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206-187
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187 END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap 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 11,900 feet N/A feet true vertical 10,041 feet N/A feet Effective Depth measured 11,886 feet 9,351' feet true vertical 10,041 feet 9,238'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / 13CR-80 9,650' 9,526' 1,508' MD Packers and SSSV (type, measured and true vertical depth) See Above 4-1/2” HXO SVLN 1,507' TVD 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: 4,760psi6,870psi9,604'9,730'9-5/8' 10,098' 9,962' 11,220psi 8,530psi 9-5/8"x4-1/2" Baker S-3 TVD 3-3/16"10,114' N/A 2,260psi 7,660psi 11,780psi 5,020psi 6,870psi 8,520psi 11,200psi 4,760psi 10,041' 10,400' 11,900' Liner 30" 9-5/8' 131' 2,504' 8,357' Production Liner 611'7" 1,373' 8,357' 8,286' Casing 13-3/8" ENDICOTT / ENDICOTT OIL Conductor 2,504'Surface Burst N/A Collapse Production Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0034633 DUCK IS UNIT MPI 1-39A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-187 50-029-21827-01-00 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) 174 Gas-Mcf 1900 6777 19005870 9 3331147 335 924 N/A measured true vertical Packer MD 131' Size 131' 2,502' Length Liner 952' 2,504'2-3/8" 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. Aras Worthington aras.worthington@hilcorp.com 907-564-4763 325-091 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 8:20 am, Apr 08, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.04.07 16:54:23 -08'00' Justus Hinks (3691) DSR-4/11/24JJL 5/8/25 RBDMS JSB 041025 Well Name Rig API Number Well Permit Number Start Date End Date END 1-39A Slickline / Eline 50-029-21827-01-00 206-187 3/3/2025 3/12/2025 ELine: ***WELL S/I ON ARRIVAL*** (34' ADPERFS) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH GUN1 PERFORATE INTERVAL 10105'-10125' WITH 1.56'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=7.6' CCL STOP DEPTH= 10097'. CONFIRM SHOTS FIRED. GUN2 PERFORATE INTERVAL 10091'-10105' WITH 1.56'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=7.8' CCL STOP DEPTH= 10083.2'. CONFIRM SHOTS FIRED. LOG CORRELATE TO SLB MEMORY COMPENSATED NEUTRON LOG DATED 15-APRIL-2007 JOB COMPLETE READY TO POP ***WELL S/I ON DEPARTURE*** Slickline: ***WELL FLOWING ON ARRIVAL*** TAGGED SSSV @ 1508' SLM w/ 3.84'' G-RING PULLED 4-1/2" BBE(sn=HBB-490) FROM HXO NIPPLE @ 1,508' MD DRIFTED WITH 33' x 1.72" DUMMY GUNS, 1-1/2" SAMPLE BAIL(total oal= 35' 4") TO 10,113' SLM / 10151' MD DRIFTED W/ 23' x 1.56" DUMMY GUNS(max swell=1.72"), 1-1/2" SAMPLE BAILER(oal=24' 5") TO 10,118' SLM / 10156' MD (no samlpe) DRIFTED w/ 2' x 1-7/8'' STEM, 3.48'' CENT, BULL NOSE, TAG DEPLOY SLV @ 9358' SLM, 9396' MD (38' corretion) ***JOB COMPLETE, WELL LEFTS/I*** 3/4/2025 - Tuesday 3/3/2025 - Monday 3/12/2025 - Wednesday Slickline: ***CONT WSR FROM 3/11/25*** SET 4-1/2" BBE (ser #: HNBB-54, lih: 60", 3 set std pkg w/ std o-rings) IN HXO SVLN @ 1,508' MD RAN 4-1/2" CHECKSET TO 4-1/2" BBE @ 1,508' MD (checkset sheared) PREFORM DRAW DOWN TEST W/ OPS (successfull) ***WELL LEFT S/I. NOTIFY DSO OF STATUS*** Hilcorp Alaska, LLC Weekly Operations Summary Hilcorp Alaska LLC 1.56" 6 10189 - 10216 O 7/1/2008 1.56" 6 10130 - 10142 O 5/7/2021 1/23/23 DGD Add 08 & 21 Perfs Added PERFORATION SUMMARY REF LOG: MCNL on 4/15/2007? Angle at top perf: 12° @ 10,091' SIZE SPF INTERVAL OPN/SQZ DATE 1.56" 6 10,091 - 10,125 O 3/4/25 1.56" 6 10,130' - 10,142' O 5/7/21 1.56" 6 10,189' - 10,216' O 7/1/08 1.56" 6 11,448, - 11,638' O 4/15/07 3/4/25 DH Added 3-4-25 Perfs Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,900 NA Casing Collapse Conductor NA Surface 2,260psi Production 4,760psi Production 5,090psi Liner NA Liner NA Liner 11,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 611' 7" 10,098' 9,963' NA Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 11,200psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 206-187 C.O. 462.007 DUCK IS UNIT MPI 1-39A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21827-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 10,041 11,886 10,042 3,043 ENDICOTT OIL SAME 131' 131' 12.6# / 13Cr80 TVD Burst 9,650 NA MD NA 8,150psi 5,020psi 6,870psi 2,502' 8,286' 9,604' 2,504' 8,357' 10,114'3-3/16" 131' 30" 13-3/8" 9-5/8" N-80 2,504' 9-5/8" T-951,373' 8,357' 907-564-4763 aras.worthington@hilcorp.com Operations Manager March 1, 2025 11,900'2,504' 4-1/2" 10,041' Perforation Depth MD (ft): See Schematic 9-5/8" x 4-1/2" Baker S-3 and 4-1/2" HES HXO SVLN 9,351 MD / 9,238' TVD and 1,508' MD / 1,507' TVD NA 10,400' 9,730' 952' 2-3/8" See Schematic Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-091 By Gavin Gluyas at 9:55 am, Feb 20, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.02.20 09:08:05 -09'00' Justus Hinks (3691) A.Dewhurst 20FEB25 10-404 DSR-2/20/25JJL 2/24/25 *&: 2/25/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.25 13:55:41 -09'00' RBDMS JSB 022625 Adperf Well: End 1-39A Well Name:END 1-39A API Number:50-029-21827-01 Current Status:Operable, online PTD 206-187 Estimated Start Date:03/01/2025 Estimated Duration:Two days Reg.Approval Req’std?403 Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner 777-8406 First Call Engineer:Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Reservoir Engineer:Gavin Dittman (907) 564-5246 (O) (907) 903-1903 (M) Geologist:Brock Rust (907) 777-8394 (O) (615) 306-9509 (M) Current Bottom Hole Pressure:4,039 psi @ 9,965’ TVD (SBHPS 8/14/16) -7.8 ppg MPSP:3,043 psi (0.1 psi/ft gas gradient) Max Deviation: 97° at 10,471’ MD Minimum ID:1.92” 3-1/2” x 2-3/8” XO @ 19,404’ MD Tie In Log:SLB CNL 4/15/2007 Last Tag:10,140’ MD w/ 1.50” x 20’ DG (5/4/21) 70 Degree Deviation:10,290’ MD Brief Well Summary: Endicott well 1-39A is a gas-lifted producer, CTD sidetrack drilled and completed in 2007. Objective: Adperf in the S3A4 Sands. Procedure: Slickline: 1. Pull SSSV. 2. Drift with 1.5” x 40’ Dummy Guns to deviation (~10,290’ MD). Target depth for bottom perf is 10,130’ MD. Eline/Fullbore: 3. Perforate per annotated tie-in log. 34’ of 6 SPF/60 PH, 1.56” Millenium guns (or similar). Pump guns down with non-freezable fluid (if necessary). Max tubing pressure 3500 psi. Slickline: 4. Set SSSV. Attachments: Current WBD Annotated Tie-In Log Adperf Well: End 1-39A Current WBD: Adperf Well: End 1-39A Adperf Well: End 1-39A Adperf 10,091’ – 10,125’ MD David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. Received By: 07/15/2021 37' (6HW By Abby Bell at 1:46 pm, Jul 15, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing PNL Log Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,900 feet N/A feet true vertical 10,041 feet N/A feet Effective Depth measured 11,886 feet 9,351'feet true vertical 10,041 feet 9,238'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4.5" 9,650' 9,526' 1,508' MD Packers and SSSV (type, measured and true vertical depth)Baker S-3 See Above 4-1/2” HXO SVLN 1507' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 11,220psi 8,530psi Collapse N/A 2,260psi 10,114' Burst Liner 611' 7" 10,098' 9,962' 8,520psi 777-8333 Senior Engineer: Senior Res. Engineer: 11,200psi 9,604' 10,041' 4,760psi 4,760psi N/A 5,020psi 6,870psi 6,870psi 11,780psi 7,660psi Surface Production 30" 13-3/8" 9-5/8' 2,502' 8,286' Production Liner Casing Conductor Liner 2,504' Length 131' 2,504' 8,357' DUCK IS UNIT MPI 1-39A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 208 Gas-Mcf 1,050 Casing Pressure Tubing Pressure 5,586 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-195 330 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 1,300 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-187 50-029-21827-01-00 Plugs ADL0034633 5. Permit to Drill Number: ENDICOTT / ENDICOTT OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 158 Representative Daily Average Production or Injection Data 3233,608 measured true vertical Packer 3-3/16" 2-3/8" 9,730' 10,400' Size 9-5/8' 11,900' 131' 6,100 Oil-Bbl 1,373' 952' N/A 12.6# / 13CR-80 / Vam Top 2. Operator Name:Hilcorp Alaska LLC WINJ WAG 7,706 Water-Bbl MD 131' 2,504' 8,357' TVD PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 7:56 am, Jun 21, 2021 Chad Helgeson (1517) 2021.06.18 15:30:50 - 08'00' DSR-6/21/21 SFD 6/21/2021MGR30JUL2021 RBDMS HEW 6/21/2021 Hilcorp Alaska LLC Proposed Perforations +/- 10,130' MD to +/-10,142' MD 1.56"10,130' - 10,142'o 5/7/2161.56"10,130' - 10,142'o 5/7/216 Well Name Rig API Number Well Permit Number Start Date End Date END 1-39A CTU #6 / Slickline 50-029-21827-01-00 206-187 5/5/2021 5/21/2021 5/7/2021 SLB coil and Halliburton TCP conduct JSA and approve PTW. verify 1/2" ball on firing head seat. Measure gun BHA. MU, RIH to flag and correct to top shot. Perforate 10,130 - 10,142'. POOH and blowdown coil reel with N2. Hand well over to production. RDMO. 5/5/2021 Hilcorp Alaska, LLC Weekly Operations Summary SLB coiled tubing unit #6 arrive. Conduct JSA and approve PTW. MIRU. MU coil nozzle and prep for drifting coil with 1" ball. Pump 8 bbls of 60/40 MeOH and coil pressure locked up. Appears to have ice in coil reel, pressure not bleeding down. Wrap coil reel with parachute and hook up 2 heaters to thaw. Able to get fluid moving and pump 1" ball around coil. Recover ball in nozzle. Set injector with BOP's on back deck. LDFN. 5/6/2021 SLB Coil arrive and test BOPE to 250 psi low / 4000 psi high. RIH with coil memory flag log. Log from 10,500 to 9,000' at 50 ft/m. Paint flag at 10,200'. Laydown memory toolstring. Install night cap on well. Confirm good data from memory log. Hand well to production to bring on-line over night. LDFN. WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. PULL 4-1/2" BBE SSSV (serial# HNBB-50, 2 pieces of packing torn on top stack, valve stuck open) FROM SVLN AT 1,510' SLM/1,508' MD. BRUSH SVLN WITH 4-1/2" BRUSH AND 3.805" G-RING (no restrictions). SET 4-1/2" BBE-SSSV (serial# HN BB-58, sec lock) IN SVLN AT 1,510' SLM/1,508' MD, TAG WELL. PERFORM PASSING DRAW DOWN TEST WITH WSL. RDMO, CLOSE PERMIT W/PAD-OP. 5/20/2021 5/21/2021 WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. PULL 4-1/2" BBE SSSV (serial# HNBB-58, valve leaking internally) FROM SVLN AT 1,510' SLM/1,508' MD. SET 4-1/2" BBE SSSV (serial# HN BB-48, sec lock) IN SVLN AT 1,510' SLM/1,508' MD, TAG WELL. PERFORM PASSING DRAW DOWN TEST WITH PAD-OP & WSL. RDMO, CLOSE PERMIT W/PAD- OP. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,900'N/A Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Production 4,760psi Liner 11,220psi Liner 7,660psi Liner 11,780psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng DUCK IS UNIT MPI 1-39A C.O.462.007 Baker S-3 and 4-1/2" HES HXO SVLN 9,351 MD / 9,238 TVD and 1,508 MD / 9,238 TVD Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 10,400' 1,373' 952' 10,114' Authorized Signature: 4/28/2021 11,900'2,504' 4-1/2" 10,041' 9,604' Perforation Depth MD (ft): See Schematic 2-3/8" See Schematic 3-3/16" 131' 30" 13-3/8" 9-5/8" 2,504' 7"611' 8,357' 5,020psi 6,870psi 2,502' 9,604' 9,962' 2,504' 8,357' 12.6# / 13CR80 / Vam Top TVD Burst 9,650' 8,520psi MD 10,098' 6,870psi 10,042' 3,000 9-5/8" 9,730' 131' 131' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 N/A 50-029-21827-01-00 Hilcorp Alaska LLC Length Size N/A ENDICOTT / ENDICOTT OIL Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY 8,530psi 10,041' 11,886' Tubing Grade: Tubing MD (ft): 206-187 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: 11,200psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad Helgeson (1517) 2021.04.13 10:47:05 - 08'00' By Samantha Carlisle at 11:05 am, Apr 13, 2021 321-195 DLB 04/13/2021MGR19APR21 10-404X DSR-4/14/21Comm. 4/20/21 dts 4/20/2021 RBDMS HEW 4/21/2021 Coil Perf Add Well: END 1-39A PTD: 206-187 API: 50-029-21827-01 Well Name:END 1-39A API Number: 50-029-21568-00-00 Current Status:Producing Rig:SLB CT Estimated Start Date:April 28th, 2021 Estimated Duration:2 Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:206-187 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:Ian Toomey (907) 777-8520 (O) (907) 903-3987 (M) AFE: WellEZ Entry Required:Yes Current Bottom Hole Pressure:4,000 psi @ 10,000’ TVD (Based on Offset Bottom Hole Pressure) Maximum Expected BHP:4,000 psi @ 10,000’ TVD (Based on Offset Bottom Hole Pressure) MPSP:3,000 psi (0.1 psi/ft gas gradient) Minimum ID:1.920” @ 9,404’ md Brief Well Summary: Endicott 1-39A was sidetracked using Coil Tubing setting a 2-3/8” TBG string across the production zone in 2007. The well is currently a K2A producer. Objective: Utilize 1.5” coil to run a tie-in log and to run tubing conveyed perforation guns to perforate the S3A3 sand. Procedure: PRE- Sundry Slickline 1. RU SL unit. Pressure test PCE to 250 psi low / 3,500 psi high. 2. Pull 4-1/2” SSSV from 1,508’ md. 3. RD SL unit. Coil Tubing (Sundry Required) 4. MIRU CT unit with 1.5” Coil and spot support equipment. 5. Pressure test BOPE to 250psi low / 3,500psi high, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 6. MU & RIH w/ logging tools to obtain a GR correlation log. Mark the coil. 7. Review the log run with the operations Engineer and Geologist, Confirm depths. 8. PU TCP perforation guns (6 spf 60° phasing) get on depth, drop the ball and pump the ball down to seat, pressure up and fire the guns. Gun Run # Perf Top Perf Bottom Perf Length 1 ±10,130’ MD ±10,142’ MD 12 Total 12 9. POOH with perforation guns. Confirm all shots fired. 10. RD CT unit and support equipment. Slickline 11. RU SL unit. Pressure test PCE to 250psi low / 3,500psi high. o perforate the S3A3 sand. s currently a K2A producer. 