UM At top of productive intelVal 47411 NSL, 14301 WEL, SEC. 15, T13N, R13E, UM At total depth 48111 NSL, 17391 WEL, SEC. 15, T13N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 312808, 1293' MD (Approx.) Nsoa Is 9.64' away at 400' MD 16. To be completed for deviated wells Kick Off Depth 3001 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casino Weioht Grade Couplina 20" 169# X-56 WELD 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-Mod 7" 26# L-80 Hydril521 4-1/2" 12.6# 13Cr Vam Ace 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Lenath 2001 35321 115501 15441 7961 Quantitv of Cement (include staoe data) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED Perforation depth: measured MAR 2 8 2002 true vertical AlllklOII&GIICcaO:ølllion ~..,. Approved By Form 10-401 Rev. 12-01-85 re to the be my knowledge itle Senior Drilling Engineer . ~missionUseOnIy. Permit Number API Number Approval Date See cover letter 2. 0..2. - 0 7 7 50- d.2 9' - z 3 0 ? I for other requirements Conditions of Approval: Samples Required D Yes ~No Mud Log Required ~ Yes D No Hydrogen Sulfide Measures DYes J8I No Directional SUlVey Required ŒI Yes D No Required Working Pressure for BOPE D 2K D 3K D 4K D 5K D 10K D 15K D 3.5K psi for CTU Other: ~S~O ~\ ~<:J"?~s:.~ Origma\ Signed Bv'" 4 "". by order of C . Ooens\\ Commissioner the commission &Inrny U ~~.l (J ¡ N J\ L" 0 BOP Sketch 0 Diverter Sketch II Drilling Program 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By NameINumber: Sandra Stewman, 564-4750 20. Attachments II Filing Fee 0 Property Plat II Drilling Fluid Program 0 Time v~Pih Plot Contact Engineer NameINumber: Barbara Holt, 564-5791 21. I hereby certify that the foregoing is true and . /J111t=é'~t,,-i --Ie... JÍ /.~/ Signed _Ãl~ 11.,..- '-- / ¥1.¿~~ Date ?i}7-~-è Date Submit In Triplicate bp ') ... ..\.\,.",. .~~ ~~. ~.- -..-. .....#~ ~...~ . jj,.jl\- ". BP Exploration Alaska Inc. To: Tom Maunder - AOGCC Date: March 25, 2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS07 Application for Drilling Permit Mr. Maunder, Well NS07 is currently scheduled for Nabors 33E on April 16, 2002. A Diverter waiver is also requested on NS07. To date, BP has drilled ten development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. All ten surlace 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 rDarker. Well mud logs and seismic data do not indicate the presence of a shallow gasV' hazard. . / Well NS07 will have cement placed to the top of the SV6 confining shale as per EPA permit NS10 Area of Review drilling requirements which states "New wells within the area of review shall be constructed in accordance with the AOGCC Regulations Title 20-Capher 25. Further, all wells in the area of review shall have casing cemented to the formation throughout the entire section from the base of the lower confining zone to the top of the upper confining zone.". Please find attached the NS07 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5791. ]~ Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 ) ) NS 07 SUMMARY DRilLING OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ASS Vetco landing ring for the ASS Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ria Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. . ./ NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the top of the SV6 marker at approximately 3329' MD. v' Surface casing point has been picked at 3532' MD. POOH. ~/ 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. NO diverter / riser system and NU casing / multi-bowl wellhead. NU SOPE and test)O 250/4500 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 (approximately 11 ,550'MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.0 ppg at the top of Kuparuk. POOH. ¡! 9. RU Schlumberger. Run open hole Dipole Sonic and FMI (4 arm caliper). POOH and RD Schlumberger. 10. Make a cle~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 SV6 confining shale 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 packoft. Down-squeeze cement followed by a spacer and diesel to 2000' TVD for freeze protection. 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 13.5ypg. (FIT/LOT procedure on file with AOGCC). 14. Weight up to 12.2 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the ~g at approximately 12,910' MD. Int9imediate casing point has been picked at 12,944' MD. POOH. 15. Run and cement a 7" 26# dfïíling 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 tOK 3500-psi with 12.2-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 7" shoe with 12.2-ppg mud and perform a Formation Integrity test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.1 ppg after the FIT, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.1 ppg drill-in fluid. / / 18. Drill 6-1/8" production interval to the proposed TO at 13,590' MD. POOH. NS07 Permit to Drill ') ) 19. RU Schlumberger E-line unit. Run open hole Dipole Sonic and FMI (4 arm caliper). POOH and RD Schlumberger. 20. Make a clean out run, if required, and 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 80 NTU's) using spacers as per Baroid recommendation 25. POOH with the clean out assembly and prepare to run the 4 Y2" completion. 26. Run the 4 Y2", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 27. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +1- 2000' TVD (2119' 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 head 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 4 Y2" x 9 5/a" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (4508'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. MIRU Slickline. Pull the ball and rod I IìHC profile from 'XN' nipple below the new production packer. RDMO Slickline. ) 37. MIRU Schlumberger Wireline. Run USIT/CBL. RD Schlumberger Wireline. 38. Perforate -140' Ivishak formation between the Top Ivishaynd OWC. 0 Perforate interval based on PE recommendation. 39. MIRU Slickline. Run SSSV. RDMO Slickline. 40. Install (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: April 16, 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 2 NS07 Permit to Drill ') ) NS07 WELL PLAN SUMMARY 1 Type of Well (producer or injector): Northstar Slot: Surface Location: Brookian Target: 400' Radius Target (top of SAG): 400' Radius Bottom Hole Location: 1 AFE Number: 1831309 1 Producer NS07 1109' FSL, 642' FEL, Sec. 11, T13N, R13E, UM X = 659835 Y = 6030882 4192' FSL, 4285' FEL, Sec. 14, T13N, R13E, UM X = 656241 Y = 6028608 4741' FSL, 1430' FEL, Sec. 15, T13N, R13E, UM X = 653805 Y = 6029107 10,796' TVDrkb 4811' FSL, 1739' FEL, Sec. 15, T13N, R13E, UM X = 653495 Y = 6029171 11,345' TVDrkb I Rig: 1 Nabors 33E / I Estimated Start Date: 14/16/02 I I I 56.0' /15.9' I I I 1 Operating days to complete: 141.1 I MD: 113,590 I I TVDrkb: 111,345 I I RKB/Surface Elevation: (a.m.sJ.) I Well Design (conventional, slim hole, etc.): I Modified Big Bore I Objective: I Ivishak Producer with fiber optic surveillance control line Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS07 Producer 5175 psi @ 11,100' TVD / 8.95 ppg / 254 of @ 11,100' TVD Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20", 169#, X-56 (pre-driven) 3 NS07 Permit to Drill ') "\ I MUD PROGRAM: Surface Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3532' MD /3175' TVD (-150' TVD below top SV6). Interval Density Viscosity VP Tauo Gel API FL pH (ppg) (seconds) 10 sec Initial 8.8 - 9.0 1 00 - 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 TD *9.5 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. Intermediate Hole Mud Properties: Seawater Polymer 12-1/4" Hole Section From Surface Casing Shoe to 11,550' MD / 9645' TVD (-top Miluveach). Interval Density (ppg) PV VP Initial 8.7 - 9.3 10 -16 20 - 30 Top HRZ 9.6 10 - 16 20 - 25 Top Kuparuk to Miluveach 10.0 10- 18 20 - 28 Tauo 4-7 4-7 4-7 API/ HTTP FL 6-10 4-6/<12 4-6/<12 pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 12,944' MD /10,786' TVD (top of Sag) Interval Density (ppg) / PV VP Miluveach & Kingak to top of Sag 11.8-12.2./ 10 - 25 20 - 25 Tauo 4-7 API FL pH 4-6/<10 8.5 - 9.5 1 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 13,590' MD / 11,345' TVD Interval Density (ppg) PV VP Initial/Final 9.1 - 9.3 8 - 12 20 - 25 6-1/8" Hole Section Tauo 4-7 APIFL 3-5 pH 8.5 - 9.5 4 / :t300. MD Cantenary curve 1 °/1 00' to 2.75°/100' build :t40.1 ° Surface- 10' well spacing . NS06 - planned well, not yet drilled. / NS08 - closest point at 400' MD center-to-center distance is 9.64 ft. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1500'. Standard MWD surveys from +/-1500' to TD. NS07 Permit to Drill PIRECTIONAL:(P14) KOP: Maximum Hole Angle: Close Approach Well: Survey Program: ) SURFACE AND ANTI-COLLISION ISSUES: ./ Well NS07 is 9.64 ft center to center from NS08 at 400' MD. NS07 is 8.06 ft center to center at 550' MD from the NS06 plan. Both wells pass the 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 NS05 NS06 plan NS08 NS09 NS10 NS11 NS12 NS13 NS14 NS15 NS16 NS18 NS20 NS21 NS23 NS24 NS25 NS26 NS27 NS28 NS29 NS31 NS35 Seal #A-1 Seal #A-2 Seal #A-2A Seal #A-3 Seal #A-4 Allowable Deviation (ft) 12.67 4.26 6.73 9.45 27.48 33.01 43.36 50.67 66.74 72.71 83.07 102.66 122.97 133.45 153.02 163.14 173.63 181.80 194.50 202.94 213.85 234.13 273.02 436.66 417.62 417.80 420.81 454.86 Depth (MD) 450 550 400 350 200 450 400 400 350 450 450 450 450 350 450 450 350 400 450 450 350 400 450 400 150 150 400 200 5 Precautions Pass major risk Pass minor risk 1 :200 Pass minor risk 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 major risk Pass major risk Pass major risk Pass major risk Pass major risk Pass major risk Pass major risk /' NS07 Permit to Drill LOGGING PROGRAM: 16" Section: Drilling: Open Hole: Cased Hole: 12-1/4" Section: Drilling: Open Hole: Cased Hole: 8-1/2" Section: Drilling: Open Hole: Cased Hole: 6-1/8" Section: Drilling: Open Hole: Cased Hole: Inte~ritv Testinq: Test Point 12 %" Surface Shoe 9 5/8" Intermediate Shoe 7" Drilling Liner Shoe ) ) GR/Directional - Gyro as needed Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) None None GRlDirectional, Resistivity (real-time), Density/Neutron (recorded), PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples from 9750' MDrkb (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Dipole Sonic (TD to surface shoe), FMI (4 arm caliper) None GR/Directional, Resistivity (real-time), Density/Neutron (recorded), PWD 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) Dipole Sonic (TD to Intermediate shoe), FMI (4 arm caliper) None GRlDirectional, Resistivity/Density/Neutron (recorded) 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) GR, Resistivity, Density, Neutron, Dipole Sonic (TD to 7" shoe) USIT/CBL (after rig release) Depth Test Type 20' min from 12 1/4" shoe FIT 20' min from 9 5/8" shoe FIT 20' min from 7" shoe FIT CASINGITUBING PROGRAM: Hole Size Casing/ Wt/Ft Grade Conn. Casing Tbg a.D. Length 20" 20" 169# X-56 WELD 200' 16" 13 3/8" 68# L-80 BTC 3532' 12 %" 9 5/8" 47# L-80 BTC-Mod 11550' 8 Y2" 7" 26# L-80 Hydril 521 1544' 6-1/8" 4-1/2" 12.6# 13Cr Yam Ace 796' Tubing 4-1/2" 12.6# 13Cr Yam Ace 12794' 6 EMW 12.5 ppg EMW Target 13.5 ppg EMW Target / 12.2 ppg EMW Target (dependant on final MW in 8 Y2" hole.) Casing Top MDITVDrkb Su rface Su rface Surface 11400'/9530' 12794'/10655' Surface Hole Btm M DITVDrkb 200' /200' 3532'/3175' 11550'/9645' 12944'/10786' 13590'/11345' 12794'/10655' ) " NS07 Permit to Drill ) FORMATION MARKERS: TVDss MDrkb Pore Press. Comment Formation Top estimated (Psi) I (ppg EMW) Top Permafrost 1149 1216 542 8.65 Base Permafrost 1519 1617 708 8.65 Set surface csing 1051 tvd below SV6 - top confining zone 2950 3329 1352 8.65 top SV6 Surface casing point 3119 3532 0 0.00 / SV5 - base confining zone 3226 3661 1476 8.65 SV4 3521 4016 1609 8.65 SV2 - top upper injection zone 3930 4508 1793 8.65 SV1 - top major shale barrier 4320 4977 1968 8.65 TMBK - top lower injection zone - Top Ugnu 4642 5364 2113 8.65 WS1 - top Schrader Bluff - Base Ugnu 6194 7231 2811 8.65 CM3 - Base lower injection zone (top Colville) 6697 7834 3038 8.65 Geol target #1 7586 8932 3437 8.65 THRl - Top HRl 8441 10050 3822 8.65 BHRl - Base HRl 8560 10205 3876 8.65 Hydrocarbon bearing (mainly Top Kuparuk 8680 10362 4265 9.45 gas) Hydrocarbon bearing (mainly Kuparuk C 9002 10783 4428 9.46 gas) Set intermedate casing into the Top Miluveach 9432 11345 4333 8.83 top of the Miluveach Intermediate casing point 9589 11550 0 0.00 I Intermediate logging point 9589 11550 0 0.00 Top Kingak 9912 11972 4690 9.10 Fault 115211 - throw = 150. 10033 12125 Expected in upper Kingak Set drilling liner into top Sag River to cover Kingak. Top Sag River 10700 12910 5006 8.95 Hydrocarbon bearing. Intermediate casing point 10730 12944 0 0.00 ./ Geol target #2 10740 12956 4992 8.94 Top Shublik 10788 13011 5047 8.95 Top Ivishak 10850 13083 5076 8.95 Oil - Water contact 11 069 13336 5178 8.95 Top Kavik 11249 13544 5261 8.95 Total Depth 11289 13590 5280 8.95 / Top Lisbu me 11329 5438 9.19 Possible lost circulation zone 7 NS07 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L~80 Drlg Liner: 13Cr Liner: 13Cr Completion: ) 3532' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1 - 13 5/8" 11550' 1 -95/8" 1 -95/8" 1 - set 1 - 13 5/8" x 9 5/8" 100 - 9 5/8" x 12" 1544' 1 - 8 Y2" 1 -7" 1 -7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1 -7" 796' 1 -4-1/2" 1 -4-1/2" 40 - 4-1/2" x 5-3/4" 20- 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 -4-1/2" 12794' 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 95/8",47# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB- VG I Casing Hanger SV Rigid Centralizers 7",26# L-80 Hydril521 BBL reamer shoe HES Super Seal II Float Shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker HR running tool Baker Landing Collar and plug set 4-1/2",12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Vam Ace 4 Y2" ABB- VG I tubing hanger 4 Y2" ABB-VGI adapter flange 4 Y2" ABB-VGI 5-1/8" 5K Swab Valve w/ tree cap CIDRA mandrel and 0.25" fiber optic cable (w/4 Y2" cable clamps). 4 Y2" SVLN and 2 - 0.25" control lines 4 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 8 NS07 Perm it to Drill ) ) PERMAFROST: The 13-3/8" surface casing will be run approximately 1500' TVD below the permafrost to -3532' MD I 3175' 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. ./ CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MO, 1375' of Open Hole + 175% excess from the permafrost t~~)Urface + 50% excess to 750'MD above the shoe. Lead TOC: Surface Tail: Based on 750' of 16" open hole x 133/8" casing with 50% excess + 80' shoe joint. Tail TOC: -2782' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpha Sp~er weighted to 1.0 ppg over mud weight 455 bbl /ß16 sk I 2556 ft of 10.7 ppg Permafrost 'L' Cement. 4.15 cf/sk, BHS"(50° I BHCT 50°, TT = 6.0 hrs 96 bbV466 sk1541 ft::! of 15.8 ppg Premium 'G' wI 2% CaCI2. 1.16 cf/sk, BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 6033' of 1J/1/4" open hole x 9 518" csg with 30% excess Lead TOC: At -3329' MD (3006' TVD) Tail: Based on 2188' of 12 14" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -9362' MD (8177' TVD) IStage 1: Total Cement / Spacer Preflush Spacer Lead 20 bbls sea water 50 bbl Alpha S~cer we~hted to 1.0 ppg over mud MW 437b»1 I 758 sk I 2456 ft of 11.2 ppg Econolite. 3.24 cf/sk, BHS.1210° (BHCT 130°, TT = 4.0 hrs 159b91/ 1775 sk / 891 ft::! of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs Tail Casing 17" Drilling Liner Basis: Stage 1: Slurry: Based on 1394' of 8 1/2" open hole x 7" csg with 500/0 excess + 150' 9 5/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe ~ove TaL + 80' shoe joint. Slurry TOC: At -11400' MD (9530' TVD) Stage 1: Total Cement / Spacer Spacer 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW /. ::! Slurry 69 b9VI 252 sk /378 ft of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs Casing 14-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 646' of 6 1/8" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 4 1/2" csg liner lap + 200' 7" csg x 4" drillpipp above TaL + 80' shoe joint. Slurry TOC: At -12794' MD (10655' TVD) Stage 1: Total Cement / Spacer Spacer 35 bbl Alpha SRacer weighted to 1.0 ppg over mud MW Slurry 28 bbV/102 s10153 ft::! of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs 9 NS07 Permit to Drill ') ) WELL CONTROL: / ~ A Diverter waiver has been requested on well NS07. To date, BP has drilled ten development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. All ten 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 I ~ Based upon the calculations below, BOP equipment will be tested to 4500 psi. Surface Section: . Maximum anticipated BHP: 1352 psi @ 2950' TVDss - SV6 . Maximum surface pressure: 1057 psi @ surface / (Based on BHP and a full column of gas from TO @ 0.10 psi/ft) Intermediate Section: . Maximum anticipated BHP: 4428 psi @ 9002' TVO$s - Kuparuk 'C' . Maximum surface pressure: 3528 psi @ surface'/ (Based on BHP and a full column of gas from TO @ 0.10 psi/ft) Drilling Liner Section: . Maximum anticipated BHP: 5006 psi @ 10700' TJDSS - Sag River . Maximum surface pressure: 3936 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/ft) Production Section: . Maximum anticipated BHP: 5280 PSi@11289'T;VDss-TotaIDepth . Maximum surface pressure: 4151 psi @ surface (Based on BHP and a full column of gas from TO @ 0.10 psi/ft) . 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 subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. 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 NS10 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 NS1 0 Class I Waste Disposal Well. 10 NS07 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. I . Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS08 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. . . . . . . I 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 2000-2002 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, an uninterrupted fault is possible in both the Schrader and the Upper Kuparuk (approximately 8900' TVDrkb), the possibility of losses exists. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone 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 69.2 bbls assuming an influx from the Kuparuk interval at -8736' TVD. This is the worst-case scenario based on a 10.0 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (based on a FIT) of 12.5 ppg at the 13-3/8" shoe, and 10.0 ppg mud in the hole. . . . . . . 11 NS07 Permit to Drill ") ') DRILLING LINER SECTION: . Mudloggers will be rigged up throughout the entire section. The directional target has been designed to penetrate fault #52 at 10089'MD. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone 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 12.2 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 9.6 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 12.2 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 12.2 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. 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 (CaC03) 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 9.69 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 12.2 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. . . . . . . 12 ') ) NS07 Permit to Drill NS07 Ri~-site Summary of Drillin~ Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS07 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 NS07 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 .) TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl5ksi NS07 - Proposed 133/8"TAM Port Collar at +1-1600'MD 133/8", 68#/ft, L-80, BTC @ 3532' MD ./ 4 1/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT 9-5/8" 47# / >4 L-BO BTM-C @ 11550' MD ..= 4.5" X NIPPLE, @ 12744' MD 3.813" ID 4.5" X NIPPLE, @ 12764' MD 3.813" ID 4.5" XN NIPPLE, @ 12774' MD 3.725" ID 4.5" WLEG, @ 12784' MD 3.958" ID - 7", 26#/ft L-80, Hydril521 @ 12944' MD PBTD @ 13510' TD @ 13590' DATE ~ .. 3 '\ E / J. /l REV. BY COMMENTS BMH ~S07 Proposed 3/19/02 ~ l ') ORh.",r:JAL KB. ELEV = 55.9' KB-BF. ELEV = 40.2' CB. ELEV = 15.9' ~ '1 1/2" SSSV @ 2000' TVD wi HXO SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 3986' TVD (4508'MD) 4 1/2" GLM @ 4500' TVD (5362' MD) wi 4.62" ID II" I ~ - 7" LINER TOP @ 11400' MD ~ ~ ~ 4.5" Fiber Optic Transducer 3.958" ID ~ - 7" PACKER,13 Cr @ 12754' MD ,~ 4.5" LINER TOP @ 12794' MD 4.5", 12.6#, 13CrVam Ace Northst~r WF. . : NS07 API NO: BP Exploration (Alaska) I KB KOP Bid 1/100 Build 1.5/100 Bid 2.5/100 Top Permafrost Base Permafrost bp Report Date: Client: Field: Structure 1 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: Station ID MD (ft) 0.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1215.91 1300.00 1400.00 1500.00 1600.00 1616.64 1700.00 NS07 (P14) report. xis NS07 Proposed Well Profile - March 19, 2002 BP Exploration Alaska Northstar Northstar PF / NS07 l1li1 II'" ~~~~ Feaslb. ...~ 50029 NS07 (P14) S19/ March 19,2002 73.192° /7152.34 ft /5.797/ 0.63C NAD27 Alaska State Planes, Zone 4, US Fee1 N 70.49091397, W 148.69327617 N 6030881.770 ftUS, E 659834.580 ftUS +1.23172678° 0.99992902 Incl (°) 0.00 0.00 1.00 2.00 3.00 4.50 7.00 9.50 12.00 14.50 17.00 17.40 19.50 22.00 24.50 27.00 27.42 29.50 Azim (°) 233.57 233.57 233.57 233.57 233.57 233.57 233.75 233.84 233.89 233.92 233.94 233.95 233.96 233.97 233.99 TVD (ft) 0.00 300.00 399.99 499.96 599.86 699.65 799.13 898.09 996.33 1093.66 1189.90 1205.10 1284.86 1378.37 1470.24 234.00 1560.30 234.00 1575.10 234.00 1648.38 VSec I (ft) 0.00 0.00 0.81 3.22 7.25 13.29 22.55 35.82 53.08 74.30 99.43 103.79 128.43 161.23 197.79 Geodetic Report Survey 1 DLS Computation Method: Vertical Section Azimuth: Y Vertical Section Origin: TVD Reference Datum: S'tU 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: N/-5 (ft) 0.00 0.00 -0.52 -2.07 -4.66 -8.55 -14.48 -22.95 -33.95 -47.45 -63.43 -66.20 -81.86 -102.70 -125.91 EI.W (ft) 0.00 0.00 -0.70 -2.81 -6.32 -11.58 -19.65 -31.23 -46.29 -64.81 -86.75 -90.56 -112.07 -140.72 -172.64 238.03 -151.45 -207.78 245.08 -155.92 -213.94 281.87 -179.27 -246.07 Page 1 of 3 I DLS (0/100ft) 0.00 0.00 1.00 1.00 1.00 Schlumberger Minimum Curvature / Lubinski 256.130° N 0.000 ft, E 0.000 ft KB 56.1 ft relative to MSL 15.670 ft relative to MSL 26.466° 57516.119 nT 80.933° May 01, 2002 BGGM 2001 True North +26.466° Well Head Grid Coordinates Northing Easting (ftUS) (ftUS) 6030881.77 659834.58 6030881.77 659834.58 6030881.24 659833.89 6030879.64 659831.82 6030876.98 659828.36 1.50 2.50 2.50 2.50 2.50 6030872.97 6030866.87 6030858.16 6030846.84 6030832.94 659823.19 659815.25 659803.85 659789.03 659770.81 659749.22 659745.47 659724.30 659696.11 659664.70 -" Geographic Coordinates Latitude I Longitude N 70.49091397 W 148.69327617 N 70.49091397 W 148.69327617 N 70.49091255 W 148.69328189 N 70.49090832 W 148.69329914 N 70.49090124 W 148.69332783 N 70.49089062 W 148.69337083 N 70.49087442 W 148.69343679 N 70.49085128 W 148.69353145 N 70.49082123 W 148.69365455 N 70.49078434 W 148.69380593 .~ N 70.49074069 W 148.69398527 N 70.49073312 W 148.69401641 N 70.49069034 W 148.69419223 N 70.49063341 W 148.69442641 N 70.49057000 W 148.69468732 2.50 6030725.90 659630.12 N 70.49050022 W 148.69497455 2.50 6030721.30 659624.06 N 70.49048801 W 148.69502490 2.50 6030697.27 659592.44 N 70.49042422 W 148.69528752 2.50 2.50 2.50 2.50 2.50 6030816.49 6030813.64 6030797.53 6030776.08 6030752.19 3/19/2002-1 :43 PM Grid Coordinates Geographic Coordinates Station 10 MO Incl I Azim TVD VSec N/-S EJ-W I OLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 1800.00 32.00 234.01 1734.32 329.23 -209.31 -287.44 2.50 6030666.35 659551.73 N 70.49034215 W 148.69562566 End Bid 1870.20 33.75 234.01 1793.27 364.54 -231.71 -318.27 2.50 6030643.29 659521.39 N 70.49028095 W 148.69587766 SV6 3328.94 33.75 234.01 3006.10 1115.43 -707.97 -974.12 0.00 6030153.08 658875.97 N 70.48897972 W 148.70123796 13-3/8" Csg Pt 3532.21 33.75 234.01 3175.10 1220.06 -774.34 .1065.51 0.00 6030084.76 658786.04 N 70.48879837 W 148.70198484 SV5 3660.90 33.75 234.01 3282.10 1286.31 -816.36 -1123.37 0.00 6030041.51 658729.10 N 70.48868355 W 148.70245769 SV4 4015.72 33.75 234.01 3577.10 1468.95 -932.20 -1282.89 0.00 6029922.28 658572.12 N 70.48836702 W 148.70376132 SV2 4507.64 33.75 234.01 3986.10 1722.18 -1092.81 .1504.06 0.00 6029756.96 658354.47 N 70.48792815 W 148.70556869 SV1 4976.72 33.75 234.01 4376.10 1963.64 -1245.96 -1714.96 0.00 6029599.33 658146.92 N 70.48750964 W 148.70729206 TMBK 5364.01 33.75 234.01 4698.10 2163.00 -1372.41 .1889.09 0.00 6029469.17 657975.56 N 70.48716408 W 148.70871492 WS1 7230.69 33.75 234.01 6250.10 3123.89 -1981.87 .2728.35 0.00 6028841.86 657149.66 N 70.48549840 W 148.71557201 Cry 2/100 7465.10 33.75 234.01 6444.99 3244.55 -2058.40 .2833.74 0.00 6028763.09 657045.95 N 70.48528922 W 148.71643301 3262.57 -2069.61 -2849.53 2.00 6028751.54 657030.40 N 70.48525858 W 148.71656201 ~ 7500.00 33.66 235.26 6474.03 7600.00 33.45 238.86 6557.37 3314.79 -2099.66 -2895.90 2.00 6028720.50 656984.69 N 70.48517644 W 148.71694084 7700.00 33.35 242.49 6640.86 3367.82 -2126.61 -2943.87 2.00 6028692.53 656937.32 N 70.48510276 W 148.71733276 7800.00 33.35 246.13 6724.40 3421.61 -2150.44 -2993.39 2.00 6028667.64 656888.32 N 70.48503761 W 148.71773735 CM3 7834.36 33.38 247.37 6753.10 3440.25 -2157.90 -3010.75 2.00 6028659.81 656871.13 N 70.48501721 W 148.71787918 7900.00 33.46 249.75 6807.89 3476.09 -2171.11 -3044.40 2.00 6028645.88 656837.77 N 70.48498108 W 148.71815412 8000.00 33.68 253.35 6891.22 3531.18 -2188.59 -3096.83 2.00 6028627.28 656785.73 N 70.48493327 W 148.71858250 8100.00 33.99 256.90 6974.29 3586.83 -2202.88 -3150.63 2.00 6028611.84 656732.26 N 70.48489417 W 148.71902209 8200.00 34.41 260.38 7057.01 3642.97 -2213.94 -3205.72 2.00 6028599.60 656677.42 N 70.48486389 W 148.71947223 8300.00 34.92 263.78 7139.26 3699.53 -2221.77 -3262.04 2.00 6028590.56 656621.29 N 70.48484243 W 148.71993243 8400.00 35.53 267.08 7220.95 3756.43 -2226.35 -3319.52 2.00 6028584.75 656563.92 N 70.48482985 W 148.72040212 8500.00 36.22 270.28 7301.99 3813.61 -2227.69 -3378.09 2.00 6028582.15 656505.40 N 70.48482612 W 148.72088073 8600.00 37.00 273.37 7382.26 3871.01 -2225.77 -3437.68 2.00 6028582.79 656445.79 N 70.48483129 W 148.72136768 8700.00 37.85 276.35 7461.68 3928.54 -2220.61 -3498.22 2.00 6028586.64 656385.15 N 70.48484531 W 148.72186241 8800.00 38.78 279.21 7540.15 3986.15 -2212.20 -3559.63 2.00 6028593.73 656323.58 N 70.48486821 W 148.72236427 8900.00 39.77 281.95 7617.57 4043.75 -2200.56 -3621.84 2.00 6028604.03 656261.14 N 70.48489992 W 148.72287267 --- End Cry / Brkn Tgt 8931.99 40.10 282.81 7642.10 4062.17 -2196.16 -3641.89 2.00 6028608.00 656241.00 N 70.48491192 W 148.72303653 8931.99 40.10 282.81 7642.10 4062.17 -2196.16 -3641.89 2.00 6028608.00 656241.00 N 70.48491192 W 148.72303653 Top HRZ 10049.74 40.10 282.81 8497.10 4705.47 -2036.55 -4343.93 0.00 6028752.47 655535.75 N 70.48534692 W 148.72877415 Base H RZ 10205.31 40.10 282.81 8616.10 4795.01 -2014.34 -4441.64 0.00 6028772.57 655437.59 N 70.48540744 W 148.72957273 Top Kuparuk 10362.18 40.10 282.81 8736.10 4885.30 -1991.94 -4540.17 0.00 6028792.85 655338.61 N 70.48546847 W 148.73037802 Kuparuk C 10783.13 40.10 282.81 9058.10 5127.57 -1931.83 -4804.57 0.00 6028847.26 655072.99 N 70.48563222 W 148.73253899 Top Miluveach 11345.28 40.10 282.81 9488.10 5451 . 