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Home My WebLink About200-211Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/01/2025 InspectNo:susGDC250613161019 Well Pressures (psi): Date Inspected:6/14/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:2/1/2001 #301-018 Tubing: IA: OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:6/11/2025 Type of Inspection:Subsequent Well Name:NORTHSTAR UNIT NS-26 Permit Number:2002110 Wellhead Condition The wellhead is rusting fairly badly with no signs of any leakage. No well sign - wellhouse removed. I asked Steve Soroka to attach a tag with the well ID information to the well that is better suited for surviving the elements. Surrounding Surface Condition Good clean gravel pad. Condition of Cellar Very little snow and ice with no signs of hydrocarbons. Comments The location of the well was verified by a pad map. The wellhead is in a cellar covered with a steel plate. The opening for inspecting the well is too small to enter. Ground water/snow-melt is getting on the wellhead causing the rust. Supervisor Comments Photos (7) Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, August 1, 2025          2025-0614_Suspend_Northstar_NS-26_photos_gc Page 1 of 4a Suspended Well Inspection – Northstar NS-26 PTD 2002110 AOGCC Inspection Rpt # susGDC250613161019 Photos by AOGCC Inspector G. Cook 6/14/2025 Northstar NS-26 in well cellar covered with hatch 2025-0614_Suspend_Northstar_NS-26_photos_gc Page 2 of 4a Northstar NS-26 in well cellar as found; zero pressure 2025-0614_Suspend_Northstar_NS-26_photos_gc Page 3 of 4a Northstar NS-26 in well cellar; operator placed paper tag on well with well information. I requested a tag with well information that is better suited for surviving the elements 2025-0614_Suspend_Northstar_NS-26_photos_gc Page 4 of 4a Well sign on connex found behind Northstar NS-27 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3,302 feet 1,237 feet true vertical 3,225 feet NA feet Effective Depth measured 3,200 feet NA feet true vertical 144 feet NA feet 3,130 Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 13Cr 75' 75' Packers and SSSV (type, measured and true vertical depth) NA NA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 5,210psi TVD N/A 2,470psi Slotted Liner 20"193' 3,288' Casing 10-3/4" NORTHSTAR / NORTHSTAR OIL Conductor 3,288'Surface Burst N/A Collapse Intermediate Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 NORTHSTAR UNIT NS-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-211 50-029-22996-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) NA Gas-Mcf NA NA NANA NA 0NA 0 NA N/A measured true vertical Packer MD 193' Size 193' 3,211' Length Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 NA PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:00 pm, Jul 14, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.07.14 13:06:45 -08'00' Justus Hinks (3691) JJL 7/21/25 RBDMS JSB 071725 DSR-7/21/25 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email:steve.soroka@hilcorp.com If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA NA OA NA Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm Follow Up Actions Needed: Hilcorp Alaska, LLC 200-211 Condition of Surrounding Surface Location: 02/01/01 301-018 REVIEWED BY: Other (specify in comments) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Guy Cook 06/14/25 Yes Steve SorokaNS-26 907-830-8976 Yes Offshore 06/09/25 Subsequent The wellhead is located below the pad grade, covered by a steel plate with an inspection hatch. It has some rust but is in clean condition and free of debris. The sign is on a Conex behind the well row next to the well slot.. The area above ground is clean and free of debris. The cellar is clean with a small amount of clean ice. Put a tag on the Well head with the sign information per the AOGCC inspector. Complete. Location verified by Pad map WBS Pictures Area map Yes PLB 12/2014 NS26 Suspended Well Inspection Form 2025 QSI, Hilcorp, Hilcorp, Quantum Spatial, Inc.Date:6/11/2025Scale:One Map AlaskaN1:7450 0.01 0.01 0.02 0.020miPolaris PipelinesPipelines Sevice CategoryGasOilWaterOtherOBO pipelines, Casings, & Pipe RacksPipelines Operated by OthersNS_ModulesModulesNS_Detailed_2024_ImageryRed: RedGreen: GreenBlue: BlueNS 2020 Fieldwide Aerial ImageryRed: Band_1Green: Band_2Blue: Band_3 _____________________________________________________________________________________ Revised By: DH 7/8/2025 SCHEMATIC Northstar Unit Well: NS-26 Suspended: 2/1/2001 PTD: 200-211 TD =3,302’ (MD) / TD = 3,225(TVD) 20” Orig. KBE =55.39’Nabors 33E ES cementer @ 1,622’ 10-3/4” 9.2 ppg mud PBTD =3,200’ (MD) / PBTD =3,130’(TVD) TOC @ 1,237’ BOC @ 1,700’ TOC @ 3,200’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169 / X-56 / N/A N/A Surface 193’ N/A 10-3/4" Surface 68 / L-80 / N/A 9.950 Surface 3,288’ 0.0962 Tubing Detail 4-1/2” Tubing 12.6# / 13-Cr 3.958” Surface 75’ 0.0152 OPEN HOLE / CEMENT DETAIL 20" Driven 10-3/4" 1,499 sx PF ‘E’, 345 sx Class “G” in 13-1/2” Hole GENERAL WELL INFO API: 50-029-22996-00-00 Completed –2/1/2001 NS26 Photo 1. Front view. June 14, 2025. NS26 Photo 2. Front closeup view. June 14, 2025. NS26 Photo 3. Back view. June 14, 2025. NS26 Photo 4. Well sign. June 14, 2025. NS26 Photo 5. Hatch door. June 14, 2025. NS26 Photo 6. View down into the center of the cellar. June 14, 2025. NS26 Photo 7. View down into the left side of the cellar. June 14, 2025. NS26 Photo 8. View down into the back side of the cellar. June 14, 2025. NS26 Photo 9. View down into the right side of the cellar. June 14, 2025. NS26 Photo 10. View down into the front side of the cellar. June 14, 2025. NS26 Photo 11. Tubing gauge. June 14, 2025. NS26 Photo 12. Tag on tubing gauge. June 14, 2025. NS26 Photo 13. Behind well row. 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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: Inspect well Hilcorp Alaska 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 3,302 feet N/A feet true vertical 3,225 feet N/A feet Effective Depth measured 3,200 feet N/A feet true vertical 3,130 feet N/A feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)4-1/2" 13Cr 75' 75' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WDSP2 WAG Water-Bbl MD TVDSize Oil-Bbl measured true vertical Packer Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-2110 50-029-22996-00-00 Plugs ADL0312799 5. Permit to Drill Number: NORTHSTAR / NORTHSTAR OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com NORTHSTAR UNIT NS-26 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured N/A Production Production Casing Conductor Liner Length 193' 3,288'Surface Intermediate 10-3/4" 5,210psi 20" 3,288' 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,211' 193' Burst 193' 777-8333 N/A N/A 2,470psi PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:31 am, Oct 09, 2020 Chad A Helgeson 2020.10.08 16:12:12 -08'00' SFD 10/12/2020RBDMS HEW 11/12/2020 200-211 MGR13OCT2020 DSR-10/12/2020 SFD 10/12/2020 _____________________________________________________________________________________ Revised By: TDF 7/14/2016 SCHEMATIC Northstar Unit Well: NS-26 Suspended: 2/1/2001 PTD: 200-211 TD =3,302’(MD) / TD = 3,225(TVD) 20” Orig. KBE = 55.39’ Nabors 33E 10-3/4” PBTD =3,200’(MD) / PBTD =3,130’(TVD) TOC @ 1,237’ BOC @ 1,700’ TOC @ 3,200’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169 / X-56 / N/A N/A Surface 193’ N/A 10-3/4" Surface 68 / L-80 / N/A 9.950 Surface 3,288’ 0.0962 OPEN HOLE / CEMENT DETAIL 20" Driven 10-3/4" 1,499 sx PF ‘E’, 345 sx Class “G” in 13-1/2” Hole GENERAL WELL INFO API: 50-029-22996-00-00 Completed – 2/1/2001 Well NS-26 r Suspended Well Inspection Review Report InspectNo: susSAM200607211653 Date Inspected: 6/6/2020 Inspector: Austin McLeod Type of Inspection: Well Name: NORTHSTAR UNIT NS -26 Permit Number: 2002110 Suspension Approval: Sundry H 301-018 Suspension Date: 2/1/2001 Location Verified? W If Verified, How? Other (specify in comments) Offshore? ❑/ Subsequent Date AOGCC Notified: 6/4/2020 Operator: Hilcorp Alaska, LLC Operator Rep: Brennan Starkweather Wellbore Diagram Avail? ❑� Photos Taken?❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Dry hole tree appeared fine. Valve zip tied open. Operator informed me the valve on tree was zip tied in the open position; not operated due to small space and lack of access to it. Gauge appeared to be in fine condition (0-200psi). Condition of Cellar Some frozen ice in box with herculite visible. No sheens or discolorations. No issues observed. Surrounding Surface Condition No issues. Gravel and surrounding areas appeared normal and like the rest of well row. Comments Well is below pad grade with — 16"x16" hatch to do a visual. Schematic showed only a 10-3/4" string ran. Pad map used to verify location Supervisor Comments Photos (4) ✓ ( j It 12� Thursday, June 11, 2020 i N W O N d OA ttl a �N� �N� Mo2--(,,`� �� F/ 0 2an��H0 Regg" Ja��es B (DOA) _, From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, September 22' J8l64:22PM �� 1,( 17-Z1 / | " To: Regg' ]ames B (DOA) l � \ Cc: Schwartz, Guy L (DOA);Taylor Wellman Subject: RE: Northstar NS-26 (PTD #200-211) Suspended Well Status Jim, Hi|co/phascomp|eteddiagnosticsonNorthsta/suspendedvveUN3'Z6 (PTD#200'I11). Downho|einte8rityofthe10- 3/4" casing was verified with a pressure test to 500 psi against the cement plug at 1237'. Wellbore fluids were ,--- successfully recovered to 21' below surface and replaced with freeze protect. The 10'3/4" casing pressures and any subsequent bleeds will be monitored and recorded going forward. Diagnostics Completed Fluid Samples taken at 10' and 25' indicated water. - 10-3/4" casing drifted with weighted line to 300' to verify no ice plugs near surface. -- - 10'3/4" casing and 2" master valve pressure tested successfully to 500 psi. Lost 25 psi in 4 hrs. ^ - Fluids vac'd out to 21' and replaced with 84 gallons of diesel freeze protect. Final wellhead pressure 0 psi and fluid - packed to surface. Please let me know if you have any questions or concerns. Thank You, Wyatt Rivard Wcll Integrity} ngineer SCANNED jUN I 6. 2017 0: (907) 777'85471C: (509)670-8001 vvrvond6»bi(curp.cuou 3800 Centeoint Drive,Suite 1f00 ! Anchorage,AK 99503 il Mew ��A, _ From: Wyatt Rivard Sent: Thursday, September 08, 2016 4:33 PM To: Regg, James B (DOA) Cc: Taylor Wellman; 'Schwartz, Guy L (DOA)'; 'mike.quick@alaska.gov' Subject: RE: Northstar NS-26 (PTD #200-211) Suspended Well Status Jim, Hilcorp would like to provide an update on the status of the .orthstar NS-26 (PTD#200'211) suspended well. As reported, the well was recently found to be in a differen ondition than previously understood.The well has only a casingheadinsta||edontho10'3/4" surfacecasingw. an adapter to a 2" master valve.The 2" valve had been left open and the gauge appeared to have broken off due v settling of the rig mat and gravel that had been placed over the well. Once this was discovered, Hilcorp installed a w gauge on the well and is monitoring pressures going forward. Since installing the new gauge, the we as slowly pressured up twice to -10-15 psi. The pressure was bled quickly back to zero with roughly 1 quart of flui• collected. A sample of the fluid recently came back from the lab as freshwater. 1 . . • • L`"`~rv_IOC'_4 [/ [) 0 Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> �|� (m Sent: Thu� �d� September0� 2Ol64:33PK4 '\- ` To: Regg,James B (DOA) Cc: Taylor Wellman; SchwartzGuy L (DOA); Quick, Michael J (DOA) Subject: RE: Northstar NS-26 (PTD#200-211) Suspended Well Status Jim, Hilcorp would like to provide an update on the status of the Northstar NS-26 (PTD#200-211) suspended well.As reported, the well was recently found to be in a different condition than previously understood.The well has only a caoingheadinsta||ednnthe10'3/4" surfacecasin8vvithanadapte/toa2" nnastervahe.The2" va|vehadbeen |eftopen and the gauge appeared to have broken off due to settling of the rig mat and gravel that had been placed over the well. Once this was discovered, Hilcorp installed a new gauge on the well and is monitoring pressures going forward. Since installing the new gauge, the well has slowly pressured up twice to —10-15 psi. The pressure was bled quickly back to zero with roughly 1 quart of fluid collected. A sample of the fluid recently came back from the lab as freshwater. When the well was previously suspended in 2001, it was left with 9.8 ppg brine and a —90'freeze protect cap of mineral oil. Hilcorp is planning to perform additional diagnostics to confirm integrity of the well and add a freeze protect cap to ~, protect the casing and wellhead from near surface freezing. Plan Forward 1) Verify integrity of 2"valve with a pressure test to 1000 psi 2) Perform an open hole drift of the 10-3/4" casing with a weighted line to 200' to verify no near surface ice plugs ' 3) Obtain fluid samples at 10' and 25' below surface to identify if mineral oil has been displaced with freshwater - 4) PerfnrmanK4|Tof10-3/4" casingtoSUDpdtoverifvin1egrityVfcasingandcementp|ugot1237' — 5) Replace or confirm near surface wellbore fluids to approximately 25' are freeze protect - Please let me know if you have any questions or concerns. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centeri iDrive'Suirel48OI &uchorage'&K99SO2 SCANNED `/UN 2 7 20j7 tbliNirp A ta*Ika,1.14� From: Taylor Wellman Sent: Friday, July 15, 2016 8:55 AM To: 'Regg, James B (DOA)' Cc: Wyatt Rivard Subject: Northstar NS-26 (PTD #200-211) Suspended Well Status Jim, +It has come to the attention of Hilcorp that the Suspended Well Status of Northstar well NS-26 (PTD#200-211) is different than what has been previously reported on the 2014 Suspended Well Inspection Report submitted by the previous operator. Enclosed are the older well schematic and the updated schematic. The well condition was discovered while developing the future plans for the well. Updated Information - The wellhead was uncovered from underneath a rig mat and small amount of gravel. - The well has no tubing hanger, tubing joint or BPV/TWC installed. - The well does have 10-3/4", 68#, L-80 surface casing and an adapter flange on top. Above the adapter flange is a single 2", 5k Vetco Gray valve, needle valve and pressure gauge. - There is zero pressure on the casing (new calibrated gauge was installed). - There is no discoloration or indications of a spill in the well cellar. Planned Action - Monitor and complete suspended well inspections of well as per regular cycle. - Wellhead will be left uncovered allowing for pressure monitoring. Brief Well History 1/26/01 Complete drilling of surface hole to 3302' md. 1/27/01 Run casing and complete pumping 1st stage cement job. 1/28/01 Pump 2nd stage cement job. 1/29/01 Begin drill out of ES cementer. 1/30/01 Drill out ES cementer at 1622' md. Mill outside 10-3/4" casing.Test casing and leak off at 300psi. Place hi-vis pill , mix and pump balance cement plug from 1700'—1237' md. 1/31/01 TIH and tag cement at 1237' md. Pressure test cement plug to 1000psi for 5 min. Displace well to 9.8ppg brine with 100' of mineral oil cap. Set tubing hanger, land 1 joint of tubing, set BPV and pressure test to 500psi via annulus casing valve. RD and move over to NS-27. 2/7/01 NS-33E completed drilling and cementing surface casing on NS-27. ND diverter, move over NS-26, ND BOP's, remove TWC, tubing hanger, tubing spool, casing valves and set master valve. 11/2/10 2010 Well Suspension Sundry Application: - Handwritten note stating "No photo of wellhead. Cut off and buried." 9/22/14 The well conditions noted in the 2014 report indicated the following: - Tbg hanger and 1 joint of 4-1/2", 12.6#, 13Cr tubing in place - Well cellar had been backfilled with gravel - T/I/O= N/A If you'd like to discuss this well feel free to contact me and we can discuss over the phone or I can come to your office. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com 2 • k! sk pri 7-6(M2_t(0 Regg, James B (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday,July 15, 2016 8:55 AM t ''11.511V To: Regg,James B (DOA) Cc: Wyatt Rivard Subject: Northstar NS-26 (PTD #200-211) Suspended Well Status Attachments: NS-26 SCHEMATIC 7-14-2016.doc; NS26 Schematic -Archive Version.pdf Jim, It has come to the attention of Hilcorp that the Suspended Well Status of Northstar well NS-26 (PTD#200-211) is different than what has been previously reported on the 2014 Suspended Well Inspection Report submitted by the previous operator. Enclosed are the older well schematic and the updated schematic. The well condition was discovered while developing the future plans for the well. Updated Information ✓ - The wellhead was uncovered from underneath a rig mat and small amount of gravel. - The well has no tubing hanger, tubing joint or BPV/TWC installed. - The well does have 10-3/4", 68#, L-80 surface casing and an adapter flange on top. Above the adapter flange is — a single 2", 5k Vetco Gray valve, needle valve and pressure gauge. - There is zero pressure on the casing(new calibrated gauge was installed). - There is no discoloration or indications of a spill in the well cellar. ✓ Planned Action - Monitor and complete suspended well inspections of well as per regular cycle. - Wellhead will be left uncovered allowing for pressure monitoring. Brief Well History SCANNED NOV 2 22016 1/26/01 Complete drilling of surface hole to 3302' md. 1/27/01 Run casing and complete pumping ft stage cement job. 1/28/01 Pump 2nd stage cement job. 1/29/01 Begin drill out of ES cementer. 1/30/01 Drill out ES cementer at 1622' md. Mill outside 10-3/4" casing.Test casing and leak off at 300psi. Place hi-vis pill , mix and pump balance cement plug from 1700'—1237' md. 1/31/01 TIH and tag cement at 1237' md. Pressure test cement plug to 1000psi for 5 min. Displace well to 9.8ppg brine with 100' of mineral oil cap. Set tubing hanger, land 1 joint of tug, set BPV and pressure test to 500psi via annulus casing valve. RD and move over to NS7. 2/7/01 NS-33E completed drilling and cementing surface casing on NS-27. ND diverter, move over NS-26, ND BOP's, remove TWC,tubing hanger,tubing spool, casing valves and set master valve. 11/2/10 2010 Well Suspension Sundry Application: - Handwritten note stating "Nophoto of wellhead. Cut off and buried." 9/22/14 The well conditions noted in the 2014 report indicated the following: - Tbg hanger and 1 joint of 4-1/2", 12.6#, 13Cr tubing in place - Well cellar had been backfilled with gravel - T/I/O = N/A If you'd like to discuss this well feel free to contact me and we can discuss over the phone or I can come to your office. • • Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com 2 • Northstar Unit Well: NS-26 • SCHEMATIC Suspended: 2/1/2001 PTD: 200-211 Hiicor');‘Inaka,LLC. OPEN HOLE/CEMENT DETAIL Orig.KBE=55.39'Nabors 33E 20" Driven 10-3/4" 1,499 sx PF'E',345 sx Class"G"in 13-1/2"Hole 20" CASING DETAIL Size Type Wt/Grade/Conn ID Top Btrn BPF 20" Conductor 169/X-56/N/A N/A Surface 193' N/A 10-3/4" Surface 68/L-80/N/A 9.950 Surface 3,288' 0.0962 GENERAL WELL INFO API:50-029-22996-00-00 Completed —2/1/2001 TOG @1,23T tm' '"F-44,r4,,kpitl)0,47!..74 ▪ *Niro, .kAtIt F1,1 4 BOC @1,700..../2▪ r TOC @ 3,202 $4,17.Y.42#: 47, TD=3,302'(MD)/TD=3,225(TVD) PBTD=3,200'(MD)/PBTD=3,130'(TVD) Revised By:TDF 7/14/2016 TREE= • • WEIL H D= SAFETY NOTES:***4-1/2"CHROME ISO*** ACTUATOR= ***WELDED PLATE ON CSG*** KB ELEV= BF. ELEV= NS26 KOP= Max Angle= Ale.011141A us-31,1 Datum MD= SLISP- NDED Datum TVD 4-1/2"TBG,12 611, 13-CR — 79' 0152 bpi,ID=3 958" 20"CONDUCTOR — 193 —A TOC 1237' 40 *I 0 4° 1622Hi 0-3/4"HES ES CEMENTER • HOC 1 –1700* PBTD H 3200' 004 *V I 110-3/4"CSG,45 5#,L-80,ID=9 950 H 3288' A . AA AAA AA DATE REV BY COMMENTS DATE REV BY CO NORTHSTAR 02/01101 SUSPENDED 1111111111111111111111111111111111111 WELL NS26 04/28111 st/JMO CANVAS REFORMATTING PERMIT tsk> 002110 AP1No. 50-029-2299640 111111111111111111111111111111111111111111111111111111111111111111111111 SEC 11,T13N, R13E 1298'FSL&648I FEL 111111111111111111111 SP Exploration(Alaska) roject Well History File Cover~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~z~ 00-~ [ j-, Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) /' Color items: [] Diskettes, No. E} Maps: [] Grayscale items: E} Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: [] Other: OVERSIZED (Non-Scannable) NOTES: [] Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERYL~~INDY Project Proofing BEVERLY ROBIN VINCENT SHERYL~WINDY BY: ScaiJning Preparation BEVERLY ROBIN VINCENT SHERYOINDY [] Other Production Scanning Stage I PAGE COUNT FROM SCANNED FLEE: BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO IF NO iN STAGE t, PAGE(S) DISCREPA~ RE FOUND: YES ..