50-029-21827-01-00 Coil Perf Add Well: END 1-39A PTD: 206-187 API: 50-029-21827-01 12. RIH and set the 4-1/2” SSSV at 1,508’ md. 13. RD SL unit. Attachments: 1. Proposed Schematic 2. Coil BOPE Schematic Hilcorp Alaska LLC Proposed Perforations +/- 10,130' MD to +/-10,142' MD DUCK ISLAND UNIT END 2-02 1/31/2020 COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic END 2-02 30 X 20 X 13д X 9з X 7 X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2д" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union • RECE1VEL Post Office Box 244027 f1 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U L 3 0 2015 3800 Centerpoint Drive Suite 100 AOGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster 2 9 Alaska Oil & Gas Conservation Commission SCANNED AUG 201b 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 o °7 6 ` Re: Duck Island Unit Well Renaming Request 1 f 36 Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig ! New API_WeliNo PermitNumber WellName WeIlNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/116 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 Image Pject ell Hilt®ry File Page xHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~~- ~ ~ ' / Well History File Identifier Or anizin (done) ^ Two-sided II I II'I II (I II I V III ^ Rescan Needed III IIII II I~ I I III III 9- 9- RE CAN DIGITAL DATA Color Items: Diskettes, No. , ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria Date: ~~ 1 ' ~ ~~ /s/ OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Project Proofing BY: Date: ~ I ~. /s/ ~ r Scanning Preparation ~._ x 30 = + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria ~' Date: ~ J ;~, ~ ~ Jsl Production Scanning Stage 7 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: i./ YES NO BY: Maria Date: ~ ~ I ~ /s/ r N (~ I Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /Sil I II ^I 11111 II I 1 111 Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III III III 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc.' ,„ Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg g17 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �� E Anchorage, Alaska 99501 _ I' Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 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, API and PTD numbers, 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, Gerald Murphy, at 659-5102. Sincerely, Mehreen Vazir U/ 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) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0-15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0 -25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 - END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0 -23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / 0-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / 0 -20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 /0-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 _ 50029220200000 15.0 10.3 0.5 _ 9/2/2010 0.85 9/24/2010 t OPERABLE: Producer END 1- 39A/No (PTD #2061870) OA Casing Pressuranagable By ... Page 1 of 1 Regg, James B (DOA) ( Rc5III From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] ( l Sent: Sunday, May 15, 2011 9:52 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Integrity Coordinator; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END AES Drillsite Lead; AK, OPS END Board Operator; Cismoski, Doug A; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; McLeod, Jennifer D; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: OPERABLE: Producer END 1- 39A/N -16 (PTD #2061870) OA Casing Pressure Managable By Bleeds All, An OA repressurization test was conducted on producer END 1- 39A/N -16 (PTD #2061870) between 5/9- 5/14%201 f after passing a PPPOT -IC on 05/03/2011. The OA pressure increased less than 10 psi /day during the test making it manageable by bleeds. The well has been reclassified as Operable and may continue on production. - Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator AMItoi MA 1 8 WI Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, April 30, 2011 2:50 PM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END AES Drillsite Lead; AK, OPS END Board Operator; Cismoski, Doug A; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; McLeod, Jennifer D; Daniel, Ryan Cc: King, Whitney Subject: UNDER EVALUATION: Producer END 1- 39A/N -16 (PTD #2061870) Sustained Casing Pressure on OA All, Producer END 1- 39A/N -16 (PTD #2061870) has confirmed sustained OA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 244/2100/1100 on 04/28/2011. The well has been reclassified as Under Evaluation and may remain online for diagnostics. The plan forward: 1. DHD: Bleed IA and OA to 0 psi 2. Wellhead: PPPOT -IC 3. DHD: Outer Annulus Repressurization Test Thank you, Mehreen Vazir Murphy) (AIIes�nradc� Gerald Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 5/17/2011 UNDER EVALUATION: Producer EI- 39A/N -16 (PTD #2061870) SustainCasing Pressu... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] 71 Sent: Saturday, April 30, 2011 2:50 PM / To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END AES Drillsite Lead; AK, OPS END Board Operator; Cismoski, Doug A; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; McLeod, Jennifer D; Daniel, Ryan Cc: King, Whitney Subject: UNDER EVALUATION: Producer END 1- 39A/N -16 (PTD #2061870) Sustained Casing Pressure on OA Attachments: END 1 -29A TIO 04- 30- 2011.doc; 1- 29.pdf All, Producer END 1- 39A/N -16 (PTD #2061870) has confirmed sustained OA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 244/2100/100 on 04/28/2011. The well has been reclassified as Under Evaluation and may remain online for diagn ostics. The plan forward: 1. DHD: Bleed IA and OA to 0 psi 2. Wellhead: PPPOT -IC 3. DHD: Outer Annulus Repressurization Test «END 1 -29A TIO 04- 30- 2011.doc» «1- 29.pdf» Thank you, Mehreen Vazir _ MAY 0 3 2011 (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 5/2/2011 Endicott 1- 39A/N -16 PTD #2061870 4/30/2011 TIO Pressures Plot Welt 1 -39 4,000 — • 3,000 - — Tbg —II— IA 2,000 - — ► - OA OOA• 000A On 1,000 - • 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 TREE= CW e SAFETY NOTIIIVELL REQUIRES A SSSV *** 4 WELLHEAD = FMC ACTUATOR= BAKER C END 1 -29 CHROME TB IPPLES*"" ZB. ELEV = 55.25 I SF. ELEV = 16.1' JMD DRAFT L I I 1486' H 4 - 1 1 2' HES HXO SVLN„ ID = 3,813" KuP = VaTA7-1g • Datum MD = 13645' GAS LIFT MANDRELS , ../A ST MD TVD DEV VLV LATCH PORT DATE Datum 1VD = 10000 SS 6 4170 4066 39 DOME RK 16 06/17/05 13-3/8" CSG, 68#, L-80 BTRS, ID = 12.415" H 2485' 1 5 6852 5752 48 SO RK 20 06/17/05 4 8870 7030 54 DMY RK 0 12/13/04 3 10571 8050 55 DMY RK 0 06/20/01 2 11898 8804 53 DMY RK 0 06/20/01 Minimum ID = 1.13" @ 13570' 1 12677_ 9315 46 DMY RK 0 06/20/01 2-7/8" STRADDLE PATCH II I 12874' H 4-1/2" HES X NIP, ID = 3.813" 1 12885' H 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.958" I I I 12909' H 4-1/2" HES X NIP, ID = 3.813" I lit IIIII 12930' H 4-1/2" HES XN NIP, ID = 3.725" 1 TOP OF 7" LNR H 12931' I 12930' I-14-1/2" X 2-7/8" NIP REDUCER, ID = 2.31" I I gi t.1 4-1/2" TBG, 12.6#, 13CR-80 VAM ACE, -- I 12952' I / I 12952' J-14-1/2" WLEG, ID = 3.958" 1 .0152 bpf, ID = 3.958" 19-5/8" CSG, 47#, NT95HS, ID = 8.681" H 13181' I- PERFORATION SUMMARY ....,...-. 1 13568' - 13669'1° 2-7/8" STRADDLE PATCH, ID = 1.13" REF LOG: DLL-GR on 02/24/86 ....-=.4 , (04/08/11) ANGLE AT TOP PERF: ?° @ ?' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 13648 - 13652 S 5" 5 13688 - 13720 S 5" 5 13726 - 13760 S 5" 5 13800 - 13820 S 2-1/8" 4 13756 - 13776 S 2-1/8" 4 13824 - 13864 S 2-1/8" 4 13902 - 13920 S 2-1/8" 4 13765 - 13775 S 2-1/8" 4 13800 - 13870 S 2-1/8" 4 13825 - 13855 0 I ? I - FISH - CENTRALIZER ARM (13' X 1" X 1/8") (09/27/10) I PBTD I 14147' 114"fr "."1 ? 11 FISH - 3 ELEMENTS, 3 SPACER RINGS & . . . i ■AS e # i ei 6" MULE SHOE (7/7/10) r/nr■■■ Aw• ■11,41., 7" LNR, 29#, SM-110 BTRS-TKC, --1 14230' .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 11/11/86 ORIGINAL COMPLETION 03/26/11 TA/PJC PULL PX PLUG (03/29/11) i WELL: 1-29 / M-25 06130/01 JWS RWO 04/27/11 MCM/PJC SET NIP REDUCER (04/14/11) PERMIT No: 1861810 09/22/10 BP/PJC TREE C/O (09/13/10) 04/27/11 MCM/PJC ELMD TT LOGGED (8/8/09) API No: 50-029-21669-00 10/28/10 SWC/PJC SET XX PLUG (10/06/10) 04/28/11 RUIWPJC SET PATCH (04/04/11) .. SEC 36, T12N, R16E, 2045' FNL & 2102' FEL 02/02/11 JMD CONVERT TO CANVAS 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE ,. BP Exploration (Alaska) • ~~. ~. '~ Via. ;, o. ~` ~'~ ,. ,~..:. ~~ .~~. MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~ ~-- DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2061870 Well Name/No. DUCK IS UNIT MPI 1-39AM-16 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21827-01-00 MD 11900 TVD 11041 Completion Date 4/17/2007 Completion Status 1-OIL Current Status 1-OIL UIC N - -- __ REQUIRED INFORMATION ~~ I y Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Samples No Directional Survey Ye (data taken from Logs Portion of Master Well Data Maint Ty Med/Frmt Number Name __ D D Asc Directional Survey ~pt Directional Survey ~pt Directional Survey ~D C Lis 15599 °'Neutron og Neutron 4/, ED C Las 15762f~1~nduction/Resistivity ~{'f`_D C Las i 15763~duction/Resistivity ~,L'og Induction/Resistivity ~ og i Induction/Resistivity Gamma Ray cL~og See Notes p LEIS Verification " 4 C Lis 16044 Induction/Resistivity / ~Ptpt LIS Verification D 16513 Induction/Resistivity G6~ Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 10000 11900 Open 5/3/2007 Final Hole and PB 1 10430 11900 Open 5/3/2007 Final Borehole 10000 11656 Open 5/3/2007 PB 1 9201 11882 Open 10/26/2007 LIS Veri, GR, CNT w/PDS graphics 2 Blu 1 9199 11869 Open 10/26/2007 MCNL, Mem CCL, GR, CNL 15-Apr-2007 10087 11899 Open 12/3/2007 ATR, RPM, GR, RAM, ROP 10087 11656 Open 12/3/2007 P61 ATR, RPM, GR, RAM, ROP 25 Col 10120 11899 Open 3/20/2008 MD MRP, GR, 13-Apr-2007 25 Col 10120 11899 Open 3/20/2008 TVD MRP, GR, 13-Apr- 2007 25 Col 10120 11899 Open 3/20/2008 MD GR, 13-Apr-2007 2 Col 10080 11870 Open 3/20/2008 Depth Shift Monitor Plot 10086 11899 Open 3/19/2008 LIS Veri, GR, RPD, RPS 10086 11899 Open 3/19/2008 LIS Veri, GR, RPD, RPS 10088 11654 Open 6/27/2008 P61 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 10088 11654 Open 6/27/2008 P61 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2061870 Well Name/No. DUCK IS UNIT MPI 1-39A/N-16 Operator BP EXPLORATION (ALASKA) INC MD 11900 TVD 11041 Completion Date 4/17/2007 Cog Induction/Resistivity „ IvLog Induction/Resistivity a!Log Gamma Ray ~jtog See Notes pt LIS Verification QED 16518 Induction/Resistivity ~, ~ ~ Completion Status 1-OIL 25 Col 25 Col 25 Col 2 Col (~og Induction/Resistivity 25 1'%L/og Induction/Resistivity D ~, ~ ~ s 25 ~ ~ c e~ ~og Gamma Ray 25 wog See Notes 2 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? YTiT~ -~ Analysis Y / N Received? Comments: Sample Set Number Comments Daily History Received? ~~,N~ Formation Tops -~'~'~ _ _ - _ _ _ -- - _ Compliance Reviewed By: _ Date: ! _p ~~ v~A~l q Col Col Col Col API No. 50-029-21827-01-00 Current Status 1-OIL UIC N 10120 11655 Open 6/27/2008 P61 TVD MPR, GR 10120 11655 Open 6/27/2008 P61 MD MPR, GR 10120 11655 Open 6/27/2008 P61 MD GR 10080 11630 Open 6/27/2008 Depth Shift Monitor Plot 10088 11870 Open 6/27/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 10088 11870 Open 6/27/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 10120 11899 Open 6/27/2008 TVD MPR, GR 10120 11899 Open 6/27/2008 MD MPR, GR 10120 11899 Open 6/27/2008 MD GR 10080 11899 Open 6/27/2008 Depth Shift Monitor Plot Interval Start Stop Sent Received STATE OF ALASKA~~~ ~ ALA~A OIL AND GAS CONSERVATION COM1GiISSION REPORT OF SUNDRY WELL OPERATION~ti~~,,,. `/(// 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ fr~~ Performed: Alter Casing ~ Pull Tubing ~ Perfdrate New Pool ~ Waiver ~ Time Extension ~, ,! QQ Change Approved Program ~ Operat. Shutdown Perforate Q , Re-enter Suspended W~fJ, ~ ~~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Num ~a.,, ° v0 ~ ~' Name: Development C~ - Exploratory 206-18%~- ' ~~.~a 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: /~ Anchorage, AK 99519-6612 50-029-21827-01-00~ 7. KB Elevation (ft): 9. Well Name and Number: 55.1 KB' 1-39A/N-16 - 8. Property Designation: 10. Field/Pool(s): ~ ADLO-034633 - ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 11900' feet Plugs (measured) None true vertical 10041.18 - feet Junk (measured) None Effective Depth measured 11886 feet true vertical 10041.6 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" Surface - 131' Surface - 131' Surface 2504' 13-3/8" 68# NT80-CYH Surface - 2504' Surface - 2502' 5020 2270 Production 9730' 9-5/8" 47# NT80S Surface - 9730' Surface - 9604' 6870 4760 Liner 611' 7" 29# SM 9487' - 10098' 9369' - 9963' 11220 8510 Liner 952' 3-3116" 6.2# L-80 9448' - 10400' 9331' - 10114' 8520 7660 Liner 2504' 2-3/8" 4.7# 13CR80 9396' - 11900' 9281' - 10041' 11200 11780 Perforation depth: Measured depth: O 11448 - 11648 O 10189 - 10216 / _ _ _ True Vertical depth: 10047.02 - 10043.73 10044 - 10063 = _ _. Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9650' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR S-3 PKR 9351' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 274 12520 3779 577 Subsequent to operation: 306 12587 4386 933 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~ Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ ~ WINJ ~'' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 7/10/2008 Form 10-404 Red 0412006 - `~ ~t'~: ~~~° ~ ~ ZQO~ Submit Original Only ~..~ 1-39A/N-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/30/2008 "*"WELL FLOWING ON ARRIVAL**" T/I/0=600/0/0. DSO NOTIFIED AND WELL SHUT IN. RIH WITH 1.56" DUMMY GUN AND ''!DRIFTED TO 10250', POOH. RIG UP 1.56" PJ 1606, 6 SPF, 60 DEG RUN TO PERFORATE INTERVAL 10189'-10224' IN TWO RUNS. ';"**JOB CONTINUED ON 1-JULY-2008*** 7/1 /2008... *~*JOB CONTINUED FROM 30-JUNE-2008**" CANNOT GET DEEP ENOUGH TO PERFORATE BOTTOM 20' OF INTERVAL - MAKE MULTIPLE ATTEMPTS TO PASS, SETTING DOWN FROM 10215' TO 10220'. MADE SECOND ATTEMPT WITH 1.56 IN 20 FT GUN WITH ROLLERS ON BOTTOM. TAGGED HIGH 10,219 FT, 5 FT ABOVE BOTTOM INTERVAL. TOWN PERMITS SHOOTING AS DEEP AS POSSIBLE, REMOVE ROLLERS, RIH. PERFORATE 10189' - 10216.8'. FINAL T/I/0=2080/1120/0. DSO NOTIFIED, SSV OPEN, MASTER OPEN, SWAB CLOSED, WING CLOSED, GAS LIFT SHUT IN, ANNULUS OPEN TO GAUGES. ***JOB COMPLETE"*" FLUIDS PUMPED BBLS 1 diesel 1 Total ®/tom BAKER HVGHES Salver Atlas PRINT DISTRIBUTION LIST COMPANY BY EXPLUKA'IIUN (ALASKA) 1NC CUUN 1'Y NUK'1'H SLUYIr BUKUUGH WELL NAME 1-39A/N16 STATE ALASKA FIELD ENDICOTT DATE 6/26/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1365739 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data BP EXPLORATION (ALASKAI INC 1 Company CHEVRON 2 Company PETROTECHNICAL DATA CENTER Person GLEN FREDRICK Person Address 909 W 9TH AVE Address LR2-1 ANCHORAGE AK 99519 900 E BENSON BLVD. ANCHORAGE AK 99508 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082.