11 -1851.56 -5157.64 0.00 6028919.91 654718.31 N 70.48585087 W 148.73542472 9-5/8" Csg Pt 11550.52 40.10 282.81 9645.10 5569.24 -1822.25 -5286.55 0.00 6028946.44 654588.81 N 70.48593069 W 148.73647836 NS07 (P14) report. xis Page 2 of 3 3/19/2002-1 :43 PM Grid Coordinates Geographic Coordinates I Station ID MD Inel Azim TVD VSee N/-S EI.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) Orp 1.5/100 11882.74 40.10 282.81 9899.22 5760.44 -1774.81 -5495.21 0.00 6028989.38 654379.19 N 70.48605988 W 148.73818383 11900.00 39.84 282.81 9912.45 5770.35 -1772.35 -5506.03 1.50 6028991.61 654368.32 N 70.48606657 W 148.73827227 Top Kingak 11971.92 38.76 282.81 9968.10 5811.05 -1762.26 -5550.44 1.50 6029000.74 654323.71 N 70.48609405 W 148.73863526 12000.00 38.34 282.81 9990.06 5826.69 -1758.38 -5567.51 1.50 6029004.25 654306.56 N 70.48610461 W 148.73877478 12100.00 36.84 282.81 10069.30 5881.20 -1744.85 -5626.99 1.50 6029016.50 654246.81 N 70.48614145 W 148.73926095 Fault 52 12124.68 36.47 282.81 10089.10 5894.36 -1741.59 -5641.36 1.50 6029019.45 654232.37 N 70.48615033 W 148.73937840 12200.00 35.34 282.81 10150.11 5933.83 -1731.79 -5684.43 1.50 6029028.32 654189.10 N 70.48617701 W 148.73973044 12300.00 33.84 282.81 10232.43 5984.55 -1719.21 -5739.79 1.50 6029039.71 654133.49 N 70.48621126 W 148.74018293 12400.00 32.34 282.81 10316.21 6033.34 -1707.11 -5793.02 1.50 6029050.66 654080.01 N 70.48624421 W 148.74061801 12500.00 30.84 282.81 10401.39 6080.14 -1695.49 -5844.10 1.50 6029061.18 654028.70 N 70.48627584 W 148.74103553 End Orp 12556.02 30.00 282.81 10449.69 6105.48 -1689.21 -5871.76 1.50 6029066.86 654000.91 N 70.48629294 W 148.74126161 Top Sag River 12909.83 30.00 282.81 10756.10 6263.56 -1649.99 -6044.26 0.00 6029102.36 653827.62 N 70.48639970 W 148.74267158 .--- 7" Csg Pt 12944.47 30.00 282.81 10786.10 6279.03 -1646.15 -6061.15 0.00 6029105.84 653810.66 N 70.48641016 W 148.74280964 Target 12956.02 30.00 282.81 10796.10 6284.19 -1644.87 -6066.78 0.00 6029107.00 653805.00 N 70.48641364 W 148.74285566 Top Shublik 13011.44 30.00 282.81 10844.10 6308.96 -1638.72 -6093.80 0.00 6029112.57 653777.86 N 70.48643038 W 148.74307652 Top Ivishak 13083.03 30.00 282.81 10906.10 6340.94 -1630.79 -6128.71 0.00 6029119.74 653742.79 N 70.48645197 W 148.74336186 OWC 13335.91 30.00 282.81 11125.10 6453.92 -1602.76 -6252.00 0.00 6029145.11 653618.93 N 70.48652826 W 148.74436962 Top Kavik 13543.76 30.00 282.81 11305.10 6546.78 -1579.72 -6353.34 0.00 6029165.97 653517.13 N 70.48659097 W 148.74519797 TO /4-1/2" Lnr Pt 13589.95 30.00 282.81 11345.10 6567.41 -1574.60 -6375.86 0.00 6029170.60 653494.50 N 70.48660490 W 148.74538204 Leaal Description: Surface: 1109 FSL 642 FEL S11 T13N R13E UM End Crv / Brkn Tgt: 4192 FSL 4285 FEL S14 T13N R13E UM Target: 4741 FSL 1430 FEL S15 T13N R13E UM BHL: 4811 FSL 1739 FEL S15 T13N R13E UM Northina (Y) rftUSl 6030881.77 6028608.00 6029107.00 6029170.60 Eastina eX) rftUSl 659834.58 656241.00 653805.00 653494.51 .~ NS07 (P14) report.xls Page 3 of 3 3/19/2002-1 :43 PM ) ') VERTICAL Client: Well: Field: Structure: Section At: SECTION VIEW BP Exploration Alaska NS07 (P14) Date: Northstar Northstar PF 256.13 deg March 19, 2002 Schlumberger 0- KOP Bid 1/100300 MD 300 TVD / 0.00' 2,,3.57' az 0 departure &,..II~' ~ 1(1I.lr,',":' r II) 0:',":' r (. ..... "'... ..... ..... ~,./.. ,"""'"''.'''''';:''''''''''' Bid 2.5/100700 MD 700 TVD ¿----- 4.50' 233.57' az 13 departura End Bid 1870 MD 1793 TVD -- /"-':.'''-''"= "'-~": .~ ..... '''''To.t;'''''~,!rm~¡II~ð:;'t r~n() rv'¡¡ "21)~;"rvo"'" ...., ..... .....1, ""'B,¡)~~ P<:'f'n'I':'lfì"O'.j! '161'r't'v1J "1'~r?~;"TV[::-'" ... . -" -N~~f ":~1 ~Ì:Ö ,-:ri;o '¡:¡j~D ,.,. ~:~ÿ(~' ~,::m;s r\:1Ö :~'Ö;:'j(~ 'f,} ) ,. .... ~:~\ï~' 3;j(~'1 r,:1Ö :~2,~~ 'j"ij' ) " .....j. 2000 _.... ................Hold..Angle...33.;.75!>..... ..........¡--.. ......... +-' Q) ....-. Q)....J '+-c/) 8~ 0 Q) N > II ~ c: CO :;:4= .........0 .c""": ë.~ Q)......... 01]) -~ ro .. .~ 'ã5 ~o:: > > Q).92 ::Jill L... I- ..... ...., ..... ,,,.. ..", ..... . ~'~V4 1~0'1b :\110 ~¡f"¡77 1VD i .. ~ . ; ",¡ m., 4000 _..._.. ",-"".-'""-""-,,,."""",,,..-",,...-'..,.-....._.. .,.-,.,..-....._.....- ""-'''''-'''~''':rr,.;ïj~''f-Tf:';'',!(;~\'f'"r,jO--'W'-'' .._...._,~.,'-..,., ----- - -..- - .~- _.'.w -- ~~. -~ - ~~\TI ,ì<:I";) (f~1)) :ï~; nf!\/ 0-- ..- ,_. -~. i -~, . 1\ì~1('~i{"r,,~it.;Tr...1(r'~r;{;~' !"\?f.i¡ ..... ...¡ "... 6000 _.................... ...~. ~-"~-'-'~""-'--'''''~-'~""-,,,, Cov 2/100 ....-... 746&MD....6445.TV )................ --.........-......................-.-..-..............1...-....... -.. 33...75' ...234,.q1' .~;t ...... ..... .- -.. 3245 departure r..i'Ö' r/7"i;.~ '['I'D ' End Cov / Brl," Tgt 8932 MD 7642 TVD 40.10' 282.81' az 4062 departure ...! 8000 -..-.........-........ ....-....-....-. ,.~......~.._......_.......__.... ...._-.-...-..~_..- ....u..---_.....~.,....._.,_.....,~-_.....~.__....'....~.... ''''''~'_'''.,"_,~-~,''-'-,~......~'......._... m.... ... f'''''''' Hold Angle 40.10° 1 0000 _.... 1,:1:~i:::::~::::~,,~~ ! I ':"¡'ì~';2';Yii'~i;;;~:'ir::.ii':'}}}\18~¡;~;'~~'T;/rf... : i : i .: ::~.. :~; fg~~f~~;ë~'~1j~~i;j~,,\~~:;~JB,.§ ...., .m. ..,.. .... m.' ..... ...., ....~ ..~ ~~.~~:~, r:~~,1t'~:~"~~1;;'~;~ :/f Tv.d ..- -. -.- .-- .-. ~ .~.. ~ -- D¡:p 1~5/1ÕÕW .-- ~--..... .1.! 88.~..MD..J¡8~~.1YD. . 40.10' 282.81' az . 5760 departure _.~ -.- -.- -.. End Drp 12556 MD 10450 TVD '."3Ö'öo.c'2s:fa't. '~z"'" 6105 departure ..J :: .. ..~\.~~~:i~.~~~~TVO --j . -- ..~r)\~;;~lZ:,~", Hold Angle 30.00° : TD/~1/2'"LnrPl 30.00' 282.81'az [ ! 13590 MD 11345 TVD 6284 departure ...:.... '30:öö'"':ið2:¡WiiZ''''''''''''' 6567 departure 12000 _. I 0 I 2000 I 4000 I 6000 I 8000 Vertical Section Departure at 256.13 deg from (0.0, 0.0). (1 in = 2000 feet) 1000 -- ^ ^ ^ I ..... (k:: 0 Z -1000- I ..... -2000 --- => 0 Cf) V V V -3000 _.. PLAN VIEW Client: BP Exploration Alaska Well: NS07 (P14) Field: Northstar Structure: Northstar PF Scale: 1 in = 1000 ft Date: 19-Mar-2002 I -5000 -4000 -3000 -2000 -1000 , I I I I i i tJp -6000 I True North Mag Dee ( E 26.47° ) 0-...--- '~ ' : : ' , . . . . . . . . . . I_s - -~! ,., TD / +112" Lor PI T' Csg PI 13590 MD 11345 TVD 12944 MD 10786 TVD , 30.00' 282.81' az 30.00' 282.81' az Drp 1.$/100 157556376W ! 164656061W 11883Î.m 9899TVD ...--..-..u.--- ..._.----.;1. -- 40.10'! 282.81' az I /17755¡ 5495W ; . ¡ 9-518" Csg PI : i 11551 MD 9645TVD ~ A:;~;':::;~ 7Þ-~~' , _..-.__.~--_..- -.-- _....------f---- - -~--------i..-- ; t f -~ Target! : ¡ 12956 MD 10796 TVD ; End Drp : ¡ \- 30.00' 282.81' az 12556 MD 10450 TVD Hold. ! 16455 6067 W 30.00' 282.81' az ¡ Azll7JUth ¡ ... 16895 5872W ¡ 28') 8 ' ! <. 1p . i ! ! om.fm_... I ---.+--- i I -6000 I -5000 I -4000 «< WEST Schlumbepgep 0 I KOP Bid 11100 300 MQ 300 TVD ! Build 1.5/100 0.00' h3.57' az I ~~~~~~::~O N\O f ¡ 55 6W ¡ Bid 2.51100 i ~~~~~þ:~I:: / ":/11 ~ End Bid : ! \ 1870 MD 1~93 TVD ¡ 33.75' 234.!)1' az I 2325 318'Î,/ 13-3/8" Csg PI 3532 MD 3175 TVD ¡ 33.75' 234.01' az ; 7745 1066 W ~'\o ; r¿,.f>;)f>;). . ~~ ~~! ~O'Ò ! Cry 2/100 ; 7465 MD 644$ TVD 33.75' 234.01r az 20585 28340/ End CIV I ~rkn Tgl 8932 MD 7642 TVD 40.10" 28?81' az ----.. 21965 ~2W ..-.---.--.----.-.----- 1000 -"' -0 ---1000 -2000 .-" ------..--....-....--L..-..---..--....-- -3000 I I I I -3000 -2000 -1000 0 EAST»> ) Schlumberger Anticollision Report ') Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Northstar Northstar PF NS07 Plan NS07 Date: 3/19/2002 Time: 14:31 :21 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: NS07, True North NS07 plan 56.1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.20 to 13589.95 ft Maximum Radius: 2000.00 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 3/19/2002 Validated: No Planned From To Survey ft ft 40.20 1000.00 1000.00 13589.95 Version: Toolcode 29 Tool Name Planned: Plan #14 V1 Planned: Plan #14 V1 GYD-GC-SS MWD Gyrodata gyro single shots MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 3531.81 3174.77 13.375 16.000 13 3/8" 11550.09 9644.77 9.625 12.250 95/8" 12944.09 10785.77 7.000 8.500 7" 13589.95 11345.10 4.500 6.125 4 1/2" Summary <-'--' Offset Wellpath ---,.> Reference Offset Ctr-ctr No-Go Allowable Site Well Wellpath MD MD Distance. Area Deviation Warning ft ft ft ft ft Northstar PF NS05 Plan NS05 V4 Plan: Pia 450.56 450.00 20.13 7.47 12.67 Pass: Major Risk Northstar PF NS06 Plan NS06 V7 Plan: Pia 550.42 550.00 8.06 3.80 4.26 Pass: Minor 1/200 Northstar PF NS08 NS08 V18 400.00 400.00 9.64 2.91 6.73 Pass: Minor 1/200 Northstar PF NS09 NS09 V14 349.88 350.00 15.70 6.25 9.45 Pass: Major Risk Northstar PF NS10 NS10 V17 200.32 200.00 31.03 3.55 27.48 Pass: Major Risk Northstar PF NS11 Plan NS11 V3 Plan: Pia 449.70 450.00 41.13 8.12 33.01 Pass: Major Risk Northstar PF NS12 Plan NS12 V9 Plan: Pia 400.00 400.00 50.44 7.08 43.36 Pass: Major Risk Northstar PF NS13 NS13 V12 400.00 400.00 57.55 6.88 50.67 Pass: Major Risk Northstar PF NS14 NS14 V11 350.15 350.00 73.12 6.38 66.74 Pass: Major Risk Northstar PF NS15 Plan NS15 V15 Plan: PI 449.59 450.00 80.90 8.19 72.71 Pass: Major Risk Northstar PF NS16 Plan NS16 V18 Plan: PI 448.97 450.00 91.05 7.98 83.07 Pass: Major Risk Northstar PF NS18 Plan NS18 V3 Plan: Pia 448.68 450.00 110.83 8.18 102.66 Pass: Major Risk Northstar PF NS20 Plan NS20 V4 Plan: Pia 448.85 450.00 130.93 7.96 122.97 Pass: Major Risk Northstar PF NS21 Plan NS21 V37 Plan: PI 349.64 350.00 140.16 6.72 133.45 Pass: Major Risk Northstar PF NS23 Plan NS23 V15 Plan: PI 447.95 450.00 161.13 8.11 153.02 Pass: Major Risk Northstar PF NS24 Plan NS24 V3 Plan: Pia 447.80 450.00 171.09 7.95 163.14 Pass: Major Risk Northstar PF NS25 Plan NS25 V2 Plan: Pia 349.45 350.00 180.17 6.54 173.63 Pass: Major Risk Northstar PF NS26 NS26 V22 398.45 400.00 188.84 7.03 181.80 Pass: Major Risk Northstar PF NS27 NS27 V29 447.37 450.00 202.59 8.09 194.50 Pass: Major Risk Northstar PF NS28 Plan NS28 VO Plan: Pia 447.23 450.00 210.89 7.95 202.94 Pass: Major Risk Northstar PF NS29 NS29 V22 349.26 350.00 220.09 6.25 213.85 Pass: Major Risk Northstar PF NS31 NS31 V14 397.74 400.00 241.17 7.04 234.13 Pass: Major Risk Northstar PF NS35 Plan NS35 VO Plan: Pia 446.69 450.00 281.00 7.99 273.02 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 395.38 400.00 444.43 7.77 436.66 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 150.68 150.00 421.92 4.29 417.62 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 150.68 150.00 422.19 4.39 417.80 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 396.03 400.00 428.67 7.86 420.81 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 206.07 200.00 460.36 5.50 454.86 Pass: Major Risk Site: Northstar PF Drilling Target Conf.: 99% Description: Map Northing: 6028608.00 ft Map Easting : 656241.00 ft Latitude: 70029'05.683N Shape: Circle ) Target: NS07 BrIm! Tgt ------. _._-------~--_..,-_._-,,_._,--_._______h__'_"..' ,,--,-------,-""-- ,..--."....., ...----- -- ----- V' "'-. NS07 1. J on: Planned Program Vertical Depth: 7586.00 ft below Mean Sea Level Local +N/-S: -2196.15 ft Local +E/-W: -3641.89 ft Longitude: 148°43'22.932W Radius: 400 ft -.- -_._"_._.._._".__.__.-"~_.__._-_.,---,._-----------------------_._-_._--,-------~._--,--_..,--_..__.._-_. ,--......--..-.-'_'-'_n____'- -----~--_.._.h__...'_"-- -, ----.-. .--".-- " -14-00 -1500 -1800 -2000 -2200 -24-00 -2500 / -2800 / /' 0 CJ CJ CJ CJ CJ CJ CJ CJ / / 0 0 CJ CJ CJ CJ CJ CJ CJ CJ /' 0 0 N CJ m l..O -=I- N CJ m 0 ~ ø -=I- -=I- (Y) (I) (I) (I) (Y) N ~ 0 ( I I I I I I I I ~ f Site: Northstar PF Drilling Target Conf.: 99% Description: Sag Tgt Map Northing: 6029107.00 ft Map Easting : 653805.00 ft Latitude: 70°29' 11.089N Shape: Circle ) Target: NS07 (S-19) " \NS07 l 4 on: Planned Program Vertical Depth: 10740.00 ft below Mean Sea Level Local +N/-S: -1644.86 ft Local +E/-W: -6066.77 ft Longitude: 148°44'34.280W Radius: 400 ft ---...---.------.--.--.----.. "..,,-~_._--- ---.'...'.. .. ._-~-- <- ~..._~...,._--- .-----,-"-,,-_.._....~. --'---'-----'--.--.---.---- -.. ---..---..------ .--. .--.--...---......----.---.------.".------ - -_. .---- .... ---------'-"- ----'.'--'-",,-.--..,. -'------'--'-----'--"' "----'-'-"--' -.-.- - - ---'._,---,---,--'. .-. '--"-'---"------~-'_. -800 -1000 -1200 -/4-00 -1500 -1800 -2000 -2200 -24-00 ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 § 0 LD J N 0 CO LD J N / LD LD LD LD LJl LJl LJl LJl / I I I I I I I I ~ ~ ~ / / H 206290 ) DATE INVOICE / CREDIT MEMO DESCRIPTION 031202 CK031202 PYMT COMMENTS: HANDLING INST: GROSS 100.00 Permit to Drill Fee 5tH - Terrie Hubble X4628 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 \,f~o1 100.00 } DATE 03i14i02 CHECK NO. 00206290 VENDOR DISCOUNT ALASKAOILA NET õü 100.. 00 RECEI'/ED MAR 2 82002 AIIIkI ON & GIICcIII. CoIIIrrllloo ..AndIarIg., 100.00 No.H 2062 SO FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 4'12 CONSOLIDATED COMMERCIAL ACCOUNT 00206290 PAY ONE HUNDRED to( 001 1 OO~**i;1¡********************************* US DOLLAR To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333WESX 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 DATE 03/14/02 III 2 0 b 2 CJ 0 III I: 0... ~ 2 0 ::I a q 5 I: 0 0 a ...... ~ CJ III . AMOÚNT $1 00 ~... 00 NOTVALlD. AFTER 120 DAYS n,,'..'....... . ...,.",..',i ",..,'.."...'.,... ..,...,....,'.--:"'."'....,.. ..'....... ...".. .... \<.~~I!i~ . ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 ST ANDARD LEITER DEVELOPMENT v DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME A/D/'/~ st,-. /J.\ -6 7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) Pll.,OT HOLE (PH) . ANNULAR D~OSAL . iJZ)-ÑO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL' "CLUE" The permit is for a Dew wellbore segment of existing weD -----' Permit No, , API No. . ., Production should continue to be reported 85 a function of the original API number stated above. . In accordance with 20 MC 25.005(1), all recordS, data and logs acquired for' the pilot hole mu'st be clearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from , records, data and logs acquired for wel~ (n~me on permit). Annular disposal has ~ot 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 L-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 10 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. /údr/).?~/ WELL PERMIT CHECKLIST COMPANY 8~ X WELL NAME ¡U.. ç - 0 '"7 FIELD & POOL ~.çio /(")0 INIT CLASS j).~i/ )--0: / ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to E/5 00 psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . N 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N 34. Contact name/phone for weekly progress reports [exp/ ory only] Y N 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 dispo (D) will not damage producing formation or impair recovery fr a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.41 . Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEM~~ SFD- WGA \¿J.GA- APPR DATE ENGINEERING AP~ DATE VJ..;It 1) { 2. 'i 10 I ,~'M. ~(.).~-Ö~ GEOLOGY APPR DATE APPR DATE PROGRAM: Exp - Dev YRedrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA ((1 n UNIT# /'~"'d ON/OFF SHORE al"'r 'y\ N Y:N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N II I ^ J . N Ù) a.Yi "~r'O 2..00 . ~ AdeÕ u-,-,t.> WC/çc.. &~ t2N ø N ¡JC1.&Of So ~~E ~ ";'-/A , '\ . 1 @ N C10 ç,(. ç,t t>..{> P y\peuL = 9. f¿4 . .:¡t:. Y N Ù ' " ~.,...t-'-y vJ eU 1/ '&" y"e ~ ¡,lRS, t~ . ~~ & N msp -:. '-lIS; ¡7 '--: ~~ Y<tSP f . "'~-.)'" \ ~'t-\. ""'E.~:J ~ (lM. { c~ =Þs.t ~ 4' ~ 00 e c.:. --1 /f/, /l ( ¡U~ /1/ Comments/Instructions: COT . DTS D'¿;¿ ~ 2- JMH...- G: \geology\tem plates\checklist. doc e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I I 1 J I I LOSN ~V lSH1~ON I I I I I I I I I l~Od3~ "3M :10 CN3 V>lSV'V NOll V~O'dX3 dB LL-o-eot? 5 a ::::J 1/\ t::I a 5 g N I'" I !::I [] uns-l\wLJads 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 NS07 Northstar North Slope Alaska United States 50-029-23081-00 AK-AM-22066 April 18, 2002 May 18, 2002 True 26.476 deg 80.932 deg 57515.73 nT April 21, 2002 North 70 deg 29 min 27.29 see East 148 deg 41 min 35.79 see 256.130 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Joe Polya Mike Dinger. Ken Lemley Northstar 107 Alaska North Slope 5perr"v- sun 1:1 RI L.L.I N 6 !!5e: f9\J I c: e 5 BP Exploration - Northstar NS07 Daily Well Summary I '14/] 6/02. Prepare to move rig to NS07 slot. 04/17/02 Rigging up on NS07 slot location. II )4/18/02 Finish rigging up rig on slot NS07. Nipple up riser. Drill and clean out 20' conductor. Drill 16" hole with Bit #1 (MXC-l) and BHA #1 to 331' MD. Run Gyro. Trip out of hole for drilling assembly and MWD. Run in I '¡ole with new assembly and drill to 750' MD, running Gyro surveys every stand. 04/19/02 Drill ahead to 2965' MD. First indication of methane gas seen at 1195' MD. Maximum gas of25 units I mcountered at 1728' MD. Top of the Permafrost at 1195' MD, 1194' TVD. Base of the Permafrost at 1585' MD, .564' TVD. Top of the SV6 marker at 3378' MD, 3043' TVD. Some clay bit balling was evidenced in this interval and treated with Walnut sweeps. I )4/20/02 Drill ahead to 3774' MD, T.D. for the 13 3/8" casing. Circulated hole clean. Trip out of the hole. Rig up to run 13 3/8" casing. Begin running 13 3/8" casing. Top of the SV5 marker at 3378' MD, 3043' TVD. Top of the SV6 I narker at 3710' MD, 3316' TVD. Maximum gas 11 units at 3118' MD. Total hours, footage and Krevs on bit no. 1 = 17.5 hrs, 3573' and 274 Krevolutions. )4/21/02 Run 13 3/8" casing. Circulated staging up pumps on bottom with a maximum gas of 9 units on bottoms up. _v1oderate amount of cuttings seen at bottoms up. Cemented casing as per well plan. Good cement to surface. Nipple down riser. Nipple up stack. Dumped and cleaned pits. Mix new mud for 12 2/4" hole section. I J4/22/02 Test BOP stack. Pickup new BRA with rotary steerab1e assembly and Bit # 2 ( 12 \/,," RS238HFGNP, jets 3xll, 6x12= TFA- 0.9410) Trip in hole and test MWD. Test casing. Drill cement and 20' of new formation to 3794' I v1D. Displace hole with new mud. Perform Leak Off Test = with a resultant 13.0 ppg Equivalent Mud Weight. Trip ~ut of the hole for MWD failure. 114/23/02 Pickup new MWD. Trip in hole with same and test-OK. Slip and cut drilling line. Continue to trip in hole. .Jegin drilling ahead with 12 J;4" assembly. Trip gas of 4 units seen. Drilled from 3794' to 6512' MD with no hole problems. Maximum ROP 565 ft/hr at 4635' Md. Maximum gas of217 units at 5885' MD. Mud weight at 6512' Md J vas a 8.9 ppg. Top of the Ugnu at 5472' MD, 4767' TVD. 04/24/02 Drill 12 J;4" hole with rotary steerable assembly from 6512' to 8221' MD. Pumped a high viscosity sweep. I ~irculated out same and began a short trip to the 13 3/8" casing shoe. Pulling tight, began to pump out on stand 22.. .t:vacuated rig at 23:15 hrs due to a high gas alarm in the rig cellar. Alarm false. Resumed trip out of the hole at 00:50 hrS 04/24/02. Top of the Schrader Bluff at 7310' Md, 6309' TVD. Top of the Colville at 7997' MD, 6883' TVD. Jaximum ROP in this interval was 511 ft/hr. Maximum gas was 196 units at 6592' MD. 104/25/02 Circulated bottoms up at 13 3/8" casing shoe to clean hole of cuttings from backreaming in the open hole. :ervice top drive and level rig ( harmonic vibration rubbing at rotary table and BOP stack). Trip in hole, reaming through tight spot from 6143' to 6600' MD. Trip in hole to bottom. Short trip gas of 498 units. Drill ahead from I S\221 ' to 9177' MD. Maximum ROP was 225 ftJhr at 8325. Maximum gas was ] 20 units at 9085' MD. BP Exploration - Northstar NS07 I Daily Well Summary u4/26/02 Drill from 9177' to 10619' MD, weighting up to 10.2 ppg prior to penetrating the HRZ formation. Top of Ithe HRZ at 9897' MD, 8373' TVD (first indication of 150+ gamma). Base of the HRZ formation at 10315' MD, :693' TVD. Top of the Kuparuk formation at 10395' MD, 8754' TVD. Maximum ROP 140 ft/hr at 9493' MD. Maximum gas 245 units at 9182' MD. 1 14/27/02 Drill from 10619' to 11048' MD. Circulate bottoms up. Trip out of the hole for a bit change due to slow ROP's. Top of the Kuparuk "c" formation at 10787' MD. 9047' TVD. Maximum ROP in this interval was 155 ft/hr I"t 10798"MD. Maximum gas was 1600 units at 10834' MD. A drilling break was seen in the Kuparuk "C" from .. 0790' to 10918' MD which was where the maximum gas was recorded in this interval. Bit # 2 hours/ footage/ Krevs+ 63.5 hours, 7274 feet and 560K revs. 114/28/02 Make up BHA and bit #3, ( 12 ~"DSI41HDF+GNS,jets=4x14, 2x15, TFA= .9460). This assembly was of the "packed hole type". Trip in hole. Shallow test MWD. Slip and cut drilling line and service drawworks. Trip in I'iûle to 11048' MD. Drill ahead to 11440' MD, T.D. for the 95/8" casing. Circulate bottoms up and condition mud to 2000 strokes. Trip out of the hole for 9 5/8" casing run. Maximum ROP in this interval was 138 ft/hr at 11359' MD. Maximum gas was 252 units at 11345' MD. Total bit Hours/footage/Krevs= 4.5 hrs, 392 feet, 36.9 Krevs. f 4/29/02 Continue to trip out of the hole to run 9 5/8" casing. Laydown BHA #5 and pull wear ring. Unable to pull wear ring. Change BOP rams to 9 5/8" and pickup Baker spear and retrieve wear ring. Install test plug and test door .1 eals to 3000 psi. Rig up casing tools and make up float equipment. Run 9 5/8" casing to 13 3/8" casing shoe and irculate one casing volume. Continue running 9 5/8" casing into open hole. 1":4/30/02 Land 95/8" casing at 11415' MD. Had to work down last 3 joints. Break circulation at ~ bbl/min, staging p to 10 bbl/min. Pump cement job and displace cement with rig pumps. Bumped plug with 8087 strokes. Rig down cement head and casing running tools. Drained BOP stack and unfroze lines in the rig cellar. Performed down squeeze r)b with 75 bbls of cement. Freeze protect 13 3/8" x 9 5/8" annulus with 130 bbls of diesel. Test BOP's. 05/01/02 Continue testing BOP's, service drawworks. Make up BHA #6, (6 ~" STR454 Bit # 4 with 4x 13 jets and a I 7/8"" sweep" PDC Reamer ( TF A .497, jets 2 x18) with a profile of 8 ~" to ream out a 9 7/8" for easier running of . " drilling liner ), load nuclear source in MWD tool and Trip in hole. Trip out of hole, remove nuclear source and laydown nuclear AND tool. Trip in hole to 10890' MD. Wash down from 10890' to 11328' MD top plug) and I irculate and condition mud. Test 9 5/8" casing to 4050 psi-OK. Perform D6 drill. Slip and cut drilling line. Drill out , ",ement and float. Abundant metal shavings on possum belly magnet and over shakers. I 5/02/02 Continue to drill out cement and rat hole to 11440' MD. Drill to 11458' MD. MWD not working. ~irculate until MW in = MW out at 10.4 ppg. Per form extended Leak off Test to 15.4 ppg EMW. Weight up mud to 12.7 ppg at 26000 strokes. Drilling from 11460' to 11551' MD. Circulate and condition mud. Monitor well and pull 2 I tands to casing shoe. Monitor well. Trip out of hole for MWD failure. Maximum ROP in this interval was 132 ft/hr at 11465' MD. Maximum Gas in this interval was 47 units at 11441' MD. I 5/03/02 Continue drilling from 11551' to 11933' MD, sliding 30 to 60' per stand. Circulate bottoms up. Perform ~hort trip to 9 5/8" casing shoe. Maximum gas was 35 units at 11648' MD. I 5/04/02 Continue drilling from 11933' to 12787' MD. Top Kingak at 11960' Md, 9952' TVD. Drilling ahead. Iv1aximum gas was 48 units at 12524' Md. Maximum ROP was 101 ft/hr at 11973' MD. BP Exploration - Northstar NS07 Daily Well Sunlmary L/05/02 Drilled from 12787' to 12976' MD, 10810' TVD, T.D. for the 7" drilling liner. Perfonned a short trip to the shoe, no problems. Trip in hole to bottom and circulate bottoms up. Trip out of the hole to run Wireline logs. Top of r ag River formation at 12930' MD, 10770' TVD. Maximum gas was 176 units at 12975' MD. Maximum ROP was ,2 ftIhr at 12883' MD. Bit #4 hours, footage and K revs= 37 hours, 1535 feet and 680 k revs. 5% splintered shale rwas noted on the circulation of bottoms up after the wiper trip. During drilling there was less than 1 % splintered . uttings while drilling the Kingak interval. 05/06102 Rigged up and began running e-Iogs. The first run was good, but the second run hit a ledge. Pull out of the I ole with wireline and begin to rig up to run 7", 26 lblft drilling liner. Run 7" drilling liner on 5" drill pipe. Stage up pumps at 2nd joint of drill pipe from bottom. Circulating down due to taking weight I 5/07/02 Continue washing down last joint of 5"drill pipe to bottom for 7" drilling liner. Cement 7 " drilling liner according to cement plan. No problems. Test BOP's-passed. Pick up BHA #8 with 6 1/8" drilling assembly (Bit #5 (TX-30CD,jets 3x15, TFA= 0.518). Trip in hole with ^ 1/8" drilling assembly. U5/08/02 Continue running in hole and tested casing. Drilled float equipment and cement,. Ran L.O.T to 12.7 PPG. ¡Drilled ahead, to Top of Well projected TD has changed to estimated depth of 11298' TVD, 13525' MD Shublik @ 3046' MD, 10872' TVD, Top of Ivishak @ 13133' MD, 10950' TVD. Max Gas was 226 units and the max ROP was 218 ftlhr. 15/09/02 Drilled to TD 100' MD below 11222' TVD, which is 13,529' MD, 11321' TVD. Circulated BID while Pumping a sweep. Short triped to shoe, CBU, monitored well, the well was static. Continued to POOH to 9211' MD. Derformed derrick inspection, Continued to POOH.. Top of the Kavik 13472' MD, 11266' TVD Max gas was 106 nits and the roax ROP wast33 ftlhr. 