-. NO ON AI',T'T1'~IDUAL PAGE BASIS -- RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comrnents about this file: /sl Quality Checked 12/10/02Rev3NOTScannedwpd A A E LASKA O F SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 M CONSERQATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble Data Management Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS26 1 Sundry Number: 310 -337 ` Dear Mr. Preble: 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, zl Daniel T. Seamount, Jr. Chair �L DATED this 2 - day of November, 2010. Encl. ' • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 October 06, 2010 ' Mr. Daniel Seamount, Chairman iwww Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Northstar Unit 26 (PTD # 2002110) Suspended Well Inspection Report (10 -404) Application for Renewal of Existing Suspension (10 -403) Dear Mr. Seamount, BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Northstar Unit well 26 on 9/20/10. Enclosed is a Report of Sundry Well Operations (1 Q with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Recent well events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one- /e quarter mile radius of the surface location fP � • Photograph showing the condition of the surrounding location -- N° r ,111 ' Northstar Unit well 26 was suspended on 2/01/01. It is located on a pad with activ wells and /or service wells. /Gtr la•2�- td Based on this information, BPXA requests approval for renewal of the existing / suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Northstar Unit well 26 is mechanically sound and secure and will meet the requirements for renewal of suspended status. If ou require an additional information lease contact me at 564 -5637 Torin Y q Y information, Murphy at 659 -5102 or Chris Stone 564 -5518. J Sincerely, "'t'4 ven R ssberg BPXA, Wells Operations ager Attachments: Report of Sundry Operations (Form 10 -404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Pictures of location Application for Sundry Approval (Form 10 -403) with attachment: Technical Justification Cc: Roschinger /Murphy Harry Engel Mike Bill Chris Stone Mark Sauve Gary Preble 4 STATE OF ALASKA 0 1 � ' ALASAL AND GAS CONSERVATION COMMISSIGW1,Z ,1 Q 7 a��Q y0 - �f - APPLICATION FOR SUNDRY APPROVALjd,,,gj&G83G0p3.CW . 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ C e pp ved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: RENEW SUSPENSION - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ - Exploratory ❑ 200 -2110 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22996 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ NS26 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 312799, NORTHSTAR Field / NORTHSTAR 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): 3302 3225.37 r 3202 3130 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 193 20" 169# X -56 SURFACE 193 SURFACE 193 4260 2590 Surface 3288 10 -3/4" 45.5# L -80 44 3288 44 3212 5210 2480 Intermediate 11337 7 -5/8" 29.7# L -80 43 11337 1 43 10764 1 6890 4790 Production 11915 4 -1/2" 12.6# 13CR 42 11915 42 11231 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - 4 -1/2" 12.6# 13CR SURFACE 75' Packers and SSSV TVDe: Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑� - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑� 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pr Title Data Management Engineer Signature Phone Date 564-4944 01 r , W� 1 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _ �, , h, �+�` /4G�assG Cppr aec �r Zo AAC- ZS•1 /v ''� ✓ P Subsequent Form Required: V - f - - tom+`.- R r APPROVED BY Approved by: " UMS COMMISSIONER THE COMMISSION Date: 0 = t-410- Z 7• /b Form 10 -403 Revised 1/2010 Submit in Duplicate * Northstar Unit well 26 • Technical Justification for Application for Renewal of Suspension Status October 06, 2010 Well Status Northstar Unit well 26 was suspended on 02/01/01 after the surface casing failed a pressure test after a two stage cement job. The surface casing was set at 3287'. A 9 J 9 cement plug was left from about 1700' to 1237' MD across an HES cementer. The well is not p erforated. The well is mechanically sound as indicated by a passing a pressure test to 1000 psi. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. Condition of the Wellhead and Surface Location Northstar Unit well 26 is located on Northstar Island, an active, well maintained pad with clean gravel. The area surrounding the well is in good condition. There is no discoloration and no sheens on the pad. The well pressure readings are T /I /O = NA. A_ fter the well was suspended, the cellar was filled with gravel. Request BPXA requests approval for renewal of the existing suspension status for Northstar Unit 26. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. The well does not penetrate any hydrocarbon intervals and there are no underground sources of fresh water in this area. NS26 "RIGINAL KB. ELEV = 55. r e.r S� 9.8 ppg o i, �" ' = e l, J NaCI with a 100' cap of g•��'�'``"' mineral oil on top for L 20" driven to 199' RKBmd freeze P rotect i pT to /aap pf. Cement plug from 1722' -1100' and HES cementer , @ 1622' md. 17 9.2 Ppg mud RLC IVED JAN 3 zoo 1 Kaska Ofl & Gas FC @ 3200' FS @ 3287` 10 -3/4" casing at 3287' RKBmd DATE REV. BY COMMENTS Northstar Nyf= NS26 API N0:50 -029.22996 -00 BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, • 62ECEIVED MAY ~ ~ ~~~~' ,~sk~ ~ ~ rmiss-~7~ ~n aoo - 2, ~s_a.~ 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) f Date Northstar 4/20/2010 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 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 NSi6A 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. F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 2002110 MD 3302 f TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. NORTHSTAR UNIT NS-26 Operator BP EXPLORATION (ALASKA) INC 3225 ~ Completion Dat 2/1/2001 .-/ Completion Statu SUSP ~. Current Status SUSP APl No. 50-029-22996-00-00 · -- UIC N REQUIRED INFORMATION Mud Log No Sample N.~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No D D (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH I CH 9997 FINAL 199 3302 ch Dataset Received Number Comments 5/15/2001 9997~'"'~199-3302 Digital Data 199-3302 Color Print L L L L R R L L L L D D ~[~DMudLog 1 ~"~udLog 1 -..-F~Well Report ~VDMudLog '/ 2 = j~ectional Survey ,.,Bfl~ctional Survey 9936 2 2/5 FINAL 199 3302 ch FINAL 199 3302 ch FINAL ch FINAL 199 3302 ch FINAL 199 3302 ch 220 3302 Open 199 3302 Case FINAL FINAL FINAL 115 3302 ch FINAL 115 3302 ch FINAL 220 3302 ch 5/15/2001 5/15/2001 5115/2001 5115/2001 5/15/2001 3/1/2001 5115/2001 2/14/2001 2114/2001 3/112001 3/1/2001 3/1/2001 199-3302 Color Print Final Well Report 199-3302 Color Print 199-3302 Color Print 09936 ~220-3302 ~ ~ 09997 ~'~--39-33;2 Dir Survey Digital Data Dir Survey Paper Copy 115-3302 BL, Sepia J.5-3302 BL, Sepia 9936./220-3302 Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis R ~. c.~.iv~.d '~ Daily History Received? '~ N Formation Tops Y / ~) Permit to Drill 2002110 MD 3302 TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. NORTHSTAR UNIT NS-26 Operator BP EXPLORATION (ALASKA) INC 3225 Completion Dat 211/2001 Completion Statu SUSP Current Status SUSP APl No. 50-029-22996-00-00 UIC N Comments: Compliance Reviewed By: Date: bp .. .. { coNrID£NTIAL ( Date: 05-4-2001 Transmittal Number:92090 B PXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If, 'ou have any questions, please contact me in the PDC at 564-4091 i- ¥ · - A .............. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type )NS26 01-01-2001 SPERRY - - END OF WELL REPORT; NS26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG; (COLOR) 1:600 MD; ~1S26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG; (COLOR) 1:600 TVD; NS26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG; (SEPIA) 1:600; N,~S26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG DATA (DISKETTE 1EA) /,NS26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG; (COLOR) 1:240 MD; ,b}S26 01-15-2001 SPERRY 1,2 199.00 3302.00 MUDLOG; (COLOR) 1:240 TVD; Please Sign and Return o~a-e copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc Attn: Buford Bates RECEIVED HAY 1 5 2001 Oil & Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 i~'~ STATE OF ALASKA M~ ALAS JIL AND GAS CONSERVATION CO . ..~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas I~! Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number aP Exploration (Alaska) Inc. 200-211 301-018 '3'. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ ~.,s,~.____/,__j,~ _ . 50- 029-22996-00 4. Location of well at surface r ...... r, ........ ~ ...... ~.v~.~ ~,~,,., t. 9. Unit or Lease Name 1298' NSL, 648' WEE, SEC. 11, T13N, R13E, UM ! ;Ai'~ ! [$ut~ Northstar Unit At top of productive interval i Z -o/.¢::)/ ~, N/A - Not Penetrated ..... · ~'..n~ ..... ~ {~.~ 10. Well Number At total depth ~ ' r:~,'~,,:-, ~ 1586' NSL, 1043' WEE, SEC. 11 T13N, R13E, ElM ! _~~__~..'~'""~"'"~ NS26 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 11. Field and Pool Northstar Field KBE = 55.39' ADL 312799 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 1/15/2001 1/26/2001 2/1/2001 39' MSL I Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 3302 3225 ETI 3200 3130 FTJ [] Yes [] NoI N/A MD] 1545' (Approx.) 22. Type Electdc or Other Logs Run GR, DIR 23. CASING, LINER AND CEMENTING RECORD CASING SE-l-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 169# X-56 Surface 193' Driven 10-3/4" .45.5# . L-80 44' 3288' 13-1/2" 1499 sx PF 'E', 345 sx C!~_~s 'G' · ......... ,, ............. ...................... ,, .................................. ................................. 24. Perforations .open to. P~d'ucti.on (M.D+.TVD of TOp ahd ..... 25. ' ........ ~rU~,Ne' R~c~RD .......... Bottom and ~merval, raze uno number) ........ S~ZE ......... DEPTH SET (~D) ........... 'PAt~KER"SE-r' (t~'D) ...... None 4'1/2'i, i2.6#, 13Cr .......... 75' ' ............ MD TVD MD TVD ...... 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1237'- 1700' Balanced Cement Plug, 336 sx Class 'C' Freeze Protected with 9.8 ppg NaCI 27. PRODUCTION TEST r'~ r'~ I rTM ~ ~. I ~. ~ Date First Production Method of Operation (Flowing, gas lift, etc.) U ~, 1 ~ ! i~/L3t L~ Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-aBE GAS-MCF WATER-aBE CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-aBE GAs-MCF WATER-aBE OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. ' ..... CORE DATA ' ' Brief descriptio~ of lith(~logy, p'~rosity, fractures, a~Parent dips and presence of oil, gas or wate'~. S~b'~it ~0re chips. ' ..... RECEIVED MAR 0 6 2001 Alaska 0ii & Gas Cons. C0mmis, Annhnr;~n8 Form 10-407 Rev. 07-01-80 submit In Duplicate 29. 30. Geologic Markers Formation Tests , Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. , N/A RECEIVED 06 2001 Alaska 0ii & Gas Cons. Commission Anchorage 31. List of ~,tta6hme~t~:" ' summanj ~)f [~ail'y'Drilling Reports, su'rve~,s (~SUbmitted' SeParately by"vend0ri ........................................ ' ........... 32. I'hereby ~erti~'tl~a'i'i~e foregoing is true'and'c0rrect to"the best ~f my I~r~o~,l'edg~ .................................. Signed TerrieHubble ~.~~_, ~ Title Technical Assistant Date NS26 200-211 301-018 Prepared By Narne/Nurnbec Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. iNSTRUCTiONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: N826 Common Well Name: NS26 Spud Date: 1/15/2001 Event Name: DRILL+COMPLETE Start: 1/15/2001 End: ~Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/13/2001 08:30 - 09:00 0.50 MOB PRE Warm up and function test hydraulic system for Columbia moving 'system. ,09:00 - 18:00 9.00 MOB PRE Move rig from NS10 disposal well to NS26 conductor. 18:00 - 22:00 4.00 MOB PRE Reconnect systems between substructure and service unit. Berm rig. 22:00 - 22:00 24.00 MOB PRE Accept Rig on NS26 @ 2200 hrs. on ol/13/01. 22:00 - 00:00 2.00 MOB PRE Begin NU Diverter Line. Clearing NS10 location for handover to the production group for commissioning of disposal well. 1/14/2001 00:00 - 04:00 4.00 RIGU PRE Loosen Lockdown Screws on Vetco Diverter Adapter, Orient Diver[er Line, RD first two sections, Put Section with Drain Valve Adjacent Knife Valve. Add another 40' section. RILD Screws and Test -- Good Test. Berm around rig. 04:00 - 06:00 2.00 RIGU PRE Continue Berming around rig, set mudloggers shack, close north side cellar door and finish chinking holes with insulation and plywood. 06:00 - 09:00 3.00 RIGU PRE Remove mats from around NS10 to provide access to wells group to commission well, secure BOPs in cellar, condtion mud and put surface riser in shed. 09:00 - 10:00 1.00 RIGU >RE PJM -- RU Pipe Skate. 10:00 - 11:00 1.00 RIGU PRE Clean bottom of hydril and set bottom section of riser. 11:00 - 12:00 1.00 RIGU PRE Arrange 10-3/4" casing in pipe shed and star[ loading BHA in pipe shed. 12:00 - 13:00 1.00 RIGU PRE RU another section of 16" diver[er line and set up berm for cuttings tank. Diverter operations shut down due to high winds and crane operations. Finish cutting hole in north pile wall for diver[er exit. 13:00 - 14:00 1.00 RIGU PRE Island Evacuation Drill - Everyone loaded into the Arktos. 14:00 - 21:00 7.00 RIGU , PRE Finish installing riser and flowline. Finish Ioadinga BHA in' pipe shed. Preparing to RU diverter extension off island with loader operations -- ' PJSM with Co Rep -- Co Rep shut operation down to wait for weather conditions to become suitable to use crane to finishing assembly of diver[er line extending past the pile wall. 21:00 - 22:00 1.00 RIGU PRE PU stand of 7" collars, rmove corrosion ring. Bring 3 joints of 16" diver[er line inside of pile wall as per Co. Rep. 22:00 - 23:30 1.50 RIGU PRE Assemble two 40' + a 10' 16" diverter pipes together in preparation for the crane operations. 23:30 - 00:00 0.50 RIGU PRE Star[ changing out the saver sub and stabbing bell guide on the Top Drive from 5" to 4". 1/15/2001 00:00 - 04:00 4.00 RIGU PRE Change out pipe handler guide and saver sub f/4" HT to 4-1/2" IF. Install turnbuckles and check plugs on conductor. 04:00 - 05:00 1.00 RIGU PRE PU stand HWDP and function test diver[er. 05:00 - 06:00 1.00 RIGU PRE Drift stack with 10-3/4" hanger to landing ring with Vetco Gary '06:00 - 07:00 1.00 RIGU PRE PJM -- Write procedure and perform Hazard Risk Mitigation for Picking Up BHA. 07:00 - 09:00 2.00 RIGU PRE MU BHA while welder welds installs 4" collar and valve below the landing ring on the 20" conductor. 09:00 - 10:30 1.50 RIGU PRE Install the diverter line outside of pile wall and finish welding 4" valve on 20" conductor. 10:30 - 11:30 1.00 RIGU PRE Fill Hole and Stack -- Circulate and check knife valve and surface circulating system - no leaks. Pressure test surface line to 3500 psi. Printed: 2/26/2001 3:10:14 PM BP EXPLORATION Page 2 of 7 Operations Summar Report Legal Well Name: N826 Common Well Name: NS26 Spud Date: 1/15/2001 Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/15/2001 11:30 - 12:00 0.50 DRILL SURF Circulate and Ream while cleaning out the 20" conductor from 157' to 193' md. 12:00 - 13:00 1.00 DRILL SURF Drilling f/193' -- 206' md. Experiencing eratic torque while during the last 0.5 feet of drilling. Unable to get past this point. 13:00 - 14:30 1.50 DRILL SURF Circulate and Wait on Operator for Slickline uint. 14:30 - 16:00 1.50 DRILL SURF Run Gyro to base of conductor -- 0.5 deg inclinationa and 150 degree azimuth. 16:00 - 16:30 0.50 DRILL SURF Rig Down Slickline Unit. 16:30 - 18:30 2.00 DRILL SURF Stand back HWDP and lay down rotary BHA. Inspect BHA for signs of junk damage -- none. Bit was in good shape with no sign of rotaing on junk or metal. 18:30 - 21:00 2.50 DRILL SURF PU BHA lB. 21:00 - 00:00 3.00 DRILL SURF Drill f/206' to 400'. No problem exiting conductor -- Minor sign of torquing, but drilled thru without incident. 1/16/2001 00:00- 03:00 3.00 DRILL CIRC SURF Clean suction and discharge screens on mud pumps 1 & 2. Check and clean suction and discharge valves on pump 2. Plugged up with unsheared polymer globs. 03:00 - 12:00 9.00 DRILL SURF Drilling f/400'-1151' md. 12:00 - 13:00 1.00 DRILL SURF Drilling f/1151'-1203' md. 13:00 - 14:00 1.00 DRILL HSD SURF Report recieved from loader operator that cuttings cell #6 was leaking drilling cuttings and fluid onto pad. Ceased drilling and released rig crew to repsond to spill. Circulate and condition. 14:00 - 16:00 2.00 DRILL HSD SURF Tripped out of hole to conductor. Swabbed on,, ,-- .,,,___&rand4 with increase in flow. Shutdown hole fill and monitor well -- sta~. J~(l~'rnl~t{~tr~ I~ shoe. 16:00 - 18:00 2.00 DRILL HSD SURF Stab TIW Valve, service rig while Waiting on Or;l~r_s. 18:00- 18:30 0.50 DRILL HSD SURF RIH to TO @ 1203' md.J}v/Ail~. 0 ~) 2007 18:30 - 20:00 1.50 DRILL HSD SURF Circulate bottoms up and monitor well. Trip Gas 4 units. 20:00 - 20:30 0.50 DRILL HSD SURF POOH to Shoe -- Hole fill good. '4'~aska 0il & Gas Corls. 20:30-00:00 3.50 DRILL ODR SURF Housekeeping and Service Rig. 1/17/2001 00:00- 08:30 8.50 DRILL OTHR SURF Monitor well on trip tank. Well taking a average of lng morning tour. Clean and organize rig. ACS continue to clean up spilled material from disposal pit cell ~6. 08:30 - 11:00 2.50 DRILL OTHR i SURF PJSM - L/D Motor, MWD, and Stabilizer. 11:00 - 12:00 1.00 DRILL OTHR !SURF M/U new BHA. Bit, B/S, Stab, 2-L/C, Stab, 3-Monel D/C, X-O. Total length = 129.96' 12:00- 13:00 1.00 DRILL OTHR SURF Monitor well on trip tank. Continue to clean and organize rig. ACS continue spill clean up. 13:00 - 13:30 0.50 DRILL OTHR SURF GIH for wiper trip. Tag up 17' off bottom. M/U top drive. Rotate thru. 13:30 - 14:30 1.00 DRILL OTHR SURF Circulate bottoms up. Max gas 2 units. 14:30 - 15:30 1.00 DRILL OTHR SURF POOH to 130'. First 2 stds pulling tight. M/U top drive and pump out 2 stds out. Continue POOH slick. 15:00- 00:00 9.00 DRILL OTHR SURF Monitor well on trip tank. Well taking an average 0.2 bph last 12 hr tour. Continue to clean and organize rig. ACS continue spill clean up. 1/18/2001 00:00 - 01:30 1.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and . organize rig. ACS continue spill clean up. 01:30- 02:30 1.00 DRILL OTHR SURF GIH for wiper trip. Hole slick. No Problems. 02:30- 03:00 0.50 DRILL OTHR SURF Circulate bottoms up. Maxgas 2 units. 03:00- 04:30 1.50 DRILL OTHR SURF POOH. First std tight. M/U top drive and pump first std out. Continue POOH slick without top drive. 04:30- 13:00 8.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. BP spill investigation team on location. Printed: 2126/2001 3:10:'14 PM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: N826 ,Common Well Name: NS26 Spud Date: 1/15/2001 ~ Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/18/2001 13:00- 14:00 1.00 DRILL OTHR SURF GIH for wiper trip. Hole slick. No problems. 14:00 - 14:30 0.50 DRILL OTHR SURF Circulate bottoms up. Max gas 4 units. 14:30 - 16:30 2,00 DRILL OTHR SURF POOH. Pull off bottom slick. Start pulling wet. M/U top drive and circulate 500 stks. Continue POOH slick. 16:30- 00:00 7.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. 1/19/2001 00:00- 00:30 0.