~~ HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated B :BAKER ATLAS-PDC 17015 Aldine Westfield Houston Texas 77073 This Distribution List Completed Bv: e' f ~ ~~~ i J `% Page 1 of 1 INTEQ Log & Data Transmittal F®rm To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1-39A/N16 '~ Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - MPR/Directional TVD Log (to follow) 1 color prints - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1365739 Sent by: Catrina Guidry Date: 06/26/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (y0'7j 26~-663 Baker Hughes INTEQ 7260 Homer Drive ~ ~ Anchorage, Alaska 99518 ~~,~~,.> ~ '~ Direct: (907) 267-6612 I IYTFQ FAX: (907) 267-6623 Vii' • BAKER H V6NE5 • Barer Atlas PRINT DISTRIBUTION LIST C:UMYANY BY EXYLUKA'I'lUN (ALASKA) INC CUUN'1'Y NURTH SLUYE BUKUUCiH WELL NAME 1-39APB1 STATE ALASKA FIELD ENDICOTT DATE 6/26/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1365739 Copies oC Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company CHEVRON Person PETROTECHNICAL DATA CENTER Person GLEN FREDRICK Address LR2-1 Address 909 W 9TH AVE 900 E BENSON BLVD. ANCHORAGE, AK 99519 ANCHORAGE AK 99508 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. TTH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This Distribution List Completed B~ Page 1 of 1 • INTEQ I.og ~ Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1-39APB1 __ -- -- -- Contains the following: " 1 LDWG Compact Disc (Includes Graphic Image files) ` 1 LDWG lister summary ',,r 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - MPR/Directional TVD Log (to follow) ` 1 color prints - MPR/Directional Measured Depth Log (to follow) Sent by: Catrina Guidry Date: 06/26!0$ " Received by: ~ ~ ~ ~~~ Date: ~ / PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (yU7) 167-663 ~~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~~ ~~ ~ ~ i .~ ~ -~} ~e ~yw ~~ -~ BAKER HVGNES COMPANY WELL NAME FIELD Baker Atlas PRINT DISTRIBUTION LIST BY EXYLUKA 1'IUN (ALASKA) INC COUNTY NUK1'H SLUYE BUKOUGH END 1-39A/N16 STATE ALASKA ENDICOTT DATE 3/l8/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1365739 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company UNOCAL Person PETROTECHNICAL DATA CENTER Person TIM E. RODRIGUEZ Address LR2-1 Address 909 W 9TH AVE 900 E BENSON BLVD. ANCHORAGE. AK 99519 ANCHORAGE AK 99508 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE_ AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This Distribution List Completed By; Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7~h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: END 1-39A/N16 .Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ~~ 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - MPR/Directional TVD Log (to follow) 1 color prints - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1365739 Sent by: Catrina Guidry Date: 03/18/08 ~~-u ~ ~~" ., ,.~ i Received by: (i ~,- Date: ~~~. ~ C ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~~' 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907} 267-6612 tiYTFQ FAX: (907) 267-6623 r~o~~~~ Date 11-30-2007 Transmittal Number:92922 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv Questions, please contact Douglas Dortch at the PDC at 564-4973 Contents 05-28B hoc,-o~-g ~ I~-}f,~f 05-28BPB1 ~o(,-0~9 a 1S~-~OS 1-39A/N-16;~ocP-t~~ e~(oa 1-39A/PB1 ~vt,- t b~ 15$~ 15-12B -~~ /-l t`~ i C-32C ~o~ -13q '~ ~5~~~ E-11B -no ~pZ E-11 BL1 ~o~--oil "~ ~~ ~, E-11BL1-01 ao~-6G2'~15 ~~ E-l i BL1 PB1 ~o'~_pt, ~ ~cc ~~-~~ E-116L1 PB2 26~-- p(o 1 ~ ~ 5~ ~ `;~ E-19B ~o~-o'~~ # i 53~ 1 G-25B av~--b ~~ # IS~~-~ NK-14A ~i aoc~-o3 I ~- `~-~-3 NK-14APB1 ~0~-031 ~ r~-~~t.l NK-61A ~61o-o3S ~ IS~~ S _~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 a~.~ Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 1966(2 Anchorage, AK 995 1 9-66 1 2 10/19/07 5~~~~mbe~~~~ NO. 4449 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cans Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Wnll 1nh i! ~ ,. new.. ...o,... MPL-09 11767141 MEM INJECTION PROFILE 09/16/07 1 S-400A 40015442 OH MWD/LWD EDIT ~ 09/14/07 1 12-12A 40015307 OH MWD/LWD EDIT 08!18/07 3 1 G-17A 40013619 OH MWD/LWD EDIT - 'R 06/18/07 3 1 S-400A 11855508 CH EDIT PDC GR (USIT) ¢ 09/18/07 1 G-266 10942213 MCNL '-'_ L -tt: 05/23/05 1 1 C-32C 11628756 MCNL ~T 02!18/07 1 1 E-04A 11801079 RST / 06/23/07 1 1 07-07B 11216202 MCNL (o - ~ 06/28/06 1 1 L2-11 11209603 MCNL sr p 04/30/06 1 1 E-32A 11767130 MCNL - ~' fs'(e0a. 06/19/07 1 1 L-04 11603118 MCNL - 12/30/06 1 1 E-196 11767134 _ MCNL ~- - '~- '~ j`Fj7pV / 07/21/07 1 1 2-16/M-16 11846803 RST U - L d1J 08/13/07 1 1 1-39A/N-16 11628769 MCNL ~,t^ ~ 04/15/07 1 1 ...-.-.............~...v~....v.... , v. v.v~.~..v r~~w ~~c~vn~~~nv v~~c vvr~ GMVfI ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ - -" ' ~, 900 E. Benson Blvd. ~ ~,~, ,~, - , ~ „~ '„ Anchorage, Alaska 99508 Date Delivered: !..' ~. ! ! ~~ ( i Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503- 3 / ATTN: Beth Received by: s : .. _ .;i';"f i ~S~/ ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~~~~V~~ MAY 1 0 2001 WELL COMPLETION OR RECOMPLETION REPORT AND LOG?;4ska Uil & Gas Cons. Commission ~ Anchorage 1 a. Well Status: ®Oil ^ Gas ^ Plugge ^ GINJ ^ WINJ ^ WDSPL No. o ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o Completions One O 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp Susp., or Aban 4/17/2007 12. Permit to Drill Number 206-187 3. Address: P.O. Box 196612, Anchorage, Alaska 9 519-6612 6. Date Spudded ~ 3/26/2007 13. API Number 50-029-21827-01-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/13/2007 14. Well Name and Number: END 1-39AIN-16 " 2113 FNL, 2147 FEL, SEC. 36, T12N, R1 Top of Productive Horizon: 1514' FNL, 3015' FEL, SEC. 36, T12N, R1 E, UM E, UM 8. KB Elevation (ft): 55.10 15. Field /Pool(s): Endicott Field / Endicott Pool { Total Depth: 1421' FNL, 2134' FEL, SEC. 36, T12N, R1 E, UM 9. Plug Back Depth (MD+ND) 11886 + 10042 Ft 4b. Location of Well (State Base Plane Coor Surface: x- 259055 y- 5982302 Z inates): ne- ASP3 10. Total Depth (MD+TVD) 11900 + 10041 Ft 16. Property Designation: ADL 034633 TPI: x- 258206 y- 5982929 Z Total Depth: x- 259089 y- 5982993 Z ne- ASP3 ne- ASP3 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1465' (Approx.) 21. Logs Run: MWD DIR, GR, RES, CNL / GR / CCL /,(/jN,dOf~ A> /O/a~.5 %~.Q ~~~~1'`l~d ~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT SIZE Wrr PER FT. GRADE TQP BOTTOM TOP BOTTOM SIZE.. CEMENTING REGORD PULLED 30" Structural Drive Pie Surface 131' Surface 131' N/A Driven 13-3/8" 68# NT80 Surface 2504' Surface 2502' 17-1/2" 4185 cu ft Permafrost 9-5/8" 47# NTSOSlNT95HS Surface 9730' urtace 9604' 12-1/4" 575 cu ft Class'G' 7" 29# SM 9487' 10 98' 9369' 9963' 8-1/2" 547 cu ft Class'G' 3-3/16" 6.2# L-80 9448' 10400' 9331' 10114' 4-1/8" 94 cu ft Class'G' 2- / " 4.7# 13Cr80 93 6' 1190 ' 9281' 10041' 3" 56 cu ft Class'G' 23. Perforations open to Production (MD + D of Top and 24. TusrN~ RECORD Bottom Interval, Size and Number; if non ,state "none"): SIZE DEPTH SET MD PACKER SET MD 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9650' 9351' MD TVD MD TVD 11448' - 11648' 10047 - 10044' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 800' Freeze Protect w/ 18 Bbls of Diesel 26. PRODUCTION TEST Date First Production: May 2, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 5/8/2007 Hours Tested 4 PRODUCTION FO TEST PERIOD OIL-BBL 104 GAS-MCF 203 WATER-BBL 601 CHOKE SIZE 104 GAS-OIL RATIO 1,953 FIOW TUbing Press. 1,550 CaSing PreSSUre 450 CALCULATED 24-HOUR RATE OIL-BBL 622 GAS-MCF 1,215 WATER-BBL 3,607 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, f Submit core chips; if none, state "none', None actures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). . ; ; °~ S ~ MAC IW ~ .~ 20Q7 ~.i..i ~ I!'fs~l~/ltll~ ®rf~. MNT / 1 Ll'""~` Form 10-407 Revised 12/2003 C NT UED ON REVERSE SIDE / G~N~ (/~ ~. 28. GEOLOGIC MARKEf~ 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NArwe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top S3A3 10143' 10005' None Top S3A2 10165' 10025' Top S3A1 10260' 10090' Top K2B 10273' 10097' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~ ~ ~ Signed Terrie Hubble Title Technical Assistant Date ! ~9f END 1-39A/N-16 206-187 Prepared ByName/Number. Terrie Hubble, 564-4628 Drilling Engineer Well Number Permit No. / A royal No. Greg Sarber, 564-4330 INSTRUCTIONS GeneRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness, IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE .Contractor Name: NORDIC CALISTA ',Rig Name: NORDIC 2 Date From - To ;Hours Task Code NPT Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Phase 13/19/2007 00:00 - 02:55 2.92 RIGU ' P PRE 02:55 - 03:10 0.25 RIGU P PRE 03:10 - 08:30 5.33 RIGU P PRE 08:30 - 09:30 I 1.001 RIGU I P I I PRE 09:30 - 13:00 I 3.501 RIGU I P I I PRE 13:00 - 15:30 I 2.501 RIGU I P I I PRE 15:30 - 18:00 ~ 2.501 BOPSUp P PRE 18:00 - 18:30 0.50 BOPSU P PRE 18:30 - 19:45 1.25 BOPSU P PRE 19:45 - 20:30 I 0.751 BOPSUR P I I PRE 20:30 - 00:00 I 3.501 BOPSUR P ) I PRE 3/20/2007 00:00 - 10:00 10.00 BOPSUF~ P PRE 10:00 - 10:30 0.50 BOPSU N SFAL PRE 10:30 - 11:45 1.25 BOPSU~ P PRE 11:45 - 12:30 0.75 BOPSU P PRE 12:30 - 13:00 0.50 BOPSU P PRE 13:00 - 18:00 5.00 BOPSU P PRE 18:00 - 20:20 I 2.331 BOPSUFI P I !PRE 20:20 - 20:30 0.17 BOPSU P PRE 20:30 - 21:30 1.00 BOPSU P PRE 21:30 - 22:30 1.00 BOPSU P PRE 22:30 - 22:50 0.33 BOPSU P PRE Page 1 of 25 Spud Date: 2/12/2007 End: Description of Operations Swapped from Ecoil to efree coil. Veco working on mousehote. PJSM on LD kelly. Veco working on mousehole LD Kelly, still working on MH. Track-hoe Called for SL unit to conduct SSSV wok on END 1-47. Working to have welder cut slot in conductor pipe to use same as drill in Veco pounded the 16" conductor down the required 20 ft (the other crew). RD Veco dryhole digger. Make ready to move rig back over well. Set 7-1/16" BOP in Cellar (stored in Endicott's VMS Bldg) Set rig mats and cover the mouse hole annulus with gravel Held PJSM and discussed SOP's for moving the rig over the well. Endicott DSO attended and he discussed HAZARDS identified. Moved rig over well and set down. RU cellar and drip pans. Held PJSM on NU BOP's. SIMOP with SLB Slickline changing out SSSV on END 1-47 (driller side of rig) NU 7-1/16" BOP's Tighen adaptor flange bolts after installing BOPs. Lined up lubricator to rotary table. PJSM for new crew rigging up BOPE. Complete NU of 7 1/16" BOPE. Seal up around cellar to facilitate warming ROPE. Function test BOP's. SIMOPS continue with SLB Slickline on END 1-47. Attempt to test BOPE. Choke and kill line connections leaking. Blowdown and changeout seal rings. BOP test. Received the cross over Wireline unit working on END 1-47 had a leak on an o-ring when wire parted. Pulled wire out of hole and shut swab valve. SD Nordic 2 equipment and muster in the ops cab. Bleed 1-47 wellhead pressure down to bleed tank. Nordic crew sniffed the rig for LEL and checked OK. Started rig back up and notified Endicott Security and Safety on situtation. Finish BOP test. Unloaded lubricator RU Valve shops lubricator. Held PJSM with crew on pulling TW C. Pullled TWC and RD lubricator WHP = 0 psi. Wait on wireline unit. Grease crew working on END 1-47 to grease lock the swab valve so they can rig down off the well. Grease crew serviced our IA and OA valves. Tested the cellar mainfold line while waiting on the slickline unit. Slickline unit is RD on END 1-47 and moving over to END 1-39 Doug Varble and Bruce Roberson came by and conducted THA on situtation with working on 1-47 with rig on 1-39. Discussed hazards and stopped job on 1-47. RD unit and moved to 1-39. RU Tiger tank hardline to rig and PT to 3000 psi RU cutting box. Wireline crew got Unit Work Permit. Crew change and then wait for SLB wireline relief and handover. Finish spotting cuttings box where Slickline unit was sitting for work on END 1-47. PJSM to rig up, PT, and run Slickline. R/U slickline BOP and Lubricator, etc. PT lubricator to 2000psi. Good test. Pull dummy SSSV on first run. Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 2 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours ! Task ~ Code NPT Phase Description of Operations 3/20/2007 22:50 - 00:00 1.171 BOPSUFi P 3/21/2007 00:00 - 00:35 0.58 RIGU 00:35 - 01:45 1.17 RIGU 01:45 - 02:45 1.00 RIGU 02:45 - 04:45 2.00 RIGU 04:45 - 06:15 1.50 RIGU 06:15 - 08:15 2.00 I RIGU 08:15 - 08:30 0.25 RIGU 08:30 - 10:30 2.00 RIGU 10:30 - 12:45 I 2.251 RIGU 12:45 - 17:35 4.83 RIGU 17:35 - 18:45 1.17 RIGU 18:45 - 19:15 0.50 RIGU 19:15 - 21:00 1.75 PULL 21:00 - 23:00 2.00 CLEAN 23:00 - 00:00 1.00 CLEAN 3/22/2007 00:00 - 04:30 4.50 WHIP P 04:30 - 05:00 0.50 WHIP P 05:00 - 08:30 3.50 WHIP P 08:30 - 10:45 2.25 WHIP P 10:45 - 12:35 1.83 WHIP P 12:35 - 13:00 0.42 WHIP P 13:00 - 15:30 2.50 ZONISO P 15:30 - 17:00 1.50 ZONISO P 17:00 - 17:30 0.50 ZONISO P 17:30 - 18:45 1.25 ZONISO P 18:45 - 20:45 I 2.001 ZONISO I P 20:45 - 21:45 1.00 ZONISO P 21:45 - 00:00 2.25 ZONISO P 3/23/2007 00:00 - 00:45 0.75 ZONISO C PRE RIH to set valve catcher sub at 9330'. Set down at 8107' and released sub. POOH to set-up to retrieve valve catcher sub. PRE Continue to POOH on run #2. PRE Run #3 to pick up valve catcher sub successful. PRE Run #4 - re-run valve catcher sub with nuckle joint. Set-down at 3904'. PRE Run #5 -run 3.805" guage ring to 9400' PRE Run #6 - re-run the valve catcher sub w knuckle jt. Set Catcher sub on rod and pall at PRE RIH and change out DCK to DGLV at 3500 ft. Wireline Crew change at 8:00 hrs PRE PJSM with rig and slickline crew. PRE PU KO Tool with DGLV and RIH Working at trying to set DGLV, POOH and re-pin DGLV Held THA on traction device footware. Mitigated the hazards and posted crews THA in Doghouse for review Held Pre Spud Meeting with Crews PRE RIH to set DGLV in mandel at 3,500 ft. POOH and PT tubing to 2000 psi 30 min OK PRE PU and RIH to catcher sub Failed run, repin to steel and RIH POOH dragging . Recovered catcher sub PRE RIH to recover the rod and ball (1-3/8" FN). POOH with rod and ball. PRE SLB changeout DECOMP Run GS spear and pull RHC plug. WEXIT Run 20' x 3.70" dummy WS drift to 10,170' with no issues. WEXIT Rig down SLB slickline unit. WEXIT Rig-up E-line and PU WS setting BHA. WEXIT PT lubricator to 500 psi WEXIT RIH with WS on E-line. RIH and tied-in, corrected -42 ft. relogged and confirm tie-ine. OK. RIH and PU to CCL at 10,106 ft TOW S at 10,120 ft. Oriented W S to 0.6 L HS. Set WS as per TDT Log Dated 3-1991 and B-P's PDL log. Set down, OK, PUH, lost 500 Ib TOWS @ 10,120 ft ELMD RA Marker ~ 10,130 ft ELMD BOWS ~ 10,137.53 ft ELMD WEXIT POOH with eline. WEXIT RD Eline and lubricator WEXIT PJSM on RU CT and injector DECOMP PU and stab inject and pack off on the well. RU to pull CT across pipe shed roof DECOMP Pull tested cable and pull CT across the pipe shed roof DECOMP Install BOT's external CTC and pull test to 35k DECOMP Make ready to fluid pack CT and pump dart. PJSM with new crew. Pump 20 bbls around to bung hole. DECOMP Pump dart. Calculated volume of 59.7bbls. Flash still in coil. 57.5bbls actual. PT CTC to 3500psi. Good test. Pump second dart to verify coil volume. 