1"5/10/02 Finished POOH and laid down BHA#8. Rigged up to run Wire Line. 05/11/02 Finished running second run of logs.. Picked up 4.5" liner and inner string. And RIH on Drill Pipe. CBU at l hoe then Finished TIH with liner. Circulated Bottoms Up again prior to cementing. Max Trip gas was 42 units. I I I I I I f BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I. le ;) Elapsed Time Operations Breakdown 1/16/0~ /.00-00.00 24.00 L. 7/02 ):00-06:30 6.50 LO-11:00 4.50 l:00-16:00 5.00 1 Prepare rig for move to NS-7 -- waiting for power from Hiline to perform NSI0 kill. 1) CIO single gate to hydril, and reorient spacer spool to allow BOP scaffolding to clear the wellhouses. 2) Lay Herculite 3) Turn tubing spool on stack. 4) Clean rig. 5) Weld hinges incellar. 6) Moved rig 25' to south. 7) Put herculite over the top ofNS8 & 9 wellhouses. 8) Clean well house in cellar. 9) Empty & clean L pit to install 12" equalizers. 1 0) Blow down & tear down lines from piperack. 11) Building berms I I I. I I 00-20:00 4.00 1):00-22:00 2.00 00-00:00 2.00 1/18/02 I 00-01?0 1.50 l .30-03.30 2.00 ~ :30-04:30 1.00 I k30-06:45 2.25 I Continue preparing rig for move. G & I completed killing NS-I0 wi 11.2 ppg mud. Blow down lines from piperack to rig. Disconnect lines. PJSM - Move rig & level wi shims. Note: Necessary to manuever around NSI0 wellhouse which is 12.5' above pad level but shimmed to provide clearance betweeen wellhouse and tree. Connect service lines to piperack. P JSM - Hook up new injection line & weld brackets on side of rig. N/U riser. Clean up around NS-15 & PIU HWDP & stand back. >:45-07:30 0.75 I (30-11:15 3.75 P/U & stand back HWDP. M/U BRA # 1 to clean out conductor. Pre-spud meeting, review D- 7 drill. Fill conductor wi mud. Leak detected on riser clamp I o-ring. Calibrate rig gas monitoring system. Tighten clamp on riser to try & repair leak to no avail. Slide rig floor 6" towards piperack to get riser into vertical position which alleviated problem. Clean out conductor & drill to 241'. Note: Spud well @ 0700 hours on 4/18. (See Rig Move in Remarks Section) Circulate & R!U Schlumberger for gyro. Difficulties getting power to Schlumberger. 480V drops on piperack not functional due to a bad breaker. Parts on order. Wired Schlumberger directly into 1600 amp breaker available by Halliburton BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) f le ;) Elapsed Time Operations Breakdown i. .15-12:00 0.75 !:00-15:00 3.00 l 00-18:00 3.00 .00-00:00 6.00 f 19/02 00-02:00 2.00 ~:00-02:45 0.75 145-03:15 0.50 .15-12:00 8.75 !:OO-OO:OO 12.00. I 20/02 ):00-08:45 8.75 transformer. (near miss - see remarks) R!U sheave in derrick & run gyro. Drill to 330' & run gyro. POH & PIU BHA # 2. Drill & slide from 330' to 780'. Run gyros. Drill & slide from 780' to 1100'. Pump sweep. Run gyro. Gyro & MWD data correlating per JORPS criteria. LID sheave & E-line out of derrick. RID Schlumberger. Drill & slide from 1100' to 1750'. Pump sweep. Drill & slide from 1750' to 3008'. Pump sweep. I ~:45-11 :00 2.25 f 00-11 :30 0.50 Drilling fl 3008' -- 3774' md (TD of 16" surface hole). Note: TD picked by Sperry Sun and confirmed with Anchorage Geologist. Pump sweep and circ and cond mud in preparation to run casing. Note: Rotate and reciprocate pipe during conditioning. Monitor Well, Pump Dry Job, Blow down Top Drive, standpipe and bleeder. POOH with drill pipe to 1006' md. Note: Wiped stands 4 and 21 based on drilling these intervals -- hole in good shape. POOH with HWDP to 216' md -- inside 20" conductor. Note: Wiper trip not necessary based on hole condition -- decision to LD BHA and run casing. Lay Down BHA.#2 Note: Top stab had some clay and next stab had less -- about average for a surface hole bha. Service Top Drive Note: Clean Rig Floor ofBHA components and drilling mud. PJSM -- RU Frank's Tool and Casing Tools. PJSM -- RIH with 13-3/8" 68# L80 Btrc Surface Casing (60 of92 total joints in the hole). I 30-13 :30 2.00 I 30-14:00 0.50 I 00-16:30 2.50 I 30-17:30 1.00 7:30-19:00 1.50 I 00-00:00 5.00 I '21/02. J.00-02.45 2.75 Run remaining 13 3/8" casing & land wI mandrell hangar. (Jts. 61 -92) Note: Casing SIO wts. 80K to lOOK onjts. 64,65 & 66.2,563' to 2,685' Casing SIO wts. 95K to 125K onjts. 74 - 78. 2,972' to 3,177'. Jt. 90 stacked up & would not go down. PIU & run back down only to lose 5'. Retried PIU & run back down & lost additional 5'. Was finally able to work down without pumping. Last 3 joints stacked up, ! I,," ,I BPExploration - Northstar NS07 Daily Operations (I.A.D.C) I L1e . 5) Elapsed Time Operations Breakdown I . ~.45-03.30 0.75 ~:30-06:30 3.00 I but not as bad as joint 90. LID Frank's fill up tool & M/U HOWCO cement head & x-over. Circulate & condition mud in preparation for cement job. PJSM for cement job during circulation. Note: No significant cuttings at shakers throuhout circulation. Pump 5 bbls. of water & test lines to 3,000 psi. Pump 484 bbls. of 10.7 lead cement & 97 bbls. of 15.8 tail cement. Displace cement wi 25 bbls. of clean up water & 525 bbls. of9.0 ppg mud. Note: Bumped plug @ 95% pump efficiency. LID cement head & blow down lines. Drain stack, remove casing elevators, LID landing jt, change out bails & install 5" elevators. Clear & clean rig floor. Nipple down surface riser. NIU tubing spool & test to 1,200 psi & hold for 10 min. PJSM on setting BOP's on tubing spool. N/U BOP. Install turn buckles, kill & choke lines. Install Koomey lines, both sections of riser, & mousehole. Function test BOP's. 'PJSM - Install bushings & floor track. P JSM - CIO MWD pressure sensor on top of stand pipe. Completed cleaning all pits. >:30-09:30 3.00 t .30-1 0:45 1.25 1,,45-13:30 2.75 (,;30-15 :30 2.00 1,:30-16:30 1.00 30-17:00 0.50 , :00-20:00 3.00 (00-22:30 2.50 ~:30-23:00 0.50 (00-00:00 1.00 1/22/02 1.00-04:45 4.75 k45-05:15 0.50 115-09:30 4.25 .):30-12:00 2.50 I ~:00-12:30 0.50 (30-13:30 1.00 ):30-15:00 1.50 I 00-16:30 1.50 >:30-17:00 0.50 17'00-17:30 0.50 30-18:00 0.50 ~:00-19:30 1.50 1\'30-20:00 0.50 00-21 :30 1.50 P/U testjt, floor valves, & test BOP's. Test to 250 10w/4500 high & hold for 5 mins. Pull test plug, set bowl protector, & blow down mud lines. PJSM - PIU bias tool & test. OK. PIU remaining BHA & shallow test MWD. OK. RIH - tag cement @ 3,665' & clean out to 3,675'. Tag up on cement plugs @ 3,675'. Finish drilling to float collar @ 3675.5'. Test casing to 3,600 psi wi 9.0 ppg mud & hold for 30 minutes. OK. Note: Discuss well control wi rig crews & review D1, D2, & D5 drills. Drill out shoe track from 3675.5' to 3758'. drill rat hole from 3758' to 3774'. Drill 20' of new hole to 3794' Condition mud & circulate. Change over to new mud. 8.6 ppg. Conduct LOT to 13.0 ppg EMW. Condition mud & circulate. Pump dry job. Monitor well & blow down top drive & kill line. POR to RWDP - monitor well. Shallow test MWD - blow down lines. Handle BHA # 3 & LID MWD. , BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I ne I s) Elapsed Time Operations Breakdown I 30-22?0 1.00 ~.30-23 .30 1.00 ):30-00:00 0.50 I '23/02 ):00-02:00 2.00 '" 00-03 :00 1.00 00-00: 00 21. 00 Handle BRA # 4 & MID MWD & shallow test. OK. Continue M/U BHA # 4. RIH wi DP. I I 1.00-00:00 21.00 I f I 1./24/02 ):00-18:00 18.00 I I P JSM - Cut & slip drilling line. Service top drive & drawworks. RIH Drill per directional plan with Rotary Steerable from 3794' to 6609'. Notes: 1. Pumping hi-vis sweeps every 400' md (or as needed). 2. Spent 1 hr. and 40 minutes unballing bit -- bit balled up while drilling bottom 40' ofSV3 (clay) from 4443' -4483' md (3914' - 3945' tvd). Pumped 25 bbl 15 ppb walnut sweep, then 25 bbl 50/50 mud water with 15 ppb walnut and 1 ppb SAPP, then break connection and add vis cup SAPP with no apparent results. Adjusted drlg parameters from 80-180 rpm and WOB from 0-25K (Hycalog cautioned against stacking too much weight) and shut off pumps and rocked bit on bottom -- again with no apparent results. Checked mudlog comparison with NS 14 lithology and noted SV2 sand within 15 '. Increased WOB to 20K and drilled ahead at '"V 15 fph -- hit SV2 sand and bit unballed. Drilled ahead while adding fresh Condet, Clayseal and BDF263 to combat bit balling. Conclusion: treat for clays and clean up in sands -- in this depositional environment with the repeating sand, siltstone, clay sections, the bit should not stayed balled long provided we are careful to not stack too much weight and bake the ball on the bit. 3 . Well is tracking NS 14 lithology very close. (00-19:00 1.00 ):00-19:30 0.50 1'.30-23:30 4.00 Directionally Drill 12.1/4" Hole with rotary steerable from 6,609 ft to 8,221 ft> (7,883 MD , 6790 ft TVD for Colville). No Drag, No Losses. Wiper trip point decided on TVD depth! lithology. Pumping sweeps every 400 ft, ECD steady @ 9.8 ppg. Just wiping bottom 30 ft of each stand. P-rates higher than breakeven threshold for roundtripping for new bit according to offset data on last 500 ft drilled. Decreased RPM to 130 from 160 due to surface harmonics shaking Top Drive components- downhole shocks minimal. Sweep hole clean while RPM @ 150 and working pipe. X 150% bottoms up. Take survey. Flowcheck. Pump dry job. Make wiper trip back to 13.3/8" Shoe. Hole OK Back to 6,324 ft. Pulling tight back to 6,038'. Pump out of hole to 5,350 ft @ 300 GPMI I I BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I 1e I ;) Elapsed Time Operations Breakdown Lo-oo:oo 0.50 600 psi, 10-25 klbs overpull. Unable to dry pull. High LEL alarm triggered in cellar area combined with observations of fluid release ( see remarks). Well Shut in and rig evacuated. Northstar ERT mobilised with SCBA and declared rig clear @ 0040 hrs. Courtesy call made to AOGCC @ 0100 hrs to infonn the of ram Closure and false alarm- rechecked sensor- OK. I I 1/25/02 1"00-00:30 0.50 ):30-05:00 4.50 I (00-06:30 1.50 >:30-10:00 3.50 I 00-13:00 3.00 t.OO-13:30 0.50 I 30-00:00 10.50 Rig Declared Clear @ 0040 hours and stand. Work Pipe and circulate well- OK. Bit @ 5,350 ft. Continue with wiper trip back to 13.3/8" shoe @ 3,758'. Unable to dry pull Assembly. Pump out @ 300 GPMI 600psi with 10-25 klbs overpull and occaisonal packing off if assembly pulled too fast. Circulate hole clean at 13.3/8" shoe while working pipe. Pump X 2.5 bottoms up. until shakers cleaned up. Inspect Top Drive and derrick for any loose objects after the harmonics issue. Align rig. RIH- Hole good until 6,143 ft.Ream wash from 6,143' to 6,225 ft ( Bottom Ugnu) and 6,500 to 6,650 ft. Continue to RIH- Hole good. Break circulation & set rotary steerable. Drill from 8224' to 9150' pumping hi vis weighted sweeps every 400'. 1'26/02 I 00-05:00 5.00 1=.00-05:30 0.50 30-06:30 1.00 Drill 12.1/4" Hole from 9150' to 9560'. No Drag, No Losses. ECD steady. Down link rotary steerable. Locking Nut from a solenoid valve fell from Top Drive. Inspect Top drive and replace solenoid valve. Continue to visually inspect Top DRive ach stand down and continue to make the rigfloor a no go zone while the surface harmonics is a conscem. Drill from 9560' to 10035'. Raising Mud weight to 10.2 ppg and prepaing properties for HRZ and Kuparuk. HRZ @ 9,897 ft MD, ,8373' TVD Top Kuparuk 10,395 8754' Lubricate rig & service top drive. Drill 12.1/4" Rotary Steerable from 10035' to 10620'. No Drag, No losses. Placed Non Rotating sleeve in at 10,135'. Helped Harmonics considerably for another 300-400 ft. ( Indicates "node" may be at a depth of 300-500 ft mD. Top of Kuparuk "c" @ 10,787' MD, 9047' TVD I >:30-12:00 5.50 I ~:OO-12:30 0.50 r 30-00:00 11.50 I. '27/02 .00-13:30 13.50 Drill 12.1/4" Hole with Rotary Steerable system from 10,620 ft to BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) II tle t s) Elapsed Time Operations Breakdown I I I ~:30-15:30 2.00 f .30-16:00 0.50 ,.00-21.00 5.00 I 00-22:00 1.00 ~:00-22:30 0.50 1.)~30-23:00 0.50 00-00:00 1.00 11,048'. No Drag, No Losses. P-rate average declining in Lower Kuparuk. 5-30 ftJhr average ( 50-70% lower than offsets for comparable lithology). Vary parameters with no improvement. Last two stands averging 20 ft/hr . Make decision to make bit trip based on economics of a wiper trip to the shoe for casing and on the remaining footage required versus the projected improvement of P-rate for new bit. Maximum gas 1287 units @ 10,763' MD Circulate 130% bottoms up until shakers clean- no gas. Flowcheck well and Pump Dry job. POH to shoe. Hole is slick with no tight spots. Monitor well @ shoe for 10 minutes. Okay Continue POH to HWDP. Monitor well. Losses @ 6 - 10 bbls. per hour. Continue POH to BHA. Handle BHA # 4. Bit Hammered. In gage but no cutting structure. l/28/02 I 00-02:00 2.00 (00-04:00 2.00 kOO-05:00 1.00 : .00-06:00 1.00 I 00-07:00 1.00 7:00-12:00 5.00 I 00-13:00 1.00 I ):30-21 :00 0.50 I 00-00:00 3.00 1 Continue to lay down BHA # 4- Rotary 12.1/4" Assembly. Bit Hammered but in gauge. Make up BHA # 5- Packed hole assembly with rebuilt Hycalog DS 141. Loss to hole = 4 bbls over 4 hours. Make up HWDP and Jars. Surface test MWD- Fine. Slip and Cut 102 ft of drilline. Inspect and servive Top Drive. RIH. No problems. Some ledg~s @ 9,155', 9,817' and 10,097'. A little tight tthrough top of Kupuruk from 10,476' to 10,515'. Stage up Pumps gradually and fan" bottom of hole to pre-empt any junk issues from previous bit run. Drill from 11048' to 12 1/4" TD @ 11440' MD. Consulted wi Anchorage Geologist for TD determination. Pump hi-vis weighted sweep wi barofiber & nut plug. Circulate 1 1/2 X BID. Shakers indicated hole was clean. Spotted 8 drums of torque trim on bottom & in the open hole to aid in running casing. Monitor well - pull 2 stands - monitor well. Okay. Pump dry job & blow down lines. POH. Work tight spots @ 10909', 10330', 9650', 9610'-9448'. Tight spots to 40K over in the above listed areas, but was able to dry wipe through & clean up. Pulled smooth for the remainder of the trip. 1"00-18:30 5.50 ~:30-20:30 2.00 1/29/02 I 00-02:00 2.00 . _:00-02:30 0.50 POOH to 13.3/8" shoe @ 3,758'- hole good. Flowcheck. POOH to HWDP. BPExploration - Northstar NS07 Daily Operations (I.A.D.C) I ne I 5) Elapsed Time Operations Breakdown I 30-04:00 1.50 . .00-05.30 1.50 ,I 30-07:00 1.50 7:00-08:30 1.50 1..30-09:00 0.50 >:00-11 :00 2.00 I 00-11?0 0.50 l.30-12.30 1.00 ~:30-16:00 3.50 tOO-16:30 0.50 (30-00:00 7.50 L/30/02 100-01:00 1.00 Lay down 12.1/4" Packed hole assembly. Attempt to pull wear ring- no go. Flush- no go. Unable to J into wear nng. Install 9.5/8" Rams in top cavity while mobilisng Tristate Spear and hand. Spear into Wear ring and pull free. The Wear ring had some damage to the J-slot- damage from a BHAI Bit? Test Rams to 3000 psi/ 10 mins RID to run 9.5/8" and install Franks tool. PJSM for running 9.5/8" Make up Shoetrack and check floats- OK. Run 9.5/8" Casing, BTC, L-80, 47Ib/ft. Run to 13.3/8" Casing shoe @ 18 jts/ hr. Seepage losses- 2-5 bbls/hr. Circulate casing contents @ 7 BPM/ 500 psi. Continue to run 9.5/8" Casing to 11,240 ft @ midnight. Taking some weight 10,990 ft but still making good progress. '1:00-01:45 0.75 ' '45-05:00 3.25 rOO-08:OO 3.00 ~:00-09:30 1.50 Continue to run 9.5/8" and land the casing @ 0100 hrs- 277 joints run. No losses while running casing. Little difficult getting last three joints down- making progress with each slack off. Down weight 150-200 klbs. Up weight 400 klbs. Rig down Franks Tool and RID Cement head and cement lines. Circulate 150% bottoms up staging pumps gradually up to 10 BPM/ 735 psi. Loosing 20-30 bbls/hr. Hold PJSM for cement job while pumping. 450 units on bottoms up. Mix and Pump 50 bbls weighted spacer, 425 bbls ( 737 sxs) Lead @ 11.2 ppg and 165 bbls Tail ( 806sx) @ 15.9 ppg. Drop Top Plug. Displace Cement with 25 bbls water and 815 bbls Mud @ 9 BPM. Observe cementing lifting and bump plug (95% efficiency) to 2100 psi.( 500 psi over final pumping pressure @ 4.5 BPM. Spacer observed at surface just prior to bump. Total losses while cementing! displacing 30 bbls. Back out landing joint and lay down same. Unable to pump down stack-lines to trash pump frozen. Work issue while changing out bails and RID to run 9.5/8" Pack-off. Drain Stack and install 9.5/8" pack-off. Problems energising seal- fix pump- Energise whiile rigging up lines to pump down 13.3/8" x 9.5/8" annulus. Pump down annulus- formation broke down at 1700 psi= 19 ppg EMW @ 13.3/8" shoe (cement setting> 8 hrs since started mixing lead). Injection pressure stabilised at 2 BPM/ 850 psi. Test Pack-off and cleanup tools in cellar. Prepare to change out I :30-10:30 1.00 ):30-11 :30 1.00 I :30-13 :30 2.00 I :30-14:30 1.00 I :30-15:30 1.00 I I BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I ne s) Elapsed Time Operations Breakdown I :30-16:30 1.00 >:30-17:00 0.50 I :00-20:00 3.00 1,/01/02 ):00-02:00 2.00 [:00-03:00 1.00 ~ :00-03 :30 0.50 I I :30-05:00 1.50 1;:00-08:00 3.00 .00-09.30 1.50 9.5/8" rams to pipe rams. Work on ram change. PJSM for 9-5/8" x 13-3/8" annulus cement sqz. PT cement and HB & R lines to 3000 psig- Good. Open up to 9-5/8" x 13-3/8" Annulus. Come on line wi HOWCO pump wi SW @ 2 bpm wi 1000 psig Pump press. Pump 70 bbls Water Spacer @ 2 bpm wi 940 psig. Batch up cement. Pump 75 bbls of 15.7 ppg Type C Cement. Switch to mud. Displace cement wi 36 bbls of 10.2 ppg mud pumped by HOWCO. Switch to diesel displacement wi HB & R at 2 bpm wi 1600 psig P. press. Steady increase in pump pressure to 2 bpm wi 1900 P. pressl 1540 lAP. Pump press backed off to stabilized injection rate of 2 bpm @ 1725 psig (1550 lAP) after 50 bbls diesel pumped. Continue wi planned displacement of 130 bbls bbl~ diesel FP. SD and monitor fall-off on lAP to 600 psig. SI and RD HB & R. General Clean up and preparation work for BOP test ongoing. Continue change out of pipe rams to 5" x 2-7/8" variables. RD down cementing manifold--clear and clean cellar. Run test plug and rig up to test BOP's wi sea water. BOPE stack. AOGCC Witness, J. Spaulding, waived witness @ 18:00 hrs on 4/29/02. I I I I I :00-20:30 0.50 J:30-21 :30 1.00 II ?0-22?0 1.00 .30-00.00 1.50 1:30-10:00 0.50 J:00-10:30 0.50 I :30-16:00 5.50 >:00-18:00 2.00 1':00-19:00 1.00 Continue BOP Test. BID choke and kill lines. Pull Test Plug-- Set wear ring. Clear and clean rig floor. Service Top Drive & Draworks. Weld pipehandler brace. PJSM for BHA#6 MU BHA and Load source. Decision to lay down ADN made in morning meeting. Stand back drill collars. Remove source and lay down ADN. MU HWDP & Jars. Shallow Test MWD- good. BID lines. RIH to 10890' wi BRA #6. Wash down from 10890 ft md to 11328' md (Tag Plug).Stringer @ Circulate and condition mud for casing test. 700 GPMI 3240 psi MWin=MWout= 10.3 ppg. I I BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I ne s) Elapsed Time Operations Breakdown I :00-20:00 1.00 I :00-21 :00 1.00 ,.00-22.00 1.00 !:OO-OO:OO 2.00 I ;/02/02 1':00-01:00 1.00 .00-01.30 0.50 Pressure Test 9-5/8" casing to 4050 psig for 30 mins. 11.25 bbls Pumpl Return. Discuss well control- Stripping (D6) operations. D-6 Drill- Stripping. PJSM- Cut and Slip 102' of drilling line. Drill out shoe track from 11328 ft-md to 11416' ft-md. 50 ft/hr @ 3 Klbs WOB. Taking it easy with the bit. I 00-14:00 1.00 r.00-18.30 4.50 ~:30-20:00 1.50 I I O. 0-20?0 0.50 J.30-21.30 1.00 I 30-22:30 1.00 ~:30-23:00 0.50 ~~OO-OO:OO 1.00 1,/03/02 1)'00-04:00 4.00 00-04:30 0.50 ~:30-06:30 2.00 (30-00:00 17.50 Drill out cmt and 20' of formation to 11460' md. MWD quit. Try to come on-off pumps and rattle tools to get back signal back. Didn't work. Condition mud for LOT. Magnets have retrieved approximately 3 lbs of metal shavings mixed with fairly large shale cuttings-probably due to cutting structure on PDC reamer. MWin= MWout=10.4+ ppg Extended Leak off test. Test was conducted twice wi LO occuring at approximately 2520 psig (15.4 EMW). 7 bbls pump, 6.7 bbls returned. Wash to 11460' md. PJSM on Spike bleed to increase MW to 12.7 ppg. Bleed in 17 ppg spike mud and condition mud system to 12.8 ppg. Working pipe in open hole- hole extremely ratty, packing off, stalling assembly. Dry Pulling- 40 klbs overpulls. Drill ahead 9-7/8" hole from 11460'- 11552' md. To establish if assembly could drill hole prior to pullling out for MWD failure. Parameters steadied out. Average ROP 45 fph. CBU condition mud for TOH. Hole conditions smoothed out. POOH for new MWD. Handle BHA#6. Lay down MWD. PU BHA #7. Same as BHA #6 wi new MWD. Shallow Test BHA#7. MWD working -- however, wrong reference frames. Need to POOH and reprogram tool. POOH. Handle BHA#7. Reprogram MWD & Test - good. RIH wi BHA#7. I :30-02:30 1.00 1 .30-04:30 2.00 I. .30-05:00 0.50 100-10:30 5.50 I 30-13:00 2.50 RIH wi BHA#7 on 5" DP. Take ECD baseline @ 11420' md. ECD baseline = 13.61. Ream fl 11430'- 11552' md (50 rpm/675 gpm). Ratty Hole. Drill ahead 9-7/8" intermediate hole from 11552'-11870' md. Inclination in: 39.07--- Inclination out: 39.17** I i BPExploration - Northstar NS07 Daily Operations (I.A.D.C) I, ne , s) Elapsed Time Operations Breakdown I I I Azimuth in: 292.72 --- Azimuth out: 282.8 ** ** Note survey taken at 01 :08 on 5/4/02 Steering Time: 700/0 Rotating Time: 30%. Rotating Parameters: Avg Rot ROP= 60-70 fph. Flow: 680 gpm. SPP on 3800 wi 18 k torq. SPP off 3600 psig. WOB= 10k. ECD= 13.51. ROp while sliding 20-30 ft/hr. No Drag. I '04/02. 1.00-01.00 1.00 I :00-03 :00 2.00 1~:30-13 :30 (30-00:00 1.00 10.50 Drill ahead 9-7/8" hole through Miluveach to just above the Kingak from 11870' to 11933' md. Circulate surface to surface fiber/walnut hull sweep. Sweep brought back some excess. Circulate 14000 strokes total to clean and condition mud from 12.5-12.6 to 12.7 ppg. SID pumps, B/D lines, and monitor well--stable. Short trip from 11933' to 9-5/8" casing shoe at 11415' md. Hole in good condition no overpulls. RIH to btm. Drill ahead 9-7/8" hole from 11933' md to 12345' md. Drilling parameters: 100 rpm/ WOB= 8K1 Torque (on/off)::;:: (20-21K1 18K)/ Flowrate= 640 gpm wi 3850 psig PP. Pump # 1 broke. SID and work pipe. Drill ahead 9-7/8" hole from 11,933' to 12,785'. No drag. ECD hitting 14.2 ppg at times- fine tune flowrate, mud properties to stay under the hard line. No drag on connections. No splinters while drilling. Parameters steady. P-rate 40-60 ft/hr. I :00-04:00 1.00 1 :00-12:30 8.50 11/05/02 1'"00-04:30 4.50 I 30-06:00 1.50 I >:00-08:30 2.50 I 30-11 :00 2.50 I 00-12:30 1.50 I Drill ahead 9.7/8" hole from 12,785 ft to 12,976 ft. Parameters steady. ECD hitting hardline of 14.2 ppg at times, average 13.9 ppg. No splinters. No drag. Top of Sag @ 12,930 ft MD, 10,770 ft TVD, 46 ft rathole into Sag. Sweep Hole clean @ 650 GPM! 3950 psi. "Rest" BHA on bottom while rotating @ 1 OORPM and periodically reciprocate without rotation ( every 20 minutes). Minimise Shale damage with "wobbly" bit. Make wiper trip to 9.5/8" shoe @ 11,415 ft. Hole good. Minor "tugs" @ 12,236', 12,208' and 12,158'. Sweep Hole again @ 650 GPM! 3950 psi following same practice as earlier to get higher RPM. Shakers cleaned up quick after bottoms up ( 5% splinters) pot black product cocktail. Final mudweight 12.8 ppg. POOH to 9.5/8" shoe @ 11,415'. Minor tugs @ 12,457' and 12,392'. I I BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I ~: Elapsed Time Operations Breakdown I :30-14:00 1.50 . :00-14:30 0.50 k30-20:00 5.50 I :00-21?0 1.50 ,.30-23.00 1.50 I :00-23:30 0.50 ):30-00:00 0.50 I Cut and slip drilling line @ shoe. Pump dry job. Blow down. Drop 2.5" drift rabbit. POOH standing back 5" DP. LD HWDP. LD BHA #7. Flush tools wi fresh water. Bit/Reamer graded: 1-3- WT -A-X-I-CT - TD. Clear and clean rig floor. P JSM on SWS wireline RU for OH logs. RU SWS wireline for OH logging runs. I ~O6/02. 1.00-05.30 5.50 11:00-14:30 0.50 ,1'30-20:30 6.00 I 30-21 :30 1.00 11.30-22:30 1.00 30-00:00 1.50 W/L logging run #1 (SONICI FMI- 92' overall length). Caliper indicates the overall avg of hole in gauge. However, some ledges and under-gauge hole were logged. Just below shoe approximately 30' of 18..22" washout. No drag with logging out of hole. Change out logging tools. W IL logging run #2 (Density-43' overall length). Set down on ledge @ 11760' md. 1700 lbs drag PU. POH with 400-600 lbs drag. Talk wi Anchorage and decision made not to try second run. Rig Down SWS W/L. Rig up 7" equipment for running liner. PJSM for running 7" liner. MU and Bakerlock 8-3/8" reamer shoe jt and float collar. MU Baker landing nipple jt. Check floats. Run 44 Jts total 7" 26# Hydril 521 liner. MU torque was 12900 ft-lbs. Liner hanging wt= 11 OK lbs. MU liner hanger and packer wi HRD liner running tool for rotating Liner. Circulate liner vol @ 50 spm and 200 psig. RIH wi 5" DP to 9-5/8" shoe- fill DP every 10 stands. Circulate DP volume. Take rotating parameters: 10 rpm -6000 ft-lbs torque Rot Wt= 225 K-lbs I SOW= 210 K-lbsl PUW= 250 K-lbs. RIH wI stand #117 5" DP and liner to 12912' md with 0-10 lbs drag. PU single to wash down @ 12919'md.. PU off slips and attempt to wash down. Slack off 100m lbs - unable to go down. Attempt to break circulation at 0.5 BPM. Pressure up to 1000 PSI-unable to cir. PU to neutral wt. Attempt to rotate, torque up to 22,000 fl-lbs. -Unable to rotate. PU to 325m lbs. while holding 650 PSli pump pressure. Let set. Pressure slowly bleeding off. Maintain 650 PSIi and slowly establish cir. Bring pump up in stages to 70 SPM and 960 psi. Start rotating at 15 RPM and 14m ft-lbs torque. Slowly work single down with 5-10m lbs drag, 14-16m ft-lbs torque, 70 SPM & 950 PSI. PU last single to wash & rotate to TD. I >:30-08:00 2.50 I 1°0-08:30 0.50 ):30-09:00 0.50 1).00-09:30 0.50 30-14:00 4.5 BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) I ~e Elapsed Time Operations Breakdown I '07/02 ):00-02:30 2.50 I ~:30-03:00 0.50 I ,\'30-21 :30 1.00 I 30-23 :00 1.50 I~ .00-00:00 1.00 '08/02 ):00-01 :30 1.50 II 30-02:00 0.50 00-06:30 4.50 >:30-07:00 0.50 ,. 