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. Continue disposal well tie in. 00:30- 01:00 0.50 DRILL OTHR SURF GIH forwiper trip#4. Hole slick. No problems, 01:00- 02:00 1.00 DRILL OTHR SURF Circulate bottoms up. Max gas 3 units. 02:00- 03:00 1.00 DRILL OTHR SURF POOH. Hole slick. No problems, 03:00- 13:00 10.00 DRILL OTHR SURF Monitor well on trip tank, Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. Continue disposal well tie in. 13:00- 13:30 0.50 DRILL OTHR SURF GIH for wiper trip #5, Hole slick. No problems. 13:30 - 15:00 1.50 DRILL ,OTHR SURF Circulate bottoms up. Max gas 3 units, 15:00- 15:30 0.50! DRILL 'OTHR SURF POOH. Hole slick. No problems, 15:30- 00:00 8.50' DRILL OTHR SURF Monitor well on trip tank, Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. Continue disposal well tie in.. 1/20/2001 00:00- 01:30 1.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. Continue disposal well tie in. 01:30- 02:30 1.00 DRILL OTHR SURF GIH for wiper trip #6. Hole slick. No problems. 02:30- 03:30 1.00 DRILL OTHR SURF Circulate bottoms up. Maxgas 3 units. 03:30- 05:00 1.50 DRILL OTHR SURF Blow down tp drive and mud line. POOH. Hole slick. No problems. 05:00 - 12:30 7,50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Continue to clean and organize rig. ACS continue spill clean up. Continue disposal well tie in. 12:30- 13:00 0.50 DRILL OTHR SURF GIH for wiper trip #7. Holeslick. No problems. 13:00- 14:00 1.00 DRILL OTHR SURF Break circulation. Break offtop drive and drop carbide lag. M/U top drive and circulate out carbide lag. Lag strokes show gauge to slightly over gauge hole. 14:00 - 14:30 0.50 DRILL OTHR SURF Blow down top drive and mud line. POOH. Hole slick. No problems. 14:30- 00:00 9.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0,2 bph. Continue to clean and organize rig. Continue disposal well tie in. On site spill clean up complete, Waiting for ice road completion to haul spilled material to Drill Site 4 for disposal. 1/21/2001 00:00- 02:00 2.00 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Change out control valve on iron roughneck. Continue to clean and organize rig, Continue G&I PSSR preparations. Continue NS10 disposal well tie in. 02:00 - 04:00 2.00 DRILL OTHR SURF Start P/U additional 5" drill pipe GIH on wiper trip. Additional 5" drill pipe will be used for 9 7/8" hole section. Hydraulic cylinder leaking on pipe skate. Stop P/U drill pipe. Continue GIH for wiper trip #8 Hole slick. No problems. 04:00 - 05:30 1.50 DRILL OTHR SURF Break circulation. Break off top drive and drop carbide lag. M/U top drive and circulate out carbide lag. Lag strokes show slightly over gauge hole. 05:30- 07:00 1.50 DRILL OTHR SURF Blow down top drive and mud line, POOH. Hole slick. No problems. 07:00- 08:30 1.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Clean rig. Rig Maintenance. Continue G&I PSSR preparations. Continue NSIO disposal well tie in. 08:30 - 09:30 1.00 DRILL OTHR SURF PJSM for blowing down G&I injection line, diverter function test, and welding starting ring on NS27. 09:30- 23:30 14.00 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Clean rig. Rig Maintenance. Continue G&I PSSR preparations. Continue NSIO disposal well tie in. Weld on NS27 starting ring. Finish building ×-O for Printed: 2/26/2001 3:10:14 PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: N826 Common Well Name: NS26 Spud Date: 1/15/2001 Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/21/2001 09:30 - 23:30 14.00 DRILL OTHR SURF G&I injection hose tie into the pipe rack. Finish modifiying G&I vacuum system air intake. 23:30 - 00:00 0.50 DRILL OTHR SURF Start P/U additional 5" drill pipe GIH on wiper trip #9. Additional 5" drill pipe will be used for 9 7/8" hole section. Hole slick. No problems. 1/22/2001 00:00- 01:00 1.00 DRILL OTHR SURF Continue P/U 5" drill pipe GIH for wiper trip #10. Hole slick. No ~roblems. 01:00 - 02:00 1.00 DRILL OTHR SURF Break ciculation. Break off top drive and drop carbide lag. M/U top drive and circulate carbide. Lag stroke show slightly over gauge hole. Trip gas 3 uits. 02:00 - 03:30 1.50 DRILL OTHR SURF Blow down top drive and mud line. POOH to 130'. Hole slick. L/D 1 drill collar. 03:30 - 05:30 2.00 DRILL OTHR I SURF Drain riser. HVAC currently limited on how fast fluids can be sucked up (Quadco discusing problem with manufacture). Perform diverter function test. Close in 35 seconds. P/U single drill collar. M/U X-O and TIW. 05:30- 20:00 14.50 DRILL OTHR SURF Monitor well on trip tank. Well taking 0.2 bph. Slip and cut 102' drill line. Clean rig. Rig maintenance. Continue G&I PSSR preparations. Continue NS10 tie in. M/U X-O and injection hose between rig and pipe rack. Test complete injection line system between G&I pump to NS10 tree to 3500 psi. Test OK. 20:00 - 21:30 1.50 DRILL OTHR SURF Continue P/U 5" drill pipe GIHfor wiper trip #11. Hole slick. No 3roblems. P/U a total of 17 of 34 stds needed for 9 7/8" hole section. Stop P/U drill pipe to allow room to get surface casing tools on rig floor. 21:30 - 00:'00 2.50 DRILL OTHR SURF Break ciculation. Break off top drive and drop carbide lag. M/U top drive and circulate carbide. Lag stroke show slightly over gauge hole. Trip gas 3 uits. 1/23/2001 00:00 - 00:30 0.50 DRILL OTHR SURF Finish circulating out carbide lag. Lag strokes show slighlty over gauge hole. Trip gas 3 units. 00:30- 01:30 1.00 DRILL OTHR SURF Blow down top drive and mud line. POOH to 130'. Hole slick. No 3roblems. 01:30- 12:30 11.00 DRILL OTHR SURF Monitor well on trip tank. Well taking -0.2 bph. Repair hydraulic cylinder on pipe skate. Welder continue to fill in and cover holes / cracks on rig floor. Put rig on cold start. Simulate gas inlet line leak by closing valve up stream of the Iow gas pressure sensor. The remote valve in the let skid functioned closed properly. Operations re-set let down skid valve. Put rig back on gas. 12:30-13:00 0.50 DRILL OTHR SURF GIH for wiper trip #12. Holeslick. No Problems. 13:00 - 14:30 1.50 DRILL OTHR SURF M/U top drive and break circulation. Back out top drive and drop carbide lag. Continue to circulate out lag. Lag strokes continue to show slighlty over gauge hole. Max trip gas 3 units. 14:30 - 15:30 1.00 DRILL OTHR SURF Blow down top drive and mud line. POOH to 130'. Hole slick. No 3roblems. 15:30-00:00 8.50 DRILL OTHR SURF Monitor well on trip tank. Welltaking,,.0.2bph. Welder continue to fill ~n and cover holes / cracks on rig floor. Replace drag chain motor gear box from 10:1 to 5:1 to allow for better speed control. :1/24/2001 00:00 - 08:00 8.00 DRILL OTHR SURF Monitor well on trip tank. Well taking -0.2 bph. Welder continue to fill in and cover holes / cracks on rig floor. Replace drag chain motor gear box from 10:1 to 5:1 to allow for better speed control. 08:00- 09:00 1.00 DRILL OTHR SURF GIH for wiper trip #13. Hole slick. No problems. 09:00 - 10:00 1.00 DRILL OTHR SURF M/U top drive and break circulation. Back out top drive and drop 'carbide lag. Continue to circulate out lag. Lag strokes continue to show slighlty over gauge hole. Max trip gas 3 units. 10:00 - 11:00 1.00 DRILL OTHR SURF Blow down top drive and mud line. POOH to 130'. Hole slick. No Printed: 2/26/2001 3:10:14 PM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: N826 Common Well Name: NS26 Spud Date: 1/15/2001 Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/24/2001 10:00- 11:00 1.00 DRILL OTHR SURF problems. 11:00 - 00:00 13.001 DRILL OTHR SURF Monitor well on trip tank. Well taking -0.2 bph. Re-position EPOCH monitor down to Driller's console. EPOCH re-program mud monitoring system. Complete G&I and NS10 well PSSR. Appropriate personnel sign off that G&I and NS10 well are ready for injection. G&I preparing to begin injection. 1/25/2001 00:00 - 11:30 11.50 DRILL SURF Monitor well on trip tank. Well taking -0.2 bph. G&I complete risk analysis for injecting fluids, Begin injecting fluids. Shut down for repairs on both injection pumps. Continue injecting fluids. Rig P/U motor and MWD and GIH to 185' and wait until G&I finish injecting fluids, 11:30 - 12:00 0.50 DRILL SURF GIH to 1203'. Hole slick. No problems, 12:00 - 00:00 12.00 DRILL SURF Drill and slide from 1203' to 2459'. Fluid and cuttings transfer from rig drag chain to G&I OK. G&I continue process waste from rig and inject as needed. AST 4 1/2" hrs ART 5 hrs P/U wt 145, S/O wt 145, Rot wt 140 1/26/2001 00:00 - 13:00 13.00 DRILL SURF Drill and slide from 2459' to hole TD 3302' MD 3225' TVD. AST 1hr ART 6 hrs. 13:00 - 16:00 3.00 DRILL SURF Pump 2 hi-vis sweeps. Circulate out. Set back 1 std every 30 minutes. 16:00 - 21:30 5.50 DRILL SURF POOH for wiper trip. Hole tight from 2424' to 2329', Back ream thru tight spots. Continue POOH slick to 20" shoe at 200'. 21:30 - 22:00 0.50 DRILL SURF Clean rig floor. 22:00 - 00:00 2.00 DRILL SURF GIH to 3302' TD. Hole slick. No problems. 1/27/2001 00:00 - 03:00 3.00 DRILL SURF Pump hi-vis sweep. Circulate and condition mud for running casing. 03:00 - 06:00 3.00 DRILL SURF PJSM - Drop ESS. Pump slug. POOH to run casing. Hole slick. No problems. ESS maTCH mwd. 06:00 - 08:30 2.50 DRILL SURF PJSM - L/D 13 1/2" BHA. 08:30 - 11:00 2.50 DRILL SURF PJSM - Clear rig floor. R/U 10 3/4" casing tools. 11:00 - 19:30 8,50 DRILL SURF PJSM - Baker lock bottom 3 jts. R/U casing ~l-up tool, Continue running a total of 78 jts 10 3/4" 45.50~ L-80 BTC casing. Special drift to 9,875". Run straight blade rigid centralizers on 1st 15 jts and 1 each side of the ES cementer. M/U hanger and landing joint. Hole slick. No problems.' F/S at 3287,82'. L/C at 3199,94', ES cementer at 1622.62'. 19:30 - 23:00 3.50 DRILL SURF R/D ~l-up tool. R/U Halliburton cementing head and hose, Circulate and condition mud for cementing. Hold PJSM for cementing while circulating. 23:00 - 00:00 1.00 DRILL SURF Mix and pump 1st stage cement, Lead - Permafrost E, 210 sks, Wt 12.0, Yield 2.17. Tail - Premium (3, 350 sks, Wt 15,8, Yield 1.15. Maintain full returns, Reciprocate casing 10 ft only to keep hanger out of Hydril until bump plug. Bump plug at calculated strokes. POB at 0108 hrs 1/28/01. Check BPV, OK. 1/28/2001 00:00 - 03:30 3.50 DRILL SURF Finish 1st stage cement job. Bump plug at calculated stks. POB at 0108 hrs. Pressure up to 2300 psi and open ES cementer. Small amount of cement returns observed from ES cementer. Continue to circulate for 2nd stage cement job, Hold PJSM for 2nd stage while circulating, 03:30 - 06:30 3.00 DRILL SURF Mix and pump 2nd stage cement until cement is at surface. Tail - Permafrost E, 1290 sks, 498 bbls, Wt 12.0, Yield 2.17. Drop plug and displace with mud. Bump plug at calculated stks. POB at 0603 hrs. Close ES cementer with 1000 psi, Bleed off pressure. Check for flow. No flow. Note: Identified bottle neck in (3&l being able to handle fluids at higher rates (6 bpm) from rig and made modifications while running casing. (3&l handled the diverted fluid OK at 6 bpm from the 2nd stage Printed: 2/26/2001 3:10:14 PM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: N826 Common Well Name: NS26 Spud Date: 1/15/2001 'Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/28/2001 03:30 - 06:30 3.00 DRILL SURF cement returns. 06:30 - 09:00 2.50 DRILL SURF PJSM - Flush out 20" riser and diverter with seawater. L/D landing joint. R/D casing tools. Change bails and elevators. 09:00 - 14:00 5.00 DRILL SURF PJSM with AIC - R/D diverter line in rig cellar and move outside. N/D flowline. Lift 20" diverter off NS10 on set on NS27. Vetco Gray test connection to 1000 psi. OK. 14:00 - 15:30 1.50 DRILL SURF PJSM with Vetco Gray - Bring wellhead into rig cellar. N/U wellhead and test to 1000 psi. OK. 15:30 - 22:00 6.50 DRILL SURF PJSM - Hook bridge crane to BOPS and set on wellhead. Change 4" rams to 5" rams. Finish N/U BOP equipment. Function test BOPS. Clean cellar area. 22:00 - 00:00 2.00 DRILL SURF PJSM - Set BOP test plug. P/U test joint and R/U to pressure test BOPS. AOGCC Lou Grimaldi waived witness of BOP test 0900 hrs 1/27/01. 1/29/2001 00:00 - 01:30 1.50 OTHR INT1 Rebuild air pump on BOP test pump. 01:30 - 10:00 8.50' INT1 Test BOPS. Hydril 250-3500 psi. Rams, associated valves, choke manifold, floor valves to 250-5000 psi. 10:00 - 12:00 2.00 INT1 Attempt to N/U bell nipple and flowline. R/U testing equipment on rig floor to test top drive, kelly hose, and standpipe manifold. Cross thread bolts on bell nipple. Pull out and re-tap same. N/U bell nipple. 12:00 - 13:30 1.50 INT1 Pressure test top drive, kelly hose, stand pipe manifold to 250-5000 psi. 13:30 - 14:00 0.50 INT1 Blow down top drive and mud line. 14:00 - 15:30 1.50 OTHR INT1 Air boot on bell nipple started leaking. Replace air boot. 15:30 - 19:00 3.50 INT1 M/U bit, motor, MWD, CDR, and GIH with BHA. 19:00 - 20:00 1.00 DRILL INT1 P/U singles and GIH with 5" drill pipe to 1600'. 20:00 - 20:30 0.50 DRILL INT1 M/U top drive and pressure test casing to 1000 psi before drilling out ES cementer. Test OK. 20:30 - 00:00 3.50 DRILL INT1 Tag up ES cementer closing plug at 1621'. Start drilling out ES cementer. Experience bit being pumped off bottom. Kick out pump and P/U off bottom to clear rubber from under the bit and motor stabilizer. Did not notice any unusual surface torque with bit while drilling out ES cementer until the motor stabilizer entered the ES cementer. 1/30/2001 00:00 - 01:30 1.50 DRILL INT1 Finish drilling out ES cementer at 1622'. 01:30 - 02:00 0.50 DRILL INT1 Attempt to test casing to 1000 psi to ensure ES cementer has not opened. Pumping away at 500-600 psi at 4 bpm. Shut down pump. Pressure bleed down to 300-400 psi and stabilize. Check surface equipment for leaks. No leaks. Discuss operation with Superintendent and Drilling Engineers. 02:00- 08:00 6.00 DRILL FLTS INT1 POOH and L/D BHA. GIH with HWDP. POOH with HWDP and rack back on opposite of derrick. 08:00 - 09:30 1.50 DRILL FLTS INT1 P/U mule shoe and GIH with 5" drill pipe to 1700'. 09:30 - 11:00 1.50 DRILL FLTS INT1 Circulate hi-vis sweep around at 1700'. 11:00- 11:30 0.50 DRILL FLTS INT1 Peform LOT on suspected casing leak at-1622'. E-mail datato Engineer. 11:30 - 17:00 5.50 DRILL FLTS INT1 Waiting on orders. Preparing rig for possible P&A and move to NS27. Monitor well on trip tank at 1605'. PJSM on P&A operations. 17:00- 17:30 0.50 DRILL FLTS INT1 GIH to 1891'. 17:30 - 18:00 0.50 DRILL FLTS INT1 Spot hi-vis pill barrier for cement plug. 18:00- 18:30 0.50 DRILL FLTS INT1 POOH 2 stdsto 1704'. 18:30- 19:00 0.50 DRILL FLTS INT1 Circulate 2 bottoms up. 19:00 - 19:30 0.50 DRILL FLTS INT1 Mix and pump cement balance plug from 1700' to 1100'. Class C + 0.17 Ib/sk sodium citrate, 336 sks, 56.9 bbls, Wt 15.7, Yield 0.95. Rig Printed: 2/26/2001 3:10:'14 PM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: NS26 Common Well Name: NS26 Spud Date: 1/15/2001 Event Name: DRILL+COMPLETE Start: 1/15/2001 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 33E Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/30/2001 19:00 - 19:30 0.50 DRILL FLTS INT1 displace with mud and balance cement plug. 19:30 - 20:00 0.50 DRILL FLTS INT1 POOH 10 stds (first 8 stds very slow) to 1041'. 20:00 - 20:30 0.50 DRILL FLTS INT1 Circulate 3 botoms up. Did not see any cement returns at surface. 20:30 - 21:00 0.50 DRILL FLTS INT1 Finish POOH to surface. 21:00 - 22:30 1.50 DRILL FLTS INT1 Change bails from long to short. M/U mill tooth bit and X-O. 22:30 - 00:00 1.50 DRILL OTHR INT1 Change out offside Driller tugger line. 1/31/2001 00:00- 01:30 1.50 DRILL FLTS INT1 Clean Rig whileWOC. 01:30- 03:00 1.50 DRILL FLTS INT1 TIH and Tagged Cement at 1237' md w/20K. 03:00 - 03:30 0.50 DRILL FLTS INT1 Press Test Cement Plug to 1000 psi for 5 rain -- OK -- Chart. 03:30 - 05:00 1.50 DRILL FLTS INT1 Displace the hole with 9.8 ppg sea water at 40 spm & 100 psi. 05:00- 07:00 2.00 DRILL FLTS INT1 POOH & LD Hydra Jars and PU 1 jt HWDP. 07:00- 08:30 1.50 DRILL FLTS INT1 Pull Wear Bushing, pumped 8 bbls mineral oil. Blow down mud and kill line. 08:30- 12:00 3.50 DRILL FLTS INT1 PU 1 jt 4-1/2" chrome tbg. MU tubing hanger, pu 4-1/2" tubing elevators. PU 4-1/2" tubing hanger landing joint, land hanger, ran BPV and Test to 500 psi. 12:00 - 13:00 1.00 DRILL FLTS INT1 PJSM -- Test BPV to 500 psi through annulus for 10 minutes -- Good Test. 13:00- 17:00 4.00 DRILL FLTS INT1 Prep Rig for Move. 17:00 - 00:00 7.00 DRILL FLTS INT1 Weld base plate on NS27 and Thaw and Unload cuttings out of cuttings tank. 2/1/2001 00:00 - 03:00 3.00 DRILL INT1 Thawing and Unloading Cuttings Tank 03:00 - 04:00 1.00 DRILL INT1 Drag Cuttings tank to North 30 feet with Loaders. Printed: 2/2612001 3:10:14 PM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Northstar Well ..................... : NS26 API number ............... : 50-029-22996-00 Engineer ................. : J. Rathert Rig: ..................... : Nabors 33E w..~3tate: ................... : Alaska Survey calculation methods- Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Floor GL above permanent ....... : 15.57 ft KB above permanent ....... : 55.39 ft DF above permanent ....... : 55.39 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point .... '~--Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 305.92 degrees -CONFIDENTIAL 30-Jan-2001 15:50:43 Page 1 of 3 Spud date ................ : 15-Jan-01 Last survey date ......... : 30-Jan-01 Total accepted surveys...: 37 MD of first survey ....... : 0.00 ft MD of last survey ........ : 3302.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 14-Jan-2001 Magnetic field strength..: 1149.76 HCNT Magnetic dec (+E/W-) ..... : 26.89 degrees Magnetic dip ............. : 80.91 degrees MWD survey Reference Criteria Reference G .............. : 1002.69 mGal Reference H .............. : 1149.76 HCNT Reference Dip ............ : 80.91 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.89 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N).; ...... : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_1C_08] FEB 1 2 200 ,,, Alaska Oil & Gas Cons. Commission Anchorage ' ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 15:50:43 Page 2 of 3 ___ Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 190.00 0.50 150.00 190.00 3 263.64 0.49 127.40 73.64 4 292.16 0.51 125.69 28.52 5 382.60 0.24 110.07 90.44 6 471.90 0.24 111.48 7 564.76 0.74 316.36 8 655.76 0.98 303.49 9 745.22 0.94 308.07 10 835.52 1.05 305.72 89.30 92.86 91.00 89.46 90.30 11 930.55 0.23 351.74 12 1025.67 0.27 44.17 13 1120.08 0.21 40.52 14 1213.11 0.30 32.17 15 1307.41 0.43 20.38 95.03 95.12 94.41 93.03 94.30 16 1401.20 0.81 326.18 17 1495.85 1.40 313.90 18 1589.94 3.93 311.73 19 1687.47 6.69 311.39 20 1780.69 7.96 308.85 93.79 94.65 94.09 97.53 93.22 21 1874.38 8.81 306.94 22 1968.83 10.37 308.28 23 2063.43 12.42 306.79 24 2157.09 14.11 307.27 25 2252.93 16.56 307.74 93.69 94.45 94.60 93.66 95.84 26 2347.68 18.97 306.52 27 2442.49 19.53 306.16 28 2536.50 20.40 305.06 29 2630.95 21.22 303.43 30 2726.52 20.80 303.69 94.75 94.81 94.01 94.45 95.57 [ (c) 2001 Anadrill IDEAL ID6_1C_08] TVD Vertical DisPl Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 190.00 -0.76 -0.72 0.41 0.83 263.63 -1.37 -1.19 0.83 1.45 292.15 -1.61 -1.34 1.03 1.68 382.59 -2.20 -1.64 1.53 2.24 471.89 564.75 655.74 745.19 835.47 930.50 1025.62 1120.02 1213.05 1307.35 1401.14 1495.77 1589.75 1686.85 1779.31 1872.00 1965.12 2057.85 2149.01 2241.43 2331.66 2421.17 2509.53 2597.82 2687.03 -2.56 -1.77 1.88 2.58 -2.16 -1.41 1.65 2.17 -0.80 -0.55 0.59 0.81 0.69 0.32 -0.62 0.70 2.26 1.26 -1.88 2.26 3.27 1.96 -2.61 3.27 3.37 2.31 -2448 3.39 3.32 2.60 -2.22 3.42 3.32 2.94 -1.98 3.54 3.43 3.48 -1.72 3.88 4.15 4.36 -1.97 4.78 5.92 5.72 -3.17 6.54 10.27 8.66 -6.41 10.77 19.25 14.64 -13.17 19.69 31.10 22.28 -22.27 31.50 44.76 30.66 -33.05 45.09 60.48 40.28 -45.51 60.77 79.16 51.64 -60.34 79.42 100.65 64.59 -77.49 100.88 125.98 80.03 -97.59 126.21 154.88 97.46 -120.65 155.10 186.14 115.98 -145.83 186.33 218.24 134.67 -171.93 218.39 251.77 153.54 -199.67 251.88 286.01 172.48 -228.22 286.07 At DLS Srvy Azim (deg/ tool (deg) i00f) type 0.00 0.00 TIP 150.00 0.26 GYR 145.20 0.26 MWD 142.49 0.'09 MWD 136.91 0.32 MWD 133.25 0.01 MWD 130.47 1.04 MWD 132.91 0.34 MWD 297.46 0.10 MWD 303 . 