57.4bbls actual. DECOMP PU cementing nozzle. DECOMP RIH to tag WS. Paint flag. DECOMP RIH to tag WS. Paint flag. Printed: M79/2007 10:20:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To - _ 3/23/2007 _- - 00:45 - 01:05 01:05 - 01:35 01:35 - 02:25 02:25 - 04:05 t ^~ 04:05 - 04:35 ~ ~j `L~ ~ 04:35 - 08:00 ~ 08:00 - 08:30 ~ 08:30 - 09:25 09:25 - 11:45 11:45 - 13:00 C L _y JC 13:00 - 15:50 t-39 ~V~~lo 15:50 - 17:00 17:00 - 20:20 20:20 - 21:00 21:00 - 22:40 22:40 - 23:15 23:15 - 23:30 23:30 - 00:00 1-39A/N-16 1-39A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code 0.33 ZONISO C 0.50 ZONISO C 0.83 ZONISO N 1.67 ZONISO C 0.50 ZONISO P 3.42 ZONISO P 0.50 ZONISO P 0.92 ZONISO P 2.33 STWHIP P 1.251 STWHIPI P 1.171 STWHIPI P 3.331 STWHIPI P 0.671 STWHIPI P 1.671 STWHIPI P 0.58 STWHIP P 0.25 STWHIP P 0.501 STWHIPI P Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: NPT ~ Phase ~ Description of Operations DECOMP PJSM for cement squeeze. DECOMP Perform infectivity test. 1200psi @ .5bpm, 1900psi C~ 1.Obpm. Dropped slowly after SD pumps. DECOMP PT cement lines and wait on cement test results. DECOMP Pump abandonment job. Pump 15 bbls of 15.8ppg cement. Perfs basically sealed as soon as cement contacted. Pressured up to 3000psi, holding steady. Bled off pressure and laid remainder of cement in hole. Highest possible cement at 9800'. Pulled to safety at 8900'. DECOMP SD and hold 500psi on abandonment. DECOMP RIH to WS 10,120 ft. contaminating cement. POOH at 3.00 bpm chasing cement to surface. Jetting all jewelry. DECOMP Jetted up BOP stack. DECOMP Change out BHA. PU window Exit BHA WEXIT Check depthometer on injector. RIH with Window Exit BHA at min rate Set down at 10,118 ft (cement node in perf area) WEXIT PUH. Wash/ream out cement nodes from 10,118.8 ft Op = 2.75 / 2.73 bpm at 1,996 psi off btm Density = 9.16/9.13 ppg PUH from 10.124 ft to 10,000 ft wash back down wtxi i nnuu wnnaow starring at iuizn.a tt c; ~ nnu at ui tt i s minutes Op = 2.72 / 2.70 bpm. CTP = 1926 psi Vp = 226 bbl W EXIT Pump 2 ppb biozan pill. Milling window Op = 2.72 / 2.70 bpm. CTP = 1926 / 2100 psi Vp = 226 bbl Pumped another 10 bbl sweep at 10,129 ft Mix up another 20 bbl sweep WEXIT Pump 2 ppb biozan pill. Milling window Op = 2.72 / 2.70 bpm. CTP = 1940 - 2000 psi Vp = 227 bbl Pumped another 10 bbl sweep at 10,131'. Bottom of window at 10,131.5'. WEXIT Mill 8' of formation at 0.3fpm to 10,139.5'. WOB 6K#'s, 1930 psi. Geo confirms, good samples show in open hole. PROD1 Ream up and down thru window to dress. Do 3 passes with very little motor work. Run in dry, no bobbles on the weight indicator. No bottom of hole!! Stop and pull up ~ 10,148'. PROD1 Discuss options with rig team and town engineer. PROD1 RIH to tag bottom to understand what's happening downhole. Set down at 10,191.5'. Motor work began just prior to sitting down. Pull caliper log from original hole drilled in 7/3/1988. 7" casing ran and cemented. Window exit HS. Guage hole 8.5", caliper from 10,155-10,190' washed out to 11-12". Shale interval. Guage hole starting again at 10,190' according to log. Travelling between 7" casing and washed out hole. PROD1 POOH to swap milling BHA for cementing nozzle. Order Page 3 of 25 Spud Date: 2/12/2007 End: Printed: 4/19/2007 10:20:26 AM BP EXPLORATION Page 4 of 25 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To ; -39A/N- -39A/N- REENTE NORDIC NORDIC Hours 16 16 R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase ; Spud Date: 2/12/2007 : 3/19/2007 End: Release: 4/19/2007 Number: Description of Operations 3/23/2007 23:30 - 00:00 0.50 STWHIP P PROD1 20bbls of 15.8ppg cement from SLB. Trucks ETA 6:00 am. 3/24/2007 00:00 - 02:50 2.83 STWHIP N DPRB W EXIT Continue POOH to swap milling BHA for cementing nozzle. Order 20bbls of 15.8ppg cement from SLB. Trucks ETA 6:00 am. PJSM to swap milling BHA for cementing nozzle. 02:50 - 03:45 0.92 STWHIP N DPRB WEXIT LD milling BHA. Pilot mill worn badly on one side and underguage 3.73" go/3.72" no go. Reamer 3.79" go/ 3.78" no go. PU cementing BHA. 03:45 - 07:15 3.50 STKOH N DPRB PROD1 RIH to attempt to cement original hole washout. RIH with nzl BHA to confirm PTD outside of 7" casing. Tagged at 10,175 ft. PU clean PUH and wait on lab results and clean brine. Vp = 219 bbl at 07:07 hrs Op = 2.70 / 2.68 bpm CTP = 1307 psi 07:15 - 08:00 0.75 STKOH N DPRB PROD1 Circulating clean 9.1 ppg brine down hole Cement Results CFlass G 15.8ppg, Yield = 1.16 ft3/sxs; Water = 5.095 gal/sxs TT = 3:47 hh:mm W L = 80 ml Having communication problems with radio skip from N1. 08:00 - 08:45 0.75 STKOH N DPRB PROD? Held PJSM meeting on pumping cement on P&A 08:45 - 10:55 2.17 STWHIP N DPRB PROD1 Take on water and batch mix 20 bbl cement Water temp at 56 deg F. will have to shear cement 1 hrs to bring up the T to 80F. This will reduce our TT to 2:45 min. Cement at 15.8 ppg at 10:20 hrs. Shearing cement and bring fluid temperature from 56 F to 70F. 10:55 - 12:10 1.25 STWHIP N DPRB PROD1 Pumped 3 bbl water, PT to 4000 psi. Pumped 2 bbl water followed by 22 bbl of 15.8 bbl cements bbl of water. SD and switch to pumping 50 bbl of 9.1 ppg brine with 2.00 ppb biozan. RIH to 10,175 ft and tagged. Chasing cement to nozzle. With 58 bbl pumped, PUH laying in cement at 1:1 from 10,174 ft to 9900 ft. Losing 0.5 bpm while laying in. Stopped at 9,600 ft. Cement out of nozzle at 77 bbl. Closed choke and squeeze cement at low pressure. Op = 0.25 psi, W HP starting to rise to 754 psi. WHP holding at 750 psi with 1.5 bbl squeezed away. 12:10 - 12:34 0.40 STWHIP N DPRB PROD1 RIH contaminating cement at 1:iwhile holding 500-600 psi on the well. Cleaned out to 10,115 ft (5 ft above WS). PUH with chasing cement to surface with clean 9.1 ppg brine hold 500 psi on W H With 9.1 ppg bio out RIH cleaning out to 10, 115 ft with 350 psi WH 12:34 - 13:30 0.93 STWHIP N DPRB PROD1 PUH chasing contamination cement to surface. With 90 bbl , cement to surface divert to cutting box. PUH jetting up gas lift mandels and WOC Cement sample in UCA at 12:45 hrs 13:30 - 16:30 3.00 STWHIP N DPRB PROD1 RIHrIH and stopped at 10, 114 ft, RRIH to 10,114 fHl 16:30 - 19:00 2.50 STWHIP N DPRB PROD1 PUH from 10,114 ft. Cement at 1000 psi at 1630 hrs. Inc Op to 0.9 bpm W OC Cement at 1720 psi at 17:20 hrs climbing slowly. UCA ~ 2000psi ~ 6 pm. 19:00 - 19:20 0.33 STWHIP N DPRB PROD1 RIH and tag cement at 10,120'. Set down 75001bs. Cement job a success. 19:20 - 21:10 1.83 STWHIP N DPRB PROD1 POOH to pick-up cement milling BHA. PJSM prior to getting to surface for LD BHA and cutting coil. 21:10 - 22:10 1.00 STWHIP N DPRB PROD1 Cut 100' of pipe, LD cementing nozzle BHA. Printed: M19/2007 10:20:28 AM ~' r BP EXPLORATION Operations Summary Report Page 5 of 25 ~ Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task Code NPT ~ Phase ~ Description of Operations 3/24/2007 - 22:10 - 22:30 0.33 STWHIP N DPRB PROD1 PJSM for connecting new Baker CTC and PU milling BHA. 22:30 - 23:30 1.00 STWHIP N DPRB PROD1 M/U CTC, pull test 35klbs and PT 3500psi. PU milling BHA. 23:30 - 00:00 0.50 STWHIP N DPRB PROD1 RIH to mill cement out of window. 3/25/2007 00:00 - 01:50 1.83 STWHIP N DPRB PROD1 RIH to mill cement out of window. 01:50 - 03:40 1.83 STWHIP N DPRB PROD1 Tag cement at 10,120'. Mill thru hard cement to 10,141'. 03:40 - 04:20 0.67 STWHIP P PRODi 04:20 - 06:30 2.17 STWHIP P PROD1 06:30 - 08:15 I 1.751 STWHIPI P I I PROD1 08:15 - 08:30 I 0.251 DRILL I P I I PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 09:45 0.75 DRILL P PROD1 09:45 - 15:45 6.00 DRILL P PROD1 15:45 - 20:30 4.75 DRILL P PROD1 20:30 - 21:25 0.92 DRILL N RREP PROD1 21:25 - 21:40 0.25 DRILL P PROD1 21:40 - 22:30 0.83 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 13/26/2007 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P ~ ~ PROD1 01:30 - 01:45 0.25 DRILL P PROD1 01:45 - 02:45 1.00 DRILL P PROD1 02:45 - 06:00 3.25 DRILL P PROD1 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 09:30 2.75 DRILL P PROD1 09:30 - 10:00 I 0.501 DRILL P (PROD1 10:00 - 12:30 ~ 2.501 DRILL I P PROD1 12:30 - 14:15 I 1.751 DRILL I P I I PROD1 14:15 - 16:30 2.25 DRILL P PRODi 16:30 - 17:00 0.50 DRILL P PROD1 2.62bpm/2.62bpm/5-6.5klbs WOB. FS 1790psi. Instantaneous ROP 30'/hr -very constant. Dry tag to confirm window and bottom Cu? 10,141'. Swap to new 10ppg Flo-pro system before pulling off bottom. Bring 40bbls around the corner before starting up hole. POOH to swap to a-coil. Continue swapping to 10ppg Flopro system. OOH, held PJSM on blowing down CT. Checked flow. Unstab and LD milling BHA Held PJSM on N2 blow down. Notified Doyon 16 on the operations. Finish sucking out tiger tank, RU N2 and PT to 3000 psi. Blow down reel prior to demob Swap out reel from E-free to E-coil coiled tubing Mechanic looking at SLB Power Back. RU the Eline CT hardline and eline bulk head SLB mechanics check P14 pump for hydraulic leaks SLB Mechanics continue to look at P14 pump in the powerpack. Re-head slickline while waiting. PJSM for stabbing coil. Pull CT across and stab in injector. Meg a-line -good test. Fill coil, leading with McOH for ice plugs. Prep for slack management. Fill coil, leading with McOH for ice plugs. Prep for slack management. PJSM for slack management. Pump slack management. Cut CT, install CTC. Pull test to 35klbs. Rehead UOC and meg test. PT CTC to 3500psi. Crew change with Handover. PU 5" deployment luibricator, change o-rings and function test BOP's. Held PJSM on Function testing BOP's and PU and RIH with BHI sidetrack BHA Function test BOP as per AOGCC Talked with Town on Plan forward PU BHA # 5 ST BHA with 3.8 deg /100 ft. Have to use a pipe wrench to get 3.8 deg bend motor in the hole. May have some issue pressure undeploying BHA with slickline. RU to test pull the 3.8 deg BHA with slickline. Nordic's slickline unit was unable to pull 3.8" BHA out of well. The hydraulics kicked out at 1400 psi. The wire is tension rating to 2,000 Ibf. RD Lubricator and RU Inject to RIH. Set counters, RIH (OK, Snubb force -5k to 9k) Nordic & and SLB's Electrican working on Micro Motion. Took a little wt at 9324 ft (X nipple) and 9650 ft (WLEG)RIH to 10,060 ft to tie-in Tie-in from 10,060 ft Corrected +26.5 ft Endicott Conducted Man down excercise on Nordic Rig 2 pipe Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To Hours ~ Task ~ Code I NPT --- _ ' _- -~- ---L 3/26/2007 ~ 16:30 - 17:00 ~ 0.50 ~ DRILL ~ P 17:00 - 17:40 I 0.671 DRILL I P 17:40 - 18:00 I 0.331 DRILL I P 18:00 - 21:15 I 3.251 DRILL I P 21:15 - 21:45 I 0.501 DRILL I P 21:45 - 00:00 I 2.251 DRILL I P Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 3/27/2007 00:00 - 01:25 1.42 DRILL P PROD1 01:25 - 01:40 0.25 DRILL P PROD1 01:40 - 03:50 2.17 DRILL N DPRB PROD1 03:50 - 04:25 0.58 DRILL N DPRB PROD1 04:25 - 04:55 0.50 DRILL N DPRB PRODi 04:55 - 07:35 2.67 DRILL N DPRB PROD1 07:35 - 08:05 0.50 DRILL N DPRB PROD1 08:05 - 08:45 0.671 DRILL N DPRB PROD1 08:45 - 09:30 ( 0.751 DRILL I N I DPRB I PROD1 09:30 - 12:25 I 2.921 DRILL I N I DPRB I PROD1 12:25 - 13:45 I 1.331 DRILL I N I DPRB I PROD1 Page 6 of 25 ~ Spud Date: 2/12/2007 End: Description of Operations shed. Call was made to Toolpusher from Driller about a man down in the far end of the pipe shed Toolpusher called Endicott Security at 659-6800 at 16:45 hrs SLB working with Nordic at WSL request to solve the micro motion and radio issues. Waiting for Endicott's IMT to finish the Mandown training exercise SD pump, close EDC and orient TF to HS. RIH and tagged hard with Op min at 10,146 ft. PUH and Setup to sidetrack Drilling sidetrack starting at 10,150 ft Op = 2.5 bpm at free spin 3400 psi Kicking off cement plug /sidetrack at control ROP Op = 2.5 /2.53 bpm CTP = 3400 / 3523 psi Density = 10.16 / 9.95 ppg BHP = 5739 psi w/ EDC at 11.14 ppg Set Swaco choke to hold a WHP of 100 psi maintaing a constant BHP of 5800 psi PVT 364 bbls. No progress being made at 10,177.2'. Seems like a metal contact. Continuous stalls at that depth, no motor work above that depth. Log hole upwards to attempt verify WS depth. No RA tags seen over interval. POOH to inspect BHA/bit. EDC opening problematic. Solve and continue out of hole. Continue to POOH to check BHA/bit. PJSM on BHA handling, while continue to trip out of hole. Swap BHA. Bit worn on badly on reamer section, bottom of pilot looks nearly new. Looks as if it has run against metal, possibly inside casing. Need to verify depths/find RA tag on next run. LD orienter(bring GR closer to bit), bent motor and bit. PU straight motor, 3.80' diamond mill, and rest of drilling BHA. BHI tools not testing correctly. Troubleshoot problem. Continue to PU BHA. RIH to verify depth/find RA tag. Stopped at 10,090 ft PUW / RIW = 30.5 / 21 klbf Logging tie-in Corrected 7.5 ft RIH logging down to locate the RA Marker BHP = 5806 psi with ECD at 11.3 ppg Started taking wt at 10149.9 ft with pump pressure Bit at 10164 ft Phase II Weather Conditions Logging up to tie-in again RA at 10,138 doesn't look like RA RIH till tag at 2.00 bpm. adjusting BHP to 11.3 ppg ECD. Tagged with 2k motor work at 10,179 ft No RA Marker were seen POOH to PU 7" underreamer Phase II weather conditions across GPB Turned to Phase I at 12:00 hrs LD milling BHA and PU BOT motor and DB Underreamer Test tool, OK set counters RIH Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 7 of 25 Operations Summary Report Lega{ We{I Common W Event Nam Contractor Rig Name: Date~ Name: 1 ell Name: 1 e: Name: From - To ~ -39A/N- -39A/N- REENTE NORDIC NORDIC Hours 16 16 R+COM CALIST 2 Task PLET A Code E NPT~ Start Rig Rig Phase Spud Date: 2/12/2007 : 3/19/2007 End: Release: 4/19!2007 Number: Description of Operations 3/27/2007 13:45 - 16:30 2.75 DRILL N DPRB PROD1 RIH with DB Underreamer 16:30 - 17:30 1.00 DRILL N DPRB PROD1 PUH and closed EDC at 10,075 ft UR from 10,075 ft to 10,115 ft at 2.4 bpm and 3,600 psi at 1 fpm 17:30 - 18:30 1.00 DRILL N DPRB PROD1 SD pump, PUH and Underream 10,075 ft to 10, 115 ft again at 1.5 fpm with 2.3 bpm at 4000 psi 18:30 - 20:30 2.00 DRILL N DPRB PROD1 Open EDC. Circulate out of hole. 2850 psi at 2.49 bpm. Hold PJSM in ops cab to discuss handling BHA. 20:30 - 21:30 1.00 DRILL N DPRB PROD1 At surface. Flow check. LD undereamer tools. 