00-08:00 1.00 00-09:00 1.00 Wash last single down with 3.8 BPM, 650 PSI, 16-20M ft-Ibs torque and 5-10 weight on shoe. String would take weght and torque up. No change in pump pressure. PU P PU Cement head. and cirlrotate to TD (strap showed 5' deeper then drill depth). Final parameters: PU 275M lbs, SO 225M lbs, Rot String Wt. 260M lbs, Torque 17500 ft-Ibs @ 10 RPM & Pump pressure 1000 PSI & 8 BPM Circulate at 8 BPM & 1000 psi. Conduct PJSM Pump 5 bbls 13.2 ppg Alpha Spacer. Pressure test cement lines to 4500 psig. Pump remaining 45 bbls Spacer. Mix and pump 129 bbls (485 sks) of 15.9 ppg Premium Cement. Drop 2.25" pump down plug. Pump 1 bbls water (1 bbls cemt on top of plug). Isolate and clean up cement lines. Displace wI Mud @ 7.5 bpm while rotating 5 rpm wI torque 18-20K ft-Ibs. Slow rate to 4 bpm wI 187 bbls pumped. Latch plugs and see good pressure lift while cont to rotate. At 230 bbls displacement see totque and pressure increases (21K ft-Ibs and 2200 psig). Quit rotating and continue displacement wI 1250 psig PP. Bump plug @ 258 bbls and 3034 stks pumped to 3250 psig. Slack off 55 K and pressure up to 4250 psig. Bleed down and check floats- good. PU 9'. Set liner top packer wI 50K lbs down while rotating 10 rpm. PU and sting out wI 1000 psig. Pressure increasing. PU an additional l' and circulate at 200 spm while reciprocating running tool. See cement at 5800 strokes and estimate appro x 40 bbls cement returned to surface. Monitor well. RD cementing head. LID singles. Pump dry job. BID lines. POOH wI HRD liner running tool. Inspect and LD running tool. Set test plug & RU to test BOP stack. Test H2S and Gas Monitors. Test BOP stack. AOGCC Representative- Lou Grimaldi witnessed test. Pull test plug and set wear ring. P PJSM. MU BHA #8 - 6-118" Bit I 4-3/4" 0 deg PDMI Slim pulse MWDI and ADN. MU HWDP and RIH wI BHA#8. ) :00-03 :30 0.50 'I :30-05 :30 2.00 I I I (30-07:00 1.50 1,7'00-08:30 1.50 30-14:30 6.00 k30-15:00 0.50 1;'00-15:30 0.50 30-20:30 5.00 Continue RIH wI BHA #8. Shallow test MWD- OK. RIH wI BHA#8 on 5" DP to 12801' md. Wash down to 7" Landing Collar @ 12891' md. No cement stringers. Circulate to even Mud Wt of 12.5 ppg. Pressure up to 3000 psig wI 100 strokes and record on chart for 30 mins. Good Test. PJSM on well control and mud swap. I I BP Exploration - Northstar NS07 Daily Operations (I.A.D.C) ,. ne s) Elapsed Time Operations Breakdown I :00-14:00 5.00 ':00-14?0 0.5 1.30-00.00 9.50 Drill out plug and L. C. at 12891' md (2hrs). Drill cmt to 12928' and begin mud displacement to 9.2 ppg. Drill FC @ 12932' md. Drill shoe at 12973' md. Drill ahead 6-1/8" hole to 12996' md- 20' of new formation. Perform FIT to 12.65 EMW wi 1920 psig and 9.25 MW. Drill ahead 6-1/8' production hole. I ;/09/02 I :00-07:00 7.00 . .00-08.00 1.00 I :00-09:45 1.75 ,.45-12.00 2.25 ~:00-13:00 1.00 1.:00-15:00 2.00 >:00-15:30 0.50 [:30-16:30 1.00 >:30-17:00 0.50 17:00-19:30 2.50 30-22:00 2.5 I 2.00 ~: 00-00: 00 I f~'1 0/02 I 00-01 :00 1.00 l :00-02:00 1.00 rOO-03 :00 1.00 00-05:00 2.00 Drilling from 13190' - 13500' md. Plant tried to start LP compressor wi no notification to rig. Lost high-line power. Rig started generators and lined up to back -feed power to G & I. Drill ahead from 13500' - 13529' md. Circulate sweep surface to surface. Monitor well. Short trip to 7" shoe. Max pull 335K-Ibs. RIH to btm for circulate and condition. SOW= 245 K. Circulate and condition hole for logs and 4-1/2" liner run. POOH to shoe. Monitor. Slip and cut 102' drilling line. Pump dry-job and drop 2-3/8" hollow steel rabbit. POOH for E-line OH- Logs. A retaining ring (2.5" OD x 0.625" deep x 0.25" thicknessl WT= 1.25 oz- aluminum) fell to rig floor. Shut operation down- pump across top of the hole. Perform zonal derrick inspection. The retaining ring appears to came from light at 110' level in derrick. Light was removed. POOH for E-line OH-Iogging runs. I" 00-05:30 0.50 30-08:30 3.00 POOH. Stand Back 5" DP. Change to 4" equipment. POOH. Stand Back 4" DP. LD 4" HWDP. DRILL BHPULD P PJSM on LID ofBHA #8 wi source. LID BHA #8. Flushing Tools wi fresh water. 6-1/8" Bit grade: 2-6-BT-G E-I-WT-TD Clear and clean rig floor. PJSM for SWS W/L rig up. Get Electrician to supply power to pipe rack for ElL unit. Test Tools. Logging run #1- HRLA-Density-Neutron-DS PROD 1 EV AL LOG P Logging run #2- RFT (20 data points). I' 30-15:30 7.00 30-00:00 8.50 I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS07 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 10787 to 10880 ft 9047 to 9116 ft Show Report No.1 DatefTime: 4/27/02 Depth (MD) (TVD) Interpretation: Steam still analysis indicates this upper portion of the Kuparuk "C" would produce gas. Drilling Mud contained 1 -2 % lubricants. A very very dull gold sample fluorescence was ocserved, with no cut fluorescence in the 10840' cuttings sample. The 10880- 10920 cuttings sample also exhibited a very dull gold sample fluorescence, but no cut fluorescence. KUPARUK"C" INTERVAL I % Depth # 1 0800 ft Gas x Units 1329 Mud Chlorides (ppm) = 18k ---¡:iõwlrñë-------~üëiiõn------~-hõw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 27.0 3.76 = 98571 - -- C2 3.05 0.55 = 9835 - -- C3 1.82 0.58 = 5754 - - C4 1.54 0.80 = 3356 - -- C5 1.21 0.72 = 2060 - -- --PrõduCtiõ-ñ------------------------------------------------------------------------- Analysis (X1Gas (X1°il nwater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios ClIC2 = 10.0 C1/C3 = 17.1 ClIC4 = 29.4 C1/C5 = 47.9 I I Depth 10820 ft Gas x Units 819 Mud Chlorides (ppm) = 18k ---FrõW1rñë-------~üëiiõn-----=-!rhÕw"::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 26.20 3.76 = 80.59 - -- C2 5.02 0.55 = 4.47 - -- C3 4.47 0.58 = 3.89 - -- C4 3.53 0.80 2.73 - -- C5 2.50 0.72 1.78 - -- --PrõduCtiõ-ñ------------------------------------------------------------------------- Analysis nGas (X1°il nwater nNon-Producible Hydrocarbons 3 % Depth # 10840 ft Gas x Units 833 Mud Chlorides (ppm) = 18k --Frõwlrñë-------Šüëiiõn-----~1i'õw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 19.00 3.76 15.24 - -- C2 3.41 0.55 2.86 - -- C3 2.77 0.58 = 2.19 - -- C4 2.27 0.80 = 1.47 - -- C5 1.74 0.72 = 1.02 -"j5rõðuëTío-ñ------==-------=----------------------------------------------- Analysis nGas [Xl Oil nwater nNon-Producible Hydrocarbons 4 % [ Hydrocarbon Ratios C1/C2 = 18.0 ClIC3 20.7 C1/C4 = 29.5 C1/C5 = 45.3 I I Hydrocarbon Ratios C1/C2 = 5.3 ClIC3 = 7.0 ClIC4 = 10.4 ClIC5 = 14.9 Depth 10880 ft Gas x Units 134 Mud Chlorides (ppm) = 18k ---¡:rõ\Ñliñë-------šüëiiõñ-----=-š1i'õY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 16.80 3.76 = 13.04 - -- C2 3.50 0.55 = 2.95 - -- C3 3.03 0.58 = 2.45 - -- C4 2.55 0.80 = 1.75 - -- C5 1.87 0.72 = 1.15 --prõduCtiõ-ñ------==------ - ---------------------------------------------- Analysis Gas x Oil Hydrocarbon Ratios C1/C2 = 4.4 ClIC3 5.3 ClIC4 = 7.5 ClIC5 = 11.3 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 - ---~-------,._-------- NPH 100.0 -- -- ~~~~#~~-::~-=- ,--, n~_- - --," -,-,,-.---'''."," ,- .. Gas ..._---_.~_..__.-..---- - .....__._._-----_._~.._... .----..--.." .. 1 0.0 -------~-_... -_._-_.,""'.-.----~--_.. .-- _.--.... -",...".---....-..--.-----""'''''-- --....,-.".- "".~--.- .--.--'" ..",- -~---_._-_._---- -"._"-_.._-_._...._-_...-,~.,, -0 _....~-,.._.- - . -.,...---.-.---.-.. . .-.-..---....- ---,-""---- u.-. ,,_.-..._.~- Oil -.-.-...-...-..-,.,.-,..-- ..--..-,. --..-. NPH 1.0 C1 C2 .. HydroéàÌ'bòn Ratios C1 C1 - - C3 C4 C1 C5 1000.0 .. .-...-.--....-.u_..-,..,_o.. ._-,---_. -,,~._--_.._. ".._.,,_..-~- ---_.-------_._.~...~.~~_.- NPH -- -- 100.0 -,--,.,-"."---"-'--'--'- .-..---..-"".---.----- ----. ...._,....__._,-----_..__u_~ -.----...- .- "'-"-'----~-'-'-'------'- -..---.--.....----.- _.~.,._-"._,.---.-.__...._-"'_u- .....~".~- -'-"--'----~"-"'-"---"----"'-- Gas - -- ~-'---'-"---'-"'--~-'-'--~_U '__.__.n_..__._.- ----'---"--'.. _..,--"._....._-~,"._-_..,,-- .. - - 0 - - ~ ~ :::.- .;';;';-""'-_.."'-~"'-~. Oil . .__._._-_.~._----_._- ----.-.-,,-....- ..-. - ...-...-....-..--- NPH 1.0 I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS07 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY Depth (MD) (ND) 10880 to 11020 ft 9116 to 9221 ft Show Report NO.1 A DatefTime: 4/27/02 Interpretation: Steam still ratio analysis indicates this lower section of the Kuparuk "C" would produce gas. 1-2% mud lubricant Overall low gas readings and low steam still readings indicate a tight formation in the lower Kuparuk "C" interval. All cuttings samples in this interval displayed a very dull gold sample fluorescence, but no cut fluorescence. An examination of the sample cut fluorescence with the samples dried for 8 hours showed a very slow I 1 % Depth # 10900 ft Gas x Units 68 Mud Chlorides (ppm) = 18k ---FïõWirñë-------šüëiiõñ------~-liõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 8.0 3.76 4.27 - -- C2 2.28 0.55 1.73 - -- C3 2.94 0.58 = 2.36 - - C4 3.13 0.80 = 2.33 - -- C5 2.47 0.72 = 1.75 -15roaücTío-ñ------===-------=---------------------------------------------- Analysis (Xl Gas fX10il nWater nNon-Producible Hydrocarbons 2 % Depth 10960 ft Gas x Units 94 Mud Chlorides (ppm) = 18k --Fiõwlrñë-------§üëiiõñ-----=-!ftiõy¡~--------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 10.5 3.76 = 6.74 - -- C2 2.52 0.55 1.97 - -- C3 3.02 0.58 = 2.44 - -- C4 3.10 0.80 = 2.30 - -- C5 2.48 0.72 1.76 'i~:- 5rõaüctiõñ------===-------===------------------------------------------------ , Analysis [)qGas fX10il nwater nNon-Producible Hydrocarbons '3 % I Hydrocarbon Ratios ClIC2 = 2.5 ClIC3 = 1.8 ClIC4 = 1.8 C1/C5 = 2.4 I I Hydrocarbon Ratios ClIC2 = 3.4 ClIC3 = 2.8 ClIC4 = 2.9 C1/C5 = 3.8 I I Depth # 10980 ft Gas x Units 73 Mud Chlorides (ppm) = 18k ---Fiõwliiië-------§üëiiõñ-----=-šliõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 9.06 3.76 5.30 - -- C2 2.31 0.55 = 1.76 - -- C3 2.89 0.58 = 2.31 - -- C4 3.04 0.80 = 2.24 - -- C5 2.62 0.72 = 1.90 --prõaücIiõ-ñ------===-------=---------------------------------------------- Analysis fX1Gas fX10il nwater nNon-producible Hydrocarbons 4 % Depth 11000 ft Gas x Units 65 Mud Chlorides (ppm) = 18k --FiõWirñë-------§üëiiõñ-----=-~-tiõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 12.20 3.76 = 8.44 - -- C2 4.18 0.55 3.63 - -- C3 3.91 0.58 3.33 - -- C4 3.49 0.80 2.69 - -- C5 2.78 0.72 2.06 - -- --Prõaüctiõ-ñ------------------ ---------------------------------------------- Analysis Hydrocarbon Ratios C1/C2 = 3.0 C1/C3 = 2.3 C1/C4 = 2.4 C1/C5 = 2.8 Hydrocarbon Ratios ClIC2 = 2.3 C1/C3 = 2.5 ClIC4 = 3.1 C1/C5 = 4.1 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 . -...' "--'- - --_._---_._--~-_._,---- -- .._-,,--- . NPH ----".-'''n_- --~..,--- --~"'- ,--- -"'.-'.'.. """--~"- '---"-- --"..._._._-,.._,~-,..- 100.0 -- -- -- -- ~' ~.?_~-~~~~ ~~-_..-._._-_..__. ..--.-....----- Gas -------------- 10.0 Oil. ~ ~....... -~-,._,--. _. .._,,------ - NPH 1.0 .-.---.-..---.----..-...-.-.-----....-.....-.-...."---.----. -'.-'.-----'-.---'--'----'--.------.--..-- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 --------.- -.--.--..-- "-'.'--' _.h____..--,,-.-.-,,----. -,,~._..,,", _. .-. -. -. ---..--- -~ - - "._-". --..-..,,-.-- -- ..~---- ,-.-_._--- .._~~.._.._~- - -. - ----- -- -------.- -"-'-'--"'---'--'--,,~---'-"~."- - ...~..._.._.~._- _._~-----..-.--~.--_.--- . .. .. ".'."" -...- .. --. -"'.'--'''_.'_.__.~__...n'''' NPH 100.0 -- -- . --_. --_._..._._-,,_.._--.-.~-- - - -- ..,,"..._..._~.__...._-- ---_._._.~..- Gas - - - - - -';"; .,;;;,;.._._._.._....--.......~...:""" . 10.0 -.---....--.---".--...-.-- --.-----..-_.__._- ...-.-. . ...- ~--_._--_._- .-- .- --.-...... --..- -. Oil -. _._._--n'___'''---- N~~ ~-=-~_._= sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS07 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY 13020 to 13100 ft 10846 to 10918 ft Show Report NO.2 DatefTime: 5/12/02 Depth (MD) (1VD) Interpretation: Steam still ratio analysis indicates this section of the Sag River fonnation would produce oil. Overall low gas readings and low steam still readings are do to low ROP 15-30 ftlhr and higher mud weights 9.3 in the Sag River fonnation. All cuttings samples in this interval displayed 20% yellow/green sample fluorescence and a slow-mod, streaming, pale, white/yellow cut fluorescence. I % Depth 13020 Gas x Units 98 Mud Chlorides (ppm) = 20K --Fiõwirñ¡-------šiJëiiõn------~-lÏõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1 3.4 0.06 3.29 C1/C2 = 6.4 - - - - C2~~ ~ ~ ClIC3 = ~ p"J' 0.49 ~ = ~ ClIC4 = ~ C4 0.41 0.11 = 0.30 C1/C5 = 11.1 :->(;5 =dQ.42 - o:i3 = Q30 - ;~"~'r6daaiÕ-ñ------==-------==------------------------------------------------ ',"."f.d1aIYSis nGas [Xl Oil nwater nNon-producible Hydrocarbons i1 % DEij>th 13040 ft Gas x Units 24 Mud Chlorides (ppm) = 20K ----FiõW1rñ¡-------Šüciiõn-----=-!flÏõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.9 0.06 = 1.83 - -- C2 0.31 0.06 = 0.25 - -- C3 0.37 0.07 0.30 - -- C4 0.36 0.11 0.25 - -- C5 0.34 0.13 = 0.21 --Prõduëi'iõ-ñ------==-------=---------------------------------------------- Analysis nGas [Xl Oil nWater nNon-Producible Hydrocarbons ...!J % I I Hydrocarbon Ratios C1/C2 = 7.4 C1/C3 = 6.0 C1/C4 = 7.3 C1/C5 = 8.8 r Depth 13060 ft Gas x Units 33 Mud Chlorides (ppm) = 20K ---Fiõwiiñ¡-------ŠiJcüõn-----=-!flÏõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.92 0.06 = 0.86 - -- C2 0.22 0.06 0.16 - -- C3 0.37 0.07 = 0.31 - -- C4 0.42 0.11 = 0.31 - -- C5 0.32 0.13 = 0.19 --Prõduëi'ío-ñ------==-------=---------------------------------------------- Analysis nGas [Xl Oil nwater nNon-Producible Hydrocarbons 4 % Depth 13100 ft Gas x Units 7 Mud Chlorides (ppm) = 20K ---FiõW1iñ¡-------!fucÐõn-----=-!flÏõY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.67 0.06 = 0.61 - -- C2 0.14 0.06 = 0.08 - -- C3 0.25 0.07 = 0.18 - -- C4 0.25 0.11 = 0.14 - -- C5 0.32 0.13 0.19 - -- --Prõduëi'iõ-ñ------------------ ---------------------------------------------- Analysis Hydrocarbon Ratios C1/C2 = 5.4 ClIC3 = 2.8 C1/C4 = 2.8 ClIC5 = 4.5 Hydrocarbon Ratios C1/C2 = 7.5 ClIC3 = 3.3 ClIC4 = 4.3 ClIC5 = 3.2 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 NPH 100.0 -- -- -- -- .~-~., :.:~~-==.:_...__._._....__.. Gas , -.".--....- ----......- --- -------------- 10.0 . ~. :8 ..... .. Oil ----~.----_.,._,-,----,.-._. NPH 1.0 C1 C2 --- ---- - --~. -.--,-----"'--.-..-.-..-........-...."'.--.- .." - Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 - --...--.-...."..--....- ...-..-...".-- NPH ,,----'"--'---.---,,-,----_.- "._-,.._.._._.._._...._--~--,,-_.._... . - -- ._.,._-,.~..._---_._'"_.._---,,_....~ 100.0 -_.._.-.~._'''h.-'_''__._._.- .- Gas ---,-----....-..-.----...- -.-.-._"'~-_.'"._-- - ...: '::.:,n:.:.-.:;. ...;;;.,;;,;;..,,,,..-,-, ...~,~.......... _..... 10.0 Oil ~=~~~~~~ --.---.-....-... -..- ,----...,,_. ---- NPH 1.0 sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS07 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY 13120 to 13200 ft 1 0935 to 11008 ft Show Report No. 3 DatefTime: 5/12/02 Depth (MD) (TVD) Interpretation: Steam still ratio analysis indicates this lower section of the Ivishak fonnation would produce oil. Overall low gas readings and low steam still readings indicative to higher Mud Weights, 12.3 PIG in the Ivishak. All cuttings samples in this interval displayed a yellow green sample fluorescence and a slow dull yellow cut fluorescence. 1 % I Depth # 13140 ft Gas x Units 80 Mud Chlorides (ppm) = 20k ---¡:ïõŸlïrñë-------ši.iëï¡õn------š-li"õY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 4.9 0.06 5 - -- C2 0.86 0.06 1 - -- C3 0.74 0.07 = 1 - - C4 0.61 0.11 = 1 - -- C5 0.38 0.13 = 0 --prõaüCtiõ-ñ------===-------=---------------------------------------------- Analysis nGas [X10il nwater nNon-produCible Hydrocarbons 2 % Depth # 13160 ft Gas x Units 98 Mud Chlorides (ppm) = 20k ---¡:ïõWiiñë-------Šüctiõn-----=-Š-li"õY¡-=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 100~ C1 2.4 0.06 2.38 - -- C2 0.53 0.06 = 0.47 - -- C3 0.51 0.07 0.44 - -- C4 0.48 0.11 0.38 - -- C5 0.36 0.13 = 0.23 - -- --proaüctiõñ------------------------------------------------------------------------- Analysis nGas [X10il nwater nNon-Producible Hydrocarbons 3 % Hydrocarbon Ratios ClIC2 = 6.0 ClIC3 = 7.1 C1/C4 = 9.6 C1/C5 = 19.4 I Hydrocarbon Ratios ClIC2 = 5.0 ClIC3 = 5.4 C1/C4 = 6.3 ClIC5 = 10.4 I Depth # 13180 ft Gas x Units 76 Mud Chlorides (ppm) = 20k ---¡:ïõ\Ñiiñë-------Šüctiõn-----=-ŠhÕY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 6.20 0.06 = 6.14 - -- C2 1.24 0.06 1.18 - -- C3 1.09 0.07 = 1.02 - -- C4 0.87 0.11 = 0.76 - -- C5 0.56 0.13 = 0.43 - -- --proaüctiõ-ñ------------------------------------------------------------------------- Analysis nGas [X10il nwater nNon-producible Hydrocarbons 4 % Depth 13200 ft Gas x Units 93 Mud Chlorides (ppm) = 20k ---FïõŸlïrñë-------šüëtiõn-----=-sli"õY¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 0.78 0.06 = 0.72 - -- C2 0.19 0.06 0.13 - -- C3 0.16 0.07 0.10 - -- C4 0.13 0.11 0.02 - -- C5 0.11 0.13 0.02 - -- --Prõaüctiõ-ñ------------------ ---------------------------------------------- Analysis Hydrocarbon Ratios C1/C2 = 5.2 ClIC3 = 6.0 C1/C4 = 8.0 C1/C5 = 14.3 I Hydrocarbon Ratios ClIC2 = 5.4 C1/C3 = 1.4 ClIC4 = 4.6 ClIC5 = -1.2 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 NPH 100.0 -- -- -- .¡",;.-- .~...:.:.:..:.:~:= .~.. .... Gas - - - - ---~--~ ~~ 10.0.:~:..........~............... ............ ..~~ Ii .....~...~- Oil _'.0._..'.....-...--..""'---. --.-. ........-.----. .--..-- --.---.-...... .--.- -.-.... ..--..--.,-.- '.- NPH 1.0 C1 C2 ... . m ._-. . .. - .-.-....-..--..-------.---.----.---..-.- Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ----- - .-- . -'-'-~---"-~'--- -- - --._'___0.'_- ".W- --,"-'-'.'-_._"-'",""--"-'---,"---' .-"--.---,.---"..-.----....-.. -.-....-.. -~ - 1000.0 .----..-.-.---.---.----.----.- -...-----.--...,,-..-- - ---.--.-.-.-.--.--.-,.-..--.-....--."'--" h_~_._"--_., ..- _."-~,-- NPH 100.0 -- --- . --.--- Gas ---------~-- ____m__,,- --- - - ---....-. :;~~~~;~~~ ~-=~:-/ N~~ ===~=-==~-~=-~~ I I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS07 Location: NORTH STAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY 13280 to 13360 ft 11082 to 111 57 ft Show Report NO.4 DatefTime: 5/12/02 Depth (MD) (NO) Interpretation: Steam still ratio analysis indicates this lower section of the Ivishak formation would produce oil. Overall low gas readings and low steam still readings indicative to higher Mud Weights, 12.3 PIG, in the Ivishak. All cuttings samples in this interval displayed 15-35% yellow sample fluorescence and a slow to moderate dull yellow cut fluorescence. I % Depth # 13300 ft Gas x Units 86 Mud Chlorides (ppm) = 20k ---Fiõwirñë-------~iiëüõñ------~hõw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 2.2 0.06 2.11 - -- C2 0.51 0.06 0.45 - -- C3 0.59 0.07 = 0.52 - - C4 0.61 0.11 = 0.50 - -- C5 0.48 0.13 = 0.36 --prõaüëi'iõ-ñ------====-------=---------------------------------------------- Analysis nGas fX10il nwater nNon-Producible Hydrocarbons 2 % Hydrocarbon Ratios ClIC2 = 4.7 ClIC3 = 4.0 ClIC4 = 4.2 C1/C5 = 6.0 I Depth # 13320 ft Gas x Units 72 Mud Chlorides (ppm) = 20k ---Fiõwlrñë-------suëüõñ-----=-~-ti'õw.::::"_-------------------------------------------- ppm ppm ppm (Steam Still PPM's in 100~ . C1 3.8 0.06 = 3.71 - -- C2 0.79 0.06 = 0.73 - -- C3 0.79 0.07 = 0.72 - -- C4 0.75 0.11 = 0.64 - -- C5. 0.63 0.13 0.50 - -- --Prõaüctiõ-ñ------------------------------------------------------------------------- Analysis nGas fX10il nwater nNon-Producible Hydrocarbons 3 % Depth # 13340 ft Gas x Units 68 Mud Chlorides (ppm) = 20k ---FrõŸlliñë-------ãiiëüõñ-----=-sti'õw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 2.02 0.06 = 1.96 - -- C2 0.58 0.06 = 0.52 - -- C3 0.76 0.07 = 0.69 - -- C4 0.63 0.11 = 0.52 - -- C5 0.54 0.13 = 0.41 - -- --Prõaüëi'iõ-ñ------------------------------------------------------------------------- Analysis nGas fX10il.. nwater nNon-Producible Hydrocarbons 4 % I Hydrocarbon Ratios ClIC2 5.1 C1/C3 5.2 ClIC4 = 5.8 C1/C5 = 7.4 I I Hydrocarbon Ratios C1/C2 = 3.8 C1/C3 = 2.8 C1/C4 = 3.8 ClIC5 = 4.8 I Depth # ft Gas x Units Mud Chlorides (ppm) = ---FiõŸllTñë-------šiiëÜõñ-----=-Šhõw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 2.30 0.06 = 2.24 - -- C2 0.60 0.06 = 0.54 - -- C3 0.63 0.07 0.56 - -- C4 0.59 0.11 = 0.48 - -- C5 0.45 0.13 0.32 - -- --Prõaüëi'iõ-ñ------------------ ---------------------------------------------- Analysis Hydrocarbon Ratios C1/C2 = 4.2 ClIC3 = 1.0 ClIC4 = 1.2 C1/C5 = 1.5 C1 C2 Hydorcarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 NPH 100.0 -- -- ¿~~::"~~~ '"=- , u- ,.. Gas - - - - - - - - - - - ,;;;,-,;;;,'...;. 10.0 u_..--. --. -.. _u . .. .. ,'-.-.----.----..'-'--,-".. .~-~:~~~~~:JI~~~~.~~~..~ Oil .-...-....-...--".-..-..--""-...--.-.-.-. NPH 1.0 -. -'----"'--"--"'-".'.' _..._----,---_.._.-,..- -""'-'---'--'_.'-"~'-"--" .. -.-----.-..----.-- ...-....~._- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 . - .. - .. _. --- .- n_"_...--.-----.-.----."--"'- . ,-..--.-.. ._,....---~....~..._,,~-~-----~- ---,----~-_._--_.__. . ~ 0 _n_,,'.,,- - ..~ --___'._0"__'0- "",..0.."".---"-,-----.,,,,,-,---- .. -.. -... -.. . .. - . . -. ._...-----~.._..- --.-----0,...-.---, --, ......-. .._.~.._--- -.-.,-'.- --"._~..__._----_.._._- '"_.-..~ _.._._.."....__._._.._-"~---,,--._-- .------- -,--....-,..-. -...-....-. - ----.- -.-".".... ,-.-.--.."--..-- --'_."-~'.""-'''-'''-'-'---'---~ -"-'-'---"--"_.'--'-'-'..'-'-"~- NPH 100.0 '''';'' '--'''''''-'''''''.~ --- ..._,. --,..,,--..--.-.. ..-,,---.--.-...,-....-.,- ',_.__.,,--.." -.. .~...,,_. ,." ".--,-.- .--.-".-.-. ...~-"_._._,...,,-,,.._---- Gas) .-_._..~--_.._---_.... .....-.. ._:~.._................. ..- ..c..:.: .........-....-...-.-- .... -.. _.__._..._.._.,,-----~.._.~_._- ._-_._-_._._-_.o.......~._---- --".,.,'-"-,_'._'.n~_",---."- on' ~::~~::=:=~! - --.,...,....-.......---.--.-...-..-- .__.._._----~ -- ..~..._- ...---,.".- . ---------- NPH 0.1 I .f;i"...";~\i~iØ~ør~v_:~t\1~~"'~' "... ,." . ". _~r'cJt.1It.C';'ut'f..u.~WlIJUj IJI~üllnU II~~~.. ,- :" Customer: BP Alaska Report No.: 1 'f Well: NorthStar NS 07 Date: 4/16/02 I 5pe,.,,.....v- sun Area: North Slope Depth 0 ~,; b RILL I N G 5 e R v I co e 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 0 i~ Rig: Nabors 33E Rig Activity: Kill NS-10 ~~ Job No.: AK AM 22066 Report For: Polya/Dinger " Mudlogger's Morning Report Shows: ';,;~ ~';~',i;';~':~~1;~;;~~'~~~)mi~.f~ij.,.m...\~~~:stt::lnll3t'~!!R~~~M~~.:,:J.LU:.:~'~.A,~~i , :,.,1 Current 24 hr Avg 24 hr Max Pump and Flow Data IiI R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow -L gpm ';~ Gas. 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow -L gpm :;~ Temp Out 50 Deg F ( deg F @ ) Pump 3 spm AV @ DP -L fpm .., Pump Pres -L psi A V @ DC -L fpm, :~~~~~~.;t~J.Ul~~t:--~~r.:JMfm;'1":u.:;uœ:;::I~i$ì~A~4:U.::~_t~~t'iÄl.,J;t,_.:nJ!t':Açø;j¡~;~1.~'.:J~1".~~~~ šIt ;~ Mud Wt In 9.05 ppg Vise 144 sees API filt 18.8 ml HTHP 0.0 ml Mud Wt at Max Gas 9.1 ppg ,~ Mud Wt Out 9.05 ppg PV 2~ YI 56 Ibs/1 OOft~eIS~ / 25 I 34 Ibs/100ft2 pH 9.0 ~ 0 % ,. '''::_c;¡xr.W:JI::I::cn~_I1I[ [[ 111 I \:II"'1L:=UIIIIIIIIi=-m:':~:m:¡::Ir:i1TIII j Jl.IJI'::W;:»!:I~:;&E(I11lï[I\:ønW';r~JIIiIIlr1l::u.Jt~1Irl. ( after \ \ TFA: 0.0000 --- Footage for Bit Run 0 I Bit No.: Wt On Bit: 0 0 Type: RPM: 0 0 Bit Size: 0 Hrs. On Bit: 0.0 Jets: 0 \ 0 \ 0 \ --- Total Revs on Bit: 0 Trip Depth: ft Trip Gas: Mud Cut: ppg TripCI: ppm Short Trip Depth 0 ft Short Trip Gas: 0 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %lCM Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks before Drill Rate during after before Gas during % Lithology Sst Sltst Sh Depth to to to to ---- -- -- ---- ~.'.i.,..:,.1 24 hour accumulation of Steel Filings from Possum Belly Magnets: ~ Description of fiilings: ~~124 hr Rec¡ Prep rig to move to NS07 :,:~ :j~ I . ~ .........~.,. ",.~ voo-'" ~ Æ;~ Logging Engineer: Reg Wilson / Mark Lindloff . :;:.:~:i~:'):~W.~Æ~L. .'..'~.' .. * 10000 units = 100% Gas In Air . ;.' ~i"'~.~l."'" ., ..' /.. ;t,~. ' .... '.:., " ."...'.' . "". . '., . ". "'.., -",,:..~ '.¥I'~~~~7f~_~" I .r~t1lw:t8itr._..rlf~l7 ..... .. 'l--t~~JlWI~r~. 'J".~1t\t1r.1J!"l~~~~~ti'. '*~ Customer: BP Alaska Report No.: 2 I'.;; Well: NorthStar NS 07 Date: 4/17/02 spe"""'-'V-5Un Area: North Slope Depth 0 ¡.". ÇI_~.J_~L I NG.::.' seA v I c: e 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 0 1 Rig: Nabors 33E Rig Activity: Rigging Up ;~ Job No.: AK AM 22066 Report For: PolyaJDinger ~; Mudlogger's Morning Report Shows: '~~'~, J¡r;\i{~(\;~~\)~~~Øi~~~~~w4!i~_l.t!1::A ~;,.~~~tìt~m~~~,~~1Jt~~~~~~~~ n fff r m][ I IIJ8'.NI.~~;.ø¡.¡;. ",( Current 24 hr Avg 24 hr Max Pump and Flow Data ~. .~~ R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow --2- gpm rt Gas. 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow --2- gpm .~~ Temp Out 50 Deg F ( deg F @ ) Pump 3 spm AV @ DP --2- fpm );1 ;~/ Pump Pres --2- psi A V @ DC --2- fpm : .tt-~~~~~~JIl~~. :nri'_~u;'.1IßI.~~ø~~__ijJIUOJJUin"":,:~"';I:~~~~]1qy;\.;.~~'.::l')':&~lU',\'.-'~: :~: Mud Wt In 9.05 ppg Visc 182 secs API filt ~ml HTHP - °.:9..ml Mud Wt at Max Gas ~ppg '~ Mud Wt Out 9.05 ppg PV 20 cP YI 69 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 9.0 Sd 0 . ";¡IJ:u.m:~~tmrlJl1Ilir 1111 i ~ J 11111 ]t:1W~IW..tl I1I1 1 1i\~ntlCl.':a~L1.m::nJ,.i;).:x:; .. I I 0 0 Type: RPM: 0 0 Bit Size: 0 Hrs. On Bit: 0.0 Jets: 0 \ 0 \ 0 \ \ \ TFA: 0.0000 ------ Total Revs on Bit: 0 Footage for Bit Run 0 Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth 0 ft Short Trip Gas: 0 Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM - after ft ft ft units -ppg units ppg units - ppg f1 ft f1 units units units ppg ppg ppg Connection Gas and Mud Cut f1 units ppg f1 units ppg f1 units ppg I Drilling Breaks before Drill Rate during after before Gas during % Lithology Sst Sltst Sh Depth to to to to ---- ---- ---- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. -,^,^-,-,=J:IL: "';\Inf.lI 24 hr Recé Rigging up on NS07 .,:~ , .~,~ :<1 Logging Engineer: Doug Wilson / Mark lindloH . ,;,.':~~~~¡~~~~i~~.~~~;!J~~-~!~"~:"~ * 1 0000 units = 1 00% Gas In Air ~~~i~.¡. .. '~Ìi.~Ii¡BfML~.îlnUf'.':tr.r~~1t~~Øtf' jmì~l/ hIIm.~[anr U' lI1lJf~~._""T~~,:,. Customer: BP Alaska Report No.: 3 Well: NorthStar NS 07 Date: 4/18/02 Area: North Slope Depth 750 Lease: NorthStar NS 07 Footage Last 24 hrs: 750 Rig: Nabors 33E Rig Activity: Drilling Job No.: AK AM 22066 Report For: Polya/Dinger ~ Mudlogger's Morning Report Shows: i~ , '.' ," .,... ,'. '.. .,. ... " , ' . " ,., . " , '.' ." , J1r:"?c~~~~",::¡¡.!¡1;~~!.~~!~t(\)¡:~',ÌÒ..I;;~~;::#i:~~~~~i\1¡:'5i~~U~!~\t~'t.:;J''''.,n;.:;,~~'JI¡~~~mJ~'.-Ji..:'~J.