93 0.13 MWD 306.89 0.95 MWD 312.93 0.24 MWD 319.57 0.07 MWD 326.07 0.10 MWD 333.67 0.16 MWD 335.70 0.70 MWD 330.97 0.67 MWD 323.50 2.69 MWD 318.04 2.83 MWD 315.02 1.41 MWD 312.85 0.95 MWD 311.51 1.67 MWD 310.56 2.19 MWD 309.81 1.81 MWD 309.35 2.56 MWD 308.93 2.57 MWD 308.50 0.60 MWD 308.07 1.01 MWD 307 . 56 1.06 MWD 307.08 0.45 MWD FEB I g Z09 Alaska Oil & Gas Cons. Commission Tool qual type -- -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 30-Jan-2001 15:50:43 Page 3 of 3 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) 31 2820.37 21.18 303.95 93.85 2774.65 32 2914.26 20.74 303.66 93.89 2862.33 33 3008.85 20.60 303.79 94.59 2950.83 34 3102.89 20.74 305.65 94.04 3038.82 35 3196.16 20.51 306.38 93.27 3126.11 36 3230.64 20.24 306.17 34.48 3158.43 Survey Projected to total depth: 37 3302.00 20.60 306.00 71.36 3225.31 Vertical Displ section +N/S- (ft) (ft) 319.60 191.19 -256.15 319.64 306.74 0.42 353.17 209.88 -284.06 353.18 306.46 0.48 386.53 228.42 -311.83 386.54 306.22 0.16 419.72 247.32 -339.11 419.72 306.10 0.71 452.57 266.64 -365.68 452.57 306.10 0.37 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 464.57 273.74 -375.36 464.58 306.10 0.81 MWD 6-axis 489.47 288.41 -395.48 489.47 306.10 0.51 Projection [(c)2001 Anadrill IDEAL ID6 lC 08] Alaska Oil & Gas Cons, Commission Anchorage bp BPXA WELL DATA TRANSMITTAL Date: 02-27-2001 Transmittal Number:91958 Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NS26 01-15-2001 SCH 1,2 199 3234 MEASURED DEPTH LOG; 'COMPOSITE FINAL PRINT; NS26 01-15-2001 SCH 1,2 199 '3234 TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 (2BL). Tim Putnam MB3-6 (1BL) AOGCC, Howard Okland (1BL/1RS/CD) Buford Bates, Murphy Exploration (Alaska), Inc (1BL/1RS/CD) ' Tim J. Ryherd, Division of Natural Resources (1BL) MMS, (1BL/1RS/CD) Petrotechnical Data Center LR2-1 900 E. Benson Btvd. PO Box 196612 ' Anchorage, AK 99519-6612 bp BPXA WELL DATA TRANSMITTAL Date: 01-08-2001 Transmittal Number:91921 Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Title Media NS26 SURVEY REPORT PAPER NS26 SURVEY REPORT DISKETTE Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Jim Seccombe MB 12-3 AOGCC, Attn: Howard Okland Murphy Exploration (Alaska), Inc. DNR MMS RECEIVED VE 3 1 2 ZO0 Alaska Oil & Gas Cons. Commission Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASK,(' ,L AND GAS CONSERVATION COMi(" APPLICATION FOR SUNDRY APPROVAL .~ION 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1298' NSL, 648' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 3240' NSL, 3326' WEL, SEC. 11 T13N, R13E, UM (Planned) At effective depth At total depth 3367' NSL, 3503' WEL, SEC. 11 T13N, R13E, UM (Planned) [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Type of well: [] Development [] Exploratory [] Stratigraphic [] Service i6. Datum Elevation (DF or KB) Planned RKB = 55.8' 7. Unit or Property Name Northstar Unit 8. Well Number NS26 9. Permit Number 200-211 10. APl Number 50- 029-22996-00 11. Field and Pool Northstar Field 12. Present well condition summary Total depth: measured Effective depth: Casing 3302 feet true vertical 3225 feet measured 3200 feet true vertical 3130 feet Structural Conductor Surface Intermediate Production Liner Length Size 193' 20" 3244' 10-3/4" Plugs (measured) Junk (measured) Cemented Driven 1499 sx PF 'E', 345 sx 'G', MD 193' 3288' TVD 193' 3212' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED JAN 3 0 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation January 30, 2001 16. If proposal was verbally approved Name of approver~~d~ Date Approved I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Steve Chesher, 564-4196 Prepared By Name/Number: Sondra Stewman, 564-4750 17. I hereby ~ertify;'th'at the foregoing is tru'e and c~r~ect t~ the best ~)f my I~r{owledge ......... ~i~ned FiZz ~'" Title Senior Drilling Engineer Date Conditions of Approval: Notify Commissio,~.so representative may witness Plug integrity /~ BOP Test Location clearance Mechanical Integrity Test~ Subsequent form required 10- ~'"~'~"~ ORIGINAL SIG~',~i~: ~ Approved by order of the Commission Form 10-403 Rev. 06/15/88 - ' -" ORIGINAL Approval No..~l '" O[~' Commissioner Date0,~ ~- ~)/~ Submit In Triplicate NS26 Suspension Procedure Background: The NS26 drilled a 13-1/2" hole to 3302' md/3225' tvd with a 9.2 ppg mud. A string of 10-3/4" casing was run to 3287' md and cemented in two stages. The first stage cement job had full returns throughout, the tail slurry on the first stage was a 15.8 ppg 'G' and the plug was bumped and the floats checked. The HF, S cementer at 1622' md was opened and the second stage cement was pumped with cement being circulated to surface. The HES cementer was closed and the pressure bled off. The diverter was nippled down, the wellhead system installed, BOP's nippled up and tested. A 9-7/8" PDC bit on a motor was run. The bit tagged up at 1620'. The casing above the HES cementer was tested to 1000 psi - OK. The HES cementer was drilled out with excessive torque and stalling of the bit. After the HES cementer was drilled, the bit Was worked through the area twice. The bit was pulled above the cementer. A pressure test was attempted but would pump in at 500-600 psi. The PDC bit was pulled and was rung out. All indications are that there is a hole in the casing or the HES cementer is leaking. Forward Plan: . . 3~ . . RIH with open ended 5" DP to +/-1922'. Circulate the well clean with 9.2 ppg mud. Spot a viscous freshwater, bentonite plug up to 1722'. Pull up to 1722' and circulate clean. Spot Permafrost 'C' 15;7 ppg cement plug from 1722' - 1100'. Pull up to 1100' and circulate the wellbore clean with 9.2 ppg mud. POOH. RIH with bit. Circulate on top of the cement. WOC. Pressure test the cement plug to 1000 psi. For freeze protect, displace the wellbore with 9.8 ppg NaC1 brine from 1100' - 100' md. Pull up and put a cap of mineral oil from 100' to surface. ND BOPE. NU suspension cap. Move rig to next well. RECEIVED J/iN 3 0 ~00! Alaska 0il & Gas Cons. Commission Anchorage · ( NS26 ,,O,.AL Ks. ELEV = . ~ , k 20" driven to 199' RKBmd i I ; ~ 9.2 ppg mud HES cementer !1 [] @ 1622' md. , , ' REC Alaska Oil & FO @ 3200'~ FS @ 3287' ' ~"/////~/,'.. 10-3/4" casing at 3287' RKBmd DATE REV. BY COMMENTS Northstar WELL-.NS26 APl NO:50-029-22996-00 BP Exploration (Alaska) 0 2001 ,ons. Commission rage HES cementer @ 1622' md. FC @ 3200' FS @ 3287' NS26 - P~°-<~b (~,IGINAL KB. ELEV = 55.77' 9.8 ppg NaCI with a 100' cap of mineral oil on top for freeze protect 9.2 ppg mud 20" driven to 199' RKBmd Cement plug from 1722' - 1100' md RECE JAN 3 Alaska Oil & Gas Co, Anchora 10-3/4" casing at 3287' RKBmd DATE REV. BY COMMENTS ~ WELL'.NS26 APl NO:50-029-22996-00 BP Exploration (Alaska) ZOO1 Commission 10:SBAM BP× ENDICOTT DEVF NS26 HES cementer 1622' md. FC ~ 3200' FS @ 3287' 9.8 ppg NaCl with a 100' cap of mineral oil on top for freeze protect 9.2 ppg mud DATE REV, BY coMMENTS ,,, _, - ~. 4/4 '?'GINAL KB. I=Lt=V -, 55.77', 20" driven to 199' RKBmd Cement plug from 1722' - 1100' md 10-3/4" casing at 3287' RKBmd ~.~,~N$26 APl NO:50.029.22996.~)~ BP Exploration (Alaska) JAN 38 '81 10:5?AM BP× ENDICOTT DEVP ~,~ NS26 t~'~."-'GINAL KB. ELEV = 55.?'?' · k 20" driven to 199' RKBmd 9.2 ppg mud @ 1622' md, , I I RECEIVED FC ~ 32.00' : ...... FS @ 3287' '- - '., 10-3/4" casing at 3287' RKBmd i; .... iii .i DATE IREV.,..Y COMMENTS ....... , '" ~;.[,~N~26 -, - AP! NO.'50-029-22996.00 ,, ,,,i ' ........ ? BP Exploration (Alaska) 'O1 10:$?AM BPX ENDICOTT DEVP P.~4 NS26 Suspension Procedure Background: The NS26 drilled a 13-1/2" hole to 3302' md/3225' tvd with a 9.2 ppg mud. A string of 10-3/4" casing was run to 3287' md and cemented in two stages. The first stage cement job had full returns throughout, the tail slurry on the first stage was a 15.8 ppg 'G' and the plug was bumped and the floats checked. The Hl~S cementer at 1622' md was ope~aed and the second stage cement was pumped wi~ cement being circulated to surface. The HES cementer was closed and the pressure bled off. The diverter was nippled down, the wellhead system installed, BOP's nippled up and tested. A 9-7/8" PDC bit on a motor was mn. The bit tagged up at 1620'. The casing above the HES cementer was tested to 1000 psi - OK. The HBS cementer was drilled out with excessive torque and stalling of the bit. After the HES cementer was drilled, the bit was worked through the area twice. The bit was pulled above the cementer. A pressure test was attempted but would pump in at 500-600 psi. The PDC bit was pulled and was rung out. All indications are that there is a hole in the casing or the HES cementer is leaking. Forward Plan: . 6. RIH with open ended 5" DP to +/-1922'. Circulate the well clean with 9.2 ppg mud. Spot a viscous freshwater, bentonite plug up to 1722'. Pull up to 1722' and circulate clean. Spot Permafrost 'C' 15.7 ppg cement plug from 1722' - 1100'. Pull up to 1100' and circulate the wellbore clean with 9.2 ppg mud. POOH. RIH with bit. Circulate oa top of the cement. WOC. Pressure test the cement plug to 1000 psi. For freeze protecl, displace the wellbore with 9.f~ ppg NaCI brine from 1100' - 100' md. Pull up and put a cap of mineral off from 100' to surface. ND BOPE. NU suspension cap. Move rig to next well. RECEIVED ENDICOTT DEVP (. P.~×4 To: Tom Maunder From; b"teve Chesher Fax,' 276-7542 Pages: Cover ~- 3 pages Phene,' I~tm~, 1/30/2001 ~ N,~?.6 CC.' rCliok here and type name] Urgent [] For Ifa~iew ,,, [] Please Comment [] Pies.se Reply [] Piease Recycle Tom, As per our phone convemation, hem Lt the requested procedure. I will follow up with a Sundry notice later today, As we talked about, the rig is currently waiting on orders from me. Please call me at 240- 8039 (cell) if a verbal approval ia acceptable. Call with any questions. Thanks. ~eve Ohesher RECEIVED ~4N ~0 2.001 ~JaskaC~lL~~. C,~ NS-26 (200-211)-Temporary SD of Operations 8ubiect: Date: ~rom: To: NS-?.6 (200.2II)--Temporary SD of Operations Tue, 30 Jan 2001 13:40:10-0900 Tom Maunder <tom_maunder@admin.state.ak. us> "Hernandez, Floyd" <HemanFl~bp.com>, Steve Cheshire <cheshesw~bp.com> AOGCC North Slope Office <aogcc_prudhoe_bay~admin.state.ak.us>, Julie Heusser <julie_heusser~admin.state.ak. us>, Daniel Seamount <dan_seamount~admin.state.ak.us>, Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us> Floyd and Steve, We are in receipt of your fax and voice information regarding NS-26. You indicate from all available information that either the ES cementer is leaking or a hole has been worn/drilled through the casing at the cementer. You propose to place some 600' of cement in the wellbore (-100' below the cementer to 500" above), verify the TOC with weight and pressure test above the cement to 1000 psi, circulate 9.8 ppg brine above the TOC to within about 100' of surface and place a mineral oil cap from there to surface. Mechanically the well will be secured at surface by running the tubing hanger with one joint of tubing, installing a two-way-check and nippling up the THA and at a minimum one master valve, Your proposal has been discussed with the Inspectors and examined by myself and John Crisp. As indicated in my call to Steve, you have approval to proceed. Following cementing, the TOC should be weight verified and the wellbore tested to 1000 psi. This is provided at 20 AAC 25.112 (g) (2). This pressure test to 1000 psi will replicate the test accomplished prior to drilling on the stage tool. We look forward to seeing you plans for the future utility of this weilbore especially your plans to restore the integrity of the surface casing. Restoring integrity is not only critical to any future operations on NS-26, but to any potential plans that may be put forward for annular disposal. Please notify our North Slope Inspector at 659-3607 so that he may witness the plug tagging and pressure test if possible, Good luck with the operations. Please feel free to call with any questions or comments. Tom Maunder, PE Petroleum Engineer AOGCC 793-1250~244-1567/345-0850 Tom Maunder <tom maunder~.admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Consewation Commission 1 of 2 1/30101 1:40 PM Re:BOP Subject: Re: BOP Date: Tue, 30 Jan 2001 18:01:36-0900 From: Tom Maunder <tom_maunder~admin.state.ak. us> To: "Chesher, Steve W" <chesheSW~BP.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay~admin.state.ak. us> Steve, Sounds like a good way to manage those large pieces of equipment. Probably won't work for all wells, but then this isn't all wells. Hopefully only I off. Tom 'Chesher, Steve W" wrote: Tom, As per our phone conversation, to optimize handling the BOP's we plan to leave the BOP's nippled up (on top of a tubing hanger with TWC in place) on the NS26 well while drilling the NS27 surface hole. At the conclusion of the NS27 surface hole, the diverter will be moved to the NS29 slot, the BOP'S on the NS26 will be removed and nippled up on the NS27. A dry hole tree (minimum of one valve) will be nippled up on the NS26 at this time. The NS26 and NS27 are within the subbase of the rig so them are no freezing problems and this will help avoid double handling of the BOP's. Regards, Steve Chesher 240-8039 Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 1/30/01 6:01 PM ~OG.O,C F~X NO. 9~ !'W6 7542 P, 02 . ,~. · . S T A T E" OF ALASKA AZA. SKA OIL AND ~$ ' CONSER VA TION COMMISSION 333 W. 7~h Ave., Suite 100 Anchorage, AK 99~01' PHONE: (907) 2~9-1433 . FAX: (907).276-7~M2 FloYd Hernandez Senio~ Drilling Engineer BP Exploiation (Alaska) Inc. P O Box 196612" Anchorage, AK.' 99519-6612 Re:" Northstar NS. 26 BP Exploration (Alaska) Inc. 'Permit No:. 200-2i 1 · Sur Loc: 1298'NSL, 648'WEL, Sec. 11, TI3N, R13E, UM Btmhole Loc. 3367'NSL, 3503'WEL,' Sec. 11, T13N, RI3E, UM . Dear Mr. Hermmdez: E. nclosed is the approved application for permit to drill the above referenced Well.. The permit to drill does· not exempt you. fi.om obtaining additional permits required, by iaw from' °ther governmental ageflcies,, and does not authorize conducting drilling operations until all other required permitting determinations are made. B!ow6Ut prevention equipment (BOPB) must be tested in accordance with 20 AAC 25.035. · Sufficie. nt notice (approxima_ ~'ely 24 hours) must.be given to a/iow a representative, ofth~ · C~mmission tO witness a test of BOPE installed prior to drillin8 new hole. Notice may be given'" by.contacting the Commission petroleum field inspector on the North Slope Paser at 6~59-3607. ' Si:hoerS./~.. ' iel T. Seamount, ~r. Commissioner sY om)r.]{ coM nssxoN :' ' DATED this' / ~- ~ . ' _._day of January, 2001 ' ' ' dill/Enclosures · cc: '. Department ~Fish & Oan~ Habitat Section W/o encl, . · Department of Environmental .Col~ervation w/o en¢l. .. Re: Northstar NS26 annulus freeze prote~t plan Subject: Re: Northstar NS26 annulus freeze protect plan Date: Wed, 03 Jan 2001 15:21:29 -0900 From: Julie Heusser <julie_heusser@admin.state.ak. us> To: Wendy Mahan <Wendy_Mahan@admin.state.ak. us> Wendy, Thanks for summarizing our conversation. I have placed two phone calls to BP and left messages for Steve Chesher and Floyd Hernandez to discuss this. Julie Wendy Mahan wrote: Julie, As we discussed, BPXA is planning to pump approximately 1000 bbls mud as a preflush to the normal diesel used to freeze protect the well. You asked whether this should'be considered an annular disposal operation and the necessary regulatory information obtained for approval. If this is going to be a long term development plan at Northstar, I suggest we address the practice when we draft the Pool Rules and AIO. For the time being, if you feel more comfortable with handling it as true annular disposal, the operator should submit the necessary info to obtain commission approval. Would the operator have any problems with this? Wendy Al_ASK IL AND GAS CONSERVATION COM · ,SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil . la. Type of work B Drill [] Redrill lb. Type of well ' Re-Entry [] Deepen Service Development Gas Si?~e Zone Multiple Zone 2. Name of Operator i5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 55.77' Northstar Field 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312799 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1298' NSL, 648' WEL, SEC. 11, T13N, R13E, UM Northstar Unit At top of productive interval 8. Well Number 3240' NSL, 3326' WEL, SEC. 11 T13N, R13E, UM NS26 Number 2S100302630-277 At total depth 9. Approximate spud date 3367' NSL, 3503' WEL, SEC. 11 T13N, R13E, UM 01/01/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312799, 3503' MDI No Close Approach 4472.37 11915' MD / 11281' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 1500' ' Maximum Hole Angle 20.65 ° Maximum surface 4266 psig, At total depth (TVD) 11281'/5388 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include stare data) Driven 20" 169# X-56 WELD 160' Surface Surface 199' 199' 13-1/2" 10-3/4" 45.5# L-80 BTC 3267' Surface Surface 3306' 3225' 1545 sx PF 'E', 346 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-Mod 11298' Surface Surface 11337' 10740' 797 sx Class 'G' 6-3/4" 4-1/2" 12.6# 13Cr Fox 728' 11187' 10599' 11915' 11280' 155 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD 'I'VD Structural Conductor Surface Intermediate LPirn°edrUCti°nRECEIVED RECEIVED DEC 1 1 2000 DEC 1 1 000 Perforation depth: measured Alaska 0il & Bas Cons. c0mmissi0~ Alaska 0il & (~a$ Cons. Commission true vertical Anchorage Anchorage .20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Chesher, 564-4196 Prepared By Name/Number: Sondra Stewrnan, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed FloydHernandez !~ ~ -~e,,- F~ Titl~ S~nior Drilling Engineer Date Permit Nu mob~~ APl Number .Z.~,~' _ O~"~ Approv. al_Date., x See cover letter · - 'Z.J'// 50- O,?...4 - ,~ Oj'.///,,,~'(." ! for other requirements '~3onditions of Approval: Samples Required [] Yes [] No Mud Log~equire'd [] Yes [] No Hydrogen Sulfide Measures I~ Yes [] No Directional Survey Required J~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K ~I,~K [] 10K [] 15K [] 3.5K psi for CTU Other: ORIGINAL SIGNE![) BY by order of _Approved By F'J T~vlr~r 5;~.