21:30 - 22:00 0.50 STWHIP N DPRB WEXIT Make up Baker 7" x 4-1/2" whipstock on Inteq BHA. Orient tray face to highside. Meaure tools & whipstock. 22:00 - 00:00 2.00 STWHIP N WEXIT Run in hole. 3/28/2007 00:00 - 01:00 1.00 STWHIP N DPRB WEXIT Log gr tie in from 9900' using PDC log and TDT log. Add 6' correction. 01:00 - 01:15 0.25 STWHIP N DPRB WEXIT 36k# up, 25k# do wt. PU to string up weight w/ btm WS at 10,112'. Close EDC and pressure setting tool. Setting pressure at approx 3700 psi. Set 4 k# down to verify set. 01:15 - 03:15 2.00 STWHIP N DPRB WEXIT Pull out of hole. Hold PJSM in ops cab to discuss handling the BHA and cutting and re-heading. 03:15 - 04:00 0.75 STWHIP N DPRB WEXIT LD Baker tools. Rig up hydraulic cutter. 04:00 - 08:28 4.47 STWHIP N DPRB WEXIT Cut 100' of coil. Dress coil and make up BOT connector. Note: Running BOT's 2-3/8" CTC to 2-3/8" PAC pin to reduce the need fora 1 ft cross-over between the CTC to the UOC. Need to get with BHI and have the UOC cut to 2-3/8" Reg Box. 08:28 - 10:45 2.28 STW HIP N DPRB WEXIT RIH with milling BHA. Stopped at 3000 ft and and checked micro motion. RIH 10:45 - 11:00 0.25 STWHIP N DPRB WEXIT Log tie-in at 9900 ft Corrected +7 ft to TDT log dated 3/5/1991 11:00 - 12:45 1.75 STWHIP N SFAL WEXIT Nordic and SLB Elect Tec working on Micro Motion 12:45 - 12:50 0.08 STWHIP N DPRB WEXIT RIH to dry tag the TOWS at 10,098.2 ft 12:50 - 13:18 0.47 STWHIP N DPRB WEXIT PUH, Op = 2.7 bpm at 3776 psi (off btm) Tagged with pump at 10102.9 ft Started milling window at 13:00 hrs at 10,103.1 ft CTMD 13:18 - 22:30 9.20 STWHIP N DPRB WEXIT Milling window # 2 starting at 10,103.1 ft Milling on collar at 10105 ft to 10,106 ft Lots of noise downhole on the Coiltrak DPS Op - 2.56 / 2.57 bpm WOB /DPS 4.84 klbf CTP ! 3650 / 3660 psi PVT = 352 bbl Appear to be in formation. 22:30 - 00:00 1.50 STWHIP N DPRB WEXIT Appear to be in formation. Not much evidence in samples however. 3/29/2007 00:00 - 02:00 2.00 STWHIP N DPRB WEXIT Continue to drill formation to 10,120'. Getting clear inidications of formation in samples. 02:00 - 03:00 1.00 STWHIP N DPRB WEXIT Dress window with three up and down passes. Dry drfl in down direction. Window looks smooth. 03:00 - 05:40 2.67 STWHIP N DPRB WEXIT Trip out of hole. Hold PJSM in ops cab to discuss handling BHA. 05:40 - 06:45 1.08 DRILL N DPRB PROD1 Get off well. Flow check. LD Baker milling tools. Gauge reamer and mill. 06:45 - 07:00 0.25 DRILL P PROD1 PJSM on BHA Handling 07:00 - 08:15 1.25 DRILL P PROD1 PU 3.6 deg / 100 ft BHA. PU 5 ft lubricator for pressure deploying BHA Pressure tested BOT CTC Tensile strength of CTC at 80% is 53klbf. Had trouble RIH with CT due to high Printed: M79/2007 10:20:28 AM '~ BP EXPLORATION Page 8 of 25 ~ Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours Task Code 3/29/2007 07:00 - 08:15 1.25 DRILL P 08:15 - 10:30 2.25 DRILL P 10:30 - 10:45 0.25 DRILL P 10:45 - 11:00 11:00 - 14:30 0.25 DRILL P 3.50 DRILL P 14:30 - 15:15 0.75 ~ DRILL P 15:15 - 15:30 0.25 DRILL P 15:30 - 16:10 0.67 DRILL P 16:10 - 16:23 0.22 DRILL P 16:23 - 19:30 3.12 DRILL P 19:30 - 20:00 0.50 DRILL P 20:00 - 20:15 0.25 DRILL P 20:15 - 20:45 0.50 DRILL P 20:45 - 23:00 2.25 DRILL P 23:00 - 00:00 3/30/2007 00:00 - 01:00 01:00 - 03:30 1.OOI DRILL P 1.00 CASE P 2.50 CASE P 03:30 - 04:00 04:00 - 06:15 0.50 CASE P 2.25 CASE P Spud Date: 2/12/2007 Start: 3/19/2007 End: Rig Release: 4/19/2007 Rig Number: NPT Phase ~ Description of Operations PROD1 snubbing forces. PROD1 RIH with sidetrack BHA PROD1 Log tie-in from 9890 ft downward at 150 fph to 9933 ft Corrected + 18' ) PRODi RIH and tagged bottom at 10121.6 ft PROD1 Drilling intermediate section from 10,121 ft TF set at HS and getting 20 DLS off of WS and then BR up to mid 30 deg DLS and 40 DLS. Wigwag TF to keep DL's below 40 deg/100 ft Op = 2.50 2.50 bpm at 3500 psi BHP = 5929 psi = 11.45 EDC WOB average 1-2 klbf ROP average at 30 fph PROD1 Seeing the required BR and drilling shale /coal sequence. PU are clean. Orient TF to 30 L to 30R TF Op = 2.50 2.50 bpm at 3700 psi BHP = 5917 psi = 11.40 EDC WOB (average) = 1-2 klbf ROP (average) = 30 fph Sample coverage of the shale shaker is consistance whit drilling. Lots of shale and coal coming across the shaker. PU is clean PROD1 Due vibration, PUH and pumped up survey at 10,225 ft PROD1 Drilling build section using R & L TF Op = 2.50 2.50 bpm at 3700 psi; Density = 10 / 10 ppg BHP = 5,917 psi = 11.40 EDC WOB (average) = 1-2 klbf ROP (average) = 30-40 fph PROD1 Wiper trip to base of WS at 10, 110 ft, Set down a little at 10,200 ft PROD1 Drilling build section using R & L TF. at 10,292 ft orient TF around due to stops Op = 2.50 / 2.50 bpm at 3900 psi; Density = 10.08 / 10.07 ppg BHP = 5,942 psi = 11.44 EDC WOB (average) = 2-3 klbf ROP (average) = 30-60 fph Will TD at 10,068 ft to 10,070 ft TVD PROD1 Wiper trip to window. PROD1 Log gr tie in across RA tag at 10,107'. No correction. Reduce pump rate to 0.5 bpm. Maintain BHP at 5800 psi. PROD1 Run hole to TD. Tag at 10,400'. Displace coil to 2 ppb beads in clean hi vis flopro. PROD1 Pull out of hole laying in hi vis pill. Circulate out of hole following BHP schedule. Some coal on shaker. No plugging of micro motion. Reduce WHP from 600 psi to) while nearing surface. Flow check well. Stable. PROD1 Lay down drilling BHA. RUNPRD Rig up floor to run liner. Hold PJSM to review same. RUNPRD MU 31 jts 3-3/16" ,6.2#, L-80 TCII finer w/ turbos. Bakerloc first 13 jts and shoe equipment. RUNPRD MU Inteq and Baker BHA tools. (DGS and DPS included). Stab coil. Get on well. RUNPRD Run in hole with liner. Added an arbitrary 15' correction. WT Printed: 4/19/2007 10:20:28 AM ~' BP EXPLORATION Page 9 of 25 ', Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1-39A/N-16 1-09A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 2/12/2007 Start: 3/19/2007 End: Rig Release: 4/19/2007 Rig Number: Date !From - To I Hours I Task i Code i NPT 3/30/2007 104:00 - 06:15 ~ 2.25 CASE P 06:15 - 08:30 2.25 CASE P 08:30 - 09:00 0.50 CASE P 09:00 - 10:00 1.00 CASE P 10:00 - 12:00 2.00 CASE P 12:00 - 13:30 1.50 CASE P 13:30 - 18:00 4.50 CASE P 18:00 - 22:00 I 4.001 CASE I P 22:00 - 00:00 I 2.00 I CASE I N I SFAL 3/31/2007 100:00 - 01:00 I 1.001 CASE I N I SFAL 01:00 - 02:00 1.00 CASE P 02:00 - 03:00 1.00 CASE P 03:00 - 04:45 I 1.751 CASE I P 04:45 - 05:00 I 0.251 CASE I P 05:00 - 07:50 I 2.831 CASE I P 07:50 - 08:30 I 0.671 CASE I P 08:30 - 10:45 I 2.251 CASE I P 10:45 - 11:00 I 0.251 CASE I P 11:00 - 11:30 0.50 CEMT P 11:30 - 12:45 1.25 CEMT P Phase ' Description of Operations RUNPRD check at 10,000 ft. 35klbf up. RIH and tagged bottom at 10,395' (without correction). PU and string wt at 36k. Pump to release GS. RUNPRD POOH with CT and CTLRT RUNPRD PJSM and discussed the hazards with handling BHA. Discussed SOP's developed by Nordic & BHI RUNPRD LD CTLRT. RUNPRD Make ready to pump pickle fluid down CT RUNPRD Pump SLB pickle juice and displace with N2. RUNPRD RU to swap reels to 2-3/8" Efree CT Pull CT across pipe shed. Secure CT and reel in prep of swapping out to 2-3/8" efree CT. Change reels with Veco truck. RUNPRD Secure reel. Install hardline. Pull coil to injector. Sharp bend in coil end slowing down the process. Get coil stabbed. Found some missing gripper blocks. Inspect injector. RUNPRD Order chain parts from SLB shop. Adjust gooseneck. Replace chain parts. Inspect chains. RUNPRD Continue to repair injector blocks. Recover lost gripper block. Inspect chains. RUNPRD Stab coil. MU coil connector. Pull test same. RUNPRD Displace reel to flo pro mud. Pressure test reel iron and connector. RUNPRD Install dart catcher. Circulate dart: 58.1 bbls. Circulate dart again: 57.9 bbls. Average is 58.0 bbls. RUNPRD Hold PJSM to discuss making up cementing BHA. Hold rig evacuation drill. RUNPRD MU Baker cemeting BHA w/ one jt PH6. RIH with Cementing BHA. Wt check at 9400 ft wo/ pumps = 33.4 klbf at 6.1 fpm RUNPRD Tagged top of liner at 9438 ft with seal and seen the seal go in the Deployment Sleeve. Stoped at 9446 ft CTMD, PU on 3-3/16" liner at 40k and move up hole 5 ft. Slick. Started circ at 1:1. Set liner down with 10k and Launched 5/8" ball with 400 psi to release from liner. Displace ball to GS at 2.41 bpm and 3600 psi CTP Slowed down to 0.5 bpm at 44 bbl's. Ball on seat at 45 bbl, sheared at 4,300 psi. PU and released from liner. RUNPRD Displaced hole to 10.00 ppg Brines at 2.40 bpm Circulating at 1:1 RUNPRD Held PJSM with Crews on cementing the well and all of the Hazards associated with same. SLB read the cementing procedure to the team and they signed off on same Op = 2.47 bpm at 3,600 psi RUNPRD Batch mix cement while circulating well . RUNPRD Cement at density at 11:30 hrs Pumped 6 bbl bio water to (in) MM. SD and Pumped 3 bbl water, PT to 4000 psi. Pumped 2 bbl water 16.8 bbl cement at 2.00 bpm and 2600 psi. SD and switched to water. Pumped 0.8 bbl and seen density drop, SD and installed dart with density at 14.50 ppg. launched dart with 400 psi from SLB. Pumped 1.3 bb) water and SD and confirmed the dart launched. Finished pumping the 3 bl water Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 10 of 25 ~ Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date 3/31 /2007 From - To Hours 11:30 - 12:45 1.25 CEMT P 12:45 - 15:00 2.25 CEMT P 15:00 - 15:30 0.50 CEMT P 15:30 - 18:00 2.50 CASE P Task ~ Code ~ NPT Phase Description of Operations RUNPRD behind. SD isolated cementers. Open to rig and pumped 30 bbl of 10.0 ppg brine with 2 ppb biozan. Switch to 10ppg brine chasing cement. Slowed down at 56 bbl to 1 bpm.Latched up at 57.5 bbp and sheared at 3500 psi. Pumped another 7 bbls an landed LW P at 64.8 bbl. (Calculated) SD ,check floats, OK. put 500 psi on CT and PUH and displace CT at 6 bbl/1000 ft RUNPRD POOH replace CT voidage RUNPRD LD Cement BHA RUNPRD Working on wt cell while waiting on pickle juice and N2 Pumper. RUNPRD Crew change. Hold PJSM to review reel blow down. RUNPRD Pump water, bleach,water,inhibitor, McOH. Displace reel to tiger tank with nitrogen. RUNPRD Hold table top fire and spill drills in ops cab. Hold SIMOPS/PJSM mtgs to discuss BOP work and reel swap procedure. RUNPRD Unstab coil and secure on reel. Drop reel to lowboy. SIMOPS: change BOP rams from 2-3/8" to 2" configuration. RUNPRD Remove 2-3/8" reel. PU 2" a-coil from lowboy. Install and secure same in reel stand. Continue to change rams in BOPs. Found a lot of cement in ram cavities. Opened all rams to clean out cement. Begin changing injector gripper blocks. PROD1 Perfom BOP equipment test. AOGCC wavered wittnessing BOP Test. Continue work on gripper blocks as possible. PROD1 BOP Test and change over packoff to 2' CT. Prep to pull CT across pipe shed. PROD1 Open doors on 2-318" rams. Leak by with low pressure. Pt to 250/3500 psi. PROD1 PU Injector and RU to pull CT across. Held PJSM on pulling CT across pipe shed. Pulled 2" CT across and secureed in injector head. Have trouble stabbing CT into top of the chains. PROD1 Inspect chain after pulling the CT across. Dress wire for CT Management PRODi Loading CT with 10.00 ppg brine PROD1 Rev cir for slack management at O = 2.00 bpm SD and RU cutter and cut 69 ft of CT off and 25 ft wire. 4.19 ft slack in wire. CT length 13610 ftVol = 36.4 bbl PROD1 Install CTC, pull tested to 30k. Rehead CTC to UOC. Megged line OK. PT CTC to 3700 psi. Adjusted guide arc for 2" ct PROD1 Hold PJSM in ops cab. Discuss BHA makeup and fluid swap. MU 2.74" parabolic mill and 2.74" string reamer on straight motor, w/ Inteq tools. Get on well. Detemine space out for pressure deployment. (2.6' slackoff for deployment). Get on well. Test tools. PROD1 Run in hole. PROD1 Log gr tie in from 10,090'. No correction. PROD1 RIH. Tag cement at 10,284'. Begin drilling ahead. 3100 psi fs at 1.65 in/1.65 out. 200-400 dpsi. Drilling ahead at 50-60 fph. PROD1 Drill cemnt to 10,396'. Tag float equipment. Mud rtns coming 18:00 - 18:30 0.50 CASE P 18:30 - 21:00 2.50 CASE P 21:00 - 21:45 I 0.751 CASE I P 21:45 - 00:00 I 2.25 I CASE I P 4/1/2007 100:00 - 05:00 I 5.001 CASE I P 05:00 - 08:30 I 3.501 BOPSU61 P 08:30 - 09:30 1.00 BOPSU P 09:30 - 11:10 1.67 BOPSU P 11:10 - 12:45 I 1.581 DRILL I P 12:45 - 13:10 I 0.42 ~ DRILL ~ P 13:10 - 14:45 1.58 DRILL P 14:45 - 15:25 0.67 DRILL P 15:25 - 19:00 3.58 DRILL P 19:00 - 20:00 1.00 DRILL P 20:00 - 22:30 2.50 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 4/2/2007 100:00 - 00:45 I 0.75 I DRILL I P Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 11 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date ~ From - To !Hours Task Code NPT Phase Description of Operations 4/2/2007 00:00 - 00:45 0.75 DRILL P PROD1 back at a pH of 12. dump some, treat the rest. 00:45 - 04:00 3.25 DRILL P PROD1 Drill float equipment. 