\..:~~Iìt: p Current 24 hr Avg 24 hr Max Pump and Flow Data :¡~ R.O.P. 0 ftfhr 0 ft/hr ( 0 ftfhr @ 0 ) Pump 1 90 spm DH flow ~ gpm ~, Gas" 1 units 1 unit~ ( 1 units @ 750 ) Pump 2 90 spm Total flow 762 gpm .1 Temp Out 58 Deg F ( deg F @ ) Pump 3 spm AV @ DP 60 fpm ~ Pump Pres 1050 psi A V @ DC ~ fpm ~ 1t~~~t~~~;Ð(,:~,:';,~~~Il:;':~1fI,.l.fl..::Q~~I@~~:1I~-Uu(~.~t~;œ:"'~(f,J'OO:),~~, " 3,~ :í~ Mud Wt In 9.00 ppg Visc 103 secs API filt 9.8 ml HTHP 0.0 ml Mud Wt at Max Gas 9.0 ppg ::;1 Mud Wt Out 9.00 ppg PV 21 cP YI~ Ibs/1 00ft2 Gel~~ / 34 I 37 Ibs/100ft2 pH 8.8 ~ 2 i.,~~~'. ,.. :t'tlt'\Tt'm£:X.jUUU:r:_¡l1lm(r(.UD1ll:~Jl:QOC1tn\..Uc',:~:::::r::::]LIJII II!IJ 11m nr m~ 111 11 In 1~f11 Ii _J'nrr:n:mnnlr.l[[n::]nr:::r:~~JW:::K~I,¿\!i;~ spe'-'r'v-sun ~~..J L L:-.-!_~§'..- 5 E A V I c: e 5 I I I " Bit No.: Wt On Bit: 1 10 Type: RPM: MX.C1 38 Bit Size: Hrs. On Bit: 16" Jets: 12 \ 20 \ 20 \ 20 \ \ TFA: 1.0310 ------ Total Revs on Bit: 130K Footage for Bit Run 750 22.0 Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth 331 ft Short Trip Gas: 3 Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 50 % CLY 30 % SD 20 % GVL % %LCM I ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft ft ft units - ppg units - ppg units -ppg I I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to ---- -- -- -- -- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. í '~~. ,~,~; ~~. Logging Engineer: Doug Wilson / Tom Mansfield * 10000 units = 100% Gas I n Air ~'~¡,;'"iÄ~~~~~~1~~_~_ŒØ'~U¡~i;. Rig up. Nipple up riser. Drill cement in conductor. Drilled to 331'. Ran Gyro. POOH for drilling RIH wi new assembly and drill ahead running Gyro surveys every stand. "~'._,~<:¡~~t~'U'Hí.""'~_'''!If-~Tlrm.[JI~~ì'':"'''' . ,.,. ',~i!tl\JH_~1,~1;~~í~.. I" ,0,"""'. =.. . . . . Customer:" BP Alaska' Report No.: 4 :r.:;' Well: NorthStar NS 07 Date: 4/19/02 ,I ~~~-;['~:~~~ L::~ ~~~~~~;~s 07 Footage Last 2~~~~ ;:;~; ~ Rig: Nabors 33E Rig Activity: Drilling ~{; Mudlogger's Morning Report Job No.: AK AM 22066 Report For: Polya/Dinger '~'r Shows: .'}~N:~.\':.'~'.::~;;!'~~~?II<:1~¡it~'W;,~~\,:~'<):.~'t~';~i~~~r,~~1t,r~:IM~~ft(~~~'~~~~~'¡¡/~~~:"">~.~';-..JI;.q."¡r~~I~"n~~~¡j¡;\\i",¡j;~,~,, '; I Current 24 hr Avg 24 hr Max Pump and Flow Data ;:, R.O.P. 101 ft/hr 182 ft/hr ( 730 ft/hr @ 1030') Pump 1 100 spm DH flow gpm ',~ Gas* 4 units 12 unitq 25 units @ 1728') Pump 2 100 spm Total flow ~ gpm, , ~?¡. Temp Out 66 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm .1?,. j'ø Pump Pres 1750 psi A V @ DC ~ fpm ,'~~;;'lJ'£.ll,\l';~M}P'~~",("":::~~~~~' :~~IQ.~'L,,u.r:(_JA',),~~x..~ ~ :, :.. ,~,'t ;t; ;f:;.~ Mud Wt In 9.10 ppg Visc 66 secs API filt 9.4 ml HTHP ml Mud Wt at Max Gas 9.1 ppg I I ~(~ Mud Wt Out 9.10 ppg PV 13 cP YI 36 Ibs/1 00tt2 Gels~ / ~ / ~ Ibs/1 00tt2 pH ~ ~ 2 % t:::-7~~::=:::~~::~~ 20~~:~L:'\.~ro~,. Wt On Bit: 25 RPM: 40 Hrs. On Bit: 29.1 Total Revs on Bit: 225K Footage for Bit Run 2,965 to to Mud Cut: ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm tt I I 1 Trip Depth: Short Trip Depth Tight Spots: tt Trip Gas: tt Short Trip Gas: I Current Lithology: 50 % CLY 40 % SD 10 % GVL % %LCM I tt units tt units tt units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg tt units - ppg ft ft ft units - ppg units ppg units ppg Drilling Breaks Depth Drill Rate Gas % Lithology I before during after before during after Sst Sltst Sh to - - - - to - - - - to - - - - to - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. .j , 24 hr Recé :í~ 11::¡. /ii IJ:, :~~ Drilling ahead. Top Permafrost @ 1195' MD, 1194' TVD Base Permafrost @ 1585' MD, 1564' TVD SV6 @ 3380' MD, 3043' TVD ," r~ Logging Engineer: Doug Wilson / Tom Mansfield ::':o':;';:.o:~:7¿~;:~~t~~;r~),:f~..k; * 10000 units = 100% Gas In Air. t . ',;' ..' ~.~:~~. i~"f\;!g~i+>;.\Î!tttt.'Œ~f':'_f~~~~"ill-"'"'- . .- ~ ,~~ Customer: BP Alaska ':" Well: NorthStar NS 07 "spe....,....,v-sun Area: North Slope i~ C R I LL-I N G 5 E! R V I c:: E s Lease: NorthStar NS 07 í,i' --.-. -- ,~ Rig: Nabors 33E ~(:' Job No.: AK AM 22066 Mudlogger's Morning Report "T.~r~">~"-~J~IIII~JI_~:¡;',i;~:~'k' Report No.: 5 Date: 4/20/02 Depth 3,774 Footage Last 24 hrs: 809 Rig Activity: Run 13 3/8" CSG Report For: Polya/Oinger Shows: ~'~,;~:'.:'\':~!S'F'~~~~Ä::/n:'.Jiß\'t;::.I~IIti!it~,\i.!~~~;t~"iJ'~~: :.~.;~:'~t-":<~M)..M Pump and Flow Data ) Pump 1 spm DH flow gpm ) Pump 2 spm Total flow gpm ) Pump 3 spm AV @ DP fpm Pump Pres psi AV @ DC fpm ¡ ,~t¡~~~¡~,.;!JU:m..a'lk~':!:l"I!.U",,,r,~;"'I[ :1\AU~:.;\(8U11. mlrnn t_nl",.f.!.,~I"IT,.;;:~~\r:.,¡¡t,k;;:t.~;iÄ4't1_lt\.,;U,'1.,'.U:...:Y';;,.::U~"'L.':¡J;~! .'. , ~,; :~. Mud Wt In 9.05 ppg Visc ~ sees API filt ~ ml HTHP ml Mud Wt at Max Gas ~ ppg ~r0 Mud Wt Out 9.05 ppg PV 18 cP YI 33 Ibs/1 00ft2 Gel~~ I ~ / ~ Ibs/1 00ft2 pH 8.5 Sd 0.5 % S~~ - - i~~r.mn~r.JftT._JII18I8'CiUlírrrJI m -lit:. J7Irlf::.:.dEn[ J1rmrunmlH ~ m In rJ n.U.CŒ Ull._1UI:Jl1't':Ullml~nl"," :'1. Bit No.: 1 Type: MX-C1 Bit Size: 16" Jets: 12 \ 20 \ 20 \ 20 \ \ TFA: 1.0310 ------ 'Wt On Bit: RPM: Hrs. On Bit: 37.5 Total Revs on Bit: 274K Footage for Bit Run 3,774 Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM ~::~ R.O.P. 'X; Gas" ;~ Temp Out ~.\ : I I I I íl.l.\',~~~~~~~~~~~A~Ä~X~~~!¡t:,..,., Current 24 hr Avg 24 hr Max 96 ft/hr ( 640 ft/hr @ 4 unit~ ( 11 units @ ( deg F @ 3052 3118 ft/hr units 66 Deg F ft ft ft Connection Gas and Mud Cut ft - units ppg ft - units ppg ft - units ppg units -ppg units ppg units ppg units units units ft ft ft ppg ppg ppg Drilling Breaks Depth Drill Rate during after % Lithology Sst Sltst Sh Gas during before after before to to to to ---- ---- -- -- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: :~'. 24 hr Recé 'i;' ~i' ~~~, .~. . Logging Engineer: Doug Wilson / Tom Mansfield .::.¿::.~~.~tf~:;:~~f ~. .~ ...' oz. Drilled ahead to 3774', T.O. for 13 3/8" CSG. Circulated hole clean. POOH. Rig up and run CSG. SV6 @ 3378' MO, 3043' TVO SV5 @ 3710' MO, 3316' TVO .., 10000 units = 100% Gas In Air " t:...~-~~:.. ..-'fI'.""" . I ~'.customer:~Ska ~"epo~~~~-6~":' '~ Well: NorthStar NS 07 Date: 4/21/02 ~ spe'-''''''\I-sun Area: North Slope Depth 3,774 I ~R I LL I N G-~-_~_~ffvi c: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: Test BOPE Job No.: AK AM 22066 Report For: Polya/Dinger Shows: ~ Kf Mudlogger's Morning Report ;~' f1~., '::.r;."A., -;;.';:"......,;,u.'h''''''''~ ,~",_",,:.:.\,,:::~;.:¡"Ito..........._t.\. --wI\..,.,«r""..',"""--"~~"'''.'''''::''~~..';¡'¡_'~~~¡'-~....~~..,., . '='~-'~~. ..:...û'I'!¡') ,'~"-.""-"". , '~"...l :.-.:.>. . .' . :"-...""'~.T"..:"f-I.I.. ~- ,,"'qIo~'Ji':"" -~~ ..,.,.' .-r-r..,....,...nr .-ll'~. . .. ~~18t",.v-JU.-1;.~~~ IE' "T~--w!': 'l~~I»D"If~~1InI\~~ " rI I I ,,~~ -:i~ Current 24 hr Avg 24 hr Max Pump and Flow Data ,~':' &t R.O.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow gpm rÆ~ Gas. units unit~ ( units @ ) Pump 2 spm Total flow gpm' ',Æ1 Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm .~ Pump Pres - psi AV @ DC - fpm. ~~1tt::~u~:~:r,:.:;~~'1I:.~:\(.~~~t~~j}\Ø;~~;~:'.(~':;)tt.:.~~~w..m.~\~~\ ,;l';;l.l\1I!ØlU~:~~lUr.::~:.;;>:x:,.;r!:A:;~-~~!)~A).~:"";;J:x;U£::J;.:J,'4..~', " .....- ' :;~ i Mud Wt In 9.20 ppg Visc ....£.. secs API filt ~ ml HTHP - - ml Mud Wt at Max Gas ~ppg i Mud Wt Out 9.20 ppg PV ~ cP YI~ Ibs/1 00ft2 Gels~ / ~ I _lbs/100ft2 pH ~ Sd ~ % J,."i. ", ""."'I¥:'''ò''I\'~W'''^~IiiiI~'ii'''''')\l"'''''¥t'¡¡;''ý'''''i'JIiò''i';¡'f'.'' "" "~ I "" , ~_'I'~1~}!"'I'!'Oi"'~."'.'t~'''~'''~rlr-'-1"'1-1'-~t\.-'"ij""~~I\'iIii'''V''''1iii~".,~.,,~..,.IIit'~--_(,.IF' ",," " ð ,,{.....wR.-,J.....ma.J...~,""ll..Ir...,IIU',_Ø'~f.~~-"..., Dt~mlt",,+t.--~~~~tIJM,.,M ~ II I I M I, n"~[~....~~ ."JIl,.-.".,.,.....,.,.'.-..,-v'lIL" ,rA...! If"...-aI..... .,.,.....~IftJL."'~.""'~~fI'":J,~",(~""'~-"'M....,.,.,,,II.."""".N,fA.. ~' , 'Bit No.: 2 Type: Bit Size: 121/4 Jets: -' -' -' -' -' - TFA: , Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run . , I Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM I I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft - units ppg ft ft ft units -ppg units -ppg units - ppg before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Drilling Breaks Depth to to to to ---- ---- ---- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. I ,Xl: 24 hr ReCé Ran 13 3/8" CSG. Circulated on bottom with max gas of 9 units. Cemented casing with 160 bbls. ::r4 good cement to surface. Nippled down riser. Nippled up stack. Dumped and cleaned pits. Mixing new mud \"i.} for121/4"hole. :1 ,~ .:~~~ ::~;: Logging Engineer: Doug Wilson / Tom Mansfield \;\~~~Y.~~'.:~ . ~~,.' :' ': .. 10000 units = 100% Gas In Air ~ I'-(r.'~ . _J.~.Jr ~ll\!øu.--'- - ........\..... -. ........11' ,~. ~~J8W'~ Iii ß.!..f~): Customer: BP Alaska Report No.: 7 I~\{ Well: NorthStar NS 07 Date: 4/22/02 .,' sper'''''y-5Un Area: North Slope Depth 3,794 '.~~ [:J A I L.L I N G !5 E A V I c: E !5 Lease: NorthStar NS 07 Footage Last 24 hrs: 20 r.. . Rig: Nabors 33E Rig Activity: Trip for MWD 1~~ M ' M . R Job No.: AK AM 22066 Report For: Polya/Dinger I :;;, udlogger s ormng eport Shows: J.-,,'~~,<\\;j¡\~,~.""'III.._Jl...__"'e~~ ' ~. Current 24 hr Avg 24 hr Max Pump and Flow Data Î R.O.P. ft/hr 302 ft/hr ( 585 ft/hr @ 3784) Pump 1 spm DH flow gpm t'£ Gas* units 2 unit~ ( 5 units @ 3760 ) Pump 2 spm Total flow gpm. ~ Temp Out 53 Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm "j~I, Pump Pres psi A V @ DC fpm Þ*'~ - '. : ...' . . [Jt~;,M~~.~.J::"~.:'~..:Ä;~,.',J.,,A!.J:::: 1'A\(\."._~1(~A~QlU\,.X1ftU,W;~_il::';'~~;.J;''Q)';:;JII!~j,;:..,..J1J11 . .~ .;.:\r~~~." I 'J~Þ ,.~ ì~ ~ Mud Wt In 8.65 ppg Visc 53 secs API filt 6.0 ml HTHP ml Mud Wt at Max Gas ~ppg I Mud Wt Out 8.65 ppg PV 15 cP YI~ Ibs/1 00ft2 Gel~~ I ~ 1 ~ Ibs/1 00ft2 pH 8.3 Sd 0 % i, '~\:f¡\_J1t.ItL')ø~_nŒ1.'l-r.\tJ\f~].UWliJ 1c:(rn1tl:~:~~.11 li:..::m:..:J::UU:,,'1rD I llllll I,LJ II I~ C:W.," I Bit No.: Wt On Bit: 2 Type: RS238HFGNP Bit Size: 12 114 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ RPM: Hrs. On Bit: 1.0 Total Revs on Bit: 1 K Footage for Bit Run 20 Trip Depth: Short Trip Depth Tight Spots: 3794 ft Trip Gas: ft Short Trip Gas: to to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft I Current Lithology: % % % % %LCM ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units -ppg units -ppg units -ppg I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to -- -- -- -- -- -- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~( tf..,.".~. 24 hr Recé Test stack. P/U new BHA. RIH. Test CSG. it new mud. LOT 13.0 ppg. POOH for MWD tool failure, I f~ Logging Engineer: Doug Wilson 1 Tom Mansfield '~:r,:.~.-.,~~y~lt~.. .. . ,... . 'f.¡,._.~.\~1It:..,;W.~~i .,,' ;j:~;~~~~_:~$t~J.::,~aœ¡MY~JrIà Drill cement & 20' of new formation. Displace hole to , .1 . i ~ 'f"'to... ':-,..~1 .;;~ ~ ,r-"~...',':;"'~?~",\~~~"-~':'fJ'-/':':"~:;;/:'ì::'~:'~, :,i< ";;i::.:'.'.>,:::",::'.':~:;,."~:/'.;:;~~~:~'.'.:",,;~.;~~'~\{,'.;.1~¡".' ~.r.-.:~';,.', 'i'.",~~~ A~f~.~~~t'''~'~;~I~~. * 1 0000 units = 1 00% Gas In Air ~. .'< I I I I I I ""'i~~~;I~~UtdÄ~'1t1ilW¡:':~:1LII ~J~1.~ _l~ffJ;~\~~~_1.t~«.1{tJ'~i~~-i}¡t', Customer: BP Alaska Report No.: 8 Well: NorthStar NS 07 Date: 4/23/02 Area: North Slope Depth 6,512 Lease: NorthStar NS 07 Footage Last 24 hrs: 2,718 Rig: Nabors 33E Rig Activity: Drilling :~~ Job No.: AK AM 22066 Report For: Polya/Dinger ',; Mudlogger's Morning Report Shows: ~ì1~'$~~~ìI1I.~~~r.wt~~HiJS~:¡¡'('1;:~~D~t:)lf~~"'iÞ~~~~- m i r I?r'.''''~~m~~~~' ~;f Current 24 hr Avg 24 hr Max Pump and Flow Data ",~ f~, R.O.P. 225 ftIhr 214 ftIhr ( 565 ftIhr @ 4635) Pump 1 101 spm DH flow - gpm .It Gas" 37 units 25 unit~ ( 217 units@5885)Pump2 101 spm Total flow ~ gpm. " Temp Out 74 Deg F ( deg F @ ) Pump 3 spm AV @ DP 91 fpm ~4. Pump Pres 1995 psi A V @ DC 126 fpm :~~tuX~"\1~..:~~;t~);;_Ut:;~.,~J)\~.:,Cll1.:;.J!:,~ç~...t~~:::;:~~l.t~~~'r~,:,,'::lJr.:l1~\ll~~f'ftJ\:LJC:J 11 11Il1JIKIU., lIlliJ ~~1i.:-£;!~ .1 Mud Wt In 8.90 ppg Vise 62 sees API tilt 21...... ml HTHP ml Mud Wt at Max Gas ~ ppg :~ Mud Wt Out 8.90 ppg PV ~eP YI~lbs/100ft2 Gel~~ / ~/ _lbs/100ft2 pH 8.5 Sd 0.5 % ~~.:~'L3,ltn1lt:~.UL:-' ,,_I UI WI I I~\J ~IIß . ill ~ I j 1m I ¡ K IŒ I Dr ~ ]:::11~J:CJI}Œ:J~Jj IIIn ~ .1111 1JIJ11 ¡ ~I ~I K IrtitL:I:::~:,: 5pe............v- sun CAlL-LING SEAVICES Bit No.: Wt On Bit: Type: RS238HFGNP Bit Size: 121/4 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ RPM: 150 Hrs. On Bit: 12.8 Total Revs on Bit: 141K Footage for Bit Run 2,738 2 25 Trip Depth: 3794 ft Trip Gas: 5 Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 30 % Sand 65 % Clay 5 % Silt % %LCM Connection Gas and Mud Cut ft units ppg ft un~s ppg ft units ppg ft units ft units ft units ft ft ft units units units ppg ppg ppg ppg ppg ppg Drilling Breaks Drill Rate during Gas during Depth % Lithology Sst Sltst Sh before after before after to to to to -- -- -- -- -- -- -- -- ~ > ' 1_. ~::~~~t:~~~:~t~~~ of Steel Filings tram Possum Belly Magnets: r' .mmW~![~m~J II~.~ ,- . .. H !~IIl.Ii:~::'-", , :.'.'.....:..~.' 24 hr Reel P/U new MWD, AIH. Slip & cut drill line. Cont. in hole. Trip gas 4 units. Drilled Ahead. No hole \~: hole problems. .% I 'Logging Engineer: Doug Wilson ITom Mansfield . 10000 units = 100% Gas In Air Jli ,':,~"..,',.~~ '''$'~''~~s'''á.¡o.'''' '.~~~~~'~~>l'~~~~¡¡~~~*<'.c¡?A"' ~;':t""".' "..F"~-';"- ..~\~.1ti\fti"m~~;~R.M"'.'" ,,':~"'.. ' :, '~'~:~7!.,,*,,;,~.-i~$~~~:;'~~~:~~~~-;¡î~i:tI'.~mæ~~~~~_¿'~rB~'~_K~i;':;'r:{.i; ';:::~~~\~~~;i,;:~,ilttS"U"WtiI1IIIIiD'fN!Þ.¡f~~--RM~r::';.4:, oz. I I' ,',.' ,', ..' , ,~ ' . ',. ,,'~:~mer: B~ ~:::.\t.1~m~¡~~~~~It.JlJ."~_~.~iif' ^ I", Well: NorthStar NS 07 Date: 4/24/02 .' SPeJ'""l"""v-sun Area: North Slope Depth 8,221 ::~. cf=!~ LL-I N 13 5 E A V I c: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 1,709 " Rig: Nabors 33E Rig Activity: Evac Rig i~ M 'M' R Job No.: AK AM 22066 Report For: Kidd / Dinger ,~, udlogger s ornmg eport Shows: ~l1~,t;::~~~~~~:::t\.,.;.u:;,:"~!:~J,¡¡¡;r~~~~~i,..:.:tJ¡~~~_..:L'I:~t'!l:41'/,~!I:J !t.L."'Ji~l~.".!lQ5t~ 1::: Current 24 hr Avg 24 hr Max Pump and Flow Data ~f' R.O.P. NA ftJhr 152 ftJhr ( 511 ftJhr @ 5968) Pump 1 106 spm DH flow gpm ~ j Gas" NA units 38 unit~ ( 196 units @ 6592 ) Pump 2 106 spm Total flow ~ gpm ~~ Temp Out 92 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm :;: Pump Pres 2350 psi A V @ DC ~ fpm w~~~r,~;t~~J;_tMJl.t;:.at:N;;.':t'.'~':'.I:.~:»tJ,~;~.'.""-'.t~.n~~~.:l':;:'~~]:.":~l~'I'8Jt~~~.,~MI)l:;;,:~mrl.~.U.I;'::}":~~:,' ~~ Mud Wt In 9.00 ppg Visc 66 secs API filt 5.2 ml HTHP ml Mud Wt at Max Gas 9.0 ppg "'~' - .~. Mud Wt Out 9.00 ppg PV 15 cP YI..E...lbs/1 00ft2 Gel~~ / ~ / _lbs/100ft2 pH 8.5 Sd 0.25 % I ;n¡[;;LUU1L1:Xm.IIIIl!~JlllijJ ~m rtmlì r m II I I)] II mnm ,nil I T un I . .1111811l1li1 I r] IIfTRI N\J,i,,~m[œr ¡ rm.IiŒÐI!Ø.1U&..::t\t::':i~::I::l4)~ I runt H 1I~1¡1.. I Bit No.: Wt On Bit: 2 25 Type: RS238HFGNP Bit Size: 12114 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TFA: 0.9410 ------ RPM: 150 Hrs. On Bit: 25.8 Total Revs on Bit: 237K Footage for Bit Run 4,447 I Trip Depth: 8221 ft Trip Gas: Mud Cut: ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 70 % Sltst 20 % Clay 10 % Sd % %LCM I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units ppg ft units - ppg ft ft ft units ppg units ppg units - ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to -- -- ---- -- -- -- -- i~¡. 24 hour accumulation of Steel Filings from Possum Belly Magnets: ,~~~ Description of fillings: :~r.;'¡ r oz. ,~, 24 hr Recé .Drilled to 8221'. Pumped hi vis/h.i weight sweep. Circ. ou~ and begin sh?rt trip to shoe. Pulling tight, ,~. began pumping out on stand 22. Evacuated ng at 23:15 due to false high gas alarm In cellar. Resumed POOH ¡I~¡ at 00:50. I ~g~~A~:~7i~~~F i:%1~~D, 6309' TVD :;;.: eOl VlllE @ 7997' MD, 6883' TVD :'¡ Logging Engineer: Doug Wilson / Tom Mansfield .:¡,,:,::~~~~' ! * 10000 units = 100% Gas In Air ~ . _--'11 ~~':¡.Q.¡.fÓl:\' . . :JI' .~'."...,.. .,- ",'~ .' I ,.fi~f1~~_1'tmtW1};~~~""'~~~$.?~1II\1 ~~:t_rm .lIIf~illUJr~~t~~~I:)'t~~*,,~ì,¡,;'J~, ;;;~ Customer: BP Alaska Report No.: 10 . I::}. Well: NorthStar NS 07 Date: 4/25/02 :"'; spe,..,,..,v-sun Area: North Slope Depth 9,177 '~;i [J R 11....1.... I N G -~~~-~ I c: e s Lease: NorthStar NS 07 Footage Last 24 hrs: 956 I' Rig: Nabors 33E Rig Activity: . Drilli~g "'. M dl 'M' R Job No.. AK AM 22066 Report For. Kldd / Dinger ~¡~ u agger s ornmg eport Sho S. ~ w. K~~~~~(~\~~l'1~V,~~Jl;tl.t\;Jtr;:::::J.\I1:~;.;~UA.\.'';'lIM..t¡;(~_r..',~-iIi.:,:':';~~~*,~._~~1\~J(,,"t1ti;;,;a~£~~;"Ml~'~~~ . . . . ~~ ~: Current 24 hr Avg 24 hr Max Pump and Flow Data .~;.~~. R.O.P. 98 ftJhr 138 ftJhr ( 225 ftJhr @ 8325) Pump 1 107 spm DH flow gpm :. Gas" 120 units 120 unit~ ( 120 units @ 9085 ) Pump 2 106 spm Total flow ~ gpm :~. Temp Out 88 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm !~ Pump Pres 2750 psi A V @ DC 372 fpm §~!)._t¡,:ntU~:.u.~,ðftn~~~~:.~:~Z''''''~~_1 ~lJ 8U.]l::.::U~,.;,J)LJ.ø .1~.J~~~l)æ,:"l;'it\~glW;¡¡.:t;UU¡',;L':lU~1-;;~:tt;;t.JU1Xt:.[.,~ , :ilf :~ Mud Wt In 9.10 ppg Visc ~ secs API filt ~ ml HTHP ml Mud Wt at Max Gas ~ ppg ;:~~ Mud Wt Out 9.10 ppg PV ~ cP YI 24 Ibs/1 00ft2 Gel~~ / ~ I ~ Ibs/1 00ft2 pH 8.5 Sd 0.5 % t~c~~tUL:=:NP --~itlls:ze: ~:~::--~e~;Jr.~ 1I:1.:"\I[~m; \ t 12- ;~:=. ------ Wt On Bit: 25 RPM: 150 Hrs. On Bit: 33.2 Total Revs on Bit: 302K Footage for Bit Run 5,403 I I ( I .r.;\!MfJ!'.... I Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth 8221 ft Short Trip Gas: 498 Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 70 % Sltst 25 % Clay 5 % Sd % %LCM I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units -ppg units -ppg units - ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to ---- ---- I -- -- -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~~ 24 hr Recé Circ. @ shoe to clean hole of cutting from backreaming in open hole. Service top drive and level rig. ;~ RIH reaming through tight spot from 6143' to 6600'. Run to bottom. Short trip gas of 498 units. Drilling ahead. ;(~~ ¡ I .,;,l~; ;~,~ }'; Logging Engineer: Doug Wilson / Tom Mansfield :. . . j!~ * 10000 units = 100% Gas In Air .' -.... '. '''...'' .' '-.H",~~~~~~~.' "~koo.~~~1t~;;";": - . fáM~~i~~~\!f~.'", h';:~,.~~;~~"~",, . ." I : ~~~.:n~.1J t JUI"lImWfOrmll1ll¡I11IIß [J mIl U4~HllWfllWmJ.]u~ - - .lmlm~~,~\',~~.;t\t~~;;;;"~' Customer: BP Alaska Report No.: 11 Well: NorthStar NS 07 Date: 4/26/02 ~ 5pE!~""V-5Un Area: North Slope Depth 10,619 H 9. A I L.L..I N G S_~,.A \!.. I c: e 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 1,442 'I! Rig: Nabors 33E Rig Activity: Drilling ,. ,. M 'M' Job No.: AK AM 22066 Report For: Kidd / Dinger I udlogger s ornmg Report Shows: ~;~'Ì~~~~.'.~I':"'~".~~~£~Jt.J/\,IÄ,¥:,~--:IQrøt_i .IMtiøæ4t'b1t~,'\MKJ_~~~~\~ì,~~t.~.",?~',' :;:~ ~i: Current 24 hr Avg 24 hr Max Pump and Flow Data f~~ R. O. P, 80 ftJhr 102 ftJhr ( 140 ftJhr @ 9493) Pump 1 102 spm DH flow gpm .~ Gas" 98 units 120 unit~ ( 245 units @ 9182 ) Pump 2 100 spm Total flow 854 gpm 'Î Temp Out 105 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm ,;,¡' - .~ Pump Pres 3150 psi AV @ DC 350 fpm :~~"Ii"""''''''~''''''.: .~ ", """:''' ..., "'........}'¡~DWII U:¡-';\iOO¡'''*'~~,~'~riQi~1JIIU''"'1II'jft,~'''I>'Ir!bio1,¡¡¡,:«.....:\~.:':...M::,''' 1 " ." ~',¡m"~-;-~Ir':.1I1UI~I"",O:~'~~\."",";'*'~~¡';'Íi,.t1'l,: ~~~~~~ I'~ ,-,",~~ ....~~.~"w.:~~"H~~Jì"I!~~~,¡"r~-'~~~~~~'''''~':~~,F'\!,.~"...--.-.-\ ,~~,fltWY~~~1tM~I,I,,~....~~!N~~."" ~~~..... ..",~:~1;'1.. ~ Mud Wt In 10.20 ppg Visc 51 secs API filt 3.6 ml HTHP 9.8 ml Mud Wt at Max Gas 10.2 ppg ~ Mud Wt Out 10.20 ppg PV 17 cP YI 31 Ibs/1 OOft~els 11 I 22 I 26 Ibs/100ft2 pH 8.5 SdQ.25 % ~7~~:e:IIII:S238HFG: :::::~~:œ: 3-::n;:: \- 611~ ~ \ 1~ I I :: ~n Bit: 30 RPM: 120 Hrs. On Bit: 50.5 Total Revs on Bit: 445K Footage tor Bit Run 6,845 ;:,.,r:. I ,\ I I I Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 60 % Shale 40 % Siltstone tr % Sst % %LCM I I ft units ft units ft - units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units - ppg units - ppg units -ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to -- -- -- -- ---- ---- , . ,~: ",..,.."...>~ '¡'¡:,:,.,...',',..~. ",'i:,'...,.. i".;>.;'.Y'.'.'i;,~......'."'.:!;;........!);i,;;rL:,j1\i~t.':.. ... ...;.,:'",..',.i ,.. :,'<,¡,..'+;~'.IP' ,""', ',.....'.....,...,'i:"""t;¿-I-,'>\',:C..11...',....,..'<'..':.1.'.'.'-,j\~\~!,.:~Ü\,;\'¡;;'~:;á(i,i~:7~'~~k'. ';r'~,y:~;u1~!:'/ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Rec, Drilled ahead weighting up to 1 0.2 pp~ prior to HRl. Drilling ahead at report time. , ;~ HRl @ 9897' MD, 8373' TVD ;1 Base HRl @ 10315' MD, 8693' TVD ;1 KUPARUK @ 10395' MD, 8754' TVD ~~ Update: KUPARUK "C" @ 10787' MD, 9047' TVD >1~, Logging Engineer: Doug Wilson / Tom Mansfield , ~~f. ~" ,:;'~Ui¡'i';.' : " ;¡\i-~~. . ~1à.'M(~.' ~t;;. ;;. .,,''''--~'~~ffi~~t'1J,J: . ,:-~1..- * 10000 units = 100% Gas In Air . f,~ ..-. '.' "-~¿~{~dâ~ii,\~:"~;~;a', I r...1ttlblllll... J- nUImlO~~~mer: t spe...,...,v-sun :r~~ tì ~_,=!!..LL I N G _.5 e A V I c: e ~ Lea~e: .,;;;:: RIg: ,It 11 Mudlogger's Morning Report Job No.: ~: I~:' ~ I ~~ Jlli~1N~._I.U~ltJbll~lmn~ JIIJUI.lm U:~l*~~b~!~~~~. BP Alaska Report No.: 12 NorthStar NS 07 Date: 4/27/02 North Slope Depth 11,048 NorthStar NS 07 Footage Last 24 hrs: 429 Nabors 33E Rig Activity: POOH for Bit AK AM 22066 Report For: Kidd / Dinger Shows: ".t:.;}n~¡~:£;tl!~~~~~'W~141>j~.~""~:«Il~.t1~_J'¡\.~:~Ü~J].1~jjJlLU~~*~.4I'''"'t:~~~~,:' .~ Current 24 hr Avg 24 hr Max Pump and Flow Data ~R.O.P. ftfhr 34 ft/hr( 155 ft/hr @ 10798) Pump 1 spmDHflow gpm .~t', Gas* units 130 unitq 1600 units @ 10834) Pump 2 spm Total flow - gpm ~I Temp Out 110 Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm ~; Pump Pres psi A V @ DC fpm '~~~~~~,:nr:;"~~.~~\ija:",~\",.~~~.;:c,';.I,.;:';l'~J,:;.g:':~«,:f~,~l~~;~~,,'~~.!,,;.,aWM~~_~;""'i.:n;;...~.,~;,J~;:;). >" .~ Mud Wt In 10.20 ppg Vise 49 sees API filt 4.8 ml HTHP 11.0 ml Mud Wt at Max Gas ~ppg :1i Mud Wt Out 10.20 ppg PV 18 eP YI 29 Ibs/1 00ft2 Gel~~ / 20 / 23 Ibs/100ft2 pH 8.5 Sd 0.2 % I I . Bit No.: Wt On Bit: 2 rtlI:mn::11JK Type: RS238HFGNP Bit Size: 12 1/4 Jets: 3 \ X \ 11 \ 6 \ X \ 12 TF A: 0.9410 ------ RPM: Hrs. On Bit: 63.5 Total Revs on Bit: 560K Footage for Bit Run 7,274 11048 ft Trip Gas: ft Short Trip Gas: Trip Depth: Short Trip Depth Tight Spots: I to I to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 30 % Shale 40 % Siltstone % I....~".'...' '24 hour accumulation of Steel Filings trom pos~~m.~B. elly ~~~nets:'" -. ..' ~; Description of fillings: 124 hr Rec, " Drilled to 11 048', CBU, POOH for bit change due to slow ROPs. Out of hole at 23:30, :~ KUPARUK "C" @ 10787' MO, 9047' TVO :.æ' ~~$ ;~ :~~ Logging Engineer: Doug Wilson / Tom Mansfield . ;,;, ':i.'.':"c:'~!¡:~g~~:~'1Mit._~'~~"~;(~_stif~~~ ;, . I ft units ft units ft units ppg ppg ppg Depth Drill Rate during 155 10790 to to to to 10918 before 75 30 Sst %LCM % Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft ft ft units -ppg units -ppg units -ppg Drilling Breaks after 25 Gas during 1600 after 75 % Lithology 5st Sltst Sh 70 20 10 before 70 ---- -- -- -- -- -- -- oz. " 10000 units = 100% Gas In Air I ~~1\!~~~:.¡;:,~~.~~._~~~'JI.~~JI..~~llIlllf - 1_~~lijlliml!~Þ_~~~'!t~~~~\;~'~:~+j!~';; :~~ Customer: BP Alaska Report No.: 13 i Well: NorthStar NS 07 Date: 4/28/02 Î spe'-'f"""\I- sun Area: North Slope Depth 11 ,440 "~f Q_~,LLL.I N G 5 E A V..,~,~. E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 392 ~ Rig: Nabors 33E Rig Activity: POOH for 9 5/8" !t~ Job No.: AK AM 22066 Report For: Kidd I Dinger ~~ Mudlogger's Morning Report Shows: "t;',':tJ': 'Y;\;.,;,.:~:*'~~~;~~~~"¡i(4..\1(¡;.x,:'('..f4MmOCr~J».\'t~'¡}'t:tl:':NMÜ~,~.~~~~~~~~---~~~3~U~~~~,"¡;:; '~,,: Current 24 hr Avg 24 hr Max Pump and Flow Data ~ ~,:,R.O.P. ft/hr 90 ft/hr ( 138 ft/hr @ 11359) Pump 1 spm DH flow gpm~ ¡. ,,:: Gas' units 118 unitq 252 units @ 11345) Pump 2 spm Total flow gpm, ~f Temp Out 115 Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm :~~; Pump Pres psi A V @ DC fpm ~,'.'~;'~."-'~"'~, "," .. "'>I'''~~I' 'j_I1I'n~¡¡;¡';~¡_r ''-'n''J''''_'h¡¡~¡I'III'-!lJ''''.IWf!r.'W'18r.'I."''III'''''' 1.1')'10.10"."", 'i;.'i'fiili,lif" \1it..."".~\'óì.1--I....'t'~~~'B_'_rl":!i.."u""'.'~Ylv..míi.'l'l",_:.r' IIr......m,.n'-.."'_""""-,,..' 1"o(~~~~,~I~""'~~~II't~~~,,:....~~\~\i~~,,~.~r'f.~~~~~~~~~. """,1.._~.ri"~~'f'r~~~~~J..,,IM,'ft""'!:I~~~~~ :¡ MudWtln 10.20 ppg Visc 44 secs APlfilt ~ml HTHP _11.:2.ml MudWtatMaxGas ~ppg :¡ Mud Wt Out 10.20 ppg PV 16 cP YI 24 Ibs/1 00ft2 Gel~~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8.5 Sd 0.25 % ";. :~ ',::nl.~w:1~I1r.r=::rotM:8I,nm¡1I H 1111 r JI .w..~.II~~lLl1r11l.U. ': ""z::::n::,Øi1i.¡: ~ i11mJr.'''M.nC:':-.I~.A.!Ll:JtU- I, , " Bit No.: ! Wt On Bit: 3 Type: DS141HDF+GNS Bit Size: 12114 Jets: 4 \ X \ 14 \ 2 \ X \ 15 TFA: 0.9460 ------ RPM: Hrs. On Bit: 4.5 Total Revs on Bit: 36.9 Footage for Bit Run 392 Trip Depth: 11 048 ft Trip Gas: 504 Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft I Current Lithology: 80 % Shale 20 % % % %LCM I Connection Gas and Mud Cut ft units ppg ft units ppg tt units ppg tt units ppg tt units ppg tt units ppg tt units ppg tt units ppg tt units ppg I Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during atter Sst Sltst Sh to - - - - to - - - - I to - - - - to - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: i Description of fillings: oz. !; '24 hr 'ReCé M/U BHA & bit #3. RIH, shallow test MWD. Slip & cut drill line, service draw works. RIH to 11048' ¡I~ and drill ahead to 11440', T.D. for 95/8" CSG. Circulate bottoms up and condition mud to 22000 strokes. POOH '~t for 9 5/8" CSG. I '~~} "~ :t~ Logging Engineer: Doug Wilson 1 Tom Mansfield ,;:},;tt}B1t,i~',~m:1f~«~.m~f""18C-~' , . "~I~~;(~lr~~al1 ,- -- , wOW-)¡¡Ji .. 10000 units = 100% Gas In Air I ,iri{~'#~-~~~~~~'Ui.~ ~1. ~ìI- - JPJI8~~.~JmjrIlUfllll_...~m~ç~",...,tt~'~~iP.,k;:~"¥~'. ~î Customer: BP Alaska Report No.: 14 ~ ,., I Well: NorthStar NS 07 Date: 4/29/02 if spe...,....,v- sun Area: North Slope Depth 11,440 ~; ~;U:!.! L-L I N G 5 e A v I c:. e § Lease: NorthStar NS 07 Footage Last 24 hrs: 0 I Rig: Nabors 33E Rig Activity: Run 9 5/8" CSG .~,: Job No.: AK AM 22066 Report For: Kidd / Dinger '.~i Mudlogger's Morning Report Shows: ~;::'~"l.:"~:'~~Ì?j~'~"Ir$t~~"';~\f;~\';~ ¡:'~¡;¡¡;:;¡~~~!~~~~~~~-~.~~,_!ti.;"~~'~..io;~~~~¡'t.,~~~"~,~:'" I " Current 24 hr Avg 24 hr Max Pump and Flow Data ~. RO.P. ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow gpm ¥: Gas. units unit~ ( units @ ) Pump 2 spm Total flow gpm ;:, ;1: Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ DP - fpm "f~ Pump Pres psi A V @ DC fpm ~ ,~:::.. '.'",~..,~;~"'''.'''''''~'-~__'H.u~.nJ~ rrl~1II11IIIf ~ II l-=")¡'~ U(J(wa1Jr~':'r 1'"ln'I":r.---.u"\Y',\I' '-:-r:'"'''I~..n'J1o''' -:---:\ .r:.-r:.':'.'-~x<!\:':{_..J': .l~~,'.;~~I."'~'" ,-..p.'.... '.""''' -,;.".,' ',"",y.J""J,,1t-:!u._.9'....~J8A~,.. .1..Œ.~'''''~...:''~""""k.'i-r:n.~~' Jt't'~"~'.',"'~,4-~ ~"\~~;'-:::'.,,, '~¡J, t~ Mud Wt In 10.30 ppg Visc 45 secs API filt 5.2 ml HTHP 11.5 ml Mud Wt at Max Gas ppg- :~) Mud Wt Out 10.20 ppg PV 20 cP YI 25 Ibs/100ft~eIS~ I 23 I 26 Ibs/100ft2 pH 8.0 ~0.2 % ~MI.~Itll':':::x:.uc:::D:o.::;.tŒ:mJ::1t1J1il]1\\:I~uUJØJllRr rnlnl!IfJlI [¡ g¡a'AOCU:~' . I 1.llIn..- . . Bit No.: Type: Bit Size: I Wt On Bit: RPM: Hrs. On Bit: Trip Depth: ft Trip Gas: I Short Trip Depth ft Short Trip Gas: Tight Spots: to to Jets: \ --- Total Revs on Bit: \ \ --- Footage for Bit Run TFA: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 80 % Shale 20 % % % %LCM I ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units - ppg units - ppg units -ppg before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Drilling Breaks Depth to to to to -- -- ---- ---- -- -- . ."'~- ......_~~~~~: ." 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. " il...J\\:. ':' ".,. . , .~ ~ 24 hr Recê Continue POOH to run casing, laydown BHA #5 pull wear ring, unable to pull, change rams to 9 5/8 t)~1 pick up Baker spear and retrieve wear ring. Install test plug and test door seals to 3000 psi, rig up casing tools o¡;~¡ make up float equiptment, RIH with 9 5/8 casing, circulate one casing volume at shoe, continue to RIH with casing ~l currently 5 joints off bottom with no problems. ~ iß. ~.I~' Logging Engineer: Doug Wilson I Tom Mansfield J,,~ ;!~k~_~t,;"" ¡ ,J . , , .. 10000 units = 100% Gas In Air , II i:~~;~~' r..""'1'1~1t~ùt'<~i;¡i~11tlà"~k.:'; . ..ÆU~~,..1tUf..\'iInW'rnmm~,~.f§í~~ ::.:' q,' ., II "~\" I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 07 North Slope NorthStar NS 07 Nabors 33E AK AM 22066 15 4/30102 11 ,440 0 Test BOPE Kidd I Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ;~~~~_t..~~',*~~"~~1~,",~ID~(~t:~\t.it:ItO'~j~1"t«~~~ilMl,'î~~~~~.n~~%~- i Current 24 hr Avg 24 hr Max Pump and Flow Data ~ R.O,P, ft/hr ft/hr ( 450 ft/hr @ cementing) Pump 1 spm DH flow gpm ,~ Gas. units unit~ ( units @ ) Pump 2 spm Total flow gpm I Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm :~ Pump Pres psi A V @ DC - fpm I, . _~""h't>lI!u;"\'I~I'.""", '."-"~'1\:- - UJiS¡ina 'i:"I~l'lIlr)îII''Y''!dm...tt.~'',¡I' _"nu'__wc ¡ -'¡¡U~'..If¡j["Ot"~Wi'IiK """""'""',"''Ii.'''"''''''IJI.1I>- ,,-- '-I'\'l-'~~'-~--""'-",:,..,., .J- ,;~~'~"!Ir~\~ ~""'~~"1\~~.~~1\'I".~"';"""~"'ft1~1Ø~,1""~"'~-'~.\~I.~~~'~~~\L.-...,ur..,If..~~~~...,'"'' J"......\.; A~~,.... MI ~-.~ ~~~:~~,~~~~ ,,~ i Mud Wt In 10.20 ppg Visc 42 secs API filt 5.8 ml HTHP 12.0 ml Mud Wt at Max Gas ppg I Mud Wt Out 10.20 ppg PV 16 cP YI~ Ibs/1 00ft2 Gels~ / 18 / 22 Ibs/100ft2 pH 8.2 ~ 0.1 % "ijiLL~llt::m)A:.:nlJllll 0011 JlÆ!l]lUrm ] ~i1I11(lDlU:~:.u=:~IU~D!fßJI:Jlmt_~::=!rlDfl):rrmm ml1]1 r lI!tU:JJUrXl1lJOU':::::;:' ''''', ~ : 'Bit No.: Type: Bit Size: Jets: \ \ \ TFA: ------ Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 5pe,..,...,v- sun g_~~L~_G_~ SERVIc:es ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft units -ppg ft units -ppg ft units - ppg I Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 80 % Shale 20 % % % %LCM I I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to ---- ---- ---- -- -- , 24 hour accumulation of Steel Filings from Possum Belly Magnets: :~, Description of fillings: I~ ,.' , , : 24 hr Recé Land 9 5/8" CSG. Had to work down last 3 jnts. Broke circulation at 1/2 bpm, stage up to 10 bpm. ;;, Pump cement job and displace cement wi rig pumps. Max gas while cementing 450 units. Bumped plug with ,~ with8087 strokes. RID cement head and casing tools. Drained stack and unfroze lines, Performed squeeze I job (75 bbls). Freeze protect wi 130 bbls diesel. Currently testing BOPE. ;1 ~¡1~ '~I Logging Engineer: Doug Wilson / Tom Mansfield "-s: 1t~.~4_~~1illOO..l~_~,~'- oz. ,. 10000 units = 100% Gas In Air ,;J~\,,';q.:~.¡~:,'~¡lt:':c:'¡'(¡.,'':A;'''.' i<~".': -'.'.". "...,.':.::?*\~,'\,':::'...;'.,}:'>,""" '.',\,'.:;f,~{I.. I !r''I.~~m'¡¡¡_~~ØlŒ l.JJØI~~.1n ¡ J _1J"J~L_!.lm.~~.~.tmB!lf'rìllfJ mll ~JJ\~ unrn nllg~I~~~~W<í::t" ~~¡ Customer: BP Alaska Report No.: 16 i Well: NorthStar NS 07 Date: 5/1/02 . spe.....,....,v- sun Area: North Slope Depth 11,440 ~ 9_~!_LL..1 N_~-=:~ 5 e A v_~--r;: E.Ë Lease: NorthStar NS 07 Footage Last 24 hrs: 0 I Rig: Nabors 33E Rig Activity: Drill out CMT '~,. ,. Job No.: AK AM 22066 Report For: Kidd / Clump ,k:: MUdlogger s Morning Report Shows: :£i:'" ~~~:;'i':.~~it.:,~'J';j':#~~¡~~-~tè~I\~~:ÌIf,II;~~'-tii\~:~~ ì~~~~,~~~tttr..:rtI(~l_~&.:.~:,trr.;.y";"'~r:' ~~. Current 24 hr Avg 24 hr Max Pump and Flow Data ,~~{ R.O.P, ftJhr ftJhr ( ftJhr @ ) Pump 1 101 spm DH flow gpm' .;~). Gas. 8 units unit~ ( units @ ) Pump 2 97 spm Total flow ~ gpm ~1 Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm ~~: Pump Pres 3200 psi A V @ DC 579 fpm. .~'~i. - .., :l,î~~~~:':::¡~:J;:;~~:~~~.~~:øIIlrJJ!JIJ.m--it~__~~*~ ¡~ Mud Wt In 10.30 ppg Visc 42 secs API filt 6.0 ml HTHP 13.0 ml Mud Wt at Max Gas 10.4 ppg ..\1 - -- - .~ Mud Wt Out 10.30 ppg PV 15 cP YI 21 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.5 Sd 0.1 % :~ :. '. :J~'n,I mUll!! I L I1!fIlJ ¡ , llnlUMllI1 TIIllIlk'LJ8LXJrJIII 011 I II m8.tJU1UlCœ.t:';'IX::]};If'Æ::m::!I] .K,:R.lro¡~:'"fJ.Llì[;C]r::B:::,:'ttr:;J\lt~ j' I I I I . . Bit No.: Wt On Bit: #4 2 Type: RPM: STR454 55 Bit Size: 6 1/2 Hrs. On Bit: 0.0 Jets: 13 \ 13 \ 13 \ --- Total Revs on Bit: \ \ TFA: 0.5180 --- Footage for Bit Run 0 I Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 80 % Shale 20 % % % %LCM I ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units ppg ft units ppg ft ft ft units -ppg units - ppg units -ppg I Drilling Breaks Depth before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh to to to to ---- ---- ---- ---- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ¡ i i~ , ~ ~ ~ '. It 24 hr Recé . 'Continue testing BOPE,service draw works, make up BHA#6,load source,RIH,POOH,remove source ì~~; lay down ADN, continue RIH to 10890', wash down from 10890' to 11328'(top plug) condition mud and circulate test 9 5/8" casing to 4050 psi(OK),perform D6 drill, slip and cut drilling line, continue drill out cement, abundant ,ií metal shavings on possum belly magnets and over shakers. ~ . },~' ;,:!' Logging Engineer: Doug Wilson! Tom Mansfield . 10000 units = 100% Gas In Air, . 'i;f:"'~:i~~~1~~~~1~~~~.~~I' I ~~~ì_J~tJ~'~I'1~~""IITl.. ~ 1~~~lfll "-.1~~':~'~(~1I!1~ ~l 'JlII~~~~~'!Y~.LlUJII~~~~~~~'\~~î'.~¡\" ~1 Customer: BP Alaska Report No.: 17 I Well: NorthStar NS 07 Date: 5/2/02 "Spert...-.v-sun Area: North Slope Depth 11,551 ~ i::J A I LL I N G 5 E A V I c:: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 111 .~¡ Rig: Nabors 33E Rig Activity: RIH ~. Job No.: AK AM 22066 Report For: Kidd / Clump it Mudlogger's Morning Report Shows: >,. ~"~' '.;."AI~~~"":.'øi~'<I\.'~~.>!.J~,,¡;~-.t~~,¡,!ij¡\ -r ~1Ji.~Iàt,~""'JS~~~t; '.*,f'lI"'~':I/\"..." .,~_~r... ~~',¡'J4,""';:I'I~;:,.......,~",~,:.!~,.:\:. . ),f M Current 24 hr Avg 24 hr Max Pump and Flow Data ~ ~i R.O.P. 0 ftJhr 52.44 ftJhr ( 132 ftJhr@11465)Pump198spmDHflow - gPj~'~ ::}Gas'" 3 units 17 unit~( 47 units @ 11441 ) Pump2 104 spmTotalflow ~ gpm'. :q Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ DP ~ fpm ,,~,'~,~,~,'..*'~'''''''\1i'.~lI!>.h~'''''_''\'--'''i~~'-~".""_~,1>,-..-¡o.1OIl.w~.,.¡'t"'n"'f""""_I~--U'iIi"'''-¡~'~'~¡~'''IIi--~''a!~='~::''~~~:;~'~~''~''~':~:!''~:~ , . .¡,r .,""."1if'-''I'~_,..I_-'--WII!>~''I~''~",''.I.II3,. , '~!IU~_~(~ " 'II' ..Q"!. ~~""~.~1'W>;._~""'~""~1'f"...'1!I'.\!, .~, ",.".N""'J."W"~~~~'- ., M . :'1 Mud Wt In 12.80 ppg Visc 55 secs API tilt ~ ml HTHP _12.:2. ml Mud Wt at Max Gas ~ ppg ~ :t~ Mud Wt Out 12.80 ppg PV 26 cP YI 20 Ibs/1 00ft2 Gel~~ / ..E-. 1 ~ Ibs/1 00ft2 pH 9.5 Sd 0.1 % .¡;:t) ::"" . '~umu4'1UJAOC::lr:m::tIL:D\Jt(]}~ml - r W l II, I rt~rrr:::JD1'i\:~l'I.l~-.Ul rmll !~..-r::I:~::u..tU«: ' I I Bit No.: : Wt On Bit: #4 Type: 14.3 RPM: STR454 0 Bit Size: 6 1/2 Hrs. On Bit: 2.8 Jets: 13 \ 13 \ 13 \ 13 \ 0 \ 0 TFA: 0.5180 ------ Total Revs on Bit: 145 Footage for Bit Run 111 I I Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 80 % Shale 20 % % % %LCM I I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ft units ft units ppg ppg ppg ft ft ft units -ppg units -ppg units -ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to -- -- -- -- ---- -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~ . ..." ~ ....... ~ " ,. . . " . ;~ 24 hr Recé Continue to drill out cement and Rat hole to 11440' , Drill to 11460' , MWD not working ,circulate ;f,~l! MW in = MW out 10.4 ppg ,perform extended LOT, 15.4 ppg EMW ,weight up to 12.7 ppg (26000 strokes) .~t~ Drilling from 11460' to 11551 circulate and condition mud, monitor well, pull 2 stands to shoe, monitor well , I POOH for MWD , ~:'~~, "'1:) Logging Engineer: Doug Wilson/Mark LindloH 'R.):..~~ \1ï~~~\WS'~fIIII!IJ :'r';:~H~~~~~~ g,~.,<. ,'.. ' ,~. .'. '" 1 0000 units = 1 00% Gas In Air '. ~. ,.' ""~~H*"J&%~~ .', .!. . m:~~1",'t~.~.TI:! I I~.~ !1ì1ttmWJrrw ì sper"'r"''V-sun ~~~~ Q_A I '-L.TÑ'-G-'-~'.'.~-_.? E.~VI"C: ES ,.t1~ !~;t .~~~ 1 ~ ~- Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: .. BP Alaska NorthStar NS 07 North Slope NorthStar NS 07 Nabors 33E AK AM 22066 II1J.~.I~r...øJr'''- ~l[ 1_,UûUlWmij ~ t_~~~~ , Report No.: 18 Date: 5/3/02 Depth 11 ,933 Footage Last 24 hrs: 381' Rig Activity: Short Trip Report For: Kidd 1 Clump Shows: ,I I I ~-:'t:~~\, ~ ,! "I'I~I:..', ":¡'':,'' :' . ... . ~;¡,;;/,...,,..~¡. \"'",,1(.1.''' ,.,,~ ':"'"'' ',",' f\T.:~~:.o ."." ' "" " " . .. :r, ." - "--: ' ., ; ., ", . ',,", '.~ '''';',"''rl~;1:. \ . ':.c., ..'" , . .' . '. ="" ':'4~ '~1111' :'t.,. - h:" " ",1 ~.~,~ ,f§1\~~ "~ :\!~~~~.¡~, ,'»,1-',;'" ,~,'....w~\~., -.Uij"~.ttnn~~~ !MU(,o~~"~1!~~~,,¡,¡,:!~~~~:~~¡¡ ,~,,~',,~, ,,,~:,, ï Current 24 hr Avg 24 hr Max Pump and Flow Data '~ R.O.P. 51 ft/hr 51 ft/hr ( 503 ft/hr @ 11625) Pump 1 91 spm DH flow gpm Î,,", Gas" 3 units 12 unitq 35 units@11648)Pump2103spmTotal flow ~ gpm t~ Temp Out 115 Deg F ( deg F @ ) Pump 3 spm AV @ DP 336 fpm! :~~ Pump Pres 4180 psi A V @ DC 633 fpm . r~~~~:~;;:":'~ --- ..,,, 'IlC_.IC('U::.n[D1.L.:'m[~ Im~1 --:I'_X; ~~IIII . "r.J.'1Y~:fg'~~1:;:'~:8D1r: I Bit No.: Wt On Bit: #4 Type: 110 RPM: STR454 97 Bit Size: 6 1/2 Hrs. On Bit: 15.5 Jets: 13 \ 13 \ 13 \ 13 \ 0 \ 0 TF A: 0.5180 ------ Total Revs on Bit: 371 Footage for Bit Run 492' to to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft I Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: I Current Lithology: 80 % Shale 20 % % % %LCM I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units - ppg ft ft ft units -ppg units -ppg units -ppg I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh I Depth to to to to -- -- -- -- -- -- ---- , 'i,';:i;/;";,.:;':'i:,,i,':, ','.'..'."...,..' ',. ..,.'.,':,-;".".~\\¡~,'.,.:..':: ~:'.:.~':<{~~;~,"~:tj~i};~",;t,~;:~;~,,~,,~' ":'. "::~:::;':'.:':",;:::"'::';:i':i'::.~~.;':ti"':':,:':.j"JS~ijl::i ",'.}"';:':"~:~~~\:'}::;;:~":;:"¡':';;:~~".::',::',".'.:::?,:'~.,'.':',;',':,;....",':,:, ,'::I'";~::),~',::":~~.:::;:~",:':,,,,:,:'::,,~':~::\:~:::~:~:",a:::,,:.~":',::'::':~';'::,J'~:~;'i:i~:~(:'~,.,'.,':':~,:;-'1i¿::'~,:~;:; ~":i'.-:':: -. '~":, :I':~~:':~: :':> :"'::,:"::;!L~";,~::,~~~~.~;;~':i:',;:,';.:.,,,::,',:,.:'." ,:,.:;:::~;,.:;:;'~~:,:.",:,. '::"'.:' ::..:~t::,:,;~::;~~,,:::',:.::',~'-:.:.:r\~\::-:,.:.:~..';.,: -':' '~>'J,~,'¡x:';',',',,',~'.,,~,., \~,':~,~'x,._;,~',~~)~;:,.'\'.1 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr ReCé Continue Drilling F/11551' T/11933", Sliding 30' to 60' per stand. Currently getting ready to do a wiper trip to the shoe. I ~ -¡ Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air r:"",',,' . ,,,' ,,_~~[J)m~ - Æ-ID8'.I~~ m~8r11.:Y::n"",... --l[HillJl.llt~: " " . Customer: BP Alaska Report No.: ~. Well: NorthStar NS 07 Date: " spe...,......v- sun Area: North Slope Depth ~:{, I:J .=ÎILL I NG'- 5 e R v I c: e 5 Lease: NorthStar NS 07 Footage Last 24 hrs: ;J It '-'--------'- ~,' Rig: Nabors 33E Rig Activity: I;,', Job No.: AK AM 22066 Report For: ~ Mudlogger's Morning Report Shows: ~. ,~~~,~~~"Wt~~O¡'iâm~_U1\I,FJ~~ì~~~f~:\'''''fâf-~~~~'''~~ ~":., :~1~ Current 24 hr Avg 24 hr Max Pump and Flow Data ¡ i.~iR.O.P. 53 fVhr 57 fVhr( 101 fVhr @ 11973) Pump 1 93 spmDHflow gpm;j 1i Gas* 22 units 23 uniÜ ( 48 units @ 12524) Pump 2 91 spm Total flow 654 gpm'; II Temp Out 115 Deg F ( deg F @ ) Pump 3 spm AV @ DP 221 fpm: ~:~ Pump Pres 4020 psi A V @ DC ~ fpm' ~.:. " ~..I";_nl',,,~.*"ì""".¡;:''M'~va.._0óI,_,'_''''''''U1'~>II\,---_1''.¡o \to¡~1If\1"""""'-"'.J/i!i1>II'1"3<":"""":'."I)IØNY'''-''llIII-':h~_'..t-''¡), )i~'"",,":"':'.""'w,,;¡~t~i""'J,""", ~~~.""..}?g,.., ~~~:o\'I'1T...m~~~~""~~!F.n.~~...,~n:'~':¥f.~~~.~~w~~:t\~~~~s.~,-~~~~,~~~~,~~~~';'iì:t;AJ.:.~'~,,~-~.~~,~,~~-¡~:"'~~\~, "' ,~,w~. c~~.".~"'~ . :~~t ~ Mud Wt In 12.80 ppg Visc 65 secs API filt 3.3 ml HTHP 9.0 ml Mud Wt at Max Gas ~ppg ¡" MudWtOut 12.80 ppg PV ~cP YI~lbs/100ft2 Gel~~/~/ ~lbs/100ft2 pH ~Sd ~% t I I 19 5/4/02 12,787 854' Drilling Kidd / Clump , _JJIIß.h ¡In . .JI¡¡W_~j ~ 1lJ m. ~ij rID \I U11F, ~ ! j mlDml-":: fur I Jaf ,,:l_jTI~' . #4 Type: 5-10 RPM: STR454 Bit Size: 6 1/2 107 Hrs. On Bit: 32.6 Jets: 13 \ 13 \ 13 \ 13 \ 0 \ 0 TFA: 0.5180 ------ Total Revs on Bit: 603 Footage for Bit Run 1,346 Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm I Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft I Currant Lithology: 50 % Shale 50 % Sltst % % %LCM I ~ ¡' , Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units -ppg ft units ppg ft units -ppg Drilling Breaks Depth Drill Rata Gas before during after before during after ft ft ft units - ppg units -ppg units - ppg % Lithology Sst Sltst Sh to to to to -- -- ---- ---- -- -- t::_-r" .. .'IJ[:" ~ '..- - ".o,,",,-v- ,,'. '''; '.... .,. ~......ß 24 hour accumulation of Steel Filings'from Possum Belly Magnets: Description of fillings: oz. !:,~, ',:;W,!"'.:;¡'.,.,<III:, ".::,:...,'¡,'.,:', :,; ',...', ,. ","",'.. ' :.,:,:<c,"::'.','<~>':"".""':.',:'¡'::,',..'., "..,.,..ii,<-,.<X:'...'\:.:)¡)<::':','.i,,', r:. ,'"., """...', ',',¡ "", ,',' . < ,':i,..:, , ~œ.-, , Continue Drilling F/11933' T/12787", Top of the Kingak 11960' MD, 9952' TVD. Drilling at present. ~I', ',' 24 hr Recé '\ j ~, ' II;"'.,..":,~.'~ , I. ;~1 7~ Logging Engineer: Doug Wilson/Mark lindloff :~;;)\ 'iti'J~' * 10000 units = 100% Gas In Air '''''~ ", ' , :¡aru ".,':'\' )~.,'~'. . '-~:' \ '\1,:':,'. r'.:~ ,~'.::~~':,\, .,~~~,~','. ,~'", ,'~.t~~,~~(:\, t';::~'J':~":':~~{",:'~';:'::,"~""", ':':.*%.,':~{~.; >"",":'~',"/ ",":-:;':,~ :, ':~" ~"::: '._:~',r:(;. ','::':~:;:': ."" ,::',">?J,¡~~;~~~~':':;:;'{.(,'~}t'<\",J':,~:~.':f~'.:¡:¡:':' t~~~':~'\,:i',;'::',:";'.:"';",:,:~' ,)':': r Ù;:;(::~',';",';~'.,,'~:'~,l;',;, I "tJ,:" ,.':... ~., Jml~ ~_~~1~~1L.ll[~Jt.~:~*j~8'\~ ' .. >; ~. Customer: BP Alaska Report No.: 20 : )'" Well: NorthStar NS 07 Date: 5/5/02 5pe........,v- sun Area: North Slope Depth 12,976 ., C A I L...L.. I N G 5 e A v I c: e 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 189 :, Rig: Nabors 33E Rig Activity: E-Logging .~; ,. Job No.: AK AM 22066 Report For: Kidd / Clump J¡¡~ Mudlogger s Mormng Report Shows: ,~\' ,',', ,'.. " . , ' ."" , ..' . ." " ....... . ".." "'.. ',H '" .. ' , "'.,' '" , '~ . ' , ,:,~'~'.;:~ï~'~!,¡~~~~~,,".n~,tt...I~I¡:t<t~~t..~.,,¡'l~;U.~,U,',~~~U..~.1~,JtJ.~"t~t:'f.t~~~""i~f' '," ~{ Current 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. 0 ft/hr 49 ft/hr ( 72 ftIhr @ 12883) Pump 1 0 spm DH flow gpm ~\ Gas" 0 units 45 unit~ ( 176 units @ 12975) Pump 2 0 spm Total flow --L gpm :1' Temp Out 95 Deg F ( deg F@)Pump3spmAV@DP--Lfpm :.'. Pump Pres 0 psi AV @ DC 0 fpm t;~",.~""1IC;~1:::;.f..;~~.n.mll,Jk,;;.~OC¡;;~JllU)::lJ.~,:r..~"-A~~:Ðr~~;;;)J;~[Jr.Ut};~:::;i:].,J:'.UnUW'iI'A~"!;,~œ--:;¡~;., , " , ~~ Mud Wt In 12.70 ppg Vise 67 secs API filt 4.8 ml HTHP 10.0 ml Mud Wt at Max Gas 12.7 ppg .. ~...'&~ - - - - -.~ ,~ Mud Wt Out 12.70 ppg PV ~cP YI~lbs/100ft2 Gel~~/~/ ~lbs/100ft2 pH ~Sd ~% ~ '~~;)DWU:X,:umr;UU&I.lA;.l111 ¡ I~ II .li~l VI J I :: LJ':;':(:D:ar::JR!lìŒ'-J¡nnrlll~ 1II11I!ì hJC1.I'I)(::Jitg;¡¡nnllll ìl IHl:~ t i I ! Bit No.: Wt On Bit: #4 0 Type: RPM: STR454 0 Bit Size: 6 1/2 Hrs. On Bit: 37.0 Jets: 13 \ 13 \ 13 \ 13 \ 0 \ 0 TFA: 0.5180 ------ Total Revs on Bit: 680 Footage for Bit Run 1535' Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft ft units ft units ft units ppg ppg ppg I Current Lithology: 40 % Shale 20 % Sltst 40 % Sst I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg - ft units ppg ft units ppg I Drilling Breaks % %LCM before Drill Rate during after before Gas during atter % Lithology Sst Sltst Sh Depth to to to to -- -- ---- -- -- -- -- ,',-~:',.", ¡ j 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Recé Drilled to 12976' MD, 10810' TVD. Short trip to shoe, No problems, RIH to bottom, CBU, No problems POOH to run E-LOGS. Top of the Sag 12930' MD, 10770' TVD Logging Engineer: Doug Wilson/Mark Lindloff * 10000 units = 100% Gas In Air ";')}~:;'~L .'.'.,' .",.'.".,'.. . .'" . "l.' ~ , f.Ir ,. I I I ~~ ~.'{~ r I I I I ~û~J~~.q. IIIA.':ftlJlœil~l~ I - ~~~;'~\1~".t 1JJ[~WIL,.] ]ijD~."~^~~)h~~JUlmIIŒIIU~~I;~~!8¡~{.:~." 1'i~' Customer: BP Alaska Report No.: 21 I Well: NorthStar NS 07 Date: 5/6/02 ~ SpE!r'....-.v-sun Area: North Slope Depth 12,976 ,~;; g~J LL I "!.§~ 5 e R v I c: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 0 ~ Rig: Nabors 33E Rig Activity: Running 7" Liner :~l M dl 'M' R Job No.: AK AM 22066 Report For: Kidd / Clump :1 u ogger s ormng eport Shows: ~~ ;f~t~~~'i_:r..[.:¡;;t~~~~It~~~'UUf:::,~'r'~'~:...t'~:':;~II'.œ:;_.Ll U~Ll~:~;.UU~.W:~ ......~~._tillI fTlII.~,J--~~'''''' ~ Current 24 hr Avg 24 hr Max Pump and Flow Data ,Q¿ '1i R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow - gpm ~,Üì,'~; Gas" 0 units 0 unit~ ( 0 units@0)Pump2 0 spm Total flow 0 gpm. ~'Temp Out 84 Deg F ( deg F @ ) Pump 3 spm AV @ DP 0 fpm I }¡.. ~J Pump Pres 0 psi A V @ DC 0 fpm ;;¡ ,0.:'" n, '-""'~""':":,II:"~"""'~'l't~.1.:.'..A,n\t_.lt~-1Q'iI'J,~:wr4I~'\f'~~~"~ ~"-"4'!l'r~~""' ~,..1:':'.~It,..;;;, ,,: t'".~.~.Ir.t ,"" . :;':..:. ,~ ~,,'ud WI In 1265 PPg Vise 65 secs APlldr Mud Wt Out 12.65 ppg PV 30 cP YI 35 Ibs/100ft2 52 ml HTHP 120 ml Mud Wt al Ma:< Gas ~ ppg Gel~ 12 / 39 / 45 Ibs/100ft2 pH 8.0 Sd 0.1 % --- , ' ''';_~~::H(1::XlrmLIl.1J("]1I ~ m~- Ø'4~- ŒIJJ 1m '''\'~t,;;::I:m:c',-~~:xm mI1lG!:"::1.~, Bit No.: Wt On Bit: Type: RPM: Bit Size: 0 Hrs. On Bit: 0.0 Jets: 0 \ 0 \ 0 \ 0 \ 0 \ 0 TFA: 0.0000 ------ Total Revs on Bit: 0 Footage for Bit Run 0 0 0 0 0 Sltst % %LCM ft Trip Gas: ft Short Trip Gas: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: 43000 ppm ppm ft Trip Depth: Short Trip Depth Tight Spots: to to % Sst 20 % 40 40 % Shale Current Lithology: Connection Gas and Mud Cut tt units tt units ft units ft tt ft units -ppg units -ppg units - ppg tt units tt units ft units ppg ppg ppg ppg ppg ppg Drilling Breaks Drill Rate during Gas during % Lithology Sst Sltst Sh Depth after before before after to to to to -- -- ---- ---- -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. (1'24 hr Rec'é ,. Ran E-Iogs First run good, second run hit a ledge, Come 'out and II. running 7" liner, currently washing down last stand. i :!~ ~1 Logging Engineer: Doug Wilson/Mark lindloff '~!!~~~I." '", '~~.¡;r.,~-' .-,' '.'" ,., ' ","' ~' ~~.~~~þ~,.. .~. .... " .' . '. . "" ,. ,'~.. rig up to run 7" liner, Currently * 10000 units = 100% Gas In Air !~~. ,£;: ,,;, ~:", I ~~.,'.:l..",J,;~~_.,,,-_..._,,"~~,,,~YøI , 'Ii ......~æm!lliJ J..tL.=.",~. ~~ .. -- UHtL"IJ:JlWIUUij UJ~~-~~~. I~ Customer: BP Alaska Report No.: 22 '. I Well: NorthStar NS 07 Date: 5n/02 ; spe...-...,v- sun Area: North Slope Depth 12,976 :~: cÄ I L...L I N G---- 5 e A v I"c::: es Lease: NorthStar NS 07 Footage Last 24 hrs: 0 ~ --'.'--'-----"---.--"-------.----"--- Rig: Nabors 33E Rig Activity: RIH . it M dl 'M' R Job No.: AK AM 22066 Report For: Shultz / Clump 1&,', :. .L~ u ogger S ormng eport Shows: ~ , ,~ I~::~~:~::;:~~:;:I' Rl~<~~'::-:;;:~~;;:~"~::I.' '.' I Gas* 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow ---0- gpm I Temp Out 84 Deg F ( deg F @ ) Pump 3 spm AV @ DP 0 fpm ~ -.:t~ Pump Pres 0 psi AV @ DC 0 fpm ~ :~,. ':'>.,' ," ':-""~, , '. ' '~. ,.~ ,'" ',". , .' , '.',' -, ;' . ".-..-.., c-...;-]- ., ,......' , :" --., '~". ,- - ,- . - -, '-',' .'., ~':,:. '~.:',~ ....~ ~:;:t.,~~~~",~~';'i1ï~~~~n~~~...,..,,~~~\t.!.,-w.'-,~~~"',~~~I(,~~~~~.i1~~~~~¡WI.;')))~, J~:~ Mud Wt In 12.65 ppg Visc 64 secs API filt 5.2 ml HTHP 12.0 ml Mud Wt at Max Gas 127 P .~ Mud Wt Out 12.65 ppg PV 28 cP YI 36 Ibs/1 00ft2 Gel~ 11 / 37 I 44 Ibs/100ft2 pH 8.0 ~ o.;g % --- :' ",;:rø.~.JJ::;J"::':,::1JJI_::::rr:rnal m n Iffnrmr !lr:J.r:Jf~'":::I::I",l~",...~- r]{.J(=,~~'InnllT r !~_I~'" ,. . I 5 Type: STX.30CD Bit Size: 6118 Jets: 15 \ 15 \ 15 \ 0 \ 0 \ 0 TFA: 0.5180 - - - - - - 0 RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 Trip Depth: 12976 ft Trip Gas: 75 Mud Cut: -ppg TripCI: 42500 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: -ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 40 % Shale 20 % Sltst 40 % Sst '% %LCM I after ft ft ft units -ppg units - ppg units -ppg I I ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Drilling Breaks before Drill Rate during after before Gas during % Lithology Sst Sltst Sh Depth to to to to -- -- -- -- ---- i , 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ô\ I .' .. , . ~.I.;....I,'.,..... 24 hr Recé Continue washing down last stand of line to bottom,Cement 7" liner according to well plan. No ;. problems, Tested BOP, passed. Pick up new BHA and RIH <~:) '\~ ~~~ Doug Wilson will be going in today and Reg Wilson will be coming out. ~ Logging Engineer: Doug Wilson/Mark lindloff ,.'" ~ . ~ ""-:" 'Q..~:~1;;¡':1r~'~~.' '~rt.Iil:! W1~:ImI.~'~J.'- , "'lIt.:o;~..;p'."'~~;n~~tU!mI~~~ 'lliIIJ'~.- '-m..tÄ_~.t_:w..~.' .,.,",. . '."'''!:~'.. - ,. . .. '.'",' ~ ,~~~;.'J,..~~'Y",;~~.~~~b.:c ~.:5.~,~~~~rt'~~j~~.4.':1~~\~. . ~'.' ' h~l!t~..~~~~~~,1fI1&-~~~~\~,;":'!'~".~~~;'~:f.';:~~~~.~~ ~~~.~.~.1:~' * 10000 units == 100% Gas In Air I ~1!4~.[~.i~~~~IIIlf_~~.I.Mm~IIJ ['" 1IJ11I~.Jh'] .. _J_~'_~.1fP1Ißnmlr~.c,=:u:~~"'~~;:~~ "I'~ Customer: BP Alaska Report No.: 23 ;, Well: NorthStar NS 07 Date: 5/8/02 '. sper-'r'V-5Un Area: North Slope Depth 13,193 :." 5Ãi L L I N G 5 E A V I c: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: 217 ~--'-"-'-'-----_____'h .-----'-- Rig: Nabors 33E Rig Activity: Drilling ~ M dl 'M' R Job No.: AK AM 22066 Report For: Polya / Clump ; u ogger s ornmg eport Shows: ~?~~:~:;"~Ì'\..:.,.,~';;:*;j.~~-~~~~1".,~~~~V_.:*'.t'AW~l4~".t.,1J.'Ä~;~~::aIl...altnUlll.._~:œíti~_.t~,- , ':'. :~;: Current 24 hr Avg 24 hr Max Pump and Flow Data '?i: R.O.P. 79 ftJhr 50 ftJhr ( 218 ftJhr @ 12988) Pump 1 94 spm DH flow - gpm i Gas' 41 units 54 unit~ ( 226 units @ 13007) Pump 2 0 spm Total flow ~ gpm ~ Temp Out 85 Deg F ( deg F @ ) Pump 3 spm AV @ DP 101 fpm. ~ Pump Pres 2040 psi A V @ DC 109 fpm :~'~~~;J¡:.~,r:n:1:rl;Jt~:wl""('t"'!'.J~a-~U1"]rJ~.m;O:U -U\n\.m'("n;\1R::r'-'LOC::'iUJl(»tI~'lN:lU" ro~ j~~'" ,,,,,.,',, '" ,,"'. '", ... ~., _. ".- ~_.,~ . ,,,,J. .' '." '..... ~.' ..,.-" ,,"..'.. .~ ,-, .'. , ,,",,' '" . ,~ Mud Wt In 9.20 ppg Visc 45 secs API filt ~ml HTHP _1°1..ml Mud Wt at Max Gas ~ppg ~ Mud Wt Out 9.20 ppg PV 8 cP YI 26 Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH 8.6 Sd 0 % .. .C;;¡;;:il::~"II.r.U:;n:I~~][[mløJJIUIl [In.ØR~]m,~.lffm_n~:~f:_:;~_.. ~'rt'Äl1Dt,~~ I , I Bit No.: : ! Wt On Bit: 5 35 Type: RPM: STX-30CD 80 Bit Size: 6 1/8 Hrs. On Bit: 9.4 Jets: 15 \ 15 \ 15 \ 0 \ 0 \ 0 TFA: 0.5180 ------ Total Revs on Bit: 87 Footage for Bit Run 217 to to Mud Cut: - ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: I Current Lithology: 30 % Sst 20 % Sltst 50 % Cong % %LCM ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft ft ft units - ppg units -ppg units -ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to -- -- ---- -- -- ---- !- I_..--.l~ 1m III }r.~f..:':- I ' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ." ',~I!'t;..:. "..... 1,._., ,",," oz. ; 24 hr Recé Continue to run in hole, tested casing, Drill float equipment and cement. Run L.O.T to 12.7. Drill ahead, ~c~: Well projected TD has changed to estimated depth of 11298' TVD, 13525' MD I~'IT Top of Shublik @ 13046' MD, 10872' TVD I Top of Ivishak @ 13133' MD, 10950' TVD ;¡(~ ~~ Logging Engineer: Reg Wilson/Mark lindloff :~x~.:, "..; .~~ .' i ','r,:_;',~\':':. '.':~'::¡"''',;: :;',. ," :"(\'::W':. ,"", '\l;~;..~'~,: ~:~".:.",: '.~'>,'~~:': '~I:, ;"~~. ' ':~ ' ,,:,:"', '::-, :\,:::~": -~1:Tt",')\ :"'\t':\' :., '." . .. 10000 units = 100% Gas In Air .i ...(:~ .;;~4~_" JJD~lmf ~ - . .ll~~_1Inm 1]11~'UI~Ulmn:.~11'''~~~~:;'*'f.,^'' I} Customer: BP Alaska Report No.: 24 it Well: NorthStar NS 07 Date: 5/9/02 ;; sper'''''\I-sun Area: North Slope Depth 13,529 ~~ L:J F!.I LL I N G 5 e R v I c: e 5 Lease: NorthStar NS 07 Footage last 24 hrs: 336 ;ij Rig: Nabors 33E Rig Activity: POOH ~t Job No.: AK AM 22066 Report For: Polya / Clump Ì(~ Mudlogger's Morning Report Shows:. .\l.~*~,,:¡.t:";,~'JØ'M_~~~~'tIa;;;;:';:&ìU~J:f~A;'_..Q~.ß,~'Ø!'~~~'~t.~,~"-~¡-æ~m~i!I' ' . J' .~ Current 24 hr Avg 24 hr Max Pump and Flow Data ~~t R.O.P, 0 ft/hr 64 ft/hr ( 133 ft/hr @ 13220) Pump 1 96 spm DH flow - gpm 'ji Gas" 0 units 47 unit~ ( 106 units @ 13007) Pump 2 0 spm Total flow ~ gpm .~~ Temp Out 85 Deg F ( deg F @ ) Pump 3 spm AV @ DP 138 fpm .,,;: - ;~: Pump Pres 2100 psi AV @ DC ~ fpm ~~'~.:rm.r~tL..,t:D';":i.Ji(f.1I.1J.:tr.~.ua_JlinØllllii" :Qf ;ijJ'"41BII.DU,_i''' .~~)llm::JWn:"l';J.":1" U~'i.,,~ø;,J,"^". rM~~~tln 0" ~30 ;pg .. v~~ ~.: see: API fill :6~ :1 :~HP _:~ml Mud ~t at ~ax ~as . ~3 .ppg ~~: Mud Wt Out 9.30 ppg PV 8 cP YI 27 Ibs/1 00ft2 GeIE~ I ~ I ~ Ibs/1 00ft2 pH ~ Sd ~ % ~:;~ - - , =mL1:Z:!