~moLm~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAL plicate ~ NS26 Permit to Drill I Well Name: INS26 Well Plan Summary Type of Well (producer or injector): I Slimhole Producer Northstar Slot: NS26 Surface Location: 1298' FSL, 648' FEL, Sec. 11, T13N, R13E, UM X-= 659824 Y = 6031071 Target: 3240' FSL, 3327' FEL, Sec. 11, T13N, R13E, UM 500' Radius X = 657103 Y = 6032955 10700' TVDrkb Bottom Hole Location: 3368' FSL, 3504' FEL, Sec. 11, T13N, R13E, UM X = 656923 Y = 6033079 11281' TVDrkb I AFE Number: I 831302 Estimated Start Date: I Jan 1, 2001 I Well Design (conventional, slimhole, etc.): Objective: I Drill a Ivishak slimhole producer I Rig: I Nabors33E Operating days to complete: 1 26 IRKB/Surface Elevation: (a.m.s.I.) 55.77' / 16.0' I Slimhole Mud Program: Surface' Hole Mud Properties: Inhibited KCI 13-112" Hole Section From Surface to -3306' MD / 3225' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel APl FL pH (ppg) (seconds) 10' sec Initial 8.8 - 9.0 200 - 300 45 - 70 > 9 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5 100 - 200 30 - 45 > 7 15 - 25 4 - 10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 - 100 20 - 35 > 7 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: Inhibited KCl 9-7/8" Hole Section From Surface Casing Shoe to 11337' MD / 10740' TVD (-top Sag River). Interval Density (ppg) PV YP Tauo APl I pH HTTP FL Initial 9.0 - 9.5 10 - 25 20 - 28 4 - 7 6 - 10 8.5 - 9.5 Top HRZ to 9.6 - 9.8 10 - 25 20 - 25 4 - 7 4-6 / <10 8.5 - 9.5 top Miluveach Miluveach to 11.5' 10 - 25 20 - 25 4 - 7 4-6 / <10 8.5 - 9.5 interval TD * After logging the Kuparuk, the well will be displaced to 11.5 ppg mud. RECEIVED DEC 1 1 ;!000 1 Alaska 0il & Gas Cons. Commission Anchorage RECEIVED DEC 1 1 Alaska 0il & Gas Cons. C0mmissi0~ Anchorage ~ NS26 Permit to Drill Production Hole Mud Properties: Seawater/Barite/CaCO3 Drill-In Fluid 6-3/4" Hole Section From Intermediate Casing Shoe to 11915' MD / 11280' TVD Interval Density (ppg) I PV I YP I Initial/Final 9.7 10 - 25 20 - 25 Tau0 APl FL pH 4-7 4-6 8.5 - 9.5 Directional:(wP6c) KOP: ±1500' MD Uniform curve 2.5°/100' build Maximum Hole Angle: ±20.65° - Slant Well Close Approach Well: Survey Program: None - Seal #A-l, #A-2, #A-3, #A-4 (P&A'd) and NS10 do not have close approach issues. Standard MWD surveys from surface to TD. No gyros will be needed for surface kick-off. Logging Program: 13-1/2" Section: Drilling: GR/Directional Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals), CFM (connection flow monitoring) Open Hole: None Cased Hole: None ,. , 9-7/8" Section: To base Kuparuk ~. Drilling: GR/Directional ...:~ Mud Logging - Gas analysis/detection, show kit with indexed sample, brittles, lithology samples (100' intervals down to 8215' tvdSS/8737' rkbMD; thereafter, 40'' intervals - 20' intervals at shows), Geochem samples from 8215' tvdSS/8737' rkbMD (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: Quad Combo (GRIReslDen/NeulSonic), RFT with pressurized samples Cased Hole: None 9-7/8" Section: Base Kuparuk to Intermediate TD Drilling: GR/Directional, RES, 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) Open Hole: None Cased Hole: None 6-3/4" Section: Drilling: GR/Directional, Res Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (40' intervals - 20' intervals at shows), Geochem samples (40' intervals - 20' intervals at shows), CFM (connection flow monitoring) Open Hole: Quad Combo (GR/Res/Den/Neu/Sonic) CMR, RFT or MDT with pressurized samples - the use of the RFT or MDT will be based on hole conditions as determined by Drillin~l Cased Hole: None RECEIVED DEC 11 ; 000 Alaska 0il & Gas Cons. Commissi0~ Anchorage NS26 Permit to Drill Formation Markers: Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) Top Permafrost 1205 1150 518 8.65 Base Permafrost 1556 1500 675 8.65 SV6 3146 3020 1359 8.65 Set surface casing 150' tvd below top of SV6 SV5 3445 3300 1426 8.65 SV4 3766 3600 1620 8.65 SV2 4194 4000 1800 8.65 SV1 4600 4380 1971 8.65 Top Ugnu (UG4A) TMBK 4974 4730 2128 8.65 ' Top Schrader 6667 6315 2842 8.65 Top Seabee (CM3) 7277 6885 3098 8.65 Colville Shales Top HRZ 9018 8515 3832 8.65 Base HRZ 9104 8595 3868 8.65 Top Kuparuk 9179 8865 3899 8.65 LCU 9531 8995 4048 8.65 Top Miluveach 9531 8995 4048 8.65 Top Kingak 10066 9495 4273 8.65 Top Sag River 11295 10645 5109 9.23 · Set intermediate casing into the top of · ' ..the Sag River to cover up the Kingak Top Shublik 11402 10745 5129 9.23 .... Top Ivishak 11519 10855 5210 9.23 ... .... Proposed TD 11915 11225 5388 , 9.23 .. ' Casin¢./'rubing Program: H01e Size' Csgl 'W.t/Ft - Grade Conn Casing Casing Top Hole Btm Tb9 O.D. Length MD/TVDrkb MDrrVDrkb 20" 20" 169# X-56 WELD 160' Surface 199'/199' 13 ½" 10 ~" 45.5# L-80 BTC 3267' Surface 3306'/3225' 9 7/8" 7 5/8" 29.7# L-80 BTC-Mod 11298' SUrface 11337'/10740' 6 ~" 4 1/2" 12.6# 13Cr Fox 728' 11187' 11915'/11280' Tubing 4 1/2" 12.6# 13Cr Fox 11148' Surface 11187'/10599' Cement Calculations: The following cement calculations are based upon a two stage job using a stage tool. Casin~l I 10-3/4" Surface Casin9 I Basis: Stage 1: Lead: Based on 956' of 13 ½" open hole x 10 ~" csg. with 30% excess. Lead TOC: -1600' (1600' TVD) Tail: Based on 750' of 13 ½" open hole x 10 3~,, csg. with 30% excess + 80' shoe joint. Tail TOC: At -2696' MD (2654' TVD) Stage 2: Lead: Based on 1600' of 13 ½" open hole x 10-3/4" csg. with 250% excess + csg capacity. Lead TOC: Surface I Stage 1: Total Cement I Spacer RECEIVED DEC 11 ?.000 Alaska Oil & Gas Cons. Coamission Anchorage Preflush Spacer Lead 10 bbl sea water 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight 81 bbl / 210 sk of 12.0 ppg Type 'E' Permafrost Cement. 2.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0+ hrs NS26 Permit to Drill Tail 71 bbl / 346 sk of 15.8 ppg Premium 'G'. 1.15 cf/sk, BHST 60° / BHCT 55°, TT = 3.0+ hrs Stage 2: Total Cement ! Spacer Preflush None Spacer 75 bbl Alpha Spacer weighted to 1.0 ppg over mud weight Lead 516 bbl* / 1335 sk of 12.0 ppg Type 'E' Permafrost Cement 2.17 cf/sk, BHST 60° / BHCT 55°, TT = 6.0 hrs * 2 gal Red dye in 1st 5 bbls Casing Basis: r-/-5/8,, Intermediate casingI teStage 1: , Lead: Based on 6187 of 9 7/8" open hole x 7 5/8" csg with 30% excess ad TOC: At -4150' MD - above SV2 ail: Based on 1000' of 9 7/8" open hole x 7 5/8" csg with 30% excess + 80' shoe joint ail TOC: At -10337' MD 9805' TVD) IStage 1: Total Cement I Spacer Preflush Spacer Lead Tail 10 bbls sea water 50 bbl Alpha Spacer weighted to 1.0 ppg over mud MW 307 bbl / 533 sk of 11.0 ppg Premium 'G'. 3.24 cf/sk, BHST 215° / BHCT 130°,, T,T = 4.0+ hrs 54 bbl / 264 sk of 15.8 ppg Premium G. 1.15 cf/sk, BHST 215° / BHCT 130°, TT = 4.0+ hrs Casing ~4-112" Production LinerI -,, Basis: IStage 1: , ' ' ~, ri'ail: Based on 577 of 6 3/4" open hole x 4 1/2" csg with 50% excess + 80' shoe joint. pail TOC: At ~ 11137' MD (9694'.TVD) ~ . .... " Stage 1: Total Cement / Spacer I Preflush I10 bbls sea water ..., ~ I Spacer 150 bbl Alpha Spacer weighted to 1.0 ppg over mud MW Tail 132 bbl/155 sk of 15.8 ppg Premium 'G'. I1.15 cf/sk, BHST 220° / BHCT 140°, TT = 4.0+ hrs. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 5000 psi. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Intermediate Section: · Maximum anticipated BHP: 5109 psi @ 10645' TVDss - Sag River · Maximum surface pressure: 4045 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: · Maximum anticipated BHP: 5388 psi @ 11225' TVDs~"-"Total Depth · Maximum surface pressure: 4266 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 5000 psi (annular to 3500 psi) 8.5 ppg Seawater / 6.8 ppg Diesel RECEIVED DEC 1 1 000 Naska 0ii & Gas Cons. Commission Anchorage NS26 Permit to Drill 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. Reference: 1) Northstar/Nabors 33E H2S contingency plan - on file with AOGCC. 2) Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03 - on file with AOGCC. DRILLING CLOSE APPROACH: No close approach issues exist for this well. The Seal #A-l, Seal #A-2, Seal #A-3 and Seal #A-4 wells have been P&A'd. NS10 will be the only well on the pad but does not pose any close approach issues. SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval (0-3225' TVD) 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 prior to penetrating sand intervals. ., · Lost ci.rcu, lation has only been 'noted whi.!e drilling duri.ng hole Opening runs and was most likely induced by poor hole cleaning. Losses have occurred while .running and cementing surface casing.. Be sure to condition and thin mud appropriatelY prior to pulling out of the h01e" to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. "= .. · Hole stabilization in the shallow unconsolidated intervals can I~e 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. Mudloggers will be used continuously on NS26 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. Mudloggers will be used continuously on NS26 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 not interpreted to be faulted. Seismic discontinuities from 2900' TVD to 6300' TVD are interpreted to be the artifact of rapid velocity changes and the probability of faults existing is Iow. If faults are encountered, the possibility of losses still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. · A fault is anticipated in the Kingak shale at approximately 10498' md / 9900' tvdSS (+/-300' tvd). Losses are not anticipated but the lost circulation plan listed above will be in place on the rig. RECEIVED DEC 1 1 2000 Alaska 0il & Gas Cons. Commission Anchorage "NS26 Permit to Drill · Prior to drilling the Kingak shale, the mud system will be weighted up to 11.5 ppg. The increased mud weight is needed due to hole stability and not pore pressure. With the higher mud weight, differential sticking in the shallow sands may occur. The drill string will be kept moving as much as practical. Barofibre sweeps will be pumped to prevent seepage/losses and provide a wall cake to help minimize sticking. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent cimulating 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 underbalanced. · 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. · The kick tolerance for the 9-7/8" open hole section would be 122 bbls assuming an influx from the Sag River interval at -11295' MD / 10700' TVD. This is a worst case scenario based on a 9.23 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 10-3/4" shoe, and 11.5 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The intermediate shoe will be drilled out with the 11.5 ppg mud. The mud will then be displaced with a 9.7 ppg drill-in fluid. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. Losses are not expected but calcium carbonate (CaCO3) will be maintained in the system. If · losses occur, larger sweeps of CaCO3 will be pumped and the LCM Decision.Tree will be in place on the rig. ". · . The Ivishak is a conglomerate:'section. Dire(~tional control will be maintained with MWD surveys '~'~'to minimize doglegs. .' ·I The well is not planned to per~'etrate 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 'lvishak 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 6-3/4" open hole section is infinite (due to the limited amount of open hole) assuming an influx from TD at -11915' MD / 11280' TVD. This is scenario based on a 9.23 ppg pore pressure gradient, a fracture gradient 6f 11.5 ppg at the 7-5/8" shoe, and 9.7 ppg mud in the hole. Disposal'. There will be no annular injection in this well. Cuffings Handling: Cuttings generated from drilling operations will be disposed of in the Northstar Class I Waste Disposal Well (after the well has been commissioned). If the well is not commissioned prior to spud, the cuttings will be temporarily stored at Northstar and disposed of in the Northstar Class I Waste Disposal well after commissioning or during ice road access, the stored cuttings will be hauled to grind and inject at DS-04. Fluid Handling: All Class I and Class II wastes will be disposed of in the Northstar Class I Waste Disposal Well (after the well has been commissioned). If the well is not commissioned prior to spud, any drilling and completion fluids or other Class II wastes will be stored at Northstar and allowed to freeze. This material will be recovered and hauled to DS-04 for injection during ice road access and/or disposed of in the Northstar Class I Waste Disposal Well after the well has been commissioned. Any non-hazardous Class I waste generated will be stored at Northstar and disposed of in the Northstar Class I Waste Disposal Well upon commissioning or taken to Pad 3 during ice road access. RECEIVED DEC 1 1 2000 Alaska 0il & Gas Cons. Commission Anchorage SUMMARY DRILLING OPERATIONS Pre-Riq Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. 2. Install 7' x 7' cellar. 3. Rig up and commission Nabors 33E and service module. Ri.q Operations: 1. Nipple up and function test 21-1/4" diverter system. PU 5" DP as required and stand back in derrick. 2. MU 13-1/2" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3306' MD / 3225' TVD. The actual surface hole TD will be +/-150' TVD below the top of the SV6 marker. 3. Run 10-3/4", 45.5# surface casing. Cement the casing to surface in 2 stages using a stage tool at +/- 1600' MD. 4. ND diverter system and NU casing / tubing head. NU BOPE and test to 5000 psi. 5. MU 9-7/8" directional assembly with MWD/GR and RIH to stage tool closing plug. Pressure test the casing to 2500 psi for 5 min. Drill plug and RIH to float collar. Test the 10-3/4" casing to 2500 psi for 30 min. 6. Drill out remaining cement. Drill 20' of new formation below 10-3/4" shoe and perform Leak Off Test. (FIT/LOT procedure on file with AOGCC). 7. Drill 9-7/8" intermediate 'tangent' hole,to logging point at approximately 9,681' MD / 9190' TVD (+/- 150' below the base of the Kuparuk).,; .... 8. RU Schlumberger E-line unit and,~run open logs (GR/Res/Den/Neu/Sonic; RFT). POOH and RD Schlumberger. 9. RIH with 9-7/8" directional assemb!¥ with MWD/GR/RES/PWD. Displace the well with 11.5 ppg mud. Continue to drill the 'tangent' interval tO 7-5/8" casing point at approximately 11337'MD / 10740' TVD (Top Sag River). ~, , ,, 10. Run 7-5/8", 29.7# intermediate casing. Cement the casing to +/- 4150' MD (above SV2 sand) in a single stage. Perform a downsqcieeze on the 7-5/8" x 10-3/4" annulus with diesel to 2000' MD for freeze protection. 11. Pack off the casing hanger. Pressure test the BOP's to 5000 psi. 12. MU 6-3/4" directional assembly with MWD/GR/RES and RIH to float collar. Pressure test the 7-5/8" casing to 3000 psi for 30 min. ,,.~ 13. Drill out remaining cement. Drill 20' of new formation below 7-5/8" shoe with 11.5 ppg mud and perform a Drill Off/Formation Integrity/Leak Off Test. (FIT/LOT procedure on file with AOGCC). Since the mud weight will be lowered to 9.7 ppg after the Drill Off Test, monitor the wellbore for 10 minutes. If no losses occur, displace with the 9.7 ppg drill-in fluid. 14. Drill 6-3/4" production 'tangent' interval to TD at approximately 11915' MD / 11280' TVD. 15. RU Schlumberger E-line unit and run open logs (GR/Res/Den/Neu/Sonic; CMR; RFT or MDT). POOH and RD Schlumberger. 16. Make a clean out run and condition the hole for a liner. POOH. 17. Run and cement a 4-1/2" 12.6 # 13Cr liner. Set the liner and liner top packer. Circulate off any excess cement. POOH with liner setting tool. 18. RIH with 3-3/4" cleanout assembly. Clean out to provide sufficient rathole. Pressure test the liner and 7-5/8" casing to 3600 psi with 9.7 ppg mud (this is equivalent to 4266 psi tubing leak with a 8.5 ppg completion fluid). 19. Displace well to 8.5 ppg seawater and monitor. POOH. 20. Run the 4-1/2", 12.6#, 13Cr K-Fox completion assembly to the top of the 4-1/2" liner at +/-11187' MD. Run a SSSV at 2000' MD. Displace the annulus with inhibited 8.5 ppg seawater. 21. Land the tubing hanger. 22. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 23. Set the packer. Pressure test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. Shear the valve in the GLM. 24. Freeze protect the well to-2000' with diesel. R E ¢ E IV E D 7 DEC 1 3 2000 Alaska 0Il & gas Cons, Commission Anchorage 25. Install BPV. Rig down and move off. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'XN' nipple below the new production packer. 2. Pull the shear valve in the GLM and dummy off. 3. Perforate interval based on PE recommendation. Estimated Spud Date: 1/1/01 Steve Chesher Operations Drilling Engineer 564-4196 RECEIVED DEC 1 1 ~000 Alaska 011 & $a8 Gon;. I;o~mis~ion Anchorage "NS26 Permit to Drill (' ( NS26 Ri site Summary of Drillin.q Hazards POST THIS NOTICE IN THE DOGHOUSE Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS26 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. Mudloggers will be used continuously on NS26 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. .. ~' Losses are not expected but the possibility still exists. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling. ,. 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. The Kingak shale, in the offset wells, experienced severe'hole instability. The higher mud weight (11.5 ppg) and Iow angle (20.65 deg) will help with hole conditions. No logs will be run in the Kingak and the entire section is planned to be cased off as quickly as practical. 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. None of these are expected but the wellbore must be monitored at all times. Do not drill ahead if a potential problem is detected. Northstar is not a designated H2S pad. CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION RECEIVED DEC 1 1 2000 Alaska 0il & (}as Cons. Commission Anchorage TREE: ABB-VGI 5 1/8" 6.5ksi i~" ~" 'RIGINAL KB. ELEV = 55.77' WELLHEAD: ABB-VGI 11". NS26~, F. ELEV = 40.2' Multibowl 5ksi ~ CB. ELEV = 15.57' nipple - 3.813" ID ~ 6.8PPG DIESEL FREEZE PROTECTION AT +/- 2000 ~ ~ 4.5" GLM ~ 3000' MD w/3.833" ID 10 3/4", 45.5#/ff, L-80, BTC (~ 3306' , 4.5", 12.6#/ff, 13-Cr, Fox TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT . :. ; ." ,. ,., 4.5" XNIPPLE, (~l 11137'"' ' 3.813" ID 4.5" X NIPPLE, (~ 11167' i~ ,i~ -~- 7 5/8" PACKER, 13 Crw/ . 3.813" ID" .I . I 3.875" ID @11147' ,, 4:5" XN NIPPLE, (~ 11177' ~ 3.725" ID . ,~. 4.5" WLEG, (~ 11187' ~ -- 3.958" ID 4.5" LINER TOP ~l 11187' 7 5/8", 29.7#/ff L-80, BTC-M ~ 11337' ~ ~ · i RECEIVED DEC 1 1 000 Alaska 0il & Gas Cons. Commission Anchorage PBTD ~ 11835' TD~ 11915' ~. 4.5", 12.6#, 13-CrFox DATE REV. BY COMMENTS Northstar WELL.'NS26 APl NO: BP Exploration (Alaska) NS26 Proposed Well Profile - Geodetic Report Report Date: Client: Alaska Drilling & Wells Field: Northstar Structure I Slot: Northstar PF I N826 Well: N826 Borehole: N826 Proposal Name I Modified Date: N826 (P6c) I December 7, 2000 Tort I AHD I DDI ! ERD ratio: 20.649' 13528.63 fll 4.88610.313 Gdd Coordinate System: NAD27 Alaska State Planes, Zone 04, U8 Feet Lor, alion LefJLong: N 70 29 29.157, W 148 41 35.969 Location Grid N/E Y/X: N 6031071.380 flUS, E 659824.550 flU8 Grid Convergence Angle: +1.23168487' Grid Scale FaVor: 0.99992902 December 7, 2000 Survey I DLS Computation Method: Minimum Curvature I Lubinski VePJcel Section Azimuth: 305.920' Verlical Section Origin: N 0.000 fl, E 0.000 fl TVD Reference Datum: KB 'WI) Reference Elevation: 55.77 fl relative to MSL Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL MagneUc Declination: 26.908' Total Field Strength: 57487.696 nT Magnetic Dip: 80.907° Daelination Date: December 30, 2000 Magnetic Declination Model: BGGM 2000 North Reference: True North Total Corr Mag NoP, h -> True North: +26.908' Coordinate Reference To: Well Head Scblulalmrger Grid Coordinates Geo~lraphic Coordinates I Station ID I MD I Incl I Azim I TVO I VSec I N/'S I E/'W I DLS(ft~ t") (') (fl) (ft) (It) (fl) ('llOOft) N°rthing I Eesting (flUS) (RUG) LatitudeI Longitude KB 0.00 0.00 305.92 0.00 0.00 0.00 0.00 0.00 6031071.38 659824.55 N 70 29 29.157 W 148 41 35.969 Top Permafrost 1205.77 0.00 305.92 1205.77 0.00 0.00 0.00 0.00 6031071.38 659824.55 N 70 29 29.157 W 148 41 35.969 KOP Build 2.5/100 1500.00 0.00 305.92 1500.00 0.00 0.00 0.00 0.00 6031071.38 659824.55 N 70 29 29.157 W 148 41 35.969 Base Permafrost 1555.78 1.39 305.92 1555.77 0.68 0.40 -0.55 2.50 6031071.77 659823.99 N 70 29 29.161 W 148 41 35.986 1600.00 2.50 305.92 1599.97 2.18 1.28 -1.77 2.50 6031072.62 659822.75 N 70 29 29.169 W 148 41 36.021 1700.00 5.00 305.92 1699.75 8.72 5.12 -7.06 2.50 6031076.35 659817.38 1800.00 7.50 305.92 1799.14 19.61 11.50 -15.88 2.50 6031082.54 659808.43 1900.00 10.00 305.92 1897.97 34.82 20.43 -28.20 2.50 6031091.20 659795.92 2000.00 12.50 305.92 1996.04 54.33 31.87 -44.00 2.50 6031102.29 659779.88 2100.00 15.00 305.92 2093.17 78.09 45.81 -63.24 2.50 6031115.82 659760.34 N 70 29 29.207 W 148 41 36.177 N 70 29 29.270 W 148 41 35.437 N 70 29 29.358 W 148 41 36.799 N 70 29 29.470 W 148 41 37.264 N 70 29 29.607 W 148 41 37.830 End Build SV6 10-3/4" Csg Pt 2200.00 17.50 305.92 2189.17 106.07 62.23 -85.90 2.50 6031131.74 659737.34 2300.00 20.00 305.92 2283.85 138.21 81.08 -111.93 2.50 6031150.03 659710.91 2325.98 20.65 305,92 2308.21 147.24 86,38 -119.24 2.50 6031155.17 659703.49 3146.23 20.65 305.92 3075.77 436.50 256.07 -353.50 0.00 6031319.77 659465.65 3306.53 20.65 305.92 3225.77 493.03 289.23 -399.28 0.00 6031351.94 659419.17 N 70 29 29.769 W 148 41 38.497 N 70 29 29.954 W 148 41 39.263 N 70 29 30.006 W 148 41 39.478 N 70 29 31.675 W 148 41 46.372 N 70 29 32.001 W 148 41 47.720 NS26 (P6c) report.xls RECEIVED DEC 11 000 Alaska 0il & Gas cons. commission Anchorage Page 1 of 2 12/712000-12:48 PM Grid Coordinates Geo~ral~hic Coordinates Station ID I I 'nc' I zim I TVO I VS" I I E 'W IDLs(ft, (') (', (It, ~, ~, (It) (°llOOft, N°rthlng I Eagdng ~tUS) ~US) LatitudeI Longitude