3300 psi fs at 1.55 in/1.57 out. 13k# dn, 04:00 - 05:30 I 1.501 DRILL I P 05:30 - 08:45 I 3.251 DRILL I P 08:45 - 10:30 I 1.751 DRILL I P 10:30 - 11:40 1.17 DRILL P 11:40 - 12:15 0.58 DRILL P 12:15 - 14:40 2.42 DRILL P 14:40 - 14:55 0.25 DRILL P 14:55 - 15:10 0.25 DRILL P 15:10 - 15:45 0.58 DRILL P 15:45 - 20:00 I 4.251 DRILL I P 20:00 - 20:15 0.25 DRILL P 20:15 - 21:45 1.50 DRILL P 21:45 - 22:15 0.50 DRILL P 22:15 - 23:15 1.00 DRILL P 23:15 - 00:00 I 0.751 DRILL I P 4/3/2007 100:00 - 02:15 I 2.251 DRILL I P 02:15 - 03:30 1.25 DRILL P 03:30 - 07:45 4.25 DRILL P 07:45 - 08:30 0.75 DRILL N 17.5k# up wt. DHWOB: 2-3k#. Numerous stalls. Pick up 50' every 0.5' milled. Break through into formation at 10,400'. PROD1 Drill formation to 10.405'. Back ream shoe are a few times. Smooth. PROD1 Circulate out of hole. Open EDC and cir POOH at 1.82 bpm. Surge surface with CT and recovered several pieces of rubber, cement and solids. PROD1 Checked deployment numbers (after tagging up, slack off 2.6 ft Close 2-3/8" combi, Unstabbed injector and measured check valves at 3.00 ft after tagging up with CT. PROD1 MU CoilTrac BHI and line up injector head with roll gage. Aline goose neck to injector head PROD1 PU BHA confirmed 205 deg external offset. PROD1 RIH with 2.ideg/100 ft setting PROD1 Stopped at top of liner at 9,460 ft and log down to locate the top of the liner using the BHI's CCL. BHI's CCL logging tool with the new software seem to work OK. Logged 9,460 ft to 9,650 ft Seen the top of the liner at 9448 ft PROD1 RIH Started RA Marker tie-in at 10,130 ft No correction at 10,107.5 ft. PROD1 RIH to 10,350 ft, close EDC Position missed error was seen at BHI's screen while trying to close the EDC. Rebooted computer and closed EDC. RIH and orient TF to 90RTF PROD1 RIH and tagged bottom at 10,405 ft PU orientTF to drop hole angle Drilling Lateral section in K2B Sand with 160R TF Op = 1.52 / 1.51 bpm CTP 3150 / 3450 psi Density = 10.1 / 10.0 ppg PVT = 239 bbl. Note adding 150 bbl of new mud Adjusted the choke to achieve a 5,900 psi BHP at 11.2ppg EDC PROD1 Wiper trip to liner shoe at 10,405'. PROD1 Drill ahead to 10650'. ROP: 50-70 fph. Maintain an ECD of 11.2 ppg w/ 240 psi W HP. PROD1 Wiper trip to liner shoe at 10,405'. Hole smooth. PROD1 Drill to 10,715'. Inc and azimuth lined up for BHA trip to pick up 1.1 deg mtr. Inc: 93.2, Azm: 49.5, TVD: 10054'. PROD1 Wiper trip to window. Circulate out of hole following whp schedule. PROD1 Continue to trip out of hole for motor angle change. Follow whp schedule to maintain 11.2 ppg ECD. Hold PJSM in ops cab to discuss undeployment. Jog back in hole 300'. No additional cuttings surge noted on shaker. PROD1 Pressure undeploy lateral BHA. SIWHP: 650 psi. PROD1 Change AKO to 1.1 deg. Pressure deploy lateral drilling BHA. SFAL PROD1 Working on BHI CilTrac. GR failure Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 12 of 25 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To -39A/N- -39A/N- REENTE NORDIC NORDIC Hours ~ 16 16 R+COM CALIST 2 Task PLET A Code E NPT ~ Start Rig Rig Phase Spud Date: 2/12/2007 : 3/19/2007 End: Release: 4/19/2007 Number: Description of Operations 4/3/2007 08:30 - 09:45 1.25 DRILL N SFAL PROD1 WHP at 70 psi.Conventional undeploy with WHP dropping Change out GR and tested at surface. PU and scribed HS and 09:45 - 13:00 3.25 DRILL P PROD1 Set counters and RIH with EDC open. Follow whp schedule to maintain 11.2 ppg on btm. 13:00 - 13:15 0.25 DRILL P PROD1 Log gr tie in from 10,100'. Subtract 1.5' correction. 13:15 - 13:45 0.50 DRILL P PROD1 Run in hole. Close EDC. Wiper through open hole. One bobble at 10,585'. Other wise smooth. 13:45 - 16:00 2.25 DRILL P PROD1 Drill ahead from 10,715'. 3200 psi fs at 1.50 in/out. 200-300 dpsi. DHW06:2-3.5k#. WHP/BHP/ECD: 200/5850/11.25 ppg. IA/OA/PVT: 155/5/362 bbls. INC/AZMlfF: 93.2/49.5/1358. ROP: 35-65 fph. Resistivity tool readings becoming suspect. (shallow res reading very high) 16:00 - 17:30 1.50 DRILL P PROD1 Make MADD pass into liner to try and verify tool function. Run back to btm. 17:30 - 19:25 1.92 DRILL P PROD1 Drill ahead from 10772' 1.54/3250/958 w/ 200-300 psi dill, 1-3k wob at 90 deg w/ 200 psi induced whp to give 11.25 ECD. Drill in shale from 10750' to 10835' and geo feels we are too low 19:25 - 20:30 1.08 DRILL P PROD1 Drill from 10835' at 35-458 while climb to 97 deg. Swap to left side at 10850' w/ 35-45L. Drill shale to 10900' 20:30 - 21:30 1.00 DRILL P PROD1 Wiper to window was clean 21:30 - 00:00 2.50 DRILL P PROD1 Drill from 10900' 1.52/3300/908 w/ 200-300 psi dill, 1-3k wob, at 98 deg w/ 200 psi induced whp to give 11.25 ppg EMW. Drill in 240 api shale to 10960' (10034' TVD) and entered 60-80 api sand. Continue drilling at 98 deg. Drill to 11030' by 0000 hrs 4/4/2007 00:00 - 00:20 0.33 DRILL P PROD1 Drill from 11030-11050' 00:20 - 01:00 0.67 DRILL P PROD1 W iper to window was clean. Continue PUH thru shoe to logging depth in 3-3/16" 01:00 - 01:15 0.25 DRILL P PROD1 Log tie-in down from 10100'. Add 1.5' Table top parted CT discussion 01:15 - 01:45 0.50 DRILL P PROD1 Wiper to TD was clean to tag at 11050' 01:45 - 04:50 3.08 DRILL P PROD1 Drill from 11050' 1.62/3430/1008 w/ 200-400 psi dill, 1-4k wob w/ 200 psi induced whp to give 11.25 ECD at 96 deg. Drill to 11200' and are about to enter target polygon 04:50 - 05:45 0.92 DRILL P PROD1 Wiper to window. Hole smooth. 05:45 - 08:00 2.25 DRILL P PROD1 Drill from 11,200'. 3420 psi fs at 1.57 in/1.49 out. 200-350 dpsi. DHWOB: 2-3k#. WHP/BHP/ECD: 205/5887/11.33 ppg. IA/OA/PVT: 391/101/357 bbls. INC/AZM/TF: 94.9/105.7/1038. Having weight transfer problems. Mud is likely worn out. 260 bbls at mud plant. Order additional to make new system. Call for vac trucks. Wiper trip to 10,410'. RIH. Drill ahead 15' before stacking agian. Definitely a mud problem. 08:00 - 10:00 2.00 DRILL P PROD1 Continue trying to drill ahead. Send a 10 bbl new mud sweep downhole. No effect. Continue to drill a little at a time with short wiper trips between runs. 10:00 - 14:30 4.50 DRILL P PROD1 Continue to drill and short trip. Able to make 10' to 15' between short wiper trips. 14:30 - 17:30 3.00 DRILL P PROD1 Decide to pull out of hole to change out resistivity tool while waiting on vac trucks for mud swap. Maintain whp as per schedule. Hold PJSM in ops cab to Printed: 4/19/2007 10:20:26 AM 3 BP EXPLORATION Page 13 of 25 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To -39A/N- -39A/N- REENTE NORDIC NORDIC Hours ~ 16 16 R+COM CALIST 2 Task PLET A Code E NPT 4/4/2007 14:30 - 17:30 3.00 DRILL P 17:30 - 20:00 2.50 DRILL P 20:00 - 23:45 3.75 DRILL P 23:45 - 00:00 0.25 DRILL P 4/5/2007 00:00 - 00:30 0.50 DRILL P 00:30 - 02:35 2.08 DRILL P 02:35 - 02:45 0.17 DRILL P 02:45 - 03:20 0.58 DRILL P 03:20 - 03:55 0.58 DRILL P 03:55 - 04:15 0.33 DRILL P 04:15 - 06:00 1.75 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:00 1.50 DRILL P 08:00 - 11:30 3.50 DRILL N HMAN 11:30 - 14:15 2.75 DRILL N HMAN 14:15 - 16:30 2.25 DRILL N HMAN 16:30 - 18:25 1.92 DRILL N HMAN 18:25 - 18:40 0.25 DRILL N HMAN 18:40 - 20:00 1.33 DRILL N HMAN Spud Date: 2/12/2007 Start: 3/19/2007 End: Rig Release: 4/19/2007 Rig Number: Phase ! Description of Operations PROD1 review undeploy procedure. PROD1 Pressure undeploy BHA. Starting WHP was 322 psi (bleed down from 650 in 10 minutes). Crew change/safety mtg. Ending pressure was zero. SI master and swab PROD1 RU cutter and cut off 135' of CT for chrome management. Install CTC. PT 31 k BHI prep backup res tool on catwalk. RU BHI UOC and test. PT 4000 PROD1 Open swab, master-hole is full, no press. Open hole deploy BHA PROD1 Open hole deploy BHA PROD1 RIH w! BHA #16 (backup res tool + 1.1 motor + rebuilt bit) while circ thru bit 0.5/1900 following pressure schedule PROD1 Log tie-in down from 10130', corr -1.5' PROD1 Wiper to TD holding 11.25 ECD. Had set downs starting at 10801', 10820', 10824'. Lost ground back to 10810'. Reduce pump to 1.25 bpm and able to get in hole to -10900' setdown PROD1 Backream slow w/ 5k OP's and MW from 10900' to 10800'. Wiper back in hole to 11000' w/ rough areas around 10900' due to TF change while drilling. Backream to 10800' relatively clean. Wiper back in hole and set down at 10835'. Other minor wt loss areas to 10940' PROD1 Resume wiper to TD and tagged at 11366' PROD1 MAD pass from TD to compare this res tool against prior tool Swap to fresh mud while logging 1.47/3250 PROD1 W Iper from 10,800' to btm. Some mtr work and weight bobbles down through 10,900'. PROD1 Drill ahead from 11,368'. 3200 psi fs at 1.48 in/1.46 out. 200-300 dpsi. DHWOB: 2-3k#. WHP/BHP/ECD: 200/5805/11.19 ppg. IA/OA/PVT: 168/0/238 bbls. INC/AZM/TF: 96/97.8/1508. Wt transfer and ROP good. TF straight down, but angle continuing to build. Near bit at 101 deg. Time to pull BHA to check scribe and change motor bend. PROD1 Wiper back to liner shoe. Circulate out of hole. Maintain WHP as per schedule. HOId PJSM in ops cab to review undeploy procedure. At surface. Leave 600 psi on well. PROD1 Pressure undeploy BHA. Lay down tools. Check motor scribe to orienter (ok). Check orienter highside calibration. Tool was calibrated in the wrong mode, resulting in a 170 deg error in measured versus actual tool face (no wonder we couldn't drop angle !) Install night capon lubricator. Maintain 500 psi whp. PROD1 Mu lateral BHA with 1.5 deg mtr and re-run Hycalog bi-center. Pressure deploy BHA. Found 120 psi whp once on well. PROD1 Run in hole. Maintain whp as per schedule. PROD1 Log tie-in down from 10130'. Corr -1.5' PROD1 Continue RIH. Perform wiper 1.45/3080 w/ 250 psi whp to hold 11.20 ECD from below the shoe to 11000'. From 10830-920', had a few wt loss spots with associated MW in the big shale area, but otherwise clean at DTF. Backream 11000-10800' to clean it up and had a few OP's and MW. Then, wiper to TD tagged at 11425' Printed: 4/19/2007 10:20:28 AM r BP EXPLORATION Page 14 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name:. REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 4/5/2007 20:00 - 20:10 0.17 ~ DRILL N ~ HMAN ~ PROD1 Perform two 15'/min passes over 11390-425' at low side TF to 20:10 - 00:00 I 3.831 DRILL I P 4/6/2007 4/7/2007 00:00 - 00:20 0.33 DRILL P 00:20 - 01:15 0.92 DRILL P 01:15 - 01:30 0.25 DRILL P 01:30 - 02:55 1.42 DRILL P 02:55 - 04:55 I 2.001 DRILL I P 04:55 - 05:15 0.33 DRILL P 05:15 - 05:35 0.33 DRILL P 05:35 - 06:30 0.92 DRILL P 06:30 - 08:30 2.00 DRILL P 08:30 - 10:00 1.50 DRILL P 10:00 - 13:00 ( 3.001 DRILL I P 13:00 - 15:00 2.00 DRILL P 15:00 - 22:00 7.00 CASE P 22:00 - 23:45 ( 1.751 CASE I P 23:45 - 00:00 0.25 CASE P 00:00 - 00:20 0.33 CASE P 00:20 - 01:10 0.831 CASE P 01:10 - 01:35 I 0.421 CASE ~ P help break the 100+ deg trend and begin the planned drop to TD PROD1 Drill from 11425' 1.48/3280/1798 w/ 200-400 psi dill, 1-3k wob w/ 250 psi induced whp to give 11.26 ECD. NBI maxed out at 102 deg and showed immediate drop after 11425' and by 11487' were at 86 deg. Spent considerable time doing short wipers to get weight to bit after BHA was over the 'hump'. This included some overpulls of up to 10k. Drill to 11535'. Crossed into 30 api target sand at 11460' PROD1 Drill to 11546' (-9986' TVD) and stacking PRODi Wiper to shoe. Had a few 5k overpulls 10800-10900', but otherwise okay. Pull thru shoe to log tie-in PROD1 Log tie-in down from 10130', Corr +3' PROD1 Wiper back in hole. BHI PC SD while RIH thru shale. Set down at 10950'. Wiper back up hole while reboot and was clean to 10750'. Wiper back to TD was clean PROD1 Drill from 11547' 1.49/3220/90L w/ 100-350 psi dill, 1-3k wob w/ 225-300 psi induced whp to give 11.31 ECD. NBI is at 77 deg. Drill to 11633' PROD1 200' wiper after stacking PROD1 Drill from 11633' and finally get into fast drilling at 11640'. Drill to 11660' and geo's called TD PROD1 Wiper to window. Log gr tie in. Subtract 1.5' correction. PROD1 Run in hole and make wiper trip to bottom. Tag corrected TD at 11,656'. PRODi Wiper back to 3-3/16" liner shoe. Able to RIH a lot better with reduced pump rate, 1.1 bpm vs.1.5 bpm. Hole mostly smooth, a few motor work spots, but no set downs. PROD1 Lay in 2 ppb alpine bead pill from 11,500' back to 8500'. Paint white flags at 5158' and 9400' EOP. Continue to circulate out of hole. Maintain whp as per schedule until near surface. Slowly bleed whp to zero. Flow check well. Hold PJSM to discuss handling the BHA. PROD1 Lay down Inteq tools. Prepare same for running liner. PU Baker tools and place in pipe shed. RUNPRD Hold PJSM to discuss running liner assembly. MU float equipment. MU 73 joints of 2-3/8", 4.7#, 13 Cr, STL liner with cementralizers. Drift each connection due to tight wiper plug clearance. Fill w/mud occasionally. MU BTT Deployment sub w/ GS running tools. Add BHI DPS (2281' OAL) RUNPRD RIH w/ liner on CT circ at min rate 0.25/610. Follow pressure schedule after 2500' RUNPRD 9400' 27.7k, 17k RIH thru 3-3/16" RUNPRD RIH w/liner to setdown at 10262' (60 deg). PUH, clean at 16.2k and had released from the liner RUNPRD Attempt to latch back up and couldn't. Push down hole begrudgingly with pump on and off. Maintain 600 psi whp. Try to relatch at times. Had good setdown at 10296', but couldn't latch. Circ and wash off tool. RIH and chase to 10310' and latched up after setting on it a while RUNPRD PUH 20', clean at 27.7k. RIH and push to set down at 10312'. Try to circ and pressured up. Bleed off pressure. PUH and Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-39A/N-16 1-39A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Date ~ From -To Hours Task Code; NPT Phase 4/7/2007 ~~ 01:10 - 01:35 0.42 CASE P RUNPRD 01:35 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 04:40 0.421 CASE I P 1.001 CASE I N 0.501 CASE I N 1.171 CASE I N 04:40 - 06:30 1.83 CASE N 06:30 - 07:30 1.00 CASE N 07:30 - 08:45 1.25 CASE N 08:45 - 10:00 1.25 CASE N 10:00 - 14:45 4.75 CASE N 14:45 - 17:00 I 2.251 CASE I P 17:00 - 20:00 I 3.001 CASE I P RUNPRD RUNPRD Page 15 of 25 Spud Date: 2/12/2007 End: Description of Operations lost liner again. RIH and push to 10317'. Can't latch. Open EDC to equalized pressure in BHI tools since it appears that pressure gets trapped between the checks in the UOC and the seal assy on the GS when stabbing into the DS (which puts the GS dogs in the release position) Latch up on first try and pull liner freely back up hole to 10260' at 27.7k. RBIH and stack wt at 10316' (75 deg). Close EDC. PUH 28.3k, start pump to verify liner is clear 0.45/2000 and had full returns. Continue PUH slowly w/o pump and wo press to equalize RBIH 60'/min and set down at 10320' w/ 14k BHI DHWOB. After 5 tries, had no progress. Bleed off 600 psi whp slowly while attempting to work downhole. Bled off pressure too fast and differential to CT was too high so lost liner again. RIH and tag at 10317' and unable