¡¡~::1.'r::'mhl,~(¡(.1i]ìI filii] I r Itn n:~mrm:-mv::I~:::,JJI;::.:J:~:;::X.,C¡lJ:.:::n:[:t«I- ~_,E~."'ll!I~~~ I I {~ , . Bit No.: Wt On Bit: 5 35 Type: RPM: STX-30CD 80 Bit Size: 6 1/8 Hrs. On Bit: 16.6 Jets: 15 \ 15 \ 15 \ 0 \ 0 \ 0 TFA: 0.5180 ------ Total Revs on Bit: 160 Footage for Bit Run 553 Trip Depth: ft Trip Gas: Mud Cut: Short Trip Depth 13529 ft Short Trip Gas: 8 Mud Cut: Tight Spots: to to to [ Current Lithology: 20 % Sst 50 % Sltst 30 % Cong ppg Trip CI: ppm ppg Short Trip CI: 19000 ppm Feet of Fill on Bottom: ft % %LCM ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft units - ppg ft units - ppg ft units - ppg ft ft ft units -ppg units -ppg units - ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Sh Depth to to to to ---- ---- -- -- -- -- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. . ' .¡,: ~)."" '" ~~~.. ,.....,..-. . ~ . . iI,.,'.:. ....:,. 24 hr ReCé Drill to TO 100' MD below 11222' TVD, 13,529' MD, 11321' TVD, pump sweep, Short trip to shoe, :1 CBU. Well Static, Continue to POOH to 9211' MD. Performed derrick inspection, Continue to POOH. ¡"~:~ , Top of the Kavik 13472' MD, 11266' TVD !,~{ ';~ Logging Engineer: Reg Wilson/Mark Lindloff j~[.. &.li~~i\tiii\.Ct1£r~~ .OOD..II.~~.M;Y¡~~oäM\¡ '."~":'.' . ^. ' .. ,~,,~~,' '.. ,I. I. ., "' ," ...,_~l * 10000 units = 100% Gas In Air ~~, \ !> ~.'...','.' '..:',.'.t. <::':,' ;:}~'..'~'\..:/\;:I;~,~I:J.¡~~),.\..,'.. ,..~~I ,.\',.. :11.,'.' ~\r I - ~ i Customer: BP Alaska Report No.: Well: NorthStar NS 07 Date: spe,..,...,v-sun Area: North Slope Depth \;:~ ~.~ I L...L..I N c¡ 5 E A V I c: E 5 Lease: NorthStar NS 07 Footage Last 24 hrs: ! Rig: Nabors 33E Rig Activity: ~ Job No.: AK AM 22066 Report For: :~: Mudlogger's Morning Report Shows: <:'~ ¡iÞ~~\,~~*~..$;i~~~~~"~"\\~---~~~~~"'~fNi~(:U!~:~\~$$'¡'~'~~'U\~;_l~~~~~';~'r':,~. . W ' ',I,',~ Current 24 hr Avg 24 hr Max Pump and Flow Data ~ A.O.P. 0 ftfhr 0 ftfhr ( 0 ftfhr @ 0 ) Pump 1 0 spm DH flow gpm i1,",. Gas. 0 units 0 unit~ ( 0 units@O)Pump2 0 spm Total flow -L gpm ~ Temp Out # Deg F ( deg F @ ) Pump 3 spm AV @ DP 0 fpm ~ Pump Pres -L psi AV @ DC 0 fpm \ ":'1f:r.' \r~L;:i:'J'I:::~ÄJ\~'IO'¡¡¡iI1 mil 111111 III j~ L ~[~ I I U.;:;_::L1T....~~=rs.U:1*r.r::t'=U8;;¡lt;~':fI1:::ttlÄL~G:Jlr;~~~ I i Mud Wt In 9.30 ppg Visc 43 secs API filt 4.6 ml HTHP 10.8 ml Mud Wt at Max Gas 9.3 ppg ~~Mud Wt Out 9.30 ppg PV ~ YI 25 Ibs/100ft~el~ 12 / 13/16 Ibs/100ft2 pH 8.3 ~ 0 % ~~~ - - --- - - , ~-: -BitSi~:~I.omlll- J~;::." :11;.-=.,' ~Wt On BII: ° RPM: ° Hrs, On Bit: 0,0 Total Revs on Bit: -0 - Footage for Bit Run ° I I 25 5/10/02 13,529 0 E-Logs Polya / Clump ft ft ft f ì r Trip Depth: ft Trip Gas: Mud Cut: -ppg TripCI: ppm Short Trip Depth 0 ft Short Trip Gas: 8 Mud Cut: -ppg Short Trip CI: 0 ppm Tight Spots: to to to Feet of Fill on Bottom: ft I Current Lithology: 20 % Sst 50 % Sltst 30 % Cong % %LCM ft ft ft Connection Gas and Mud Cut ft units ft units ft units ppg ppg ppg units units units ppg ppg ppg Drilling Breaks Depth Drill Rate during Gas during after after before before to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 'll,. . . :.:1=,\..24 hr Recé ¡,;! ~, ;,~,,!,~,;,.,.,~1,',i.:,' I' .: '! ,.::íi :!t! Logging Engineer: Reg Wilson/Mark Lindloff Run E-Iogs units -ppg units -ppg units -ppg % Lithology Sst Sltst Sh -- -- -- -- ---- ---- oz. '" 1 0000 units = 1 00% Gas In Air '" ;~Jl ~)ßWlLI.~]jn "ftl~~_.:r,lU- y:Ult« --1I1.IßIIJlU~I.!JIIIi~U_I~iii1iIt~m~ I:~:.~~œc~~~.' . Customer: BP Alaska Report No.: 26 Well: NorthStar NS 07 Date: 5/11/02 Area: North Slope Depth 13,529 Lease: NorthStar NS 07 Footage Last 24 hrs: 0 Rig: Nabors 33E Rig Activity: TIH W/Liner ; M dl . M . R Job No.: AK AM 22066 Report For: Polya / Clump ..:.t: u ogger s ornmg eport Shows: ", ~;.m',.(Jf~.(.1ì~~~~m:J:Lru_~~tC:_.M:n\JHUtt JI [[IU J:.rì:::..._:mu.-~;;:,..I ~i_U I 1I1r.!W.~~~~%'(:à'1:' Current 24 hr Avg 24 hr Max Pump and Flow Data , 1 R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 73 spm DH flow gpm , . Gas. 9 units 42 unit~ ( 42 units @ 12976) Pump 2 0 spm Total flow ~ gpm 1 . ; Temp Out 70 Deg F ( deg F @ ) Pump 3 spm AV @ DP -2QL. fpm , ~~:¡¡;~:!1!I....IIIJ" .ø,~--~- 1)1.11..-_---- pumpp~~~- 835 psi A~~~- , I Mud WI In 9-30 ppg Vise ~ sees API filt ~ ml HTHP _1 OJ!. ml Mud WI at Max Gas ~ppg ~ : ,', Mud Wt Out 9.30 ppg PV ~ cP YI~ Ibs/1 00ft2 Gel~~ / ~ / ~ Ibs/1 00ft2 pH ~ Sd ~ % .~ , , " JiT:J,BrJJ1 r r lII"./m:r::IJat1I11I1I1ft':"JIII ¡ J II i 1111 j [ l mlJß r fIj L II J Á nuu::nU.!:.:IlJlIr~, . spe...,....,v-sun [J A I L.L. I N G 5 E A V I c: E 5 I I I ft units ft units ft units ppg ppg ppg Connection Gas and Mud Cut ft un~s ppg ft units ppg ft un~s ppg ft ft ft units -ppg units -ppg units - ppg I Bit No.: Wt On Bit: 0 34 Type: RPM: 0 0 Bit Size: 0 Hrs. On Bit: 0.0 Jets: 0 \ 0 \ 0 \ 0 \ 0 \ 0 TF A: Q.OOOO ------ Total Revs on Bit: 0 Footage for Bit Run 0 I Trip Depth: 12976 ft Trip Gas: 42 Mud Cut: -ppg TripCI: 19000 ppm Short Trip Depth 0 ft Short Trip Gas: 8 Mud Cut: -ppg Short Trip CI: 0 ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 20 % Sst 50 % Sltst 30 % Cong % %LCM - Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst' Sh Depth to to to to ---- ---- -- -- -- -- 1~~ . ~ ,I , ..-. L,..-. .... , , 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~:i!:~24 hr ReCé F'inished 'running RFT Liner. Picked up 4.5" liner and inner string. RIH on Drill Pipe. CBU at shoe then Finished TIH with liner. Currently Circulating Bottoms Up prior to cementing. ,..'il ~ Logging Engineer: Reg Wilson/Mark Lindloff ,. 10000 units = 100% Gas In Air 1'.11' '" ~', ~,. '~"11",- I ..~¡ ,~ :!~~)¡!Í,i'~~"~~!:ill~I&.Ui81eI:ll.lil.R_1If If 1tAØ;'JI.1 j.... l.t. ,- li~'~ ~ Current ..,¡ ~I' R.O.P. 0 ftIhr :: ' Gas~ units '.' Temp Out 70 Deg F ~"'l.-U III . --.. -&11 -- _8 - _1_, 4~ Mud Wt In 8.65 ppg Visc 28 secs API filt ¡»,:; Mud Wt Out 8.65 ppg PV 28 cP YI 26 Ibs/100ft2 ~In:mI: .. um ~ __._IU[U. R J ~ L -- ~~~~¥i~l-:\~ Report No.: 27 Date: 5/12/02 Depth 13,529 Footage Last 24 hrs: 0 Rig Activity: POOH Report For: Polya / Clump Shows: _11~" ..~¡. . Customer: Well: Area: Lease: Rig: Job No.: -. BP Alaska NorthStar NS 07 North Slope NorthStar NS 07 Nabors 33E AK AM 22066 spe""'''''V-5un C A I L..L I N G 5 E R V I c: E 5 Mudlogger's Morning Report lIImIWll~U.alJliIIl f 24 hr Avg 0 ftIhr ( unit~ ( ( 24 hr Max 0 ftIhr @ units @ deg F @ ) Pump 1 ) Pump 2 ) Pump 3 Pump Pres J milium. u[ u.t...C..:.U.JJIII .. I 1 0 Pump and Flow Data spm DH flow gpm ! spm Total flow gpm : spm AV @ DP fpm psi AV @ DC fpm r !I!~...lwr jrJøUlt.:'tCl.OOf.t~.:':_:~1I Bit No.: 0 Type: 0 Bit Size: 0 Jets: 0 \ 0 \ 0 \ 0 \ 0 \ 0 TFA: 0.0000 I - - - - - - Wt On Bit: 0 RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 [ Trip Depth: 0 ft Trip Gas: 0 Mud Cut: -ppg TripCI: 0 ppm Short Trip Depth 0 ft Short Trip Gas: 8 Mud Cut: -ppg Short Trip CI: 0 ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 20 % Sst 50 % Sltst 30 % Cong % %LCM 0.0 ml HTHP - 0.:2,. ml Mud Wt at Max Gas ~ ppg Gel~~ / ~/ ~lbs/100ft2 pH 0.0 Sd ~ % I Connection Gas and Mud Cut ft units ppg ft units -ppg ft units -ppg ft units ppg ft units -ppg ft units -ppg I ft units ppg ft units ppg ft units -ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh to - - - - to - - - - to - - - - to - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ..."v..-,.......--.........,,'I'I<.1O>-'"'' 24 hr Rece Cement Liner, And displaced hole with seawater. Currently POOH ~. ,.. e' I. . ).: Logging Engineer: Reg Wilson/Mark lindloff * 10000 units = 100% Gas In Air ..Ili~UJ 1 Customer: Well: Area: Lease: Rig: Job No.: DIU..I! '.Ilmm "(1mI" 11- ll~m.lmn. .]llijllll .. m 111J~~~k: ;~~: .- Report No.: 28 Date: 5/13/02 Depth 13,529 Footage Last 24 hrs: 0 Rig Activity: RIH W/P Tubing Report For: Polya / Clump Shows: ~)~_UI II i ;,J:~;;~:~~~ ,:¡:: Mudlogger's Morning Report I ,~.' ~~¡- :;i~~_'lbdl1 :~~ ;~.~ Current I'.,lî R.O.P. 0 ;1 Gas. ., ". Temp Out 70 " ~ " I ~. Mud Wt In I Mud Wt Out "it" 1 , ' '''''¡(In:.r ~. ;þ.. Bit No.: .~., Wt On Bit: Trip Depth: Short Trip Depth Tight Spots: I Current Lithology: I ft ft ft Depth to to to to Iff W. BP Alaska NorthStar NS 07 North Slope NorthStar NS 07 Nabors 33E AK AM 22066 ~.- .-.. "lIIUOOul1T mll ~"~-,..uu 1111 I,L J U 1m lfUIUTn L II! r "Œ I!I&~}~'" ' 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 0 ft/hr ( 0 ft/h r @ 0 ) Pump 1 spm DH flow gpm - units unit~ ( units @ ) Pump 2 spm Total flow gpm Deg F ( deg F @ ) Pump 3 spm A V @ DP fpm Pump Pres psi A V @ DC fpm 8.60 ppg Visc 0 secs API filt 0.0 ml HTHP 0.0 ml Mud Wt at Max Gas ~ ppg 8.60 ppg PV 0 cP YI 0 Ibs/100ft2 Gels 0 / 0 / 0 Ibs/100ft2 pH 0.0 Sd 0 % --- j~ m 111m! un If I. IUI mIUl~~1 I.U:l1: Jets: 0 \ 0 \ 0 \ 0 \ 0 \ 0 TFA: 0.0000 ------ Total Revs on Bit: 0 Footage for Bit Run 0 0 0 Type: RPM: 0 0 Bit Size: 0 Hrs. On Bit: 0.0 0 0 to 0 8 0 0 ft Trip Gas: ft Short Trip Gas: Mud Cut: - ppg Trip CI: Mud Cut: - ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft to 20 % Sltst Cong % %LCM 50 % 30 % Sst units units units Connection Gas and Mud Cut ft units ppg ft un~s ppg ft units ppg units -ppg units ppg units ppg ft ft ft ppg ppg ppg Drilling Breaks before Drill Rate during after % Lithology Sst Sltst Sh Gas during after before ---- ---- ---- ---- '~~;i\!J!lt[li:\',~~;-~:"~,, .' ~. f 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ;i:,; 24 hr Recí ~\1s;' ! I ",i'-' l~: .'~1:; Logging Engineer: Reg Wilson/Mark Lindloff ~:'~j~~,.' Test casing, passed, Rig to run 4.511 tubing, Currently running 4.511 chrome tubing. * 10000 units = 100% Gas In Air I Schlumberger Job # 40007418 Customer BP ADW Well NS-07 Field Northstar Rig Nabors 33E AFE # 831309 DD's Rinke Co. Men Polya/Dinger I ; PDM Run # 1 . PDM Ser# 962-1126 PDM Size 9 9/16 Mud Type Spud I Ite:HT F ~crJp/lpt! 8it #1 MX-C1 TFA 1.031 Huqhes 2 9 5/8 Std PDM 1.83° *float* Ana Orienting Sub I I R/S 5/6 Stages 3.0 Rev/Gal 0.100 Mud Wt 9 Mud Vis 182 Vendor Ana MONEL STA8 Ana MONEL LC Ana MONEL LC Ana MONEL ST A8 Ana X-OVER Ana SIN T69DF 962-1126 GLDD-105 800-011-S8 810-011-LC 810-013-LC 800-010-SS ANA614 Date In 18-Apr-02 Time In 3:00 Depth In 201 TVD In 201 Drlg Hrs 1.0 Slide Hrs 0.0 Rot Hrs 1.0 Pump Hrs 3.0 PDM Jet Blk Bearing Mud Rubber RM100D Sand % Solids % 4 ;"C)Q, 16 9 9/16 8 8 8 8 1 /16 8 7x8 ID 1x12,3x20 Tool 2 3/4 2 7/8 2 13/16 2 13/16 2 7/8 2 7/8 BHA# 1 Date Out 18-Apr-02 Time Out 18:00 Depth Out 330 TVD Out 330 Drlg Ft 129 Slide Ft 0 Rot Ft 129 Rotate % 100 Inclln 0.00 Az In 0.00 Incl Out 2.27 Az Out 234.50 Avg Dls 2.0 Max Ds 2.0 RPM 40 GPM 55 DIg TQ 3.0 WOB 15 .-,StBbOD, F.N. ' C()IJn~tiØ!l$ 15 7/8 16 16 BHA Weight Dry Wt 10,718 Buoyed Wt 9,249 Inel Angle Buoy+lncl Wt 9,249 Hole Size 16 Hole Sect Surface Bha Type Steerable Hrs BRT 15.0 Avg ROP 129 Slide ROP 0 Rot ROP 129 Slide % 0 BibSrvy 35.0 T/F Carr Plan Dls SPP On 500 SPP Off 550 Length Cum Length 1.10 7 5/8 Reg P 1.35 1.35 7 5/8 Reg 8 6 5/8 H-90 8 26.06 27.41 65/8 H-90 P 65/8 H-90 8 1.46 28.87 65/8 H-90 P 65/8 H-90 8 5.54 34.41 65/8 H-90 P 6 5/8 H-90 8 9.69 44.10 65/8 H-90 P 6 5/8 H-90 8 9.96 54.06 6 5/8 H-90 P 6 5/8 H-90 B 5.63 59.69 6 5/8 H-90 P 4 1/2 IF B 3.09 62.78 I ¡ I \ 3 II : I 6 I ¡- i' ,I 8 I II I I II ~ . II I I I , 3HA and Run Objective Clean out conductor and .C3~ro 8H.~. ." I F3HA and Run Results II Nhy PoOH / Comments I m To AIM=X', Res=X', GR=X', D&I=35', PWD=X', Dens=X', Nuet=X' 2.40 2.40 1.20 Bit Data IADC # Footage 129 Hrs 1.0 k Revs 3 k Grade Comment Had trouble with wireline Hrs. Out 69.4 144.4 1.0 3.0 Tool Hrs.ln Motor 66.4 Jars 143.4 Bit # 1 I'... .. ~ ' Schlumberger Job # 40007418 I Customer BP ADW Well NS-07 Field Northstar Rig Nabors 33E AFE # 831309 DD's Tunnell/Robertson Co. Men Polya/Oinger PDM Run # 2 PDM Ser# 962-1126 PDM Size 9 9/16 Mud Type Spud I ' lIe:HT FDesJ;rJp.fkI!J Bit #1 MX-C1 TFA 1.031 2 9 5/8 Std PDM 1.830 *float* MONEL LC R/S 5/6 Stages 3.0 Rev/Gal 0.100 Mud Wt 9.1 Mud Vis 65 . .Vendor SIN.; HUÇJhes T69DF Ana 962-1126 I, 3 Ana 810-011-LC MONEL LC 4 Ana 810-013-LC MONELSTA8 Ana 800-011-S8 MWD Ana 079 Orienting Sub Ana GLOO-105 MONEL ST A8 Ana 800-007 -S8 MONEL DC Ana 831-009DC MONEL DC Anå 831-002DC MONEL ST AS Ana 800-010-58 MONEL DC Ana 831-001 DC HYDJARS DAILEY 1417-1009 26 Jts. HWDP 5" NAD 26 HWDP DP 5" to Surface NAD DP Date In 18-Apr-02 Time In 18:30 Depth In 320 TVD In 320 Drlg Hrs 24.8 Slide Hrs 13.2 Rot Hrs 11.7 Pump Hrs 35.0 PDM Jet Blk Bearing Mud Rubber RM100D Sand % 2 Solids % 4.5 00: 16 9 9/16 8 8 1/16 8 8 1/4 8 8 7 13/16 7 13/16 8 7 3/4 7 13/16 5 5 ID 1x12,3x20 Tool 2 13/16 2 13/1 6 2 7/8 3 1/4 2 3/4 2 7/8 2 13/16 2 13/16 2 7/8 2 13/16 3 3 4 8/29 BHA# 2 Date Out 20-Apr-02 Time Out 16:00 Depth Out 3774 TVD Out 3368 Drlg Ft 3454 Slide Ft 1749 Rot Ft 1705 Rotate % 49 Inclln 2.27 Az In 234.50 Incl Out 34.42 Az Out 232.03 Avg Dls 2.6 Max Ds 4.0 RPM 40 GPM 850 DIg TQ 10.0 WOB 40 Ståb::OD: F.N~ Connections 15 7/8 16 16 16 BHA Weight Dry Wt 71,066 Buoyed Wt 61,215 Incl Angle 34 Buoy+lncl Wt 50,749 Hole Size 16 Hole Sect Surface Bha Type Steerable Hrs BRT 45.5 Avg ROP 139 Slide ROP 133 Rot ROP 146 Slide % 51 Bif>Srvy 67.0 T/F Corr 140.0 Plan Dls 2.5 SPP On 1700 SPP Off 1850 Length. (;um Length 1.10 7 5/8 Reg P 1.35 1.35 7 5/8 Reg B 6 5/8 H-90 B 26.06 27.41 6 5/8 H-90 P 65/8 H-90 B 9.69 37.10 6 5/8 H-90 P 6 5/8 H-90 B 9.96 47.06 65/8 H-90 P 6 5/8 H-90 B 5.54 52.60 6 5/8 H90 P 6 5/8 H90 B 28.42 81.02 65/8 H-90 P 6 5/8 H-90 B 1.46 82.48 65/8 H-90 P 65/8 H-90 B 5.62 88.10 6 5/8 H-90 P 6 5/8 H-90 B 30.83 118.93 6 5/8 H.90 P 6 5/8 H-90 B 30.69 149.62 65/8 H-90 P 65/8 H-90 B 5.63 155.25 6 5/8 H-90 P 6 5/8 H-90 B 31.55 186.80 6 5/8 H90 P 4 1/2 IF B 31.55 218.35 4 1/2 IF P 4 1/2 IF B 786.89 1005.24 4 1/2 IF P 4 1/2 IF B 1005.24 \' 5 II : II B I 9 I . 10 I 11 I ..-. Ú~ I 13 .\ 14 II 15 ,I I 'I I BHA. and Run Objective Bu ild an~le to 33,75,. .~~!II!~ 13 3!~.._- Icasing point . BHA and Run Results I ~~~Y~~ble buildi~g an~I~_~.ot as much 11s 60' below line, but caught up by TO (hY POOH I Comments I Reach TO, run 13 3/8 casing, 19ft To AIM=X', Res=X', GR=65', 0&1=367', PWD=X', Oens=X', Nuet=X' 2.40 2.29 2.39 2.40 1.68 Bit Data IADC # Footage 3454 Hrs 24.8 k Revs 155 k Grade 4-3-FC-A-E-1-RG-PTD Comment Do not run bit more than 2 surface holes Tool Hrs. 'In Motor 66.4 Jars 143.4 Bit #1 1.0 Hrs. Out 101.4 168.2 25.8 35.0 Schlumberger , Job # 40007418 Customer BP ADW Well NS-07 Fie/d Northstar Rig Nabors 33E AFE # 831309 DD's Tunnell/Robertson Co. Men Polya/Dinger PDM Run # PDM Ser# PDM Size Mud Type Spud BHT F Item Descripiiqn ~ 8it #2 RS238HFGNF TFA=.941 HycaloQ PO 8ias Unit I R/S Stages Rev/Gal Mud Wt 9.3 Mud Vis 43 Vendor I 2 Ana PO Extention Sub Ana PO Control Collar Ana XO FLOAT SU8 Float Ana MONEL STA8 3 4 5 Ana COR Ana MWD Ana MONEL STA8 Crows Foot MONEL DC Ana Ana MONEL DC Ana MONEL STA8 Ana MONEL DC Corrosion Ring HYDJARS SIN' 202697 90097 90058 90031 GLDD117 800-002-S8 8044 196 800-013-S8 831-002DC 831-001 DC Ana. 831-009DC 800-017-S8 NAD DAILEY 1417-1009 26 Jts. HWDP 5" Dart Valve Sub BPX DP 5" to Surface NAD 26 HWDP CM7996 DP BHA# 3 Date In 22-Apr-02 Time In 6:00 Depth In 3774 TVD In 3368 Drlg Hrs 0.1 Slide Hrs 0.0 Rot Hrs 0.1 Pump Hrs 5.3 PDM Jet Bearing Rubber Sand % 0.5 Solids % 3.5 .00 Date Out 22-Apr-02 Time Out 22:00 Depth Out 3794 TVD Out 3374 Drlg Ft 20 Slide Ft 0 Rot Ft 20 Rotate % 100 Inclln 34.42 Az In 232.03 Incl Out Az Out A vg DIs Max Os RPM 80 GPM 850 DIg TQ 10.0 WOB 10 StabOD. F.N. ConnectlOl1$ Hole Size 12 1/4 Hole Sect Interm 1 Bha Type RSS Hrs BRT 16.0 A vg ROP 200 Slide ROP 0 Rot ROP 200 Slide % 0 Bit>Srvy 59.1 T/F Corr Plan Dls SPP On 1600 SPP Off 1600 . Length ,I; Cum un,iitlJ /D 12 1/4 3x11,6x12 9 5/16 Tool 9 1/4 Tool 9 3/16 Tool 8 2 13/16 8 2 7/8 12 1/16 2.40 15.13 8 5/16 3 1/4 6 II 7 I 8 I, 9 I . 10 ,I ; ~ I 13 I 14 I 15 II 16 'I 17 II I SHA and Run Objective BHA Weight I Dry Wt 67,623 BHA and Run Results Buoyed Wt 58,044 I ~A~~ ~ I Why POOH / Comments I . Buoy+/ncl Wt 48,121 MWO failure. I :1/t To IAIM=~" Res=28.8', GR=39.8', 0&1=59.12', PWO=30.55', Oens=X', Nuet=X' 8 1/4 3 1/4 8 2 7/8 12 1/4 7 13/16 2 13/1 6 7 3/4 2 13/1 6 8 2 7/8 12 7 13/1 6 2 13/16 7 13/1 6 3 5 3 6 3/4 3 1/8x4 1/2 5 4 8/29 1.64 2.32 1.53 2.45 2.40 1.68 6 5/8 Reg P 1.00 1.00 6 5/8 Reg 8 NC 70 8 3.19 4.19 NC 70 P 7 5/8 Reg P 1.31 5.50 75/8 Reg 8 6 5/8 Reg B 10.07 15.57 6 5/8 Reg P 6 5/8 H90 8 1.97 17.54 6 5/8 H-90 P 65/8 H-90 8 5.55 23.09 6 5/8 H90 P 6 5/8 FH 8 22.38 45.4 7 6 5/8 H 90 P 6 5/8 H90 8 27.66 73.13 65/8 H-90 P 65/8 H-90 B 5.44 78.57 6 5/8 H-90 P 6 5/8 H-90 8 30.69 109.26 6 5/8 H-90 P 65/8 H-90 8 31.55 140.81 6 5/8 H-90 P 6 5/8 H-90 8 5.49 146.30 6 5/8 H-90 P 65/8 H-90 8 30.83 177. 1 3 6 5/8 H90 P 4 1/2 IF 8 31.55 208.68 4 1/2 IF P 4 1/2 IF 8 786.89 995.57 4 1/2 IF P 4 1/2 IF 8 2.37 997.94 4 1/2 IF P 4 1/2 IF 8 997.94 B/fOafa Tool Hrs./n IADC # S423 Motor Footage 20 Jars 168.2 Hrs 0.1 Bit #2 k Revs k RSS Grade O-O-CT-A-X-I-NO-OTF Comment Junk from drilg out packed between blades 0.0 Hrs. Ouf 5.3 168.3 0.1 5.3 I Schlumberger Job # 40007418 'I"' Customer BP AOW Well NS-07 Field Northstar Rig Nabors 33E AFE # 831309 DD's Tunnell/Robertson Co. Men PolyalOinger I ¡ PDM Run # ì PDM Ser# ~ PDM Size I : Mud Type Seawater H2O I BHT F 154 Item Descr/ptlon , Bit #2 RS238HFGNF TFA=.941 HycaloÇJ PO Bias Unit I R/S Stages Rev/Gal Mud Wt 10.2 Mud Vis 51 Vendor Ana 3 PO Extention Sub Ana PO Control Collar Ana XO FLOAT SUB Float MONEL STAB Ana Ana COR Ana MWO Ana MONEL STAB Crows Foot MONEL DC Ana Ana MONEL DC Ana MONEL STAB Ana MONEL OC Corrosion Ring HYDJARS Ana DAILEY 1417-1009 831-009DC 26 Jts. HWDP 5" NAD Dart Valve Sub BPX DP 5" to Surface NAD SIN 202697 90097 90058 90031 GLDD117 800-002-SB 8044 074 800-013-58 831-002DC 831-001 DC 800-017-SB 26 HWDP CM7996 OP Date In 22-Apr-02 Time In 22:00 Depth In 3794 TVD In 3374 Drlg Hrs 62.5 Slide Hrs 0.0 Rot Hrs 62.5 Pump Hrs 88.5 PDM Jet Bearing Rubber Sand % .25 Solids % 8.6 :00"" 12 1/4 9 5/16 9 1/4 9 3/16 8 8 8 5/16 8 1/4 8 7 13/16 7 3/4 8 7 13/1 6 7 13/16 5 6 3/4 5 JD 3x11,6x12 Tool Tool Tool 2 13/16 2 7/8 3 1/4 3 1/4 2 7/8 2 13/16 2 13/16 2 7/8 2 13/16 3 3 3 1/8x4 1/2 4 8/29 BHA# Date Out 27-Apr-02 Time Out 0:00 Depth Out 11 048 TVD Out 9240 Drlg Ft 7254 Slide Ft 0 Rot Ft 7254 Rotate % 100 Inclln 34.42 Az In 232.03 InclOut 42.00 Az Out 287.67 Avg Dls 2.0 Max Ds 4.0 RPM 160 GPM 900 DI!¡ TQ 22.0 WOB 25 StabOD 'F.N~ Conn~t¡on$ 1.64 2.32 12 1/16 2.40 15.13 1.41 12 1/4 2.45 12 2.40 ( 2 I II : I 6 It 7 ( .,. '~ I', 9 I 10 'I 11 12 I 13 II 14 I 15 I 16 " 17 'I I~HA and Run Objective Drill to TO with one bit, make build and BHA Weight tturn and hit first target - ....- --- .----- --_._--_..- Dry Wt 67,605 I '3HA and Run Results Bit s.topped 500~- short,~~~I~. and turn Buoyed Wt 57,101 ¡hen well and target was hit Inc/ Angle 34 I Why POOH/Comments !.Bit quit Buoy+/nc/ Wt 47,339 11;t To AIM=X', Res=28.8', GR=39.8', 0&1=59.12', PWD=30.55', Oens=X', Nuet=X' 1.68 4 HoleSize 12 1/4 Hole Sect Interm 1 Bha Type RSS Hrs 8RT 122,0 A vg ROP 116 Slide ROP 0 Rot ROP 116 Slide % 0 8it>Srvy 59.1 T/F Corr Plan Dls 2.0 SPP On 3350 SPP Off 3350 Length, ,Cum Length 6 5/8 Reg P 1.00 1.00 65/8 Reg B NC 70 B 3.19 4.19 NC 70 P 7 5/8 Reg P 1.31 5.50 7 5/8 Reg B 6 5/8 Reg B 10.07 15.57 6 5/8 Reg P 6 5/8 H90 B 1.97 17.54 6 5/8 H-90 P 6 5/8 H"90 B 5.55 23.09 6 5/8 H90 P 6 5/8 FH B 22.38 45.47 6 5/8 FH P 6 5/8 H90 b 27.51 72.98 6 5/8 H-90 P 6 5/8 H-90 B 5.44 78.42 6 5/8 H-90 P 6 5/8 H-9Q B 30.69 109.11 6 5/8 H-90 P 6 5/8 H-90 B 31.55 140.66 6 5/8 H-90 P 6 5/8 H-9Q B 5.49 146.15 6 5/8 H-9Q P 6 5/8 H-9Q B 30.83 176.98 6 5/8 H90 P 4 1/2 IF B 31.55 208.53 4 1/2 IF P 4 1/2 IF B 786.89 995.42 4 1/2 IF P 4 1/2 IF B 2.37 997.79 4 1/2 IF P 4 1/2 IF B 997.79 Bit Data Tool Hrs. In IADC # 8423 Motor Footage 7254 Jars 168.3 Hrs 62.5 RRBit #1 0.1 k Revs 600 k RSS 5.3 Grade 8-4-WT-A-X-I-CR-PR Comment Bit cored and missing center blade. Hrs. Out 88.5 230.8 62.6 93.8 I Sehlußlberger BHA# 5 Job # 40007418 Customer BP ADW Well NS-07 Field Northstar Rig Nabors 33E AFE# 831309 DD's TunnelVRobertson Co. Men KiddlDinger I PDM Run # , PDM Ser# PDM Size I n~::P; ~::er : #3 DS141 HDF+GN: TFA=.946 Hycaloq NEAR 81T ST A8 Float MONEL LC Date In 28-Apr-02 Time In 2:00 Depth In 11048 TVD In 9241 Drlg Hrs 4.7 Slide Hrs 0.0 Rot Hrs 4.7 Pump Hrs 9.5 PDM Jet Bearing Rubber Sand % 0.2 Solids % 8.5 OD Date Out 29-Apr-02 Time Out 2:30 Depth Out 11440 TVD Out 9547 Drlg Ft 392 Slide Ft 0 Rot Ft 392 Rotate % 100 Inclln 42.00 Az /n 287.67 InclOut 37.06 Az Out 294.12 Avg Dls 1.0 Max Ds 1.0 RPM 120 GPM 850 DI9 TQ 24.0 WOB 20 Stab;OD '::/foN. Connection$ Hole Size 12 1/4 Hole Sect Interm 1 Bha Type Rotary Hrs BRT 24.5 Avg ROP 83 Slide ROP 0 Rot ROP 83 Slide % 0 BibSrvy 59.0 T/F Corr Plan Dls 0.0 SPP On 3350 SPP Off 3350 Length CurnLength I RlS Stages Rev/Gal Mud Wt 10.2 Mud Vis 49 Vendor .SIN ID I ' 200461 12 1/4 GLS 182 8x9 810-003-LC 8 800-002-S8 8 4x14,2x15 65/8 Reg P 1.00 1.00 6 5/8 Reg B 65/8 H-90 B 5.38 6.38 6 5/8 H-90 P 6 5/8 H-90 8 9.69 16.07 6 5/8 H-90 P 6 5/8 H-90 8 5.55 21.62 6 5/8 H90 P 6 5/8 FH 8 22.38 44.00 6 5/8 FH P 6 5/8 H90 b 27.54 71.54 6 5/8 H-90 P 6 5/8 H-90 8 5.44 76.98 6 5/8 H-90 P 6 5/8 H-90 8 30.69 107.67 6 5/8 H-90 P 6 5/8 H-90 8 31.55 139.22 6 5/8 H-90 P 6 5/8 H-90 8 5.49 144.71 6 5/8 H-90 P 6 5/8 H-90 8 30.83 175.54 6 5/8 H90 P 4 1/2 IF 8 31.55 207.09 4 1/2 IF P 4 1/2 IF B 786.89 993.98 4 1/2 IF P 4 1/2 IF 8 2.37 996.35 4 1/2 IF P 4 1/2 J F B 996.35 2 Ana 2 7/8 1.45 12 1/4 3 Ana 2 13/16 MONEL STA8 4 Ana 2 7/8 12 1/16 2.40 15.13 1.41 12 1/4 2.45 I 11- 7 II : I MONELSTA8 I 10 MONEL DC 11 C . R. Ana orrosloo 109 I HYDJARS 12 DAILEY 1417-1009 I 13 26 Jts. HWDP 5" II 14 I 15 I II 'I I 8HA and Run Objective BHA Weight I Dry Wt 63,945 I aHA and Run Results I Buoyed Wt 54,010 Incl Angle 34 I Why POOH / Comments I. Buoy+lncl Wt 44,777 I ~it To AIM=X', Res=28.8', GR=39.8', 0&1=59.12', PWD=30.55', Dens=X', Nuet=X' COR 5 Ana 8 5/16 3 1/4 8044 MWD 6 Ana 8 1/4 3 1/4 27531 MONEL STAB Ana 8 2 7/8 800-013-S8 MONEL DC Ana 7 13/16 2 13/16 831-002DC MONEL DC Ana 7 3/4 2 13/16 831-001 DC Ana 8 2 7/8 800-017-88 2.40 12 7 13/16 2 13/16 831-009DC 7 13/1 6 3 1.68 NAD 5 3 26 HWDP Dart Valve Sub BPX 6 3/4 3 1!8x4 1/2 CM7996 DP 5" to Surface NAD 5 4 8/29 DP Bft Data IADC # S423 Footage 392 Hrs 4.7 k Revs 34 k Grade O-O-CT-A-X-I-NO-TD Comment Bit can be rerun Hrs. Out 9.5 235.5 4.7 9.5 Tool Hrs. In Motor Jars 230.8 Bit #3 0.0 Schlumberger Job # 40007418 Date In 01-May-02 I Customer BP ADW Time In 7:00 Well NS-07 Depth In 11440 Field Northstar TVD In 9547 Rig Nabors 33E Drlg Hrs 2.7 AFE # 831309 Slide Hrs 0.0 OD's Tunnell/Robertson Rot Hrs 2.7 Co. Men KiddlDinger Pump Hrs 21.1 I .PDM Run # 3 R/S 4/5 PDM Jet Blk PDM Ser# 675-1231 Stages 7.0 Bearing Mud PDM Size 6 3/4 Rev/Gal 0.300 Rubber RM100D I Mud Type KCL-Polymer Mud Wt 12.7 Sand % .1 BHT F Mud Vis 20 Solids % 9 Item . Descrlptl~n Vendor SIN OD ID Bit #4 STR454 TFA=.518 HUQhes 7100842 6 1/2 4x13 2 97/8 PDC Reamer TFA=.497 HUQhes 0324134 9 7/8 2x18 I 3 6 3/4 XP 1.150 Float Ana 675-1231 6 3/4 Tool 4 CDR (PWD) Ana 7138 6 3/4 Tool 5 MWD Ana MDC-750 6 3/4 Tool 6 NM STABILIZER I '-f 7 Totco Ring Ana NMSZSS-FA 011 6 3/4 2 13/16 NM FLEX Ana MMFL-FA 021 6 3/4x 5 2 13/16 '8 NM FLEX I _. Ana MMFL-FA 016 6 3/4x 5 2 13/16 9 NM FLEX Ana MMFL-FA 014 611/16x5 2 13/16 X-OVER Ana STXOS-FE 1042 6 3/4 2 3/4 3 Jts HWDP Corrosion Ring HYDJARS NAD 5 3 (3) 5" HWDP DAILEY 6 1/2 2 3/4 1416-1574 23 Jts HWDP NAD 5 3 (23) 5" HWDP Dart Valve Sub BPX 6 3/4 3 1/8x4 1/2 CM7996 DP 5" to Surface NAD DP 5 4 8/29 BHA# 6 Date Out 02-May-02 Time Out 19:00 Depth Out 11551 TVD Out 9637 Drlg Ft 111 Slide Ft 0 Rot Ft 111 Rotate % 1 00 Inclln 37.06 Az In 294.12 Incl Out Az Out Avg Dls Max Os RPM 100 GPM 675 Dlr¡ TQ 18.0 WOB 8 :.StåliOD . '. F.N~ . . 'Connectlont; 8 1/2 Slick 20.83 II 10 II 11 12 I 13 'I 14 'I 15 I I [ I I BHA and Run Objective Drill 6 112 x 9 7/8 hole to TO BHA Weight I Dry Wt 20,512 I BHA and Run Results MWD failure .-----.. -- . Buoyed Wt 16,544 Incl Angle f Why POOH / Comments MWD failure Buoy+lncl Wt 16,544 I Bit To AIM=X', Res=xxxx', GR=xxxx', D&I=xxxxx', PWD=xxxxx', Dens=X', Nuet=X' 12.00 1.68 2.45 2.50 2.50 2.50 1.69 Hole Size 8 1/2 Hole Sect Interm 2 Bha Type Steerable Hrs BRT 36.0 Avg ROP 41 Slide ROP 0 Rot ROP 41 Slide % 0 BibSrvy T/F Carr Plan Dls SPP On 3700 SPP Off 3900 Lëngth.. ;'Cüm Length 3 1/2 Reg P 0.90 0.90 3 1/2 Reg B 4 1/2 Reg P 1.65 2.55 4 1/2 Reg B 4 1/2 XH B 26.83 29.38 4 1/2 XH P 5 1/2 FH B 22.05 51 .43 5 1/2 FH P 4 1/2 XH B 27.83 79.26 4 1/2 XH P 4 1/2 XH B 5.62 84.88 4 1/2 XH P 41/2XH B 31.02 115.90 4 1/2 XH P 4 1/2 XH B 31.01 146.91 4 1/2 XH P 41/2XH B 31.02 177.93. 