SV5 3445.46 20.65 305.92 3355.77 542.02 317.97 -438.95 0.00 6031379.82 659378.90 N 70 29 32.254 W 148 41 48.887 SV4 3766.05 20.65 305.92 3655.77 655.08 384.30 -530.51 0.00 6031444.16 659285.94 N 70 29 32.936 W 148 41 51.582 SV2 4193.51 20.65 305.92 4055.77 805.82 472.73 -652.59 0.00 6031529.94 659162.00 N 70 29 33.806 W 148 41 55.175 SVl 4599.60 20.65 305.92 4435.77 949.03 556.74 -768.56 0.00 6031611.43 659044.26 N 70 29 34.632 W 148 41 58.588 TMBK 4973.63 20.65 305.92 4785.77 1080.93 634.12 -875.38 0.00 6031686.49 658935.81 N 70 29 35.393 W 148 42 1.732 Top Schrader 6667.45 20.65 305.92 6370.77 1678.25 984.54 -1359.12 0.00 6032026.41 658444.68 Top Colville 7276.58 20.65 305.92 6940.77 1893.08 1110.56 -1533.08 0.00 6032148.65 658268.07 Top HRZ 9018.49 20.65 305.92 8570.77 2507.34 1470.92 -2030.56 0.00 6032498.21 657762.99 Base HRZ 9103.98 20.65 305.92 8650.77 2537.49 1488.61 -2054.97 0.00 6032515.37 657738.21 Top Kuparuk 9178.79 20.65 305.92 8720.77 2563.87 1504.08 -2076.34 0.00 6032530.37 657716.51 N 70 29 38.838 W 148 42 15.970 N 70 29 40.077 W 148 42 21.091 N 70 29 43.620 W 148 42 35.735 N 70 29 43.794 W 148 42 36.454 N 70 29 43.946 W 148 42 37.083 Kuparuk C 9392.52 20.65 305.92 8920.77 2639.24 1548.30 -2137.38 0.00 6032573.27 657654.54 LCU / Miluveach 9531.44 20.65 305.92 9050.77 2688.24 1577.04 -2177.05 0.00 6032601.15 657614.27 Top Kingak 10065.77 20.65 305.92 9550.77 2876.67 1687.56 -2329.65 0.00 6032708.37 657459.34 Fault 50 10498.58 20.65 305.92 9955.77 3029.29 1777.12 -2453.26 0.00 6032795.23 657333.84 Target 11294.72 20.65 305.92 10700.77 3310.05 1941.83 -2680.63 0.00 6032955.00 657103.00 N 70 29 44.381 W 148 42 38.880 N 70 29 44.663 W 148 42 40.048 N 70 29 45.750 W 148 42 44.541 N 70 29 46.630 W 148 42 48.180 N 70 29 48.249 W 148 42 54.874 Top Sag River 11294.73 20.65 305.92 10700.77 3310.05 1941.83 -2680.63 0.00 6032955.00 657103.00 7-5~8" Csg Pt 11337.47 20.65 305.92 10740.77 3325.13 1950.67 -2692.84 0.00 6032963.58 657090.60 Top Shublik 11401.59 20.65 305.92 10800.77 3347.74 1963.94 -2711.15 0.00 6032976.45 657072.01 Top Ivishak 11519.14 20.65 305.92 10910.77 3389.19 1988.25 -2744.72 0.00 6033000.03 657037.93 Top Kavik 11861.11 20.65 305.92 11230.77 3509.79 2059.00 -2842.38 0.00 6033068.66 656938.78 N 70 29 48.249 W 148 42 54.874 N 70 29 48.336 W 148 42 55.234 N 70 29 48.467 W 148 42 55.773 N 70 29 48.708 W 148 42 56.761 N 70 29 49.401 W 148 42 59.637 11914.54 20.65 305.92 11280.77 3528.63 - 2070.05 -2857.64 TD / 4-1/2" Lnr Pt 11914.54 20.65 305.92 11280.77 3528.63 2070.06 -2857.64 0.00 6033079.38 656923.29 N 70 29 49.510 W 148 43 0.086 0.00 6033079.39 656923.29 N 70 29 49.510 W 148 43 0.086 Leaal Description: Surface: 1298 FSL 648 FEL Sll T13N R13E UM Target: 3240 FSL 3327 FEL S11 T13N R13E UM BHL: 3368 FSL 3504 FEL Sll T13N R13E UM Northina C~3 rftus1 6031071.38 6032955.00 6033079.38 Eastina (X) [ftUS1 659824.55 657103.00 656923.28 NS26 (P6c) report.xls Page 2 of 2 12/7/2000-12:48 PM VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: NS26 (P6c) Field: Northstar Structure: Northstar PF Section At: 305.92 deg Date: December 07, 2000 Schlumberger 2000, 8000 10000, KB ~ ................................ J ................................ n, ............................................. i ........................................ i. .................... KOP BulI~ 2.5/t00 1500MD 1500 TVD o.om :K~2°-- T~Pemufm~ I~06MD 'I208'I'VD BeMPenllafm~ t1556MO 1556'!~D End ,ulM .................................. ~ ........................................................... [ .......... ~ .............. ~0:e,' ~.. ~s0~..WZ'..az .................................... , ............................................................. ~ ........................... '14.7 ~ q~re a~' MD ~228 TVD 49,3 departure Hold Angle ~ 0.65° Top H~Z 8018 MD 8571 'rVD ~ -- ~ ~HRZ ~104MD 'i ~ -- -- TapKupmuk ~I79MD 8721TVO ..... I- j ~.r*C ~,~ i_ ~r~T~D ags,g~-o ~z- J -- -- Top Iqngak 10088 MD g551 TVD 11~7 MD 1~41~ _ _~~ _ ~-- T~ 11~MD 1~1~ ~-- -- -- T~k 11~ 1~1T~ -- -- -- T~lk 11~ 11~ .~ , Target I ] 11295 MD I(~701 TVD TD 14-t/2" Lnr Pt 20.05· 305.9'~e 12000 ; ...... ! j ~ depe~re -2000 0 2000 4000 0000 ¥orti~l $oction Dopartum at 305.02 dog from (0.0, 0.0). (1 in = 2000 PLAN VIEW Client: Alaska Drilling & Wells Well: NS26 (P6C) Field: Northstar Structure: Northstar PF Scale: 1 in = 500 ft Date: 07-Dec-2000 Schlumberger 2O00 1500 1000, O 5oo- V V V 0I m -3000 -2500 -2000 -1500 -1000 -500 0 I I ! I I I I i ' ' ! 20~65° 305.92TM 1~1N ~W~ 2 o ..... I .......... ~ ..... ~-~-~ ...... q ............................... ~ .......................... ~ ......... I .a~eo (~ 26.9~ ) ! ......... 00 ~ ; ..................... ~ ................................. ~ .............................. ~ .................................. ~_ ................................... ~ ................................. ~ ........... __.~_ .~?:s ~?~ ~ . ~ ~ ..... / ................... ~ ............................. ~ ............................... ~ ................................. ~ .............................. ~ ................................ ~ ...................... -~ -~ .............. -~000-2S00-2000-~ $00 -~ 000-$00 0 <<< WEST EAST >>> -2000 -1500 1000 500 FW: Northstar pressure gradients Subject: FW: Northstar pressure gradients Date: Tue, 19 Dec 2000 01:58:01 -0000 From: "Lemley, Kenneth R" <LemleyKR~BP.com> To: "'steve__davies~admin. state.ak.us'" <steve davies~admin.state.ak.us> CC: "Chesher, Steve W" <chesheSW~BP.corn~ Please consider this with the NS26 drill application as requested. Ken Lemley ..... Original Message ..... From: Lemley, Kenneth R Sent: Thursday, November 16, 2000 9:42 AM To: 'steve davies~admin.state.ak, us' -- Subject: Northstar pressure gradients Steve, Attached is the information being used by our drilling department to help design the casing program at Northstar. If you have any questions, please do not hesitate to give me a call. Ken Lemley <<NS Gradients (Power Point).PPT>> [-~NS Gradients (Power Point).PPT Name: NS Gradients (Power Point).PPT ............................ ] Type: Microsoft PowerPoint Show ] (application/vnd.ms-powerpoint) ! .Enc0ding!_.b. ase64 .................................................................................................................................................................................................................................. I 1 of 1 12/19/00 8:05 AM NS26 Subject: NS26 Date: Mon, 18 Dec 2000 19:13:46-0600 From: "Chesher, Steve W" <chesheSW@bp.com> To: "Steve Davies (E-mail)" <Steve_Davies~admin. state.ak.us> Steve, As per your phone message, attached is the PP/FG curve. in the NS26 permit. Let me know if you have any questions. Regards. Steve Chesher <<Pore Pressure Diagram.ppt>> Please include this Type. Microsoft PowerPoint Show (application/vnd.ms-powerpoim) Encoding: base64 · of 1 12/19/00 8:05 AM BP fiiASIM BBRilN8 I, IlRIS Northstar NS26 Casing Design J -e-- Fmc Grad - Pore Pressure ~ e--....~~ _ i i I i i 2OO0 4000 6000 8000 10000 12000 g 10 11 12 13 14 Pressure Gradient (E~VV) DATE INVOICE I CREDIT MEMO DESCRIPTION O~ DISCOUNT NET L~OI::>OO CKIOI::>OOO 1OO. OO 1OO. OO PYNT (:OI'IPIENTS' P£RltTT TO DRZLL HANDL. i NG TN~T* S/H ~ONDRA X47'50 A'rI'ACHED CHECK ~ IN PAYMEHT r-oft ~ ~.IBEI:) ABOVE. 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''':'?:'' ,' i. ? & [, 'I, I,," ~-'0 r, I, E0 =.8 r:i 5~'- 00P. h h ;i, 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 Pressure psi 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,0~ 11,000 12,000 13,000 Res Prs from Mud W Frae Gradients [] Seal-A-01 · Seal-A-01 [] Seal-Al02 OH ~ Seal-A-02 OH [] Seal-A-02 RD · Seal-A-02 RD [] Seal-A-03 · Seal-A-03 [] Seal-A-04 ~ Seal-A-04 [] North Star 1 ~ North Star 1 [] Northstar 2 Reservoir Prs from DST Seal-A-01 Seal-A-02 OH Seal-A-03 North Star 1 reservoir pressure gradient fracture pressure gradient Overburden 11,000 12,000 13,000 Hydrostatic Note to File 200-211 The designation of "onshore" in the upper right hand comer of the well permit checklist for NS 26 is an obvious mistake on my part. Northstar Island and NS 26 clearly lie offshore. This mistake was not replicated in the NS I 0 and NS 27 well files, where I designated the wells as "offshore." Steve D February 6, 2001 WELL PERMIT CHECKLIST FIELD & POOL ,~'~ 0 ~/~ ADMINISTRATION II APPR DATE II ENGINEERING COMPANY ./~-'~ WELL NAME z4/'.~- ~::~ PROGRAM: exp INIT CLASS ..-~)~"'-"1,/ /0//-.. 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 ........... Conductor string provided ................... dev "/ redrll serv wellbore seg ann. disposal para req 14. 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... GEOL AREA ~-~'~ ~ UNIT# '" N N ON/OFF SHORE O~t 22. Adequate weilbore 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 .~J~ osig. 27.. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur Without operation shutdown. ' 29. Is presence of H2S gas probable ................. GEOLOGY A~ DATE '/2../~.,~ o 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ...... '. 32. Seismic analysis of'shallow gas zones~. ............ 33. Seabed condition survey (if off-shore) ............. 34.. Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL35. With proper, cementing records, this plan .. (A) will.contain waste in a suitable receiving zonei ' . ApPR DATE (B) will not contaminate freshwater; or cause drilling waste' .. to surface;' . (C) will not impair mechanical integrity of the well used for disposal; - (D). will not damage producing formation'or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N . GEOLOGY: .ENGINEERING: · UICIAnnular COMMISSION: WM ~ Y N Y N y.N Y.N Y N Comments/Instructions: O Z O --I c:\msoffice\wordian~iana\checklist (rev.. 111011100) ) ') 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, infonnation of this nature is accumulated at the end of the file under APPEN.DIX. No special' effort has been made to chronologically organize this category of infonnation. BP EXPLORATION ALASKA END OF WELL REPORT NORTHSTAR NS-26 BP EXPLORATION ALASKA END OF WELL REPORT Well: Northstar NS-26 Rig: Field: Nabors Alaska Drilling No. 33-E Northstar State: Alaska Date: January 2001 Job No.: AKAM10022 AFE Number: 831302 f. 1 1 w 5~ 1 7~ em 9~ TABLE OF CONTENTS General Information Operational Overview Morning Reports Show Reports Bitrun Summary Directional Survey Data Mud Reports Formation Tops Formation Evaluation Logs C] Iq.I IL.I.I N Ij Ij Jj tlI ~1/I C Ij Ii .. General Information GENERAL INFORMATION Company: Rig: Well: Field: Borough: State: Country: APl 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 E: 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 NS-26 Northstar North Slope Alaska United States 50-029-22996-00 AKAM 10022 January 15, 2001 January 26, 2001 True 26.908 deg 80.907 deg 57487.695 nT January 1, 2001 North 70 deg 29 min 27.591 sec East 148 deg 41 min 34.776 sec 305.920 deg Doug Wilson Mark Lindloff Torn Mansfield Reg Wilson Paul Lockwood Joe Polya Ken Lemley Northstar 40087 Alaska North Slope Operational Overview OPERATIONAL OVERVIEW SPUDDED NS-26 ON 01-14-01. CLEANED OUT CONDUCTOR FROM 105'MD TO 199'MD. CIRCULATED AND CLEANED HOLE. RAN GYRO, DRILLED TO 1203~4D. MUD AND CUTTINGS DIKE ON STORAGE CRIB BROKE. CEASED DRILLING UNTIL CLEANUP AND COMMISSIONING OF NS-10/WD WELL FOR INJECTION COMPLETED. 01-18-01 TO 01-21-01 TRIP IN THE HOLE TO CIRCULATE AND CONDITION MUD SYSTEM. 01-21-01 TO 01-25-01 MADE PERIODIC WIPER TRIPS AND PERFORMED CARBIDE LAG TESTS TO CHECK THE CONDITION OF THE HOLE WHICH SHOWED A CARBICE LAG OF 2500 STROKES BOTTOMS UP MAINTAINING AN ESTIMATED AVERAGE HOLE SIZE OF 14.5 INCHES. 01-26-01 BEGAN DRILLING AT 12:30. DRILLED AHEAD FROM 1203' MD TO 2618' MD. 01-27-01 DRILLED AHEAD FROM 2618' MD TO 3302'MD. CIRCULATED AND RECIPROCATED WHILE PUMPING HIGH VIS SWEEPS. SHORT TRIPPED TO THE SHOE- PULLED SLOW TO PREVENT SWABBING. BACK REAMED FROM 2424' MD TO 2329' MD. RAN IN HOLE. DROPPED A CARBIDE LAG WHILE CIRCULATING ON BOTTOM. LAG = 6975 STROKES (492 D.P + 200 TRAP LAG) = 6283 STROKES BOTTOMS UP. PUMPED HIGH VIS SWEEPS. PULLING OUT OF HOLE AT REPORT TIME. HOLE ACTING GOOD. 01-28-01 PULLED OUT OF HOLE TO RUN 10 aA" CASING. SET CASING AT 3287' MD. CIRCULATED AND RECIPROCATED CASING. 6 UNITS OF GAS FROM BOTTOMS UP. PERFORMED FIRST STAGE CEMENT JOB. CEMENTING SECOND STAGE AT REPORT TIME. 01-29-01 PERFORMED SECOND STAGE CEMENT JOB. RIGGED DOWN HALLIBURTON. NIPPLE DOWN HYDRIL AND DIVERTER. NIPPLE UP BOP'S. 01-30-01 NIPPLED UP BOP'S AND TESTED BOP'S. PICKED UP BHA AND 9 7/8" BIT. RAN IN HOLE TO DRILL OUT CEMENT AND ES CEMENTER. PRESSURE TESTED CASING TO 1000 PSI. TEST FAILED. PULLED OUT OF HOLE. 01-31-01 TRIPPED IN HOLE. PUMPED SWEEP. AWAIT OFFICIAL WORD ON ABANDONMENT. PLUGGED HOLE. PULLED OUT OF HOLE. RAN IN HOLE TO TEST. Morning Reports Mudlogger's Morning Report Current Gas* Temp Out 0 ft/hr 0 units Deg F Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg 167 ft/hr ( 0 unit., ( ( 24 hr Max 359 ftJhr @ 217 ) 0 units @ ) deg F (~ ) Report No.: 1 Date: 1/16/01 0:00 Depth 369 Footage Last 24 hrs: 369 Rig Activity: Drillin~l Report For: Joe Polya Show? Pump and Flow Data Pump I 70 spm DH flow 592 gpm Pump 2 70 spm Total flow 592 gpm Pump 3 spin AV @ rsr fpm Pump Pres 580 psi AV @ DC fpm Mud Wt In Mud Wt Out 9.30 9.30 PPg PPg Visc 70 secs PV cP YP APl tilt mi HTHP lbs/100ft2 Gels mi Mud Wt at Max Gas ~PPg \ Ibsl100ft2 pH Sd . % Bit No.: 1 Wt On Bit: Bit Type: 5 RPM: Mx-C1 Bit Size: 4 Hrs. On Bit: 13 112 Jets: 12 \ 18 \ 18 \ Total Revs on Bit: na 18 \ \ TFA: 0.8560 ~ Footage for Bit Run 369 Trip Depth: Short Trip Depth Tight Spots: Current Lithology: ft Trip Gas: 0 ft Short Trip Gas: to shoe to Mud Cut: Mud Cut: to 60 % SD 40 % GRAV % ,, ppg Trip Cl: ppm , ppg Short Trip CI: ,ppm 'Feet of Fill on Bottomi' ft % % ft units ppg ft units ppg ,, ft units _..__ppg Depth to to to to Drill Rate bef dur Connection Gas and Mud Cut ff , units ...PPg ft units ppg ft units ppg ft units pPg ff units ppg ,,, ft units ..._......_ppg Drilling Breaks Gas Chlorides aft bef dur aft bef dur ii aft Lithology Sd Sst Sit Cly 24 hr Recap: Drilled F surface T 369. Logging Engineer: Doug Wilson/Reg Wilson * 10000 units =100% Gas In Air Mudlogger's Morning Report Current R.O.P. Gas* Temp Out 0 ft/hr 0 units Deg F Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AK. AM 10022 24 hr Avg 174 ft/hr ( 0 unit., ( ( 24 hr Max 493 ft/hr @ 981 ) 4 units @ 1195 ) ~ deg F @ ) Report No.: 2 Date: 1/17/01 0:00 Depth 1203 Footage Last 24 hrs: 834 Rig Activity: W.O.O. Report For: Joe Polya Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV (~ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.30 ppg Visc 70 secs Mud Wt Out 9.30 ppg PV ___cP YP APl flit mi HTHP ,, ,, lbs/100ft2 Gels mi Mud Wt at Max Gas PPg _ lbs/100ft2 pH Sd . % Bit No.: 1 Bit Type: .Wt On Bit: 5 RPM: Mx-C1 Bit Size: 4 Hrs. On Bit: 13 112 Jets: 12 \ 18 \ 18 \ Total Revs on Bit: na 18 \ \ TFA: 0.8560 -- Footage for B-----it Run 1203 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: 0 ft Short Trip Gas: to shoe to Mud Cut: Mud Cut: to · PPg Trip CI: ppm , ppg Short Trip CI: ppm . ' Feet of Fill on Bottom: ft Current Lithology: 70 % CLY 30 % SD % % % ft units PPg ff units , PPg ______ ft _.._._units ___PPg 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 Rate Gas bef dur aft bef dur aft to . to _ .----- tO .__ ---.- to .... Chlorides bef dur aft Lithology Sd Sst Sit Cly 24 hr Recap: Drilled F 369 T 1203'. Cell dike broke. Wait on orders. Logging Engineer: Doug Wilson/Reg Wilson * 10000 units =100% Gas In Air Mudlogger's Morning Report Laska Customer: Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 Current 24 hr Avg 24 hr Max it/hr ( ._.~.__.ft/hr R.O.P. n/a__it/hr ~ 3 units -- - -- Gas* 0 units 0 unit'. Temp Out ~ ~Deg F MudWt In 9.20 PPg Visc 6_..~.8 secs MudWtOut 9.20 PPg PV 15 cP YP 13 112 Bit No.: ~ Bit Type: Mx-C1 Bit Size: ~ On Bit: 5 RPM: 4 Hrs. On Bit: .__.._.._ . ~ 1203 _ff Trip Gas: Trip Depth: _ it Short Trip Gas: Short Trip Depth _ -- to ~ ~ Tight Spots: ~ Report No.: 3 Date: 1118/01 3 A.M. Depth ~ -- 0 Footage Last 24 hfs: ~ Rig Activity: circ & con ._ Report For: ~Paul Lockwood~ ShoW? _ -- Pump and Flow Data spin DH flow _--.-- gprr ~) Pump1 ~ spmTotalfl°w ~ gpm -circulating~_)) Pump 2 _ fpm -- __ Pump 3 - spin AV @ rsr .__..__ -- Pump Pre-~ ~ psi AV ~ DC fpm APt tilt 7.0 mi HTHP mi Mud Wt at Max Gas ._..~_PPg 8.90 Sd 1.0 % 33 tbsll00ff2 Gels 1..~7 \ 2_~.4 Ibsll00ff2 pH _._..__ Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Rev"'"~on Bit""~ '-"~a ~ Foota'""~e fo"~it Run ~ -- Mud Cut: --'--"' PPg Short Trip Cl: ___..._- it .-- -- tO ~ Feet of Fill on Bottom'S' ~ Current Lithology: 7o % CLY 30 %~ it units _._..._PPg ~ ff ~ units ~ PPg ~ it units ._.. PPg Depth Connection Gas and Mud Cut' it units __.._.PPg ------- ppg ~it units ~ __ ~ ppg -- it units ~ Drilling Breaks Gas Drill Rate bef dur afl bef dur aft it units __~.PPg - -- ft ~ units ..___..PPg -- ~ units __.._.PPg Lithology Chlorides bef dur afl Sd Sst hr Recap: Tri ging Engineer: Doug WiisoniReg Wilson 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. Gas* Temp Out Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg ft/hr ft/hr ( units unit,, ( Deg F ( 24 hr Max fi/hr @ ) units @ ) deg F @ ) Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Show? 4 1/19/01 5 a.m. 1203 0 W.O.O. Paul Lockwood Pump and Flow Data 3ump 1 spm DH flow Pump 2 spm Total flow Pump 3 spm AV @ rsr Pump Pres psi AV @ DC gpm gpm fpm fpm Mud Wt In 9.20 ppg Visc 55 secs Mud Wt Out 9.20 ppg PV 1..._~.5 c'P YP APl flit 6.2 mi HTHP 30 Ibs/100ft2 Gels 15 \ mi Mud Wt at Max Gas pPg 30 Ibsll00ft2 pH 8.80 Sd 0.3 ,, ,. ,Bit No.: 1 Bit Type: Mx-C1 Bit Size: Wt On Bit: 5 RPM: 4 ~'rs. On Bit: Trip Depth: 1203 ft Trip Gas: Short Trip Depth 0 ft Short Trip Gas: Tight Spots: to shoe to Current Lithology: ___.% _-------- .___. % 131/2 Jets: 12 \ 18 \ Total Revs on Bit: 18 \ 18 \ \ TFA: 0.8560 na -- Footage for Bit Run 1203 Mud Cut: .... ppg Trip Cl: ppm Mud Cut: , ppg Short Trip Cl: ppm to 'Feet of Fill on Bottom: ft % %LCM ft , , units ... ... ppg ft units ppg it units .._...__ppg Depth to to to to Connection Gas and Mud Cut ft units ppg fl units ppg ft ~units ._.--.-PPg Drilling Breaks Drill Rate Gas before during after before during after ft units ppg ,,. ft units .... PPg ft ..---units ._--.--PPg % Lithology Sd Sst Sit Cly 24 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. BACKGROUND GAS WHILE CIRCULATING: 1 - 2 UNITS. BOTTOMS UP TRIP GAS: 4 UNITS. * 10000 units =100% Gas In Air Logging Engineer: Doug Wilson / Tom Mansfield Mudlogger's Morning Report Current R.O.P. Gas* Temp Out 24 hr Avg Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 fi/hr units Deg F 24 hr Max fi/hr( fi/hr @ ) unit.~ ( units @ ) ( deg F @ ) Report No.: 4 Date: 1/19/01 5 a.m. Depth 1203 Footage Last 24 hrs: 0 Rig Activity: W.O.O. Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spin AV (~ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Mud Wt Out 9.20 ppg Visc 55 secs APl flit 6.2 mi HTHP mi Mud Wt at Max Gas ppg PV 15 cP YP 30 Ibs/100ft2 Gels 15 \ 30 Ibs/100ft2 pH 8.80 Sd 0.3 % Bit No.: 1 Bit Type: Wt On Bit: ,5 RPM: Mx-C1 Bit Size: 4 Hrs. On Bit: Trip Depth: 1203 Short Trip Depth 0 Tight Spots: ,.._.=.._._to ft Trip Gas: ft Short Trip Gas: shoe to 13 112 Jets: 12 \ 18 \ 18 \ 18 \ __\__TFA: 0.8560_ Total Revs on Bit: na Footage for Bit Run. 1203 Mud Cut: ppg Trip CI: ppm Mud Cut: ppg Short Trip Cl: ppm tO Feet of Fill on Bottom: ,,ft Current Lithology: % __ % __..__ ___ % % %LCM ft units ppg ft units ppg ft .------ units ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units _--.-- ppg ft units pPg ~ ft ,.,. units ,. ppg ff __ units _----PPg Depth to to to to Drilling Breaks Drill Rate Gas before during after before during after % Lithology Sd Sst Sit. Cly :)4 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. BACKGROUND GAS WHILE CIRCULATING: 1 - 2 UNITS. BOTTOMS UP TRIP GAS: 4 UNITS. _ __ * 10000 units = 100% Gas In Air Logging Engineer: Doucj Wilson / Tom Mansfield Mudlogger's Morning Report Current R.O.P. fi/hr Gas* units Temp Out Deg F Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg 24 hr Max fi/hr ( fi/hr @ ) unit,, ( units @ ) ( deg F @ ) Report No.: 5 Date: 1/20/01 5 ~,.M. Depth 1203 Footage Last 24 hrs: 0 Rig Activity: W.O.O. Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 49 secs APl flit 7.5 mi HTHP mi Mud Wt at Max Gas ~ppg MudWtOut 9.20 ppg PV 12 cP YP 28 Ibsll00ft2 Gels 14 \ 21 Ibsll00ft2 pH 8.40 Sd 0.5 % Bit No.: 1 Bit Type: Mx-C1 Bit Size: 13 1/2 Wt On Bit: 5 RPM: 4 Hrs. On Bit: Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na ~ Footage for Bit Run 1203 Trip Depth: 1203 ft Trip Gas: 6 Mud Cut: ~ppg Trip CI: ppm Short Trip Depth 0 ff Short Trip Gas: Mud Cut: ~pPg Short Trip CI: ppm Tight Spots: to shoe ~ to , to , Feet of Fill on Bottom: ft Current Lithology: % , % % .. % %LCM Connection Gas and Mud Cut ft units _,_-- ppg ~ ft __ units ~ ppg ~ ff __ units ppg ff __ units ___- ppg ~ ft __ units ...._._-- ppg ~ ft __ units _.---- ppg ft. units ~PPg ft units ._.---.-PPg ft units ~ ppg Depth to to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly 24 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. BACKGROUND GAS WHILE CIRCULATING: 3 UNITS. TRIP GAS: 6 UNITS. Logging Engineer: Doug Wilson /Tom Mansfield * 10000 units = 100% Gas In Air , Mudlogger's Morning Report Customer: BP Alaska Report No.: 6 Well: Northstar NS 26 Date: 1/21/01 5A.M. Area: North Slope Depth 1203 Lease: Northstar NS 26 Footage Last 24 hfs: 0 Rig: Nabors 33E Rig Activity: W.O.O. Job No.: AKAM 10022 Report For: Paul Lockwood Show? Current 24 hr Avg 24 hr Max R.O.P. fi/hr fi/hr ( fi/hr @ ) Gas* units unit.~ ( units @ ) Temp Out Deg F ( ~ deg F @ ) Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm MudWtln 9.20 ppg Visc 49 secs APl flit 7.5 mi HTHP mi Mud Wt at Max Gas ~ppg MudWtOut 9.20 ppg PV 12 cP YP 28 Ibs/100ft2 Gels 14 \ 21 Ibs/100ft2 pH 8.40 Sd 0.5 % Bit No.: 1 Wt On Bit: Bit Type: Mx-C1 Bit Size: 131/2 Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 5 RPM: 4 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 1203 Trip Depth: Short Trip Depth Tight Spots: 1203 ft Trip Gas: 3 Mud Cut: ppg Trip CI: ppm 0 ft Short Trip Gas: Mud Cut: ____ ppg Short Trip Cl: ppm tO shoe to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM fl units ft units ft units Connection Gas and Mud Cut ____.ppg ~ft__units ._....._.ppg ff~units ppg , ppg ff units .___._ppg ff~units ppg ....__._ppg ~ff~units ~ppg ff units ppg Depth to to to to Drilling Breaks Drill Rate Gas % Lithology before during , after before during after Sd Sst Sit Cly 24 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. B,U. ~ 13:45: TRIP GAS 3 UNITS, CARBIDE LAG ~ 2270 STKS B.U. = EST. AVG HOLE SIZE OF 14.2" B.U. ~ 05:15: TRIP GAS 3 UNITS, CARBIDE LAG (~ 2680 STKS B.U. = EST. AVG. HOLE SIZE OF 14.8" Logging Engineer: Dou~ Wilson /Tom Mansfield * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 Current 24 hr Avg 24 hr Max R.O.P. fi/hr fi/hr ( fi/hr @ ) Gas* units unit., ( units @ ) Temp Out Deg F ( deg F @ ) Report No.: 7 Date: 1/22/01 5 A.M. Depth 1203 Footage Last 24 hfs: 0 Rig Activity: W.O.O. Report For: Paul Lock.wood Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm MudWtln 9.20 ppg Visc 49 secs APl flit 7.5 mi HTHP mi Mud Wt at Max Gas ~ppg MudWtOut 9.20 ppg PV 12 cP YP 28 Ibs/100ft2 Gels 14 \ 21 Ibs/100ft2 pH 8.40 Sd 0.5 % Bit No.: 1 Wt On Bit: BitType: Mx-C1 BitSize: 131/2 Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 5 RPM: 4 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 1203 Trip Depth: Short Trip Depth Tight Spots: 1203 ft Trip Gas: I Mud Cut: ppg Trip CI: ppm 0 ft Short Trip Gas: Mud Cut: .._____ppg Short Trip CI: ppm to shoe to to Feet of Fill on Bottom: ft Current Lithology: % % % % , %LCM ft units ff units ft units Connection Gas and Mud Cut ,,, ppg ~ ft ~ units ~ ppg ft , units ~ ppg '" ppg ft ~ units ~ ppg ft ~ units , ppg _....__. ppg ff units ___-- ppg ft units ._----- ppg Depth to to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly ~_4 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. CIRC (~ 1:30: TRIP GAS 1 UNIT, CARBIDE LAG (~ 2635 STKS B.U. = EST. AVG HOLE SIZE OF 14.5" Logging Engineer: Dou~l Wilson / Tom Mansfield * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. Gas* Temp Out Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg 24 hr Max fi/hr fi/hr ( fi/hr @ ) units unit,, ( units @ ) Deg F ( deg F @ ) Report No.: 8 Date: 1/23/01 5 A.M. Depth 1203 Footage Last 24 hrs: 0 Rig Activity: W.O.O. Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 50 secs APl flit 7.0 mi HTHP mi Mud Wt at Max Gas ~.ppg MudWtOut 9.20 ppg PV 15 cP YP 30 Ibsll00fi2 Gels 14 \ 21 Ibs/100ft2 pH 9.00 Sd 0.5 % Bit No.: 1 Wt On Bit: Bit Type: Mx-C1 Bit Size: 13 1/2 Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 5 RPM: 4 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 1203 Trip Depth: Short Trip Depth Tight Spots: 1203 fi Trip Gas: 3 Mud Cut: ~ppg Trip Ch ppm 0 ft Short Trip Gas: Mud Cut: ppg Short Trip CI: , ppm to shoe to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM ft units ft units ft units Connection Gas and Mud Cut ~ ppg ~ ft __ units _._-- ppg ~ fi __ units , ppg ...._._ ppg ~ ft ~ units ~ ppg ~ ff ~ units ppg ~ ppg ~ ft ~ units ~ ppg ~ ft ~ units . ppg Depth tO to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly 24 hr Recap: W.O.O. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. CIRC ~ 1:30: TRIP GAS 3 UNIT ~ 2675 STKS B.U. = EST. AVG HOLE SIZE OF 14.5" Logging Engineer: Dou~l Wilson/Tom Mansfield * 10000 units = 100% Gas In Air [:]I~IL..I_I NOS SEEI::I~JIC::EES Mudlogger's Morning Report Current R.O.P. Gas* Temp Out Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 26 North Slope Northstar NS 26 Nabors 33E AKAM 10022 24 hr Avg 24 hr Max ft/hr ft/hr ( ft/hr @ ) units unit., ( units @ ) Deg F ( deg F @ ) Report No.: 9 Date: 1/24/01 5 A.M. Depth 1203 Footage Last 24 hrs: 0 Rig Activity: W.O.O. Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In Mud Wt Out 9.20 9.20 ppg Visc 51 secs APl flit 7.0 mi HTHP ppg PV 12 cP YP 29 Ibs/100ft2 Gels 14 .\ mi Mud Wt at Max Gas ppg 22 Ibs/100ft2 pH 9.00 Sd 0.5 Bit No,: 1 Wt On Bit: Bit Type: 5 RPM: Mx-C1 Bit Size: 131/2 Jets: 12 \ 18 \ 18 \ 4 Hrs. On Bit: Total Revs on Bit: na 18 \ \ TFA: 0.8560 Footage for Bit Run 1203 Trip Depth: Short Trip Depth Tight Spots: 1203 ft Trip Gas: 2 Mud Cut: ~PPg TripCl: ppm 0 ft Short Trip Gas: Mud Cut: ~ ppg Short Trip Cl: ppm to shoe to to Feet of Fill on Bottom: ft Current Lithology: % % % % %LCM ft units ft units ft units Connection Gas and Mud Cut ....~__ppg ff units __.._.ppg ~ft~units ..ppg _.._.__ppg' ~ff~units ~ppg ~ff~units ~ppg . ppg __..___fi____units ...._...._ppg ft units _._.._.ppg Depth to to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly 24 hr Recap: WAITING FOR COMPLETION OF INJECTION WELL. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. LAST CIRC. ON BOTTOM ,~ 14:00 HRS. WITH 2 UNITS TRIP GAS AND CARBIDE LAG OF 2550 STKS B.U. Logging Engineer: Doucj Wilson/Tom Mansfield * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current R.O.P. fi/hr Gas* units Temp Out Deg F 24 hr Avg Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Max fi/hr ( ~fi/hr @ ) unit., ( units @ ) ( deg F @ Report No.: 10 Date: 1/25/01 5 A.M. Depth 1203 Footage Last 24 hrs: 0 Rig Activity: W.O.O. Report For: Paul Lockwood Show? Pump and Flow Data Pump 1 spin DH flow gpm Pump 2 spm Total flow gpm Pump 3 spin AV @ rsr fpm Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Mud Wt Out 9.20 ppg Visc 51 secs APl flit 7.0 mi HTHP mi Mud Wt at Max Gas ..-.---ppg PV 12 cP YP 29 Ibsll00ft2 ' Gels 14 \ 22 Ibs/100ft2 pH 9.00 Sd 0.5 % Bit No.: 1 Bit Type: Wt On Bit: 5 RPM: Mx-C1 Bit Size: 131/2 Jets: 1,2 \ 18,,,,\ 18 \ 18 \ ~\ TFA: 0.8560 4 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 1203 Trip Depth: 1203 ft Short Trip Depth 0 , ft Tight Spots: to , · Current Lithology: ~ % Trip Gas: 2 Mud Cut: ,,, ppg Trip Ch ppm Short Trip Gas: Mud Cut: ~ppg Short Trip Ch ppm shoe to to Feet of Fill on Bottom: ~ ft % % % %LCM ft ~ units ' , ppg , ft , units , ppg ft units .._.--- ppg Connection Gas and Mud Cut ~ ft ~ units .____. ppg ~ ft , units ppg ft units ppg ft ~ units _.._---PPg ft ~ units ppg ft units _.--.--- ppg Depth to to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly 24 hr Recap: CURRENTLY COMPLETING INJECTION WELL. MAKE PERIODIC WIPER TRIPS TO CIRC. & COND. HOLE. LAST CIRC. ON BOTTOM (~ 09:30 HRS. WITH 2 UNITS TRIP GAS AND CARBIDE LAG OF 2500 STKS B.U. Logging Engineer: Mark Lindloff /Tom Mansfield * 10000 units = 100% Gas In Air sperry-sun Mudlogger's Morning Report Customer: BP Alaska Report No.: 11 Well: Northstar NS 26 Date: 1/26/01 5 A.M. Area: North Slope Depth 2618 Lease: Northstar NS 26 Footage Last 24 hrs: 1415 Rig: Nabors 33E Rig Activity: Driliin~l Job No.: AKAM 10022 Report For: Paul Lockwood Show? n/a Current 24 hr Avg 24 hr Max R.O.P. 185 fi/hr 198 fi/hr ( 505 fi/hr @ 1826 ) Gas* 13 units 15 unit., ( 45 units @ 2278 ) Temp Out Deg F ( deg F @ ) Pump and Flow Data Pump 1 70 spm DH flow 296 gpm Pump 2 65 spin Total flow 275 gpm Pump 3 spm AV (~ rsr fpm Pump Pres 800 psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 58 secs APl flit 6.2 mi HTHP mi Mud Wt at Max Gas .._.-__ ppg Mud WtOut 9.20 ppg PV 15 cP YP 28 Ibs/100ft2 Gels 14 \ 22 Ibs/100ft2 pH 8.80 Sd 1.3 % Bit No.: 1 Bit Type: Mx-C1 Bit Size: 13 1/2 Jets: 12 \ 18 \ 18 \ 18 \ ~\ TFA: 0.8560 Wt On Bit: 5 to 10 RPM: 60 Hrs. On Bit: Total Revs on Bit: na Footage for Bit Run 2618 Trip Depth: 1203 ft Trip Gas: 2 Mud Cut: ..~..._ppg Trip CI: .ppm Short Trip Depth ft Short Trip Gas: Mud Cut: __.---ppg Short Trip Ch ppm Tight .Spots: to shoe to to . Feet of Fill on Bottom: ft Current Lithology: 80 % CLY 20 % . SI:) % % %LCM Connection Gas and Mud Cut nla 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 Depth Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly n/a to to to 24 hr Recap: Begin drilling] at 12:30. Drilling ahead at report time. Logging Engineer: Mark Lindloff /Tom Mansfield * 10000 units = 100% Gas In Air Mudlogger's Morning Report Current ).P. 96 Gas* 11 Temp Out Customer: Well: Area: Lease: Rig: Job No.: BP Alaska Northstar NS 26 North Slope Northstar NS 26 Nabors 33E AKAM 10022 24 hr Avg 24 hr Max ft/hr 198 ft/hr ( 415 ft/hr @ 2931 ) units 16 unit,,( 20 units @ 2845 ) Deg F ~ ( deg F @ ) Report No.: 12 Date: 1/27/01 5 A.M. Depth 3302 Footage Last 24 hrs: 684 Rig Activity: POOH Report For: Paul Lockwood Show? n/a Pump and Flow Data Pump 1 75 spm DH flow 317 gpm Pump 2 75 spm Total flow 317 gpm Pump 3 spm AV @ rsr fpm Pump Pres 1200 psi AV @ DC fpm Mud Wt In 9.20 Mud Wt Out 9.20 ppg Visc 51 secs APl flit 6.2 ,mi HTHP ppg PV 13 c~5 YP 26 Ibs/100ft2 Gels 11 \ mi Mud Wt at Max Gas ppg 26 Ibs/100ft2 pH 8.80 Sd 0.3 Bit No.: 1 Bit Type: WtOnBit: 20 to 30 RPM: Mx-C1 Bit Size: 13 1/2 Jets: 12 \ 18 \ 18,.\ 50 Hrs. On Bit: Total Revs on Bit: na 18 \ \ TFA: 0.8560 Footage for Bit Run 3145 Trip Depth: ft Trip Gas: Mud Cut: Short Trip Depth 3302 ft Short Trip Gas: 26 Mud.Cut: Tight Spots: 2420 to 2140 _.__t° to Current Lithology: 9__=Lo % CLY 10 % , SD , ,PPg Trip CI: ,ppm , ppg Short Trip CI: ppm 'Feet of Fill on Bottom: % %LCM Connection Gas and Mud Cut n/a ft units ppg ft , units ppg ~ ft ~ units ppg ft ,,,, units ....._--ppg ~ ff ~ units _-.--- ppg ff units .....--- ppg Drilling Breaks ft units ppg ft units ppg , ,,, ft m units _----- ppg Depth Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly n/a to to tO tO .24 hr Recap: Drilled ahead to 3302'. Circ. & recip. While pumping high vis sweeps. Short tripped to shoe: pulled slow to prevent swabbincj. Back reamed from 2424' to 2329'. Ran in hole. Dropped Carbide Lacj while circulating on bottom: L.a~] = 6975 stks - / 492 D.P. + 200 Trap Lacj/= 6283 stks Bottoms Up. Pumped Hi Vis sweeps. Pullincj out of hole at report time. Hole actincj ~lood. * 10000 units = 100% Gas In Air Logging Engineer: Mark Lindloff /Tom Mansfield nFIICLI NG S~:FtVICES Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 Current 24 hr Avg 24 hr Max R.O.P. ft/hr ftJhr ( ft/hr @ ) Gas* units unit,, ( units @ ) Temp Out Deg F ( deg F @ ) Report No.: 13 Date: 1/28/01 5 A.M. Depth 3302 Footage Last 24 hrs: 0 Rig Activity: Cement Report For: Paul Lockwood Show? n/a Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spm AV @ rsr fpm Pump Pres 1200 psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 51 secs APl flit 6.2 mi HTHP MudWtOut 9.20 ppg PV 13 cP YP 26 Ibs/100ft2 Gels 11 \ mi Mud Wt at Max Gas ppg 26 Ibs/100ft2 pH 8.80 Sd 0.3 % Bit No.' 1 . Bit Type: Mx-C1 Bit Size: 13 1/2 Wt On Bit: 20 to 30 RPM: 50 Hrs. On Bit: 14.5 Jets: 12 \ 18 \ 18 \ 18 \ \ TFA: 0.8560 Total Revs on Bit: na Footage for Bit Run 3145 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: 2420 to 2140 to Current Lithology: 90 % CLY 10 % SD Mud Cut: ppg Trip Cl: ppm Mud Cut: ppg Short Trip Cl: . ppm to Feet of Fill on Bottom: ft % % %LCM nla ft units ppg ft units ppg ft units ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg n/a Depth to to to to Drilling Breaks Drill Rate Gas before during after before during after % Lithology Sd Sst Sit Cly 24 hr Recap: Pulled out of hole to run 10 3/4" casing. Ran 10 3/4" casincj, set at 3287'. Circulated and recipricated casing. 6 units of gas from bottoms up. Performed 1st stage cement job. Cementing 2nd stage at report time. · * 10000 units =100% Gas In Air Logging Engineer: Mark Lindloff /Tom Mansfield Mudlogger's Morning Report Current R.O.P. Gas* Temp Out Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg 24 hr Max ft/hr ft/hr ( fi/hr @ ) units unit., ( units @ ) Deg F ( deg F @ ) Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Show? 14 1/29/01 5' A.M. CSG @ §287' 0 Cement Paul Lockwood n/a Pump and Flow Data Pump 1 spin DH flow Pump 2 spin Total flow Pump 3 spm AV @ rsr Pump Pres psi AV @ DC gpm fpm fpm Mud Wt In 9.20 ppg Visc 51 secs APl flit 6.2 mi HTHP mi Mud Wt at Max Gas .._._._ppg MudWtOut 9.20 ppg PV 13 cP YP 26 Ibs/100ft2 Gels 11 \ 26 Ibs/100ft2 pH 8.80 Sd 0.3 % Bit No.: I Bit Type: Mx-C1 Bit Size: 131/2 Jets: 12 \ 18 \ 18 \ 18 \ __\ __TFA: 0.8560 Wt On Bit: ' 20 to 30 RPM: 50 Hrs. On Bit: 14.5 Total Revs on Bit: na Footage for Bit Run 3145 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: ~ to to Mud Cut: ppg Trip Cl: ppm Mud Cut: ppg Short Trip Cl: ppm. to Feet of Fill on Bottom: Current Lithology: 90 % CLY 10 % SD % % %LCM n/a ft units ppg ft units ppg ft units ppg Connection Gas and Mud Cut ft __ units __--- ppg ~ ft __ units __ ppg ff __ units .___ ppg ft __ units __ ppg ft __ units ~ ppg ft __ units ppg Depth n/a to to to to Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sd Sst Sit Cly 24 hr Recap: Performed 2nd stacje of cemen{job. Ri~ed down Haliburton. Nipple down Hydril and diverter. Nipple up BOP's. Logging Engineer: Mark Lindloff /Tom Mansfield * 10000 units = 100% Gas In Air iiltl , ,, ,' , ,, Mudlogger's Morning Report Current R.O.P. Gas* Temp Out Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AKAM 10022 24 hr Avg ft/hr fi/hr ( units unit,, ( Deg F ( 24 hr Max fi/hr @ ) units @ ) deg F @ ) Report No.: 14 Date: 1/30/01 5 A.M. Depth CSG @ 3287' Footage Last 24 hrs: 0 Rig Activity: POOH, WOO Report For: Paul Lockwood Show? n/a Pump and Flow Data Pump 1 spm DH flow gpm Pump 2 spm Total flow gpm Pump 3 spin AV @ rsr fpm .Pump Pres psi AV @ DC fpm Mud Wt In 9.20 ppg Visc 43 secs MudWtOut 9.20 ppg PV 10 cP YP APl flit 8.2 19 Ibs/100ft2 mi HTHP mi MudWtat Max Gas ppg Gels 10 \ 16 Ibsll00ft2 pH 8.80 Sd tr Bit No.' .2 Bit Type: DS70FNPV Bit Size: Wt On Bit: RPM: Hrs. On Bit: 9 7/8 Jets: 14 \ 14 \ 14 \ 14 \ 14 \ 14 TFA: Total Revs on Bit: na -- Footage for I~it Run 0.9020 Trip Depth: , ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to Mud Cut: ppg Trip Cl: ppm Mud Cut: ppg Short Trip Cl: ppm to Feet of Fill on Bottom: ft Current Lithology: 90 % CLY 10 % SD % % %LCM Connection Gas and Mud Cut n/a ff~units .__..._ppg ~ft~units ~ppg ff units ..__..._ppg ft~units ....___.ppg ff units , ppg ft units , ppg ~ ft ~ units . ppg ft ~ units , ppg ft units ,,, ppg Drilling Breaks Depth Drill Rate Gas before during after before during n/a to to to after % Lithology Sd Sst Sit Cly 24 hr Recap: Nippled up BOP's and tested same. Picked up BHA and 9 7/8" bit. Ran in hole to drill out cement and ES Cementer. Pressure test casin~l to 1000 psi. Test failed. Pull out of hole. * 10000 units = 100% Gas In Air Logging Engineer: Mark Lindloff / Tom Mansfield Mudlogger's Morning Report Customer: BP Alaska Well: Northstar NS 26 Area: North Slope Lease: Northstar NS 26 Rig: Nabors 33E Job No.: AK, AM 10022 Current 24 hr Avg R.O.P. ft/hr ft/hr ( Gas* units unit,, ( Temp Out Deg F ( 24 hr Max ft/hr @ ) units @ ) deg F ~ ) .Report No.: Date: Depth Footage Last 24 hfs: Rig Activity: Report For: Show? 15 1/31/01 5 A.M. CSG @ 3287' 0 POOH/Test Paul Lockwood n/a Pump and Flow Data Pump 1 spm DH flow Pump 2 spm Total flow Pump 3 spin AV @ rsr Pump Pres psi AV @ DC gpm gpm fpm fpm Mud Wt In 9.20 ppg Visc 43 secs MudWtOut 9.20 ppg PV 10 cP YP APl flit 8.2 19 Ibs/100ft2 mi HTHP mi Mud Wt at Max Gas ppg Gels 10 \ 16 Ibs/100ft2 pH 8.80 Sd tr Bit No.: 2 Bit Type: DS7OFNPV Bit Size: Wt On Bit: RPM: Hrs. On Bit: 9 7/8 . Jets: 14 \ 14 \ 14 \ 14 \ 14 \ 14 TFA: 0.9020 , ,~ Total Revs on Bit: na Footage for Bit Run Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to Mud Cut: ppg Trip Cl: Mud Cut: ,, ppg Short Trip CI: to Feet of Fill on Bottom: ppm ppm ft Current Lithology: 90 % CLY 10 % SD % % %LCM Connection Gas and Mud Cut n/a ft __ units ppg ~ ft __units __ppg ft __ ft __ units , ppg ~ ft __ units ppg ft __ ft units ___._ ppg ft units __PPg ft units ..... ppg units . ppg units ._...__ppg Drilling Breaks Depth Drill Rate Gas before during after before during after Sd n/a to to to to % Lithology Sst Sit Cly ,! 24 hr Recap: Trip in hole. Pump sweep. Await official word on abandonment. Plug ,hole, Pull out of hole. Run in hole to test. ,,, * 10000 units = 100% Gas In Air Logging Engineer: Mark Lindloff / Recj Wilson Show Reports NO SHOWS ENCOUNTERED IN THIS WELL. Bitru.n Summary Bitrun Summary Drilling Data Start Depth: 199.00 It End Depth: 3302.00 It Footage: 3103.00 It Avg. Flow Rate: 0.00 gpm Avg. RPM: 50.00 rpm Avg. WOB: 5.00 klb Avg. ROP: 60.00 fph Avg. SPP: 1040.00 psig Run Time Data MWD Run: Rig Bit No: Hole Size: Run Start: Run End: BRT Hfs: Circ. Hrs: Oper. Hrs: 0100 1 13.50 in 15-Jan-01 14:28 26-Jan-01 12:50 262.37 0.00 0.00 MWD Schematics (17) Component (9) (8) (7) (6) (5) (4) (3) (2) (1) Mud Data Mud Type: Water Based Weight I Visc: 9.20 ppg / 43.00 Chlorides: 36000.00 ppm PV/YP: 10.00 cp / 19.00 Solids/Sand: 5 % / .25 %Oil/O:W: 0 % / 0 pH/Fluid Loss: 8.80 pH / 6.20 Max. Temp. ' 0.00 degF BHA Schematics Length O.D. I.D. (it) (in) (in) 17. Drill Pipe 16. HWDP 15. Drilling Jars HYD 14. HWDP 13. Cross Over Sub 12, Monel collar 11. Monel Stabilizer 10. Monel collar 09. Monel collar 08. Monel Stabilizer 07. 8 3~8" ANA MWD/LWD 06. Monel Stabilizer 05. MONEL LC 04. MONEL LC 03. 9-5/8" STD MTR 1.83' 02. Cross Over Sub 01. MXC-1 spqt Ihf2 % rnptm 2389.50 5.000 4.276 600.67 5.000 3.000 32,69 6.500 2.750 89.91 5.000 3.000 2.05 7,875 2,875 30.82 7,875 2,880 5.59 9.880 2,880 30.85 8.000 2,810 30,55 8,000 2,810. 