to push downhole. Start pump 0.6/2700 to warm up CT and apply 600 psi whp. SD pump and open Baker choke quickly to equalize bore and annular pressures. PUH 30k and had liner again. Work liner with and without pump w/ 600 psi whp and work down to 10328' w/ stacked wt. Gauge cementrailzers at 2.66" OD. Drift of 3-3/16" is 2.805". DLS from 10158-10363' avg 35 deg/100. Assume this is the cause of no progress. BHI PC needs a reboot. Park w/ stacked wt and circ at 10328' 0.5/2730 Discuss w/ Asset. Definitely need chrome liner in the wellbore for production reasons. So, since we are unable to get this one thru the 3-3/16" and since there is no chrome liner without cementralizers, and since the cementralizers are box x box, will have to pull this liner out of the hole and trim down the cementralizers Make arrangements for BOT to trim cementralizers. SD pump and wait for pressures to equalize. Got impatient and PUH too soon and released from liner. Had trouble relatching while pushing to final stacked resting spot of 10336' at shoe. Had to bleed off whp to equalize w/ CTP, then pressure up on BS w/ kill line to get equalized w/ CT when latching up. Then, since the wellbore had been relaxed, the cementralizers were being held in a bind by the 3-3/16". So, were temporarily immobile at 40k until increasing whp to 750 psi after resuming circ down the CT POOH w/ liner circ at min rate and following pressure schedule At surface. Hold PJSM in ops cab. Get off well. LD Inteq & Baker BHA tools. Wait on brine from MI to displace liner before pulling same. Displace liner and liner annulus to 10.0 ppg brine. Pull liner out of hole. Rinse off each joint in mouse hole with fresh water. Reverse in 3 bbls fresh water. RU and cut coil for chrome pipe management. Find a-line. Forward circulate. ANother 73' of e-line came out of pipe !. Seal a-line. Get on well and reverse circulate again. Lots of a-line movement in coil. Cut additional pipe to a-line. Re-head coil for a-line. PT 31 k, 4000 psi. Pump slack forward RUNPRD DPRBIRUNPRD DPRBIRUNPRD DPRBIRUNPRD DPRB RUNPRD DPRB RUNPRD WAIT RUNPRD DPRB RUNPRD DPRB RUNPRD Printed: 4/19/2007 10:20:28 AM ~ ~ BP EXPLORATION Page 16 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: i Date {From - To Hours Task ~ Code ~ NPT Phase Description of Operations 4/7/2007 17:00 - 20:00 3.00 CASE P RUNPRD at 1.3 bpm while over bung hole while MU CO BHA 20:00 - 22:40 2.67 CONDH P RUNPRD RIH w/ cleanout BHA (bi bit on 1.1 deg motor w/o res tool) circ thru bit at 0.2/1120 while follow pressure schedule. Adjust wt cell at 4000' 22:40 - 22:55 0.25 CONDH P RUNPRD 10100' 21.8k, 17.4k Log tie-in down from 10110', corr -3.0' 22:55 - 23:25 0.50 CONDH P RUNPRD RIH 0.5/1800/100L and started stacking wt at 10340'. Push to setdown at 10347'. PUH, clean 22.7k Start pump at 1.0/2160/110L w/ 300 psi whp and wash in hole and stalled at 10348'. Repeat at 1.25/2390/110L w/ 200 psi and wash in hole slower at 1.0'/min and had no wt loss or MW to 10390' 23:25 - 23:45 0.33 CONDH P RUNPRD Wiper back to 10250' was clean at 1.25/2300. Wiper thru shoe was clean at 1.25/2300 23:45 - 00:00 0.25 CONDH P RUNPRD W iper to TD 1.46/2850/DTF 27'/min holding 250 psi whp to give 11.25 ECD. Set down at 10565' and had MW, but then clean to 10800' 4/8/2007 00:00 - 02:00 2.00 CONDH P RUNPRD Lost wt and setdown at 10805'. Took one hour to work to 10860' at DTF getting 10' bites. The only way to get past 10800' is at 0.75 bpm or less at 40'/min or higher. The only way to get back out of the shale is to backream at <1.4 bpm at 5'/min and expect several 10k overpulls w/ MW up to 4500 psi. After one hour started getting a bunch of shale over the shaker. Wiper into the shoe at 10400' was clean 02:00 - 03:30 1.50 CONDH P RUNPRD Wiper back to 10800' while incr whp to 400 psi to give 11.4-11.6 ECD. Resume working to get back in hole. TF change from 90R to 45L at 10850' complicates getting in the hole (as mentioned above) w/o setdown. Work down hole to 10891'. Attempt to pull up hole and were temporarily immobile. Were packed off too. Cycled CT while pumping 1.0 bpm until getting returns. PUH very slow w/ 20k overpulls at 1.0 bpm-this is not fun. Continue wiper to 10700' 03:30 - 04:40 1.17 CONDH P RUNPRD Wiper back to 10800'. Incr whp to 500 psi to give 11.55-11.8 ECD. Make it to 10888' and set down. Wiper back to 10760' and wasn't too bad. Try getting by 10800' w/ higher pump rate and slower speed w/o success. So, RBIH at 0.75 bpm and after 3 tries got to 10854'. Wiper back to 10780' 1.5/3200 at 5'/min. RBIH at 0.7 bpm at 40'/min and got to planned 10920'. Wiper back to 10750' at 1.22/2600 at 5'/min w/ the usual 10k overpulls 04:40 - 05:55 1.25 CONDH P RUNPRD RBIH and only get to 10890'. Wiper back to 10780' at 5-10'/min. RBIH in the usual manner, but at 50'/min and get to 10960' (below shale!) and intentionally stop due to needed DTF change back to the right. Backream to 10780' with the usual 10k overpulls and associated MW. Continue wiper into the 3-3/16" and up to 10000' to get solids out of all the horizontal and for crew change 05:55 - 07:30 1.58 CONDH P RUNPRD Wiper back in hole holding 11.6-11.8 ECD. Maintain TF as drilled. Set down at 10855'. PU and reduce pump rate to 0.75. Continue to RIH. Set down at 10890'. PU. 10-15k# overpulls. Eventually cleaned up in up direction. RIH at 0.7 bpm. Set down again at 10895'. PU and back ream. Same overpulls in up direction. After spending all night cleaning this up, the shale interval near 10,850'-90' is still in very poor condition. Backream through open hole. Call town to discuss Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 17 of 25 Operations Summary Report Legal Well Name: 1 -39A/N- 16 Common W ell Name: 1 -39A/N- 16 Spud Date: 2/12/2007 Event Nam e: REENTE R+COM PLET E Start : 3/19/2007 End: Contractor Name: . NORDIC CALIST A Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date ~ i From - To ; Hours Task ~ Code NPT Phase ~ Description of Operations 4/8/2007 05:55 - 07:30 1.58 CONDH P RUNPRD options. 07:30 - 13:00 5.50 CONDH N DPRB RUNPRD Decide to set a Baker open hole whipstock at 10,600'. Wiper to 10,000'. Noticed signs of cuttings inside 3-3/16" liner. Decide to make wiper back to 10650'. POOH at 10 fpm to 100' above liner top at 9,438'. Increase circ rate to max (1.75 bpm). Holding 11.4 ECD with choke. Continue to circulate out of hole. AT 2500', a large amount of fine to medium grained shale/sand particles on shaker. The largest peieces were 1/16" thick x 1/4" across, looks like dark shale, but lots of loose sand grains mixed in. Surge well by running in hole form 1000' to 2000' twice. Returns cleaned up. 13:00 - 13:45 0.75 CONDH N DPRB RUNPRD At surface. Get off well. LD Inteq tools. 13:45 - 15:00 1.25 BOPSU P WEXIT Perform weekly function test of BOP equipment. Surface test mwd tools. 15:00 - 16:30 1.50 STKOH N DPRB WEXIT Bring Baker whipstock assembly into pipe shed. MU same to Inteq BHA. Scribe tray face to tool highside. Open EDC. Stab coiol. Get on well. 16:30 - 19:00 2.50 STKOH N DPRB WEXIT Run in hole w/ BTT OH WS on BHI MWD assy circ 0.34/880 thru EDC w/ open choke Slow to 20'/min thru 3-3/16" liner. Returns look like water 19:00 - 19:10 0.17 STKOH N DPRB WEXIT Log tie-in down at 10130', corr -4' 19:10 - 19:30 0.33 STKOH N DPRB WEXIT Continue RIH at 20'/min. Started losing wt at 10260' so slowed down to 2-3'/min. By 10281' had 5.Ok BHI wob on tool which is the maximum that BTT recommends. Assume we are pushing solids ahead of this large OD tool (14' @ 2.625" w/ max 2.68") 19:30 - 22:00 2.50 STKOH N DPRB WEXIT POOH w/ WS while discuss options 22:00 - 22:30 0.50 STKOH N DPRB WEXIT LD BTT OH WS in pipeshed 22:30 - 23:00 0.50 CLEAN N DPRB WEXIT MU drilling cleanout BHA (used bi bit on 1.1 deg motor) 23:00 - 00:00 1.00 CLEAN N DPRB WEXIT RIH w/ BHA #21 circ thru bit 0.3/1340 4/9/2007 00:00 - 01:30 1.50 CLEAN N DPRB WEXIT Continue RIH w/ drilling cleanout assy 01:30 - 01:40 0.17 CLEAN N DPRB WEXIT Log tie-in down at 10130', corr -4.0' 01:40 - 02:30 0.83 CLEAN N DPRB WEXIT Continue RIH 0.5/1400 at 30'/min and set down at 10281' (exactly where WS stopped). PUH, start pump at 1.0 bpm, RIH and stall at 10285'. Wash in hole slow w/ no MW to 10295'. PUH, and as a test, RIH w/ min rate and set down at 10298'. Wash by this area at 1.25 bpm w/ no MW and check again at 10310' w/ set down at min rate. Wash in hole at 1.25 bpm to 10320' w/ no MW. PU and RIH at min pump rate w/o setdown to 10' out of shoe at 10410' 02:30 - 05:00 2.50 CLEAN N DPRB WEXIT Backream to 10100' while start 30 bbls 60k LSRV mud, followed by 30 bbls 10# brine, plus 20 hi-vis mud + 20 brine + 20 hi-vis mud + 20 brine. RIH clean to 10500' and then recip initial two sweeps from 10500'-10200', final four from 10400'-10200' 05:00 - 08:00 3.00 CLEAN N DPRB WEXIT Open EDC at 10400'. Chase w/ 20 bbl hi-vis sweep then 35k mud OOH at max pump rate 1.95/3000. Got excess solids back after first two hi vis sweeps returned to surface. 08:00 - 08:30 0.50 STWHIP N DPRB WEXIT At surface. Get off well. LD clean out BHA. 08:30 - 11:00 2.50 STWHIP N DPRB WEXIT RU and cut coil for chrome pipe management. Cut 136' of pipe, and 130' of wire. MU a-coil head. Test same. 11:00 - 13:00 2.00 STWHIP N DPRB WEXIT Change in plans after morning call: plan to run aluminum billet in place of steel whipstock tray. Baker modifying setting Printed: 4/19/2007 10:20:28 AM s ~ BP EXPLORATION Page 18 of 25' Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date 1 From - To Hours Task Code NPT ~ Phase 4/9/2007 11:00 - 13:00 2.00 STWHIP N DPRB WEXIT 13:00 - 14:00 1.00 STWHIP N DPRB WEXIT 14:00 - 17:00 I 3.001 STWHIPI N I DPRB I WEXIT 17:00 - 17:15 0.25 STWHIP N DPRB WEXIT 17:15 - 17:45 0.50 STWHIP N DPRB WEXIT 17:45-20:00 2.25 STWHIP N DPRB WEXIT 20:00 - 20:45 0.75 STWHIP N DPRB WEXIT 20:45 - 22:15 1.50 STWHIP N SFAL WEXIT 22:15 - 23:00 0.75 STWHIP N DPRB WEXIT 23:00-00:00 1.00 STWHIP N DPRB WEXIT 4/10/2007 00:00-01:15 1.25 STWHIP N DPRB WEXIT 01:15-01:30 0.25 STWHIP N DPRB WEXIT 01:30-02:00 0.50 STWHIP N DPRB WEXIT 02:00 - 03:30 I 1.501 STWHIPI N I DPRB I WEXIT 03:30-04:251 0.92~STWHIP~N DPRB WEXIT 04:25 - 04:45 I 0.331 STWHIPI N I DPRB I WEXIT 04:45 - 05:45 I 1.001 STWHIPI N I DPRB I WEXIT 05:45-08:001 2.251STWHIPIN (DPRB (WEXIT 08:00 - 10:45 I 2.751 DRILL I N I DPRB I PROD1 10:45 - 11:45 I 1.001 DRILL I N I DPRB I PROD1 11:45 - 13:34 1.82 DRILL N DFAL PROD1 13:34 - 14:43 1.15 DRILL N DFAL PROD1 14:43 - 17:00 2.28 DRILL N DFAL PROD1 17:00 - 17:10 0.17 DRILL N DFAL PROD1 17:10 - 17:30 0.33 DRILL N DFAL PROD1 17:30 - 19:30 2.00 DRILL N DPRB I PROD1 Description of Operations tool/billet connection. Load Baker tools into pipe shed. MU aluminum billet and setting tool to Inteq mwd tools. Leave out the orienter. Check e-line. Stab coil. Test mwd tools. Get on well. Run in hole. Circulate through EDC at minimum rate. 24k up, 18k# do wt at 9400'. Continue to RIH through 3-3/16" liner. Log GR tie in from 10122'. Subtract 1.5' correction. Run in hole to 10451'. Hole very smooth. PU to neutral weight. Close EDC. Pressure coil to 3800 psi. Tool seUsheared. PU on coil. Appear to be free. Set back do 2K#. Billet holding. Estimate billet top at 10,440'. Pull out of hole. Circ at min rate. LD WS setting assy Work on BHI tools on catwalk-orientor problem MU drilling BHA (2.74" STR324 + 1.7 deg motor) RIH w/ BHA #23 Circ thru bit at min rate Continue RIH w/sidetrack BHA Log tie-in down from 10130', corr -3.5' RIH thru 3-3/16" and shoe, clean. RIH at min rate to tag at 10440'. PUH 24k, start pump 1.41/2840/30L while wiper to shoe and back to WS. Sneak up on it First MW at 10439.97' w/ 0.17k wob Time drill 0.05'/5 min and gradually incr speed. Had good drill offs to 10445.0' w/ no stalls Stacked w/ 4k wob. Had to PU several times and redrill at dill TF's to continue making hole. Get by then start making steady hole. Drill to 10454' 1.41/2850/30L w/ 2k wob and 0-100 psi dill and can start seeing NBI's Drill to 10460' while move TF to 5R. See NBI increase from 92.8 deg drilled to 94.2 deg so est 96.5 deg at bit Backream and ream at DTF, 0 deg and 60L until clean. Backream into 3-3/16" Open EDC at 10100' and circ at high rate while POOH. Hold PJSM to discuss handling the BHA. At surface. Get off well. LD BHA assembly. Pick up resistivity tool. Change motor to 1.3 deg with Hyc re-build bi-center. STab coil. Get on well. Test MWD. Run in hole. MWD or a-line has a short. Stop and trouble shoot same. Surface gear checks ok. The problem is downhole. Pull out of hole to check Inteq tools and a-line. LD BHA and located the short in the UPC and LOC Changed out wet connect RIH Tie-in at 10,130 ft to RA marker at 10,107.50 ft RIH with correct TF (30L). Lost Communication with BHA down hole Tagged bottom at 10,460 ft. Oriented TF to 90R Op = 1.58 / 1.57 bpm, CTP = 3700 psi Density = 9.98 / 9.89 ppg Vp = 277 bbl's ROP = 40 fph BHP = 5672 psi ECD = 10.88 ppg. Printed: 4/19/2007 10:20:28 AM ! • BP EXPLORATION Page 19 of 25 ~ Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Spud Date: 2/12/2007 Event Name: REENTER+COMPLETE Start: 3/19/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 4/19/2007 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours i Task Code i NPT Phase _ -~_ - 4/10/2007 19:30 - 20:09 ~ 0.65 ~ DRILL N ~ DPRB ~ PROD1 20:09 - 20:31 I 0.371 DRILL I N I DPRB I PROD1 20:31 - 20:35 0.07 DRILL N DPRB PROD1 20:35 - 21:30 0.92 DRILL N DPRB PROD1 21:30 - 21:40 I 0.171 DRILL I N I SFAL I PROD1 21:40 - 21:50 ~ 0.17 ~ DRILL ~ N ~ SFAL ~ PROD1 21:50 - 23:05 I 1.251 DRILL I N I SFAL I PROD1 23:05 - 23:58 0.88 DRILL N SFAL PROD1 23:58 - 00:00 0.03 DRILL N SFAL PROD1 4/11/2007 00:00 - 00:13 0.22 DRILL N PROD1 00:13 - 03:15 3.03 DRILL N PROD1 03:15 - 03:22 0.12 DRILL N PROD1 03:22 - 03:52 0.50 DRILL C PROD1 03:52 - 04:00 I 0.131 DRILL I N I DFAL I PROD1 04:00 - 04:24 0.40 DRILL N DFAL PROD1 04:24 - 04:33 0.15 DRILL N DFAL PROD1 04:33 - 07:00 I 2.451 DRILL I N I DFAL I PROD1 07:00 - 09:00 2.00 DRILL N DFAL PROD1 09:00 - 09:30 0.50 DRILL N DFAL PROD1 09:30 - 12:10 2.67 .DRILL N DFAL PROD1 12:10 - 14:30 2.33 DRILL N DFAL PROD1 14:30 - 14:40 0.17 DRILL N DFAL PROD1 14:40 - 15:25 0.75 DRILL N DFAL PROD1 Description of Operations Drill to 10,520 ft, ECD = 10.91 ppg and stagnant. Begin pressure drilling w/ 160 psi WHP to maintain ECD of 11.25 ppg Collect first sample from 10,500 ft and every 50 ft from there on. Wiper trip to 10,460 ft. Hole smooth. Coil wt = 21 k up. Drill ahead from 10,555 ft. 3800 psi at 1.42 in/out. 200 psi WHP. DHW06:1-1.8k#. WHP/BHP/ECD: 200/5877/11.25 ppg. IA/OA/PVT: 200/10/270 bbls. INC/AZM/TF: 94.4/359.1/1028. BOP: 2i-51 fph. Lost rig mud pump #1, switch to pump #2 and wiper trip to 10,460 ft. Hole smooth. Coil wt = 21 k up. Hold PJSM to discuss repairing the mud pump. RIH to bottom and wiper trip to 10,100 ft (-45 deg). Hole smooth. 