4 1/2 XH P 4 1/2 IF B 1.98 179.91 41/2 IF P 4 1/2 IF B 91.53 271 .44 4 1/2 IF P 4 1/2 IF B 32.63 304.07 4 1/2 IF P 4 1/2 IF B 695.36 999.43 4 1/2 IF P 4 1 /2 IF B 2.37 1001.80 4 1/2 IF P 4 1/2 IF B 1001 .80 Tool Hrs. In Motor 0.0 Jars 87.8 Bit #4 0.0 Hrs. Out 21.1 90.5 2.7 21.1 Bit Data IADC # Footage 111 Hrs 2.7 k Revs 49 k Grade O-O-NO-A-X-I-NO-MWD Comment There were a few chipped teeth on reamer I I Schlumberger Job # 40007418 Customer BP ADW Well NS-07 Field Northstar Rig Nabors 33E AFE # 831309 DO's Tunnell/Robertson Co. Men KiddIDinger I PDM Run # 3 .. PDM Ser# 675-1231 PDM Size 6 3/4 Mud Type KCL Polymer I BHT F . Item Description Bit #4 STR454 TFA=.518 2 97/8 PDC Reamer TFA=.497 Huqhes 6 3/4 XP 1.15° Float CDR (PWD) I MWD NM STABILIZER T otco Ring NM FLEX NM FLEX NM FLEX X-OVER 3 Jts HWDP Corrosion Ring HYDJARS 23 Jts HWDP Dart Valve Sub DP 5" to Surface R/S 4/5 Stages 7.0 Rev/Gal 0.500 Mud Wt 12.8 Mud Vis 65 VendÒl' Date In 02-May-02 Time In 20:00 Depth In 11551 TVD In 9637 Drlg Hrs 31.5 Slide Hrs 8.3 Rot Hrs 23.2 Pump Hrs 49.7 PDM Jet Blk Bearing Mud Rubber RM1000 Sand % .25 Solids % 17.6 :'00':' . ID SIN Huqhes 6 1/2 4x13 7100842 0324134 9 7/8 2x18 Ana 6 3/4 Tool 675-1231 Ana 6 3/4 Tool 7138 Ana 6 3/4 Tool Y712 Ana IMSZSS-FA 01 6 3/4 2 13/16 Ana MMFL-FA 021 6 3/4x 5 2 13/16 Ana MMFL-FA 016 6 3/4x 5 2 13/16 Ana MMFL-FA 014 6 11/16x5 2 13/16 Ana )TXOS-FE 104: 6 3/4 2 3/4 NAD (3) 5" HWDP 5 3 DAILEY 1416-1574 6 1/2 2 3/4 NAD (23) 5" HWOP 5 3 BPX 6 3/4 3 1/8x4 1/2 CM7996 NAD OP 5 4 8/29 BHA# 7 Date Out 05-May-02 Time Out 23:00 Depth Out 12976 TVD Out 10807 Drlg Ft 1425 Slide Ft 163 Rot Ft 1262 Rotate % 89 Inclln 37.06 Az In 294.12 InclOut 28.41 Az Out 281.76 Avg Dls 1.2 Max Ds 3.2 RPM 100 GPM 650 Dig TQ 22.0 WOB 8 . "$tabOO' gN~ Connèctions 8 1/2 Hole Size 8 1/2 Hole Sect Interm 2 Bha Type Steerable Hrs BRT 75.0 Avg ROP 45 Slide ROP 20 Rot ROP 54 Slide % 11 Bit>Srvy 65.2 Tn: Carr 78.0 Plan Dls 0.5 SPP On 3750 SPP Off 3950 . Leït{:¡th .' Cum Length Slick 20.83 3 1/2 Reg P 0.90 0.90 3 1/2 Reg B 4 1/2 Reg P 1.65 2.55 4 1/2 Reg B 4 1/2 XH B 26.83 29.38 4 1/2 XH P 5 1/2 FH B 22.05 51 .43 5 1/2 FH P 4 1/2 XH B 27.86 79.29 4 1/2 XH P 4 1/2 XH B 5.62 84.91 4 1/2 XH P 4 1/2 XH B 31.02 115.93 4 1/2 XH P 4 1/2 XH B 31.01 146.94 4 1/2 XH P 4 1/2 XH B 31.02 177.96 4 1/2 XH P 4 1/2 IF B 1.98 179.94 4 1/2 IF P 4 1/2 IF B 91.53 271.47 4 1/2 IF P 4 1/2 IF B 32.63 304.1 0 4 1/2 IF P 4 1/2 IF B 695.36 999.46 41/21FP 4 1/2 IF B 2.37 1001.83 41/2 IF P 4 1 /2 IF B 1001.83 II : I, : If: I, 9 I 10 I 11 I 12 f 13 I 14 I 15 II I I II I 3HA and Run Objective Turn ~ell e~ou~~t~ ~it tar~et ._--, ... BHA Weight I ~~~:;~ Run Results Sliding w"s painfulbutac~mpli:"~u_- BUO~~ ~: ~~:: ~ : I ~~ æ I Nhy POOH / Comments I TD Buoy+/ncl Wt 14,582 I ~¡t To AIM=X', Res=34.83', GR=45.83', 0&1=65.18', PWD=36.58', Oens=X', Nuet=X' 12.00 1.68 2.45 2.50 2.50 2.50 1.69 Bit Data IADC # Footage 1425 Hrs 31.5 k Revs 753 k Grade 1-2-WT-A-X- -CT-PTD Comment Wear on reamer was less on cutters. Tool Hrs. In Motor 21.1 Jars 90.5 Bit #4 2.7 Hrs. Out 70.8 122.0 34.2 49.7 Schlumberger BHA# 8 Job # 40007418 Date In 07-May-02 Date Out 10-May-02 Hole Size 6 1/8 Customer BP ADW Time In 21:3Q Time Out 5:00 Hole Sect Production Well NS-07 Depth In 12976 Depth Out 13529 Bha Type Steerable Field Northstar TVD In 10807 TVD Out 11 31 8 Hrs BRT 55.5 Rig Nabors 33E Drlg Hrs 16.2 Drlg Ft 553 Avg ROP 34 AFE # 831309 Slide Hrs Slide Ft Slide ROP #DIV/O! I ~ DD's Tunnell Rot Hrs 16.2 Rot Ft 553 Rot ROP 34 Co. Men Kidd/Clump Pump Hrs 29.6 Rotate % 100 Slide % PDM Run # 4 RJS 7/8 PDM Jet 8 Inclln 28.41 Az In 281.76 BibSrvy 72.5 PDM Ser# 475-2757 Stages 2.0 Bearing 058 InclOut 17.25 Az Out 294.00 T/F Carr N/ A PDM Size 4 3/4 Rev/Gal 0.300 Rubber RM 1 000 A vg Dls Max Ds Plan D's Mud Type Dril-N Mud Wt 9.2 Sand % .25 RPM 80 GPM 340 SPP On 2000 BHT F Mud Vis 45 Solids % 5.4 DI9 TQ 16~0 WOB 25 SPP Off 1850 Item De$t:i;lpllq" .. ' Vè(Jìlor" SIN'>';. . 'Oþ~:'" " , 'ID'. .StâJ:fOD: :"cF.'N~." ,"; 'ConnecUöns .. têrigth :'CumLength Bit #5 STX-30CD TFA=.518 Hughes 5008528 6 1/8 3x15 3 112 Reg P 0.75 0.75 2 4 3/4 PDM SSS 0.0 3 1/2 Reg B Ana 475-2757 4 3/4 Tool 6 17.40 3 1/2 IF B 23.14 23.89 3 FLOAT SUB 3 1/2 IF P Float Ana ANA 1033 4 3/4 2 3 1/2 IF 8 2.00 25.89 4 NM IB Stab 3 1/2 IF P Ana 60060811 SZ 4 3/4 2 1/4 6 2.15 3 1/2 IF 8 4.87 30.76 5 4.75 ARC 3 1/2 IF P Ana 475-061 4 3/4 2 1/4 1.70 3 1/2 IF 8 23.90 54.66 6 SLIM PLUSE MWD 3 1/2 IF P Ana SPRM-4496 4 3/4 2 1/2 1.16 3 1/2 IF 8 33.40 88.06 7 4.75 ADN 3 1/2 IF P Ana ADN~ 125 4 13/16 TOOL 5 3/4 19.49 3 1/2 IF 8 26.50 114.56 8 NMDC 3 1/2 IF P I Ana 475-31-003DC 4 3/4 2 5/16 3 1/2 IF 8 31.01 145.57 9 NMDC 3 1/2 IF P Corrosion Ring Ana 475-31-002DC 4 3/4 2 1/4 3 1/2 IF B 30.91 176.48 [ 10 P8L Sub 3 1/2 IF P Daliev NOR475BP64 4 3/4 2 1/2x1 1/2 3 1/2 IF B 8.13 184.61 HYD JAR 3 1/2 IF P 11 DAILEY 1400-1061 4 3/4 2 1/4 1.82 3 1/2 IF B 29.62 214.23 I 12 XO 3 1/2 IF P NAD NR4000018 5 1/8 2 5/8 HT 40 8 2.54 216.77 I: 13 14 Jts HWDP HT40 P NAD 4" HWDP 4 211/16 HT 40 8 429.86 646.63 14 63 Jnts. DP 4" HT40 P NAD 63DP 4 4 3 5/16 HT40B 1976.72 2623.35 15 XO HT 40 P 1,1 BPX HT27872 6 1/4 2 1/2 4 1 /2 IF 8 2.47 2625.82 16 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF 8 2.37 2628.19 I 'I I 3HA and Run Objective D~iIl_t~ ~~,',_f11~~r set at 0 I BHA and Run Results I I. NhyPOOHICGmmenls ITD -.. --'''--'-''~.'..'.'- BHA Weight Dry Wt 10,980 Buoyed Wt 9,441 Incl Angle 28 Buoy+lncl Wt 8.336 Bit Data Tool IADC # Motor Footage 553 Jars Hrs 16.2 Bit #5 k Revs 177 k PBL Sub Grade 2-6-BT-0-E-IN-WT-TD Comment Hrs. In 26.8 35.1 0.0 26.8 Hrs. Out 56.4 51.3 16.2 56.4 j I ¡If To IAIM=X', Res=37.34', GR=75.48', 0&1=72.48', ~WO=X" Oens=94.43', Nuet=97.49' - - - - -- Customer: BP EXPLORATION ALASKA Casing Program 20 inch at # 200 ft sperry-sun Well: NS07 13 3/8" inch at 3757 ft Area: BEAUFORT SEA,ALASKA 9 5/8" inch at 11415 ft Lease: NORTHST AR 7'1. inch at 12973 ft DRilliNG SERVICES Rig: NABORS DRLG RIG 33E 4.5" inch at 12750 ft Mud Company: BAROID inch at ft Bit Record Job No.: AK-AM 22066 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out ftIhr % GRADE 1 1 MX-C1 T69DF 16 1.031 200 3774 3574 25.8 138 40 5K 51 4-3-FC-A-E-1-RG-PTD 2 2 RS238HFGNP 202697 12.25 0.941 3775 11 048 7273 62.5 116 160 600 0 8-4-WT -A-X-I-CR-PR 3 3 OS141 HDF+GNS 200461 12.25 0.946 11 049 11440 392 4.7 83 120 34K 0 O-O-CT -A-X-I-NO- TD 4 4 STR454 7100842 8.5 0.518 11440 12976 1536 34.2 45 100 802K 11 1-2-WT-A-X-I-CT-PTD 5 5 STX-30CO 5008528 6.125 0.518 12976 13529 553 16.2 34 80 177K 2-6-BT-0-E-IN-WT-TD - - Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS07 13.375" inch at 3757 ft AÆa: BEAUFORT SEA, ALASKA 9.625" inch at 11415 ft lease: NORTHST AR 7" inch at 12973 ft DRilliNG SERVICES Rig: NABORS DRilLING RIG 33E 4.5" inch at 12545 ft Mud Company: BAROID DRilLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22066 Depth MW Vis PV yp Gels Fltr HTHP - Cake 501 Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ib/gal sec LB/100 10S/10M mU30 ml@deg F 32's % % % % ITlgelhg ppm ppm U4I1li/U": U ~.1 144 ":1 56 1~/":5I34 1 IUS " 5.U U.U ~5.U U 1.U ~.U U.6U .1U/.~U 1tSUUU J"U "tt1ovmg rig U4/1 flU" U ~.1 16": "U Ii~ 3":/36/3tS ~.4 " t).U U.U ~5.U U 1.U ~.U U.IU . 15/.~U 16UUU JUU "klgglng Up U4116/U" 15U ~.U 1U3 "1 53 U 134/31 ~.B 3 3.1i U.U ~5.4 " 7.U 6.tS U.1U .U5/.55 1tSUUU 4öU Lmlllng 16" 04/1~/U" "~lit) ~.1 Iili 13 31i 1li/"1/":4 ~.4 " 4.5 U.U ~.5 " 4.U 6.5 U.1U .U5/.4O 16UUU 440 LJrllllng 11i" U4/"U/U": 3lf4 ~.1 5tS 16 33 1 fI"1/":3 tS.1i 3 4.U U.5 ~.5 .5 4.U 6.5 U.3U .U5/.4O 1tSUUU 4tiU "kun 13 J/6" U4/":11U" 3774 ~." 43 ~ 1": 5/9/ 1U.": 3 5.5 0.5 ~3.U .5 3.5 1.6 0.00 .UOI.6U 18000 4tiU I est ~U...t: U4/""'U" 37~4 6.1 53 1t) "4 4/B/~ Ii.U " U.~ U.U ~6.0 U U.U tS.3 U.1U .U5/.3U 16UUU 440 I rip tor MWU U4/"3/U" li51" 6.~ Ii" 1.t) "4 ~/11 5.3 ..: 3.U 1.U ~5.U .5 ":.U tS.5 U.1U .UU/.4U 1tSUUU 4öU ùrllllng U41"4/U" 6""1 ~.U lili "Ii ..:" ~/14 5." " 4.U 3.U ~".U ."5 5.5 6.5 U.U5 .U"'.5U 1tSUUU 4tiU ùrlllmg U4/"5/U" ~151 ~.1 li5 1f "4 tSl1 J/1 5 5.tS " 4.5 3.U ~1.5 .5 1i.5 tS.5 U.U4 .U:lI.45 1tSUUU 540 ùrllllng U4/"li/U" 'Uti1~ 1U." 51 1/ 31 , 1 1":lI"1i 3.1i ~.tS " 6.1i 3.5 67.U ."5 ~.5 tS.5 U.UU .U4I."U 16UUU liUU ùrllllng U4/U IU" 11U4ö 1U." 4~ 16 ..:~ , :lI"U/"3 4.6 11.U " 6.5 3.5 6/.U ." 1U.5 6.5 U.OO . U41. "U 1~UUU ti4U "\:sIt I rip U4/"6/U": 11440 1U." 44 11i ":4 13/"4/"1i 4.6 11.U 1 6.5 4.U 61i.5 ."5 1".5 6.5 U.UU .04/.15 1~5UU 6UU I.U. tor ~ 5/6" U4/"~/U" 11440 1U.3 4ti "U ":Ii 1 :lI"3/"1i 5." 11.5 1 ~.U 3.5 61i.5 ...: 1".5 tS.U U.UU .UU/.1U 1~5UU 640 "kun ~ 5/6" l;:S~ U4/3U/U" 11440 1U.": 4": 11i "..: ~/1 6/"": 5.6 1".U 1 6.~ 3.U 1S1.1 .1 1".0 IS." U.UU .UU/.1" 19UUU 640 I est tSu...t: U5/U1/U": 11440 1U.3 4" 15 ":1 1U/14/17 Ii.U 1":.U 1 ~.U ".5 6/.5 .1 1".U ~.U U.U4 .U5/."" 1~UUU 66U ùrlll out l;M I U5/U:l/U" 1155": 1":.6 55 "Ii ":U 111U12~ 5.5 '''.U " 1f.1i ".5 lli.5 .1 1.5 ~.5 U."U U.1:l11 .ISU t)"UUU li40 "kIH U5/U3/U" 1161V 12.1 IU 33 ,,~ 1:l145/4tS 3.6 ~.U ..: 1/.1 2.5 77.U .1 ~.U 6.1S U."U 0.Uli/1.6U 5UUUU 54U anon trip U5/U4/U": 1 U 1St) 12.6 '" 31i 33 17145/52 4." ~.5 ..: "U.5 3.0 71i.5 .":5 ~.5 1S.1 U.OO oo/".UU 4~UUU 12UU ùrllllng U51U5/U" 1"~71i 1":.1 li7 37 34 16/4f156 4.6 1U.U ..: 2U.U 3.0 . 11.U .1U 1.5 6.U U.OO U/1 . 1 U 43UUU 'U4O "kJu t:logs U5/Uö/U": '''~lti 1".7 63 ":6 31 '1/31S/44 5.": 1U.U ..: "U.U 3.0 7/.U .1U 7.U 6.U U.UU U/1 .1 U 4"UUU 1140 "kun,.. Liner U5/U7/U" 12~71i 1":.1 li5 3U 35 12/36144 5.": 1".U 2 2U.U 3.0 7/.U .1U I.U IS.U U.1U U/.Ul 4"500 116U "kIH U5/UtS/U" 1314f) ~.3 45 6 "Ii 1U/11111'" 4.U 'U." 1 1i.5 1.0 ~".5 ."5 U.U 1S.1i U.1U .U5/U.U4 "UUOU ti4U ùrllllng U5IU~/U" 1J5"~ ~.3 43 6 "I 1:l114/11 4.1i 1U.1S 1 I.U 1.0 ~".U ."5 U.5 ~.U U."U . 1U/.3U 1~UUU t)liU -"'UUH U5/1U/U" 1J52~ V.3 43 6 "5 1:l113/11i 4.1i 11.U 1 7.0 1.0 ~7.U ."5 U.5 tS.3 U.1U .U5/."5 1~UOU t)UU "wIre Lining U5/11/U" 'J52~ ~.3 4ö 6 "6 1111li/1~ 4.1i 1U.6 1 7.0 1.0 ~/.U U U.5 1.5 U.UU U/." 1~UUU 5tSU "kun Liner U5I1:l1U": 135"~ 8.7 26 U U U U.U U.U U 2.0 0.0 ~6.U U U.U U.U 0.00 U/U "UUUU t)6U -"'UUH U5/1J/U": 1J5":~ 8.6 U U U U U.U U.U 1 0.0 0.0 ~~.U U U.U U.U 0.00 U/U 1~UUU U "kun ...roa IUD - Final Survey NS07.TXT ANADRILL SCHLUMBERGER Survey report 9-May-2002 15: 12:57 Page 1 of 6 Client...................: BP Exploration (Alaska) Inc. Field....................: Northstar Wel!.....................: NS07 API number...............: 50-029-23081-00 Engineer.................: M. Leafstedt RIG:.....................: Nabors 33E STATE:...................: Alaska Spud date................: 18-APR-2002 Last survey date.........: 09-May-02 Total accepted surveys...: 149 MD of first survey.......: 0.00 ft MD of last survey........: 13529.00 ft ----- Survey calculation methods------------- ----- Geomagnetic data ---------------------- Method for positions.....: Minimum curvature Magnetic modeL.........: BGGM version 2001 Method for DLS...........: Mason & Taylor Magnetic date............: 21-Apr-2002 Magnetic field strength..: 1150.31 HCNT ----- Depth reference ----------------------- Magnetic dec (+E/W-).....: 26.48 degrees Permanent datum..........: MEAN SEA LEVEL Magnetic dip.............: 80.93 degrees Depth reference..........: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent.......: na OF above permanent.......: 40.36 tt ----- MWD survey Reference Criteria --------- Reference G..............: 1002.69 mGal Reference H..............: 1150.31 HCNT Reference Dip............: 80.93 degrees ----- Vertical section origin---------------- Tolerance of G...........: (+/-) 2.50 mGal Latitude (+N/S-).........: 0.00 tt Tolerance ofH...........: (+/-) 6.00 HCNT Departure (+E/W-)........: 0.00 ft Tolerance of Dip.........: (+/-) 0.45 degrees ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 tt Departure (+E/W-)........: -999.25 ft ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.48 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.48 degrees 256.13 degrees (Total azcorr = magnetic dec - grid conv) Sag applied (Y/N)........:Np degree: 0.00 Page 1 Azimuth from rotary table to target: - - - Final Survey NS07.TXT *** All MWO surveys O-Mag corrected*** [(c)2002 AnadrilllOEAL 106_1 C_1 0] ANAORILL SCHLUMBERGER Survey Report 9-May-2002 15:12:57 Page 2 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +EIW- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 50.00 0.68 211.29 50.00 50.00 0.21 -0.25 -0.15 0.30 211.29 1.36 GYR 3 100.00 0.89 220.79 50.00 99.99 0.74 -0.80 -0.56 0.98 215.05 0.49 GYR 4 150.00 2.38 239.61 50.00 149.97 2.05 -1.62 -1.71 2.36 226.56 3.13 GYR 5 173.00 2.69 239.51 23.00 172.95 3.02 -2.14 -2.59 3.36 230.47 1.35 GYR 6 230.00 2.67 230.14 57.00 229.89 5.50 -3.67 -4.76 6.01 232.40 0.77 GYR 7 291.00 2.27 234.51 61.00 290.83 7.90 -5.28 -6.83 8.63 232.32 0.72 GYR 8 362.00 2.14 233.37 71.00 361.78 1 0.43 -6.88 -9.04 11.37 232.72 0.19 GYR 9 453.00 2.21 235.82 91.00 452.71 13.64 -8.88 -11 .86 14.82 233.16 0.13 GYR 10 545.00 2.20 236.41 92.00 544.64 16.97 -10.86 -14.80 18.35 233.73 0.03 GYR 11 635.00 3.15 241.03 90.00 634.55 20.98 -13.01 -18.40 22.53 234.73 1.08 GYR 12 661 .00 3.54 240.15 26.00 660.50 22.44 -13.76 -19.72 24.04 235.10 1 .51 GYR 13 750.00 4.43 242.72 89.00 749.29 28.43 -16.70 -25.16 30.20 236.42 1.02 GYR 14 841 .00 5.37 241.18 91.00 839.95 35.96 -20.36 -32.01 37.94 237.54 1.04 GYR 15 934.00 7.32 238.12 93.00 932.38 45.80 -25.59 -40.86 48.21 237.94 2.13 GYR 16 1003.00 10.05 236.96 69.00 1000.58 55.67 -31.20 -49.64 58.63 237.85 3.96 GYR 17 1029.17 10.95 239.92 26.17 1026.31 60.21 -33.69 -53.70 63.39 237.90 4.01 MWO 18 1124.26 13.64 241.90 95.09 1119.21 79.76 -43.50 -71.41 83.62 238.66 2.86 MWO 19 1219.15 14.53 237.62 94.89 1211.25 101.89 -55.14 -91.34 106.69 238.88 1.44 MWO 20 1313.10 13.71 237.34 93.95 1302.36 123.61 -67.46 -110.66 129.60 238.63 0.88 MWO 21 1407.30 14.52 236.22 94.20 1393.72 145.28 -80.05 -129.88 152.56 238.35 0.91 MWD Page 2 - - - - o. ~--" ' Final Survey NS07.TXT 22 1502.34 16.43 228.40 95.04 1485.32 168.38 -95.60 -149.83 177.74 237.46 2.97 MWD 23 1597.43 18.37 225.88 95.09 1576.05 193.23 -114.96 -170.65 205.76 236.03 2.19 MWD 24 1692.26 21.25 226.67 94.83 1665.26 221.11 -137.16 -193.88 237.49 234.72 3.05 MWD 25 1786.34 23.09 232.15 94.08 1752.39 252.82 -160.19 -220.86 272.83 234.05 2.94 MWD 26 1881.08 25.93 235.59 94.74 1838.59 289.20 -183.30 -252.62 312.11 234.04 3.35 MWD 27 1975.74 29.21 234.16 94.66 1922.49 330.01 -208.52 -288.43 355.91 234.13 3.53 MWD 28 2069.35 31.93 234.25 93.61 2003.08 374.17 .-236.37 -327.04 403.52 234.14 2.91 MWD 29 2164.19 33.66 235.64 94.84 2082.81 422.07 -265.86 -369.10 454.88 234.24 1.99 MWD 30 2259.56 36.22 237.15 95.37 2160.98 473.48 -296.06 -414.60 509.45 234.47 2.83 MWD [(c)2002 AnadrilllDEAL ID6_1 C_10] ANADRILL SCHLUMBERGER Survey Report 9-May-2002 15:12:57 Page 3 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +EIW- displ Azim (deg/ tool qual (ft) (de g) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- 31 2353.79 37.79 237.19 94.23 2236.23 527.12 -326.81 -462.25 566.11 234.74 1.67 MWD 32 2448.60 38.23 238.44 94.81 2310.93 582.54 -357.90 -511.66 624.42 235.03 0.94 MWD 33 2543.09 38.00 236.89 94.49 2385.27 637.86 -389.10 -560.94 682.68 235.25 1.04 MWD 34 2638.73 38.59 237.34 95.64 2460.34 693.89 -421.27 -610.71 741.92 235.40 0.68 MWD 35 2733.52 39.34 236.17 94.79 2534.04 750.12 -453.96 -660.56 801.51 235.50 1.11 MWD 36 2829.83 38.34 232.09 96.31 2609.07 806.11 -489.31 -709.50 861.86 235.41 2.85 MWD 37 2924.64 36.99 230.48 94.81 2684.12 858.68 -525.53 -754.70 919.65 235.15 1.76 MWD 38 3022.64 36.83 229.23 98.00 2762.48 911.45 -563.47 -799.69 978.27 234.83 0.78 MWD 39 3117.92 37.97 230.24 95.28 2838.17 963.29 -600.87 -843.85 1035.92 234.55 1.36 MWD 40 3212.86 38.68 229.28 94.94 2912.65 1016.03 -638.90 -888.79 1094.60 234.29 0.98 MWD 41 3307.22 38.02 232.92 94.36 2986.66 1069.06. -67S~Ô7 -934.33 1153.04 234.13 2.49 MWD Page 3 - - ~ ~ Final Survey NS07. TXT 42 3402.77 36.38 230.14 95.55 3062.77 1121.58 -711.58 -979.56 1210.74 234.00 2.46 MWO 43 3496.66 34.52 232.03 93.89 3139.25 1170.90 -745.79 -1021.91 1265.11 233.88 2.30 MWO 44 3592.14 34.45 232.48 95.48 3217.96 1220.33 -778.89 -1064.66 1319.15 233.81 0.28 MWO 45 3687.90 34.27 231.34 95.76 3297.01 1269.62 -812.22 -1107.20 1373.17 233.74 0.70 MWO 46 3705.57 34.42 232.03 17.67 3311.60 1278.69 -818.40 -1115.02 1383.13 233.72 2.36 MWO 47 3876.13 34.89 231.95 170.56 3451.90 1367.20 -878.13-1191.43 1480.08 233.61 0.28 MWO 48 3971.52 35.11 230.22 95.39 3530.04 1416.76"-912.50-1234.00 1534.73 233.52 1.07 MWO 49 4067.49 35.77 230.98 95.97 3608.23 1466.98 -947.82 -1277.00 1590.31 233.42 0.83 MWD 50 4163.26 35.98 231.26 95.77 3685.83 1517.84 -983.04 -1320.69 1646.39 233.34 0.28 MWD 51 4257.98 35.94 230.29 94.72 3762.50 1568.10 -1018.21 -1363.78 1701.96 233.25 0.60 MWO 52 4353.35 35.48 230.91 95.37 3839.94 1618.33 -1053.55 -1406.79 1757.56 233.17 0.61 MWD 53 4449.33 35.25 230.92 95.98 3918.21 1668.59 -1088.57 -1449.91 1813.07 233.10 0.24 MWO 54 4545.35 35.03 228.72 96.02 3996.73 1718.12 -1124.22 -1492.13 1868.24 233.00 1.34 MWD 55 4641.35 35.36 227.68 96.00 4075.18 1767.01-1161.10-1533.38 1923.38 232.87 0.71 MWO 56 4736.87 35.67 226.54 95.52 4152.93 1815.53 -1198.87 -1574.03 1978.60 232.71 0.77 MWO 57 4829.50 35.33 226.85 92.63 4228.34 1862.37 -1235.76 -1613.17 2032.10 232.55 0.42 MWO 58 4926.01 33.91 226.80 96.51 4307.76 1910.19 -1273.28 -1653.16 2086.66 232.40 1.47 MWD 59 5021.16 33.04 230.02 95.15 4387.14 1956.62 -1308.12 -1692.39 2139.00 232.30 2.08 MWO 60 5117.70 32.93 232.25 96.54 4468.12 2004.25 -1341.09 -1733.30 2191.54 232.27 1.26 MWD [(c)2002 AnadrilllOEAL 106_1 C_1 0] ANAORILL SCHLUMBERGER Survey Report 9-May-2002 15:12:57 Page 4 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +EIW- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- --~----- ---------------- --------------- ----- ----- ---- 61 5213.20 32.75 235.55 95.50 4548.36 2052.17"-1371..60-1775.13 2243.30 232.31 1.88 MWO Page 4 - - - - -- Final Survey NS07. TXT 62 5308.48 32.74 237.71 95.28 4628.50 2100.75 -1399.94 -1818.17 2294.68 232.40 1.23 MWD 63 5403.66 32.50 240.17 95.18 4708.68 2149.75-1426.41-1862.112345.65 232.55 1.42 MWD 64 5498.61 32.33 243.13 94.95 4788.84 2199.02 -1450.58 -1906.89 2395.91 232.74 1.68 MWD 65 5593.43 32.54 243.74 94.82 4868.86 2248.63 -1473.32 -1952.37 2445.90 232.96 0.41 MWD 66 5688.39 32.89 243.26 94.96 4948.76 2298.71 -1496.22 -1998.30 2496.38 233.18 0.46 MWD 67 5784.13 33.65 242.26 95.74 5028.81 2349.81 -1520.26 -2045.00 2548.18 233.37 0.98 MWD 68 5878.69 34.25 242.08 94.56 5107.25 2401.05"-1544.92 -2091.70 2600.38 233.55 0.64 MWD 69 5974.41 34.29 240.39 95.72 5186.35 2453.14 -1570.85 -2138.94 2653.80 233.71 1.00 MWD 70 6070.16 33.99 239.46 95.75 5265.60 2504.74 -1597.78 -2185.44 2707.22 233.83 0.63 MWD 71 6164.97 33.77 238.29 94.81 5344.31 2555.21 -1625.10 -2230.68 2759.87 233.93 0.73 MWD 72 6259.35 33.66 236.78 94.38 5422.82 2604.86 -1653.22 -2274.88 2812.15 233.99 0.90 MWD 73 6354.56 33.46 235.09 95.21 5502.16 2654.25 -1682.69 -2318.48 2864.75 234.03 1.00 MWD 74 6449.85 33.08 234.11 95.29 5581.83 2702.88 -1712.97 -2361.09 2917.02 234.04 0.69 MWD 75 6544.55 32.82 232.97 94.70 5661.30 2750.43 -1743.58 -2402.52 2968.53 234.03 0.71 MWD 76 6642.36 32.76 232.96 97.81 5743.53 2799.13 -1775.48 -2444.80 3021.49 234.01 0.06 MWD 77 6737.53 32.72 232.65 95.17 5823.58 2846.40 -1806.60 -2485.80 3072.95 233.99 0.18 MWD 78 6833.07 32.87 231.88 95.54 5903.89 2893.72 -1838.27 -2526.73 3124.67 233.96 0.46 MWD 79 6927.54 32.52 231.10 94.47 5983.39 2940.10 -1870.04 -2566.66 3175.65 233.92 0.58 MWD 80 7022.75 32.34 230.29 95.21 6063.75 2986.21 -1902.38 -2606.16 3226.63 233.87 0.49 MWD 81 7115.74 31.66 230.27 92.99 6142.61 3030.56 -1933.87 -2644.07 3275.81 233.82 0.73 MWD 82 7212.31 31.58 229.62 96.57 6224.85 3075.99 -1966.45 -2682.82 3326.33 233.76 0.36 MWD 83 7306.25 31.54 229.19 93.94 6304.89 3119.91-1998.44-2720.15 3375.35 233.70 0.24 MWD 84 7400.82 32.14 228.64 94.57 6385.23 3164.27 -2031.23 -2757.76 3425.07 233.63 0.70 MWD 85 7497.26 32.64 230.36 96.44 6466.67 3210.45 -2064.78 -2797.04 3476.60 233.57 1.09 MWD 86 7590.58 33.07 233.26 93.32 6545.07 3256.58 -2096.06 -2836.82 3527.19 233.54 1.75 MWD 87 7682.64 33.43 234.95 92.06 6622.06 3303.37 -2125.65 -2877.71 3577.66 233.55 1.08 MWD 88 7779.09 33.79 237.97 96.45 6702.39 3353.63 -2155.14 -2922.20 3630.96 233.59 1.77 MWD 89 7873.97 34.62 243.73 94.88 6780.88 3405.04 -2181.07 -2968.75 3683.82 233.70 3.52 MWD 90 7968.11 35.52 250.83 94.14 6857.96 3458.41 -2201.89 -3018.59 3736.33 233.89 4.44 MWD PageS - - - - ~ Final Survey NS07.TXT [(c)2002 AnadrilllOEAL 106_1 C_1 0] ANAORILL SCHLUMBERGER Survey Report 9-May-2002 15:12:57 Page 5 of 6 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVO Vertical Oispl Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E!W- displ Azim (deg/ tool qual (1t) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- 91 8063.99 36.00 256.15 95.88 6935.78 3514.33 -2217.79 -3072.27 3789.12 234.18 3.28 MWO 92 8156.24 35.78 258.80 92.25 7010.52 3568.39 -2229.52 -3125.05 3838.84 234.49 1.70 MWO 93 8260.46 35.88 262.00 104.22 7095.03 3629.21 -2239.68 -3185.18 3893.79 234.89 1.80 MWO 94 8354.85 36.39 265.72 94.39 7171.27 3684.34 -2245.62 -3240.50 3942.55 235.28 2.39 MWO 95 8450.96 36.59 268.80 96.11 7248.54 3740.40-2248.35-3297.58 3991.13 235.71 1.92 MWO 96 8545.86 36.99 272.70 94.90 7324.55 3795.37 -2247.60 -3354.38 4037.77 236.18 2.50 MWO 97 8640.52 37.25 276.14 94.66 7400.04 3849.59 -2243.19 -3411.32 4082.77 236.67 2.21 MWO 98 8735.45 37.57 279.46 94.93 7475.45 3903.17 -2235.36 -3468.44 4126.37 237.20 2.15 MWD 99 8830.33 37.71 283.02 94.88 7550.59 3955.61 -2224.07 -3525.25 4168.20 237.75 2.30 MWD 100 8925.13 37.36 282.49 94.80 7625.77 4007.24 -2211.32 -3581.58 4209.23 238.31 0.50 MWO 101 9019.45 37.72 281.68 94.32 7700.56 4058.92 -2199.29 -3637.77 4250.91 238.84 0.65 MWO 102 9115.58 38.46 281.60 96.13 7776.22 4112.44-2187.32-3695.86 4294.62 239.38 0.77 MWO 103 9210.62 39.06 280.96 95.04 7850.33 4166.30 -2175.69 -3754.21 4339.09 239.91 0.76 MWD 104 9308.09 39.38 280.48 97.47 7925.84 4222.34 -2164.22 -3814.76 4385.92 240.43 0.45 MWD 105 9400.90 39.69 279.39 92.81 7997.42 4276.39 -2154.03 -3872.95 4431.66 240.92 0.82 MWD 106 9497.01 40.35 278.97 96.11 8071.02 4333.26-2144.17-3933.96 4480.35 241.41 0.74 MWD 107 9592.34 40.62 279.01 95.33 8143.52 4390.29 -2134.50 -3995.10 4529.56 241.89 0.28 MWD 108 9687.64 40.92 280.54 95.30 8215.70 4447.30 -2123.94 -4056.42 4578.83 242.36 1.09 MWD 109 9781.29 41.31 281.82 93.65 8286.26 4503.08 -2111.99 -4116.83 4626.97 242.84 0.99 MWD 110 9876.45 41.92 283.25 95.16 8357.40 4559.68 -2098.27 -4178.52 4675.76 243.34 1.19 MWD 111 9969.81 41.36 285.26 93.36 8427.18 4614.39 -2083.01 -4238.64 4722.81 243.83 1.55 MWD 112 10072.12 40.49 286.32 102.31 8504.48 4672.63 -2064.77 -4303.13 4772.86 244.37 1.09 MWD 113 10166.44 39.66 286.57 94.32 8576.65 4725.04 -2047.59 -4361.37 4818.10 244.85 0.90 MWD -: 'Page 6 - - - - - - - ~ Final Survey NS07.TXT 114 10262.26 39.16 286.91 95.82 8650.69 4777.40 -2030.07 -4419.62 4863.56 245.33 0.57 MWD 115 10355.99 40.13 288.36 93.73 8722.86 4828.38 -2011.94 -4476.61 4907.94 245.80 1.43 MWD 116 10451.92 42.02 290.84 95.93 8795.18 4880.93 -1990.78 -4535.96 4953.60 246.30 2.60 MWD 117 10546.98 41.49 290.16 95.06 8866.09 4933.18 -1968.61 -4595.26 4999.18 246.81 0.73 MWD 118 10641.85 41.47 289.91 94.87 8937.17 4985.34 -1947.08 -4654.29 5045.15 247.30 0.18 MWD 119 10738.05 41.55 288.83 96.20 9009.21 5038.66 -1925.93 -4714.44 5092.66 247.78 0.75 MWD 120 10833.47 41.75 288.34 95.42 9080.51 5092.17 -1905.72 -4774.54 5140.82 248.24 0.40 MWD [(c)2002 AnadrilllDEAL ID6_1 C_1 0] ANADRILL SCHLUMBERGER Survey Report 9-May-200215:12:57 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 Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- 121 10929.09 41.99 287.70 95.62 9151.71 5146.36 -1885.98 -4835.23 5190.03 248.69 0.51 MWD 122 10980.52 41.41 288.31 51.43 9190.11 5175.41 -1875.41 -4867.77 5216.55 248.93 1.38 MWD 123 11012.22 41.07 289.26 31.70 9213.95 5193.00-1868.68-4887.56 5232.61249.08 2.25 MWD 124 11105.82 40.37 290.23 93.60 9284.89 5243.86 -1848.06 -4945.03 5279.07 249.51 1.01 MWD 125 11200.21 39.25 291.41 94.39 9357.40 5293.55-1826.58-5001.51 5324.62 249.94 1.43 MWD 126 11296.52 38.05 293.16 96.31 9432.61 5342.12 -1803.79 -5057.17 5369.23 250.37 1.69 MWD 127 11376.72 37.06 293.90 80.20 9496.19 5380.95 -1784.27 -5101.99 5404.99 250.72 1.36 MWD 128 11578.43 39.09 290.10 201.71 9655.00 5481.76-1737.78-5217.315499.11251.58 1.54 MWD 129 11673.98 40.29 285.67 95.55 9728.54 5533.64 -1719.08 -5275.35 5548.39 251.95 3.22 MWD 130 11770.66 39.49 282.57 96.68 9802.72 5588.36 -1703.95 -5335.46 5600.95 252.29 2.22 MWD 131 11862.49 39.18 280.34 91.83 9873.75 5640.97 -1692.39 -5392.50 5651.84 252.58 1.58 MWD 132 11960.78 38.17 279.96 98.29 9950.49 5697.07 -1681.56 -5452.96 5706.35 252.86 1.06 MWD 133 12055.34 37.01 280.37 94.56 10025.41 5749.75-1671.38-5509.74 5757.67 253.12 1.25 MWD Page 7 - - - - ~ ---= Final Survey NS07.TXT 134 12150.23 35.90 280.00 94.89 10101.74 5801.23-1661.41-5565.23 5807.93 253.38 1.19 MWD 135 12247.42 34.41 279.35 97.19 10181.20 5852.53-1652.00-5620.39 5858.15 253.62 1.58 MWD 136 12342.48 33.12 278.95 95.06 10260.22 5901.15 -1643.60 -5672.55 5905.87 253.84 1.38 MWD 137 12435.94 31.87 279.80 93.46 10339.05 5947.29-1635.42-5722.09 5951.21 254.05 1.42 MWO 138 12530.43 30.90 279.41 94.49 10419.71 5992.42 -1627.21 -5770.61 5995.64 254.25 1.05 MWO 139 12626.46 30.51 280.30 96.03 10502.28 6037.31 -1618.82 -5818.92 6039.90 254.45 0.62 MWD 140 12718.20 29.77 279.99 91.74 10581.61 6079.39 -1610.71 -5864.26 6081.44 254.64 0.82 MWO 141 12812.33 28.76 280.98 94.13 10663.73 6121.31 -1602.34-5909.51 6122.89 254.83 1.19 MWD 142 12907.11 28.41 281.76 94.78 10746.96 6162.33 -1593.40 -5953.96 6163.49 255.02 0.54 MWD 143 13005.23 27.99 281.98 98.12 10833.43 6204.09 -1583.86 -5999.34 6204.89 255.21 0.44 MWO 144 13102.44 26.47 281.35 97.21 10919.86 6244.23-1574.86-6042.90 6244.74 255.39 1.59 MWO 145 13195.34 23.41 285.52 92.90 11004.10 6279.05 -1565.85 -6080.99 6279.36 255.56 3.80 MWO 146 13292.20 20.49 288.57 96.86 11093.93 6310.13-1555.30-6115.61 6310.28 255.73 3.24 MWD 147 13388.21 19.17 290.52 96.01 11184.25 6337.32 -1544.42 -6146.30 6337.37 255.89 1.54 MWD 148 13452.27 18.12 292.56 64.06 11244.94 6354.01 -1536.91 -6165.35 6354.03 256.00 1.93 MWD Projected to TO 149 13529.00 17.25 294.00 76.73 11318.05 6372.59-1527.71 -6186.77 6372.59 256.13 1.27 MWO [(c)2002 AnadrilllOEAL 106_1 C_1 0] Page 8 Î , I I I NS07 Formation Top Permafrost Base Permafrost SV6 - top confining zone SV5 - base confining zone Surface casing point SV4 SV2 - top upper injection zone SVl - top major shale barrier TMBK - top lower injection zone - Top Ugnu WSI - top Schrader Bluff - Base Ugnu CM3 - Base lower injection zone (top Colville) Geol target #1 THRZ - Top HRZ BHRZ - Base HRZ Top Kuparuk Kuparuk C Top Miluveach Intermediate casing point Intermediate logging point Top Kingak Fault "52" - throw = 150' Top Sag River Geol target #2 .Intermediate casing point Top Shublik Top Ivishak Oil- Water contact Top Kavik Total Depth Top Lisburne I I I I I I [ I I I I I I I Prognosed Tops TVDss TVDrkb MDrkb 1,149 1206 1216 1,519 1576 1617 2,950 3007 3329 3,226 3283 3661 3,263 3320 3700 3,521 3578 4016 3,930 3987 4508 4,320 4377 4977 4,642 4699 5364 6,194 6251 7231 6,697 6754 7834 7,586 7643 8932 8,441 8498 10050 8,560 8617 10205 8,680 8737 10362 9,002 9059 10783 9,432 9489 11345 9,589 9646 11550 9,589 9646 11550 9,912 9969 11972 10,033 10090 12125 10,700 10757 12910 10,740 10797 12956 10,730 10787 12944 10,788 10845 13011 10,850 10907 13083 11,100 11157 13336 11 ,249 11308 13544 11,289 10907 13590 11,100 11157 13336 Actual Depths TVDss TVDrkb MDrkb 1143 1200 1208 1508 1564 I 585 2987 3044 3380 3241 3298 3687 3312 3368 3774 3563 3620 4090 3963 4020 4573 4352 4409 5046 4710 4767 5472 6236 6293 7292 6838 6895 8015 7586 7643 8932 8576 8633 10050 8747 8804 10205 8847 8904 10362 8985 9042 10783 9374 9431 11345 9492 9548 11440 9492 9548 11440 9893 9950 11960 10153 10210 12292 10713 10770 12938 10753 10810 12976 10753 10810 12976 10815 10872 13046 10893 10950 13133 11209 11266 13472 11264 11321 13529