5.72 9.880 2.880 29.02 8,380 2.000 5.56 9.880 2.880 9.53 8.000 2.813 10.45 8.063 2.810 26.64 9.630 3.000 0.90 8.810 2.880 1.50 13.500 0.000 Comments 13 1/2" HOLE SECTION - GAS OCCURENCES, L.O.T. & BIT HRS- NO L.O.T. , 27.3 BIT HOURS FIRST GAS OCCURENCE AT 1145' MD, SHORT TRIP AT 1203' MD OBSERVED 4 UNITS SHORt TRIP GAS. THROUGH INTERVAL GAS RANGED FROM 0 TO 47 UNITS ( 2280' MD)., VVITH MINOR CONNECTION GASES. NO HOLE PROBLEMS WERE OBSERVED IN THIS INTERVAL. MWD Performance Tool OD/Type: 8.00 in / 'MVVD Real-time%: 0.00 % / 0.00 % MWD Recorded%: 0.00 % / 0.00 % Min. Inc.: 0.49 deg/ 263.64 It Max. Inc.: 20.24 deg/ 3230.64 It Final Az.: 306.17 deg Max Op. Press.: 0.00 psig Job No.: AKAM10022 Well No.: NS26 · End of Well Report Page 3 Bitrun Summary Run Time Data Drilling Data Mud Data ,Start Depth: 199.00 ft i End Depth · 3302.00 ff Footage: 3103.00 ft Avg. Flow Rate: 0.00 gpm Avg. RPM: 50.00 rpm Avg. WOB: 5.00 klb Avg. ROP: 60.00 fph Avg. SPP: 1040.00 psig MWD Run · Rig Bit No: Hole Size' Run Start' Run End · BRT Hrs · Circ. Hrs' Oper. Hrs' ,, 0100 1 13.50 in 15-Jan-01 14:28 26-Jan-01 12:50 262.37 0.00 0.00 Mud Type · Water Based Weight / Visc' 9.20 ppg / Chlorides' 36000.00 ppm 43.00 spqt PV/YP: 10.00 cp / 19.00 Ihf2 Solids/Sand: 5 % / .25 % %Oil/O:W: 0 % / 0 pH/Fluid Loss: 8.80 pH / 6.20 mptm Max. Temp.: 0.00 degF MWD Schematics BHA Schematics (17) II Component Length O.D. I,D. (ft) (in) (in) (16) 17. Drill Pipe 2389.50 5.000 4.276 (15) ~ 16. HWDP 600.67 5.000 3.000 (14) 15, Drilling Jars HYD 32.69 6.500 2.750 1~231 14. HWDP 89.91 5.000 3.000 13. Cross Over Sub 2.05 7.875 2.875 (11) 12. Monel collar .30.82 7.875 2.880 (10) 11. Monel Stabilizer 5.59 9.880 2.880 (9) [I 10. Monel collar 30.85 8.000 2,810 09. Monel collar " 30.55 8.000 2.810 (8) !i ~ 08. Monel Stabilizer 5.72 9.880 2.880 (7) !~ 07. 8 3/8" ANA MWD/LWD 29.02 8.380 2.000 (6). ~ 06. Monel Stabilizer 5.56 9.880 2.880' (5) 05. MONEL LC 9.53 8.000 2.813 (4) 04. MONEL LC 10.45 8.063 2.810 03. 9-518" STD MTR 1.83' 26,64 9.630 3.000 (3) 02. Cross Over Sub 0.90 8.810 2.880 (2) 01. MXC-1 1.50 13.500 0.000 (1) Comments MWD Performance 131/2-HOLE SECTION- GAS OCCURENCES, L.O.T. & BIT HRS- Tool OD/Type' 8.00 in / MWD Real-time%: 0.00 % / MWD Recorded%: 0.00 % / Min. Inc. · 0.49 deg / Max. Inc. · 20.24 deg / Final Az..: 306.17 deg Max Op. Press. · 0.00 psig 0.00 0.00 263.64 3230.64 . i Page 3 Job No.: AKAM10022 Well No.: N526 End of Well Report Directional- Survey Data Directional Survey Data Measured Inclination Direction Depth (feet) (degrees) (degrees) Vertical Latitude Departure Depth (feet) (feet) (feet) Vertical Dogleg Section (feet) (deg/100f) 0.00 0.00 0.00 0.00 0.00 N 263.64 0.49 127.40 263.64 0.68 S 292.16 0.51 125.69 292.16 0.83 S 382.60 0.24 110.67 382.59 1.13 S 471.90 0.24 111.48 471.89 1.27 S 564.76 655.76 745.22 835.52 930.55 0.74 316.36 564.75 0.91S 0.98 303.49 655.74 0.05 S 0.94 308.07 745.19 0.82 N 1.05 305.72 835.47 1.76 N 0.23 351.74 930.50 2.46 N 1025.67 0.27 44.77 1025.62 2.81 N 1120.08 0.21 40.52 1120.03 3.10 N 1213.11 0.30 32.17 1213.06 3.43 N 1307,41 0.43 20.38 1307.35 3.97 N 1401.20 0.81 326.18 1401.14 4.85 N 1495.85 1589.94 1687.47 1780.69 1874.38 1.40 313.90 1495.77 6.21N 3.93 311.73 1589.75 9.16 N 6.69 311.39 1686.85 15.14 N 7.96 308.85 1779.31 22.78 N 8.81 306.94 1872.00 31.16 N 1968.83 10.37 308.28 1965.13 40.77 N 2063.43 12.42 306.79 2057.86 52.14 N 2157.09 14.11 307.27 2149.01 65.09 N 2252.93 16.56 307.74 2241.44 80.52 N 2347.68 18.97 306.52 2331.66 97196 N 2442.49 19.53 306.16 2421.17 116.48 N 2536.50 20.40 305.06 2509.53 135.16 N 2630.95 21.22 303.43 2597.82 154.04N 2726.52 20.80 303,69 2687.03 172.98 N 2820.37 21.18 303.95 2774.66 191.69 N 2914.26 20.74 303..66 2862.33 210.37 N 3008.85 20.60 303.79 2950.83 228.91 N 3102.89 20.74 305.65 3038.82 247.82 N 3196.16 20.51 306.38 3126.11 267.14 N 0.00 E 0.00 TIE-IN 0.g0 E -1.13 0.19 1.10 E -1.38 0.09 1.60 E -1.96 0.32 1.95 E -2.32 0.00 1.72 E -1.92 1.04 0.66 E -0.56 0.34 0.55 W 0.93 0.10 1.81W 2.50 0.13 2.54 W 3.51 0.95 2.41 W 3.61 0.24 2.14 W 3.56 0.07 1.90 W 3.56 0.10 1.65 W 3.68 0.16 1.90 W 4.39 0.70 3.10W 6.17 0,67 6.34W 10.52 2.69 13.09W 19.50 2.83 22.19'W 31.36 1.41 32.98W 45.01 0.95 45.44W 60.74 1.67 60.27W 79.42 2.19 77.42W 100.91 1.81 97.52W 126.25 2.56 120,58W 155.15 2.57 145.76W 186.41 0.60 171.86W 218.50 1.01. 199.60W 252.04 1.06 228.15W 286.27 0.45 256.08W 319.86 0.42 283.99W 311.76W 339.04W 365.61W 353.41 0'.48 386.77 0.i6 419.95 0.71 452.81 0.37 Job No.: AKAM10022 Well No.: NS26 End of Well Report Page4 Directional Survey Data CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG CLOSURE OF 306.15 DEGREES (TRUE) A TOTAL CORRECTION OF 26.91 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT iS RELATIVE TO THE WELL HEAD. HORIZONTAL DISPLACEMENT(CLOSURE) AT 3196.16 FEET IS 452.81 FEET ALONG 306.15 DEGREES (TRUE) SURVEY INFORMATION PROVIDED BY ANADRILL SCHLUMBERGER Job No.: AKAM10022 Well No.: NS26 End of Well Report Page $ Mud Reports Baroid DRILLING MUD REPORT OPERATOR ADW REPORT FOR PAUL LOCKWOOD/CHRISTIAN REPORT NUMBER: I Date ~ 0x/22/01 Well ~ Ispuu Date I } I I /| I Ol/lS/Ol ICO~<ACTOR I NABORS IREPORT FOR I FINKBINDER/JIM WOODS 10 Depth 1203 ft [MD] Present Activity MONITORW~.?.T, RIG NUMBER 33E SECT,T~TNSHP,RNG Sll-T13N-R13E WELL NAME AND NUMB~:R I FIELD OR BLOCK I COUNTY, PARISH, OS. AREAi~/PRV NS 26 SLIM-HOLE PRODUCER I NORTHSTAR NORTHSLOPE BiT DATA Ii. ri. DRILLING $'-'KING ft CASING I CIRCULATION DATA Size 13.5" in. ~ipe 09 5 ID 4.276 Lan. 201 I Puap ~k,/H~_-! 0IL~]~J. Al700 PT Type lffC #XC1 ]Pipe OD 5 ID 3.130 Leu. 690 in. ftI Size 6 X 12 I Eff. 96.001 v/st o. Ho. Jets IPipe OD ID Lea. 20 Set t 199 sp, 45 I bbl/,i, 4.5 Jets 32nd inch }Colla~ 0D 6 ID 2.75 Lea. 125 Set @ l~mp Hake/~._~__! 0ILk'~.~. Al700 PT 18I [ / in. OP~.'~ HOLE ft Set @ spin 45 I bbl/,i,_ 4.5 Tot Hoz A~ea I Size 13.5 mm. 1004 I Size Len. Size Len. Size Lei. Size T~ Buu PROPERTIES 2 3 Set @ Set@ Set@ Set@ Set@ mTo~p Depth ft < ~ei~ht pix] 8.8 ~V @ 60 D~ 40 YP ~ 15 ~I Flit. 4.0 ~ t by vol ( 8.0 SULt, ITE size iff. Iv/st spI bbl/.i._ Tot. Vol./ain 381 9p~ 9.1 h ]E 74~ 23 ITC ?i~ 1/8 ~a~ion tim foz ~~ ~ ~ RIG ACTIVITY ~y suspended op~zatians. Divsttec line successful/y tested. Preparations fo~ puttin~ ~I oaline are undenmy. 700 - 5 ~AL. CA] BARA.SCAV D - ~ ~. BAG ~nginee~g - 2 n. ~ato~ - 1 ~. MA'1'~.RIALS USED 18 1492.92 12 559.92 1 1~/5.00 1 25.00 MUD MANAG~h~ENT MUD VOLUME bbl Hole220 ] Pi~45 Active Voluse 1165 P, esezve I Total Low 9rav~ vol % 4.6 ppb 41.59 Si~ Grav~ vol % 0.0 ppb 0.00 ASG 2.40 Drill Cuttings 0 Dilution Rate 0.00 Skis Control iff 70.00 BAItOID ~awri~v ~. MUD TYPE ECL POLYllER HUD CONSUHPTIOH ADDITIONS ~1 : Oil 0 B~ine ~atsr 0 Drill ~atec 41 Sea ~ate~ o ~hole #ual 0 Rarite' o Cheaicals 0 L06S~ bbl ~ped. o Lost 0 VOLa~S/LOSS 41 IOn~C~/ao~ RHEOLOGY AND HYDRAULICS Nater Depth talc. F. G~ad '0.0 Leah Off Test 0.0 ECD ppq csg. Shoe 9.4 T~ 9.6 ~u. Diff. I~ 0 SOI'.TDS DEVIATION INFO ~D 1/03 ft TVD 1203 ft ~J.e o.oo Direction 0 Hotiz. Di~p! 0 ft 907275-2627 1 ~AILY 0~T' I C[~UI~TI~ ,: 659.-2422 3192.8 ~ 6447: DRLG CI]~C S~RF. RIG FISH]JiG RUB CS~ BA~ R~H AVERAGE ~e reco~datio~s n~ he, eon shall not be construed as authorizing the infrin~sent of any valid patent, and are nde withou: ~ssusption of any liability by BAROID DRlU.m; ~, liE. or its a~mts, ~4 a~e states@nfs of opinion only. Harold DRILLING MUD REPORT OPerATOR ADW REPORT FOR PAUL LOCKWOOD/CHRISTIAN REPORT NUMBER: Date I Ol/23/Ol ~11 ~/~ Spud Date I { I I l{ Ol/$~/o1 ICONT~CTOR {NABORS {REPORT FOR { FINKBINDER/JIM HOODS 11 Depth 1203 ft [MD] Present Activity MONITOR W~.?.T. RIG NUMBER 33E SECT,TWNSHP,RNG Sll-T13N-R13E W=~L NAME AND NUMBER NS 26 SLIM-HOLE PRODUCER BIT DATA I~' DRILLING ST~ING Size 13.5' in. ~i~ ~ 5 ID 4.276 Len. 201 ~w ~ ~a ~i~ ~ 5 ID 3.130 Len. 6~ No. Je~ {Pi~ ~ ID l~n. Je~ 32nd ~ ~o11~ ~ 6 ID 2.75 Len. 125 12 I 18I I8Io11=~ 8 ID 2.875 Lan. 187 18 in. OPEN HOLE IFIELD OR BLOCK NORTHSTAR f% 13.5 Len. 1004 Set @ Len. Set @ ~m. Set @ {COUNTY,NoRT~SLoPEPARISH, OS. AREA{E/PRV CASING CIRCtrt~TION DATA ~m~ .~.._~__1 0lL~.u. Al700 PT in. ft Size 6 ! U {Elf. 96.00{ V/st 0.3 20 Set @ 199 =cpm 45 {kh!/,},_ 4.5 Set @ Pump w~ke/}~m~__el nTt~.t A.1.700 PT Set @ size ~ Xl~- I=f. 9~.oo[ W~t o.~ Se~ @ spm. 45 {bb!/m~n 4.5 ~t Noz Area I Size Size Size Size size TFA MUD PROPerTIES Depth ft ~@60~ APl. Filt. Cake APT~m.~ 32nd Oil vol snd ~ b~ vol. ~T ' AlL Len. 2 3 Set@ Set @ 8.8 10.( 40 15 4.0 15.C < 8.0 Size JEff. I V/st spm { bbl/,{, ~t. Vo1./mln 381 cJp! 9.1 h~ BU Time 23 {TC Time 132 MUD TREATNRNTS fluid ~ias as ~ zheoio~y (~he addition of ware: vas RIG ACTIVITY Prepmrations foz ~uttin~ C&I online are und~a¥. MAT ~'.KIAL.~ U_s~D M~d Iabotato~y - 1 ~A. 1 2~.00 SOLIDS 3~~RHEOLOGY AND HYDRAULICS ~pm 53 52 ~pm 41 40 ~pm 35 34 ~4uD MANAGF~M]~NT MUD VOLUME l~o~e I ~its 220 I ~ ' A~ive Vol~ ~ITI~ 11~ 0~ ~ ~av, vol ~ 4.7 ~ Wa~ ~av, vol % 0.0 ~i~' ppb 0.~ ~ 2.42 ~ill ~tin~ 0 Dil~ion ~ 0.~ ~t S1~ ~n~l ~f 70.~ MUD TYPE MUDCONSUWPTION bbl 0 100 ~pm 28 27 0 6 ~ 14 13 34 3rpm 12 0 Prass=e Units: psig 0 P~ass lkol). ~ 207 0 Press l)~p, BIT 167 0 ~e~ D~, A~ 22 ~1 &~aml Cii~. Press 0 0 &?, DP ft/~i~ 29 0 A~, DC ~t/~h 79 VOL ca~/I~3SS 34 AV, _mj~ fttmin Iomc~/m~ _ .~o~ ~_~/~sE j~. _~_. FRAC~RF. Water Dep~ Calc. F. G~ad 0.0 Leak Off Test 0.0 BC~ Cs~. Shoe 9.4 TD 9.5 Max. Diff. Pres~ 0 DEVIATION INFO MD 1/03 ft TVD 1203 ft ' An~le 0.00 Direction 0 Horiz; Displ 0 ft 907 275-2627 659*'2422 C 2 S~RV. RIG SURVEY 0 CORE BACK PW~M ,3 REAMI]N~ C TESTING OTHER !9 AVERAGE HOP { DAILY C0~2356.4~ COHULATIVE ~$ ~ 6682S The recoImem{ations made hereon sllall not be construed as autho:izin~ tim infringement of any valid patent, and are made without assumptio~ of any liability by BAlK)ID DRII//~ FLUID~, I]{C. or its a~ents, and are statements of opidion only.. Barold REPORT NUMBER: 12 DRILLING MUD REPORT Date I Depth 01/24/011 1203 ft [liD] /[ "~amcl~tel co,,ty I ,eh [,S/~ Spud DatelPresent Activity I I I I / I I ! I I I I ] ,i/ss/Oil aOHT~3R~.T.T. OP~d~TOR I COhTliAc,-l'OR I RIG lru'NB~ ~w I N~ORS 1 3 3- m~o~ FOR ! m~O~T FOR I S-.CT,~S~rP PAr. ri, LOCKWOOD/CHRISTTa~ I FTmO~THDEA/J[H ~OODS I SlS-~[3~-R[3~. I os. NS 26 SLIM-HOr.~. PRODUCER INOR~IS?AR [NORTI~-qr~PE I~_,~ si.~. o~ lin. DRTLLTNG S'~,<i~G ct Ca.STNG [la~e" cL-_cmr~ZON D~A Size 13.5" in. ~.ipe 01) 5 I~ 4.276 Lea. 201 l~lr~ ../l~__~ ~IUr~.L 11700 f,~ ~ ac~ Ripe e 5 ~ 3.uo ~,.~0 ~.. ct a ] u I~. ~.OOl Vst 0.. ~o. ~ets ~ipe e ~ la,. 20 set ~199 ~ ~5 I~i/,~, t.5 ~'eti 323xl ~ lC, liar ~ 6 ID 2.75 la~. ~_s ~ @ -- 18t i / ia. O~,F,~ ltOI.,~ ct ~ @ ~ 45 I ~hh!?" 4.S TotN oz Xrea I Size 13.5 I size Lan. L size size size sere sere sere NUD PROPF~IES 2 Tile 32M vol Gels tPI flit. l V/~ 9.1 h 135 ~p < 8.8 40 idtad x-olde in ~ to ta'~vmit bactaria gr,~/~'o,. 4.0 < < 2.( 9.! RIG ACTIVITY P:ocMum a~e being finalized fo~ G&I to SOLIDS t, lUU vol % 4.7 HYDRAULICS ~ P0L!fll~ F. Grad ~ 41 39 Leak Off ~ UH)II'IC]~ bbl rim 35 32 l~ 0U 0, ~ ~ ~ ~.~ ~ ~ 0 ~ 13 ~ ~~ ~ ~ 11 ~. D~f. ~ ~ ~ o ~: ~ig v 42.~ ~le ~ O' ~p. ~ a4 ~ ,voll o.o ~i~ [~p,~ 1~ ~ 2.41 ~ ~l ~~.~ o I ~ ~m~ o ~ o~v,~ n/~ 19 I ~ ~ ~1 ffi ~o.~ ~L ~ ~ ~V~ ~i~ ~/.i, I ~fiz. D~! T~ reconendatioas Bade hereon -_~!! ~ot be construed as a~.iziag the infringese~ of any valid patent, and ate Bade vitbo~ asmnption of ny liability by auIoD ~ FIJJllS, l]C. e its agents, and ate statesats o~ opinion oal?. Baroid B ~.PORT NUMBER: 12 DRILLING MUD REPORT IDate I Depth ~ O1/24/011 1203 ft i APl ~/A I Sta~ I ¢o~%~ I ~11 JS/{~ ~ Spud Date ~ Present Activity PAUL LOC~OOD/C~ISTI~ ~ FIN~I~D~/JIM WOODS ~ Sll-T13~-R13E Bo. Jets Jets 32~ Tot. lioz ltea NS 26 ~T.TM-HO?.~. PRODUCER BIT DATA ]in. DRTT.T.ING SI~TNG Size 13.5' in. :.~ilm OD 5 ID 4.276 ?ipe ~ 5 ID 3.130 1~. ~i~ OD ~ ~0!!~r 0D 6 ~ 2.75 0]~ar OD 8 D 2.875 in. OP~ HOT.R Size 13.5 [e~. 1~4 TFA ~ Size Size Size Size ~D PROPERTIES 2 T~ ft CASING 201 690 tn. 20 Set~ 125 Set ~ 187 Set @ ft Set @ Set@ Set~ Set 8 APl Filt. _~_~ APl , W vol ed AlL (mo,:~des SOLUTE Set @ 40 15' 4.0 < < 199 CIRCULATION DATA Size OIUIELL 11700 PT 6 X 12 l~f. 96.00 O.l 45 4.5 OILWELL 11700 PT 6 I 12 iff. 96.00{ V/St 0.1 45 4.5 381 9.1 23 135 MUD TREATIazNTS mst klded x-cide in ozder to prevent bac~ia q~/conts~ination. MATERIALS USED 1 1115.00 1 25.00 6 636.60 SOLIDS N-OD RSle ' ' 1227 Reserve [ To~l~7' Loc Grav, vol % 4.7 ppb 42.68 ai~ ~av, vol % 0.0 plm o.oo ~ 2.41 ~in ~t~ 0 Billion ~te 0.~ KCt POLYIIER ~l)OITIOIS bbl 0il 0 ~tLue Watst 0 DrLL~ ~atet 28 Sea Watst 0 ~hole ed 0 Barite 0 cbem~' o LOSSES bbl Oaped 0 Lost 0 VOL ~u~/~ 28 lo~c~/ec~ ' HYDRAULICS DRill o. Ca~c. F. ~:mcl 0.0 C:DE 1. :pm 41 39 Leak0ff Test 0.0 IT, IPS 3.. r[~ 35 32 ECD PI~ !SZRV. RIG 0., rim 28 25 eSq. Shoe 9.4 grgV~ 0., 6 llm 13 12 TI) 9.5 [ ~L~IIG 0.~ 3 rim 11 11 flax. Diff. P~ess 0 { LOGGI~ 0.~ l~ess~e Units: peig I RU~ ¢SG 0.~ .P~ss Drop. rfp 214 { ~ 0.~ l~s ~op, R~? ~67 '" DEVIATION INFO ~ess~op, ~SS 2O I ~D ' ~2O3 ft Actual ~¢. ~ 0 I TVD 1203 ft ~v, o~ ft/.~. 29 I a~le o.~ ~ ~ 17..~ ~A~, DC f%/~iR 79 ~ D~0B ~V, R{~ ft/~ ~ H0riz. D~I 0 0 ft The reconendations nde hereon shall not be construed as authorizing the infringement of any valid p~tsnt, and ate exle ~ithout assumption of any liability by BiltOID DRILLIIG FLUIDS, I]IC. or its agents, and ate stateaents of opinion only. Baroid DRILLING MUD REPORT IDate I ol/25/oi I ~! NELL I Sta~[ cowry ~ ~n ~ I Spud Date OPERATOR ICONTRACTOR ADW NABORS REPORT FOR REPORT FOR PAUL LOCKWOOD/MIKE DINGER [ CHIS PAGE/JIM WOODS WELL NAME AND NUMBER NS 26 SLIM-HOLE PRODUCER BIT DATA lin. DRILLING STRING ft size 13.5" h. {Pipe oD 5 ID 4.276 Len. 1135 ~ ]~: ~xct IPipe OD 5 TD 3.130 Z~. 69O No. Jets [Pipe OD ~D ~. Jets 32nd inch ICollar OD 6 . ~D 2.75 Lea. ~25 REPORT NUMBER: 13 Depth 2137 £t [MD] Present Activity DRILLING RIG NUMBER 33E SECT,TWNSHP,RNG Sll-T13N-R13E FIELD OR BLOCK COUNTY, PARISH, OS. AREA[ST/PRV NORTHSTAR NORTHSLOPE AK CASING CIRCULATION DATA 12 I 18 [ 18Io]/aroD 8 ID 2.875 Lea. 18 ia. OPEN HOLE rot )ioz ~ea [ Size 13.5 Lea. 1938 I Size ~n. size ~en. Size Leu. Size Lea. MUD PROPERTIES 2 3 Fv e 6o Deaf oP ~THP e 250 :ornSo~ids t by vo2 vol ~and t by oH HETn ! 60 ux. Nud ~j/i 187 2O Sere sere ft Set~ Set@ ft size 6x22 199 ~ 75 Size 6 X 12 spI 75 ~mp ~e/~dei Size spI Tot. vol./mia BU Tile i~Ff. 9a.oo[ v/st O.lOl bbl/nln 7.6 8.8 10.C 40 15 4.0 15.( iff. 9a.oo[ v/st o.lo: bbl/nln 7.6 MATERIALS USED 635 ~pe 15.1 23 ITC Time 76 ~ TP. EA~S as per Rmmi~ seavatar at 35+/- bbl i~ to maiatsin volne, 75o+ bbl, (not usin~ ~ s~pport) < 2.( 8,0 RIG ACTIVITY ~/l~d al facility ia operation- started d~illiag again 12zoo (noon) .~oduct 0sed Cost lIRA(IH 700 - 5 GAL. CAll 18 1492.92 ~ARASCAV D - 50 LB. BAG 10 466.60 IABIIMf-D Pills - 25 LB. BAG 52 7907.12 :L~YSE~L - 55 CAL. Dml 5 3289.25 )EXTRID LT - 50 LB. BIG 13 703.82 =-WH) IX) - 14 GAL. CUi 38 1850.60 ~j~,- 2 n. 1 nl~.oo Nut) MANAG~NT [ RHEOLOGY AND ~D VOLUME '°Z o ! p,%o t MUD W,PE t HYD ULICS l~~ . ~l ~ 54 ~I,~ ~1 ~ 36 34 ~--Vol. I ~~' ~ ~ 43 40 Oil 0 ~ ~ 28 26 / ~ ~av, vol t 5.0 ~. ~ 4~~ ~: ppb 45.0~ a~ ~v, vol t o.o p~b 0.00 ~ 2.44 zill cattiags 165 ,il~tion Rate 0.43 :1~ ~1 ~f 70.~ ~ ~ATiv~ NboleMud 0 Bari~ 0 ~micals . O bbl Lost O; Pl~ss I~p, BIT IV, DP &V, DC SOLIDS ~ig 634 465 37 ft/~h ~8 ft/min 132 -~7 ~v, ~ f~/mia talc. F. ~ad 0.0 Leak Off Te~t 0.0 c~. ~ 9.4 ~ 9.5 &u. Diff. P~ 0 DEVIATION INFO ~37 VOL ~U~/LOSS IW~E 659-2422 TVD 2130 ft A~le 1L00 D~ec~ion 308 Sori:. Displ 0 ft ~7 275-2627 DAILY COST ~ ~m~TI~ ~: $ !844%4 ~ 87052.i 'he reconendations nde hezeon shall not he construed as authorizia~ the infria~ement of any valid patent, ~nd are made without ~vmption of any liability by Bilt0ID D~I.~Tm~ 1~31136, INC. o~ its a~ents, and are statements of opiitton only. Baroid REPORT NUMBER: 17 DRILLING MUD REPORT IDate I Depth t 01/29/01[ 3302 ft EMD] I ~[S~lC°~tY I #~ ~/~ ISpud Date P~esent Activity OP~OR ~ CO~'Z'~R I RIG ~R ~RT FOR ~ORT FOR SE~, ~SHP, ~G PAUL LO~OOD~I~ DINGER ~IS PAGE/JIM WOODS S11-T13N-R13E ~ N~ ~b ~~ ~FIE~ OR B~C~ ~CO~Y, P~ISH, OS. ~ST/PRV NS 26 SLIM-HOLE PRODUC~ ~ NOR~T~ [ NOR~OPE ~ ~ BIT DATA ~. DRIVING S'~'~ING ft CASING CIR~TION DATA Size ~. ~}~ ~ D ~. . ~o. Jets Jets 32~d ~ Tot Noz Area I Size ! Size Size Size She huu PROP~:KTIES Ge~s OPeN HOL~ ~a~. ~a~. 2 3 10 3/4 Set @ < 8.8 4O 199 3,302 Sa=it 4.0 < < Ifil. 9~.ooI v/st o.zo~ sim o I ~_/~tn o.o size 6x~ Iiff. ~-~lV/st 's~ o I ~!/~n o.o ' sin !~' I v/~ , ~ I--/ '~t. V0X./~ 0 ~ 0.0 bM ~ v~ o I~ ~ o RIG ACTIVITY C01~IAT~ TESTING BOP'S - PU ~iA WITH 9 7/8" BXT "HH ' DRILL OUT Cm~IT Mm Es CBNDTER ISnSUR~ TEST CASXHG TO 10GO PSI - TEST Fm.m - CURlt~TLY TRIPPING SUI~/TK MP~i~-D ~ - 25 ~. ]~G 37 5626.22 CLAYSEaL - 55 ~. ~ 4 2631.40 ES-HUD l~ - 14 GAL. CA! 1 48.70 Ac~ve Volu~e 1223 5ow Gray, vol t 5.0 45.o~ ~i~h ~rav, vol t 0.0 ~ o.~ ~ 2.44 Ml~on ~te 0.~ 31~ ~1 ~f 70.~ m.~e~tez 0 6z~! 9 9 ~rill ,ater 0 Sea ~ater 0 ~bole ~ad 0 Barite 0 C~elicals 0 ~S bbl ~ 63 8 8 [~dts: l~ig ~ ]~'op, BlT 0 AT, ~ ~/~ 0 0 Calc. F; ~rad 0.0 Leak Off Test 0.0 csg. ~ o.o ~ 0.0 Nax. Diffl Prass 0 _DEVIATION INFO ~ 3302 ft T~D 3225 ft D'~t~on 20.00 Soriz. Mspl 0 ft ~07 275-2627 659-2422 ~ 0.0 ~J13S 4.0 ~. HG 4.0 ~ o.o mW CS~ 0.~ CORE 0.¢ ~ O.C ~ 14.C ~ O.C l~ ~P 0.( ~ recmendat~ans made he~eon mU not be com~ued as authorizing the infr~ of any valid patent, and are made without essuqfcion oi any liability by BAItOID DRHidIIG ffJIIDS, IBC. or its agents, and a~e statanents of opibion only. Baroid REPORT NUMB~: 17 i ~1~=~1~ I ~u ~ I DataIIPre'ant3302 Act£vi~¥f~ I I I I I I I ! I I ! I I ~spud o~/~s/o~I ~~ o~ oP~~ I co~~ ~G ~W ~ N~ 3 3E ~R~ FOR I ~RT ~R SE~, ~SHP, PA~ LO~D~I~ DING~ [ ~IS PAGE/JIM W~DS Sll-T13N-~13E NS 26 SLIM-HOLE PRODUC~ NOR~ST~ I NOR--~pE BIT DATA ~. DRI=ING ~G ~ I ~ING I C~~TION DATA ~ F$~m ~ ~' I ~' ~ ~=e 6]~ I=f. ~-~1 v/~ ~ ~ ~ ~. ~ ~, ~99 ~ o I~/~ o.o o~a' ao= ~ o I~ o.o in. To~ lloz Aha I Size i She S~ze Size size Le~. huu PROP]~K'r~S 2 3 FUt. 0.101 hhl ~Me~- 2 n. ~ ms.oo _U_TG ACTIVITY SOnTDS UD HYDRAULICS 318 ~ GrdV, vol % 5.0' 4s.~ gh ~rav, ?ol % 0.0 o.oo 2.44 ~ ca. rigs o [eL ~q~Lnln rpu 29 29 rpu 25 24 0 rpu 1~ 18 0 6L'lm 9 9 0 0 pZ~ 8 8 AV, ~ ft/li~ O: 0 0 bbl 63 paig 0 0 0 0 0 Calc. F. Grad 0.o Leak O~f Test 0.0 g. Shoe 0o0 0.0 Bax. Diff. Press 0 DEVIATION INFO 0.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 14.00 0.00 0.00 lut~on hte 0.00 Lost 0 AY, ~C ft/ttn 0 ~'~on 307 ds Cmt~ol ~f 70.00 VOL &kI~/lmS ~3 ~, riser ft/~n_ aofiz. _~_?! 0 ft 'fal~,~/tl, O~ ~ iWi~-j R~DE &iX I~k~. _RP~___ 659-2422 . ~ 9446.3. ~ l~q~.l? e z~mmndat/ons Mde hereon sba]/not be constamd ~ an~ifin~ the in~ing~ of any va]/d patent, and are sade vitl~ mtpt/ou of any ]/abiUt~ by RUID~ ~ FLUId, IE. or i~s mpnts, and az~ statele,t3 of o9~k~on only. Formation Tops NS26 Formation Tops i i ~11 i i = :;5.3 .. Pre-drill esti.~ed depths Actual Depths Actual Tl,2)ss TVDrkb MDrkb TI'rDss TFDrkb MDrkb Days, Since Formation $$. $ estimated spud J I I II I ! i p i i ill III Ill I I I ~ I~ III I llI Top Permafrost . . .li50 1205 1205 1,140 1,195 ,1,195 0 , Base Permafrost 1500 1555 1555 1~490 1r545' SV6. top confining zone . 3020 3075 3146 3.007 3.062 3J 28 - 0 , Surface casing point 3170 ,,3,225, 330,6 3,153 3,,208 3,288 ,, 0 ..... Current depth , 3,170 3225 3302 0 . SV$ ba~ confining zone . "3300 3353 3445 .. 3,285 3,340. 3,425 SV4 3600 3655 3766 3~585 32640 . .. 8'~2 - top upper injection zpne ' ,,4000 ' 4055 4194 3,985. . 4,.,040 SV1 - top major, shale barrier . ., 4380. 4435 4600 4t365 4,.4.20 .... TMBK, top lower injettion zone, , . , 4730 4785" 4974 4,2715 4~770 .... M87F - top Shrader BI,,uff , 6315 6370 6667 6,300 6,355 M60T- Base lower ,injection zon, e,(t. op C9!ville,),,' 6885 6940 7277 6~870, 62925 ,', '. , ,, THRZ- Top HRZ ...... 8515 8570 901,8 8,500 8,555. . .... amtz,-,easenaz ...... ,8595,8650 91 , , 8,580 8,63, , , , , .Top Knparuk ....... 8665 8720 9179 .. 8.,650. .8,705 · ....... Kuparuk C ...... 8865 8920 9392 8,850. 8.,905 ..... ...... LCU . 8995 9,,0.50 . 9531. 8,9.80 .... 9,035. . . Top MiluV,~ae~,, '".' ,", '8995,".. 9050 . . 953i 8,980 9,035.... Intermediate loggias point' . .... 9135 . .9. !.90 9681' 9,120 9,178 "' .... Tgp Kinaak ..... 9495 9550 10066' 9,480 9,535 .... . ' ' : : Fault $0 ...... 9.900 ..9955 10498 9,885 ....9,940 T°pSaRRive~. ...... 10645 .. !0700 i129.5. , .10,630 10,685 .. ........ I'ntermedia,~ caslnR po.i.nt, ...... 10685 10740 113..37 .... 10~670 10,725. ' ' '.' ...... Tqp,Shublik . . 10745 ,10800 1!.4.02 .10,730 10,785 : Top [visha, k .......... 10855 .. 10910 11519 10,840 10,.895 . ...... Top Kav, ik 11175 11230 11861 1!2,160 11~215. · . . ,.Totnl, D~.pth ...' ........... '11225 ...1....12$0' '1i915 11,210 11,265 " Top. L, isbu.rne , ,11295 .1.1,350 ........ 1,19,89 1,1,280 , 11.,.,3..3.5 . . Formation Logs