125 bbls = MM out. Backream and ream until clean. Backream into 3-3/16". 140 bbls = MM out. Open EDC at 10,091' and circ at high rate, RIH. Mud pump has been repaired, close EDC ~ 10,140', RIH to TD w/ TF (30L). RIH to TD w/ TF (30L). Tagged bottom at 10,578 ft. Oriented TF to 908 Op = 1.52 / 1.53 bpm, CTP = 3600 psi Density = 10.05 / 9.97 ppg Vp = 267 bbl's ROP = 30 fph WHP = 200 psi BHP = 5891 psi ECD = 11.27 ppg. Wiper trip to 10,600 ft. Hole smooth. Coil wt = 22k up. Drill ahead from 10,675 ft. 3950 psi at 1.48 in/out. DHWOB: 1.2-1.8k#. WHP/BHP/ECD: 200/5902/11.31 ppg. IA/OA/PVT: 293/27/266 bbls. INC/AZM/TF: 94.4/18.99/127.88. BOP: 21-51 fph. Motor stalled, stop pumping & pick up. Appears there is a restriction in the coil. Circ press dropped but not back to normal rate. Suspect bit balling, RIH and tag bottom twice. No motor work. CTP = 3100 psi C~ .9 bpm. POH to 10,100 ft - 45 deg Trap 600 psi on well to maintain 11.25 ppg ECD and cycle Baker choke to break circulation. No luck. Open EDC POH while pumping 1.75 bpm through EDC. Surged BHA after tagging up to300 ft Hold 650 psi on well Held PJSM and Pressure undeptoy BHA with 650 psi on wellhead. Pressure undeploy BHA with 650 psi on wellhead. Motor was locked up, stator rubber in the bit and at the bottom of the motor. Cut off 120 ft CT for CT Management in Cr System Beheading BHI UOC. PT to 3500 psi (ok) Set counters, RIH with EDC open. Started mud swap while RIH at 10,000 ft Logged tie-in (-4.5 ft) RIH to 10, 350 ft pumping clean flo-pro down CT. With Flo-pro at bit, closed EDC and RIH to TD Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: i Date :From - To --_ 4/11/2007 14:40 - 15:25 15:25 - 18:30 1-39A/N-16 1-39A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 I Hours Task Code NPT Phase 1 0.75 DRILL N DFAL PROD1 3.08 DRILL N DPRB PROD1 18:30 - 19:00 I 0.501 DRILL I N C DPRB I PROD1 19:00 - 23:00 I 4.001 DRILL I N I DPRB I PROD1 23:00 - 23:26 0.43 DRILL N DPRB PROD1 23:26 - 23:50 0.40 DRILL N DPRB PROD1 23:50 - 00:00 0.17 DRILL N DPRB PROD1 4/12/2007 100:00 - 02:55 I 2.921 DRILL I N I DPRB I PROD1 02:55 - 03:48 0.88 DRILL N DPRB PROD1 03:48 - 04:24 0.60 DRILL N DPRB PROD1 04:24 - 06:20 1.93 DRILL N DPRB PROD1 06:20 - 07:30 I 1.171 DRILL I N I DPRB I PROD1 07:30 - 08:40 I 1.171 DRILL I N I DPRB I PROD1 08:40 - 10:15 I 1.581 DRILL I N I DPRB I PROD1 Page 20 of 25 ~ Spud Date: 2/12/2007 End: Description of Operations BHI off of NPT time at 15:30 hrs Tagged bottom at 10693 ft. TF at 105deg R TF Maintaining hole angle of RCH 94 deg Op = 1.47 / 147 bpm CTP 3150 psi / 3350 psi Conducting mud swap BHP = 5750 psi at 11.00 ppg EMW Increased WHP to 180 psi to keep BHP at 5,750 psi Lost 600 psi in pressure with new mud circulated around. Finished mud swap at 16:45 hrs MIDF check returns rheology properties. Wiper trip to 10,460 ft. Smooth hole, CT wt = 23k up. Replace cap seal on Mud Pump # 1 during wiper trip. Tagged bottom at 10,813 ft. Oriented TF to 90R Op = 1.53 / 1.57 bpm, CTP = 3700 psi (3260 psi free spin) Density = 10.12 / 10.03 ppg Vp = 371 bbl's ROP = 40 fph BHP = 5686 psi ECD = 11.11 ppg. Wiper trip to 10,460 ft. Smooth hole, CT wt = 23k up. Wiper back in hole to 10,961 ft. Tagged bottom at 10,961 ft. Oriented TF to 90R Op = 1.53 / 1.53 bpm, CTP = 3500 psi (3200 psi free spin) Density = 10.15 / 10.04 ppg Vp = 369 bbl's ROP = 40 fph BHP = 5835 psi ECD = 11.21 ppg. Continue to drill from 10,967 ft. Oriented TF to 90R Op = 1.53 / 1.53 bpm, CTP = 3500 psi (3200 psi free spin) Density = 10.15 ! 10.04 ppg Vp = 369 bbl's ROP = 40 - 70 fph BHP = 5835 psi ECD = 11.21 ppg. Wiper to shoe. No overpulls, smooth hole. Reduce pump rate to minimize bit wear once inside 3 3/16" liner. Pull thru shoe to log tie-in. (0.5 ft correction) Wiper back in hole to 11,110 ft. Tagged bottom at 11,110 ft. Oriented TF to 90R Op = 1.52 / 1.51 bpm, CTP = 3420 psi (3150 psi free spin) Density = 10.12 / 10.03 ppg Vp = 366 bbl's ROP = 40 fph BHP = 5846 psi ECD = 11.26 ppg. Drilling from 11,195 ft 120E TF. With ND at 9,995 ft, turn TF down to achieve 90 deg hole angle Op = 1.51 / 1.51 bpm at 3365 psi on btm BHP = 5802 psi w/ EDC at 11.17 ppg Vp = 363 bbl's ROP = 35-48 fph w/ 1.5-2.5k1b WOB Started Centifuge to clean mud Wiper trip from 11,260 ft to 10,460 ft. Clean wiper trip both in and out. Drilling from 11,260 ft 90-100R TF. Op = 1.51 / 1.51 bpm at 3,100 psi / 3,650 psi on btm. Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 21 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To Hours Task ~ Code NPT 4/12/2007 ~ 08:40 - 10:15 1.58 DRILL ~ N I DPRB 10:15 - 10:50 I 0.581 DRILL I N I DPRB 10:50 - 12:10 I 1.331 DRILL N DPRB 12:10 - 12:45 0.58 ~ DRILL N DPRB 12:45 - 14:15 ~ 1.50 ~ DRILL ~ N ~ DPRB 14:15 - 15:10 I 0.921 DRILL I N I DPRB 15:10 - 17:10 I 2.001 DRILL I N I DPRB 17:10 - 18:33 I 1.381 DRILL I N I DPRB 18:33 - 19:39 1.10 DRILL N DPRB 19:39 - 22:47 3.13 DRILL N DPRB 22:47 - 22:57 I 0.171 DRILL I N I DPRB 22:57 - 23:20 0.38 ~ DRILL N ~ DPRB Spud Date: 2/12/2007 Start: 3/19/2007 End: Rig Release: 4/19/2007 Rig Number: Phase ! Description of Operations PROD1 Increased Op to 1.70 bpm which increased the AV from 130 to 154 fpm BHP = 5,815 psi w/ EDC at 11.18 ppg WHP = 100 psi Vp = 360 bbl's ROP = 40-80 fph w/ 2.0 - 2.5k1b WOB Short wiper trip (100 ft) at 11,300 ft and 11,355 ft PROD1 Increased OP to 1.74 bpm increased the th AV from 130 to154 fpm CTP off btm inc, to 3500 psi PROD1 Wiper trip from 11,400 ft to 10,460 ft. Little WOB at 10,890 ft, but ok PROD1 Drilling from 11,400 ft at 90R to 50R TF. At 11426 ft. tumed TF to 50R to build some hole angle up to 92 degs Op = 1.72 / 1.72 bpm at 3425 psi on btm BHP = 5,802 psi w/ EDC at 11.17 ppg Density = 10.1 / 10.1 ppg at surface Vp = 363 bbl's LSRV at 35k at 12:30 hrs. Adding flovis. ROP = 40-60 fph w/ 1.5-3.0 klb WOB. PROD1 Motor stalled at 11,431 ft. PUH and restrart Res deep at 200+ ohms with GR at 21 API units Drilling at 90R to 50R TF. At 11426 ft. turned TF to 50R to build some hole angle up to 92 degs Op = i.72 / i.72 bpm at 3425 psi on btm BHP = 5,802 psi w/ EDC at 11.17 ppg Density = 10.1 / 10.1 ppg at surface Vp = 363 bbl's LSRV at 35k at 12:30 hrs. Adding flovis. ROP = 40-80 fph w/ 1.5-3.0 klb WOB. PROD1 Wiper trip from 11,545 ft to 10,800 ft and conducting mud swap using 290 bbl Clean wiper trip with maintainh constant BHP of 5800 psi PROD1 Drilling at 90R TF from 11546 ft to Op = 1.69 / 1.69 bpm at 3400 psi off btm 3600 psi on btm BHP = 5,800 psi w/ EDC at 11.17 ppg Density = 10.1 / 10.1 ppg at surface ROP = 40-60 fph w/ 3.0 klb WOB. ROP slowed down at 11,660 ft from 80 fph to 35 fph PROD1 Wiper trip to tie-in. Pull thru shoe to log tie-in. (0.5 ft correction). PROD1 Wiper back in hole to 11,677 ft. PROD1 Tagged bottom at 11,677 ft. Oriented TF to 90R Op = 1.52 / 1.52 bpm, CTP = 3280 psi (3000 psi free spin) Density = 10.06 / 9.92 ppg Vp = 406 bbl's ROP = 30 fph w/ 1.62 klb WOB BHP = 5779 psi ECD = 11.14 ppg. PROD1 ROP has dropped to -10'/hr and stacking weight. Perform a short 100ft wiper trip. Clean wiper trip both in and out. PROD1 Tagged bottom at 11,770 ft. Oriented TF to 90R Op = 1.50 / 1.50 bpm, CTP = 3280 psi (2960 psi free spin) Density = 10.05 / 9.99 ppg Vp = 404 bbl's Printed: 4/19/2007 10:20:28 AM ~~ • BP EXPLORATION Page 22 of 25 Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date .From - To Hours Task Code NPT 4/12/2007 22:57 - 23:20 0.38 DRILL N DPRB 23:20 - 00:00 0.67 DRILL N DPRB 4/13/2007 00:00 - 01:00 1.00 DRILL N DPRB 01:00 - 03:00 2.00 DRILL N DPRB 03:00 - 04:01 1.02 DRILL N DPRB 04:01 - 06:10 2.15 DRILL N DPRB 06:10 - 07:40 1.50 DRILL N DPRB 07:40 - 08:10 0.50 DRILL N DPRB 08:10 - 09:15 1.08 DRILL N DPRB 09:15 - 10:45 1.50 DRILL N DPRB 10:45 - 11:00 0.25 DRILL N DPRB 11:00 - 11:40 0.67 DRILL N DPRB 11:40 - 13:45 2.08 DRILL N DPRB 13:45 - 14:00 0.25 DRILL N DPRB 14:00 - 14:15 0.25 DRILL N DPRB 14:15 - 18:00 3.75 CASE N DPRB 18:00 - 18:15 0.25 CASE N DPRB 18:15 - 18:54 0.65 CASE N DPRB 18:54 - 20:03 1.15 CASE N DPRB Spud Date: 2/12/2007 Start: 3/19/2007 End: Rig Release: 4/19/2007 Rig Number: Phase Description of Operations PROD1 ROP = 10 fph w/ 2.62 klb WOB BHP = 5809 psi ECD = 11.20 ppg. PROD1 ROP increased significantly to 60 ft/hr from 11,775 ft to 11,790 ft. Wiper trip from 11,790 ft to 10,460 ft. Talk with Geo/DD/Town Eng to get the 'ok' to drill ahead to the end of the Polygon - 11,850 ft and also 100' beyond the end of the Polygon per MOC. PROD1 Wiper back in hole to 11,790 ft. Smooth hole both in and out, 22k up wt, 14k in wt. PROD1 Drilling from 11,790 ft 90R TF. Op = 1.50 / 1.50 bpm at 3,000 psi / 3,300 psi on btm. BHP = 5,793 psi w/ EDC at 11.18 ppg WHP = 200 psi Vp = 349 bbl's ROP = 60-70 fph w/ i.2 - 1.8k1b WOB PROD1 Resistivity fell off, decision was made to TD the well @ 11,900 ft. Drilled approx 48 ft outside Polygon. Perform MAD pass from 11,900 ft @ 280 fph to 11,000 ft (280 fph gives 2 data points per foot for data processing). Multiple and on going problems with BHI computers. Pull up to 11,600 ft and log over desired interval. Apparently 280 fph is to fast, 200 fph is desirable. PROD1 MAD pass from 11,600 ft to 11,200 ft ~ 200 fph. PROD1 PUH to 9400 ft to flush out 3-3/16" liner and to tie-in at 10130 ft PROD1 RIH surging out 3-3/16" liner. Logged tie-in and corrected +19.5 ft PROD1 RIH to confirm PTD and lay in liner pill. Pumping liner pill. Tagged bottom at 11,900 ft and saw CT weight and motor work PROD1 POOH laying in 50 bbl of liner pill with 2 ppb alpine breads. Stopped at 9400 ft and open EDC PROD1 RIH to 10.350 ft circulating at 1.8 bpm with open EDC to clean out 3-3/16" liner. PROD1 POOH to run liner At 8048 ft, pin hole in CT. SD and trapped 350 psi on wellhead. Lined out fill annulus while POOH. CoilCade shows 25-30% PROD1 POOH, filling across down annulus following pressure schedule. Closed EDC at 250 ft PUH and slowly release wellhead pressure to zero. PROD1 LD drilling BHA Stab on well to blow down CT PROD1 PJSM on N2 blow down. RU N2 Pumper, Load pipe shed with CTLRT and drift RUNPRD Cool down N2 and PT surface lines to 4000 psi. Pumping water followed by 12 bbl MEOH Blow down CT with N2. Held PJSM on pulling CT across pipe shed. Pulled same and secured the CT on the reel. RU floor to run liner RUNPRD PJSM for runing liner w/ Nordic crew, PJSM for c/o coil reels. Reel ID # 14376, 467,777 R.F., Approx 27.5 % used coil life. RUNPRD Open well, check for flow for 5 min- static, fluid level -hanger. Begin RIH w/ 2 3/8" liner & torque liner to 500 ft/Ibs using little jerk tongs. Drift first 6 joints torqued up with CS hydril joint to ensure no over torqued connections. Re-drift each joint while on skate before picking up. RUNPRD Fill up first 6 joints with mud to ensure proper hole fill & start Printed: 4/19/2007 10:20:28 AM o ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-39A/N-16 1-39A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Date ~ From - To i Hours ~ Task ~ Code NPT ( Phase 4/13/2007 18:54 - 20:03 1.15 CASE N DPRB RUNPRD 20:03 - 20:23 0.33 CASE N DPRB RUNPRD 20:23 - 00:00 3.62 CASE N DPRB RUNPRD 4/14/2007 00:00 - 00:30 0.50 CASE P RUNPRD 00:30 - 01:00 0.50 CASE P RUNPRD 01:00 - 01:15 0.25 CASE P RUNPRD 01:15 - 02:30 1.25 CASE P RUNPRD 02:30 - 03:15 0.75 CASE P RUNPRD 03:15 - 03:29 0.23 CASE P RUNPRD 03:29 - 04:12 0.72 CASE P RUNPRD 04:12 - 05:00 0.80 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 05:40 0.17 CASE P 05:40 - 05:51 0.18 CASE P 05:51 - 06:45 0.90 CASE P 06:45 - 09:20 2.58 CASE P 09:20 - 13:00 3.67 CASE P 13:00 - 13:31 0.52 CASE P 13:31 - 13:50 13:50 - 15:15 0.321 CEMT I P 1.421 CEMT I P 15:15 - 17:40 2.42 CEMT P 17:40 - 18:30 0.83 CEMT P 18:30 - 20:30 2.00 EVAL P 20:30 - 20:56 0.43 EVAL P RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD LOW ER1 LOW ER1 Page 23 of 25 Spud Date: 2/12/2007 End: Description of Operations trip sheet. VP's = 376 bbls. Continue making up 2 3/8" liner. Fill up first 40 joints of 2 3/8" liner. VP's = 377 bbls. VP's = 376 bbls. Continue RIH w/ 2 3/8" liner. Continue RIH w/ 2 3/8" liner. Fill 2 3/8' liner & flow check. VP's = 377. Held PJSM & THA prior to stabbing 2" coil into injector. Stab 2" coil. Make up BOT CTC & pull test to 30k, make up dart catcher. Pump 5 bbls of 60/40 methanol & load dart into coil. Launch dart with 6 bbls of water followed by flo pro. Had minor difficulties with inner reel hardline. Dart landed. Coil volume is 40.60 bbls. Bleed off coil & check dart catcher -recovered dart. Make up dart catcher. Load dart into reel. Pump dart through reel. Dart landed. Coil volume is 40.60 bbls Bleed off coil & check dart catcher -recovered dart. Pressure test BOT coil connector & hardline to reel. Low P.T. to 250 psi High P.T. to 3500 psi. No leaks. Bleed off pressure. RU and install BOT's CTLRT and deployment sleeve & stab onto liner and onto well. Tagged up, set counter to 2,513.95 ft, RIH at 0.48 / 0.79 bpm at 84 fph. RIH and tagged TD at 11,900 ft. Hole was as clean as it can get. Dropped 5/8" ball and released from liner at 4100 psi using 32.01 bbl's. PU and released from liner. Displaced wellbore to 10.00 ppg brine. Circulate well to 10.00 ppg brine at 1.60 bpm Vp = 180 bbl's Mixing up 30 bbl of 2 ppb biozan in 10.00 ppg brine Held PJSM, review the SOP for cementing liners presented by Schlumberger. Review all hazards and mitigated same Batch mix up 15 bbl of Class "G" Cement Yield = 1.17cf/sxs, 5.219 gal/sxs, at density at 13:48 hrs. Pumped Bio to reel, SD, Switch to cementers and purred 3 bbl fresh water, SD and PT surface lines to 4000 psi. Pumped 2 bbl of fresh water followed by 10 bbl of 15.8 ppg Class "G" Cement and 5 bbl water. SD, dropped dart and lanched same with 500 psi. SLB pumped 5 bbl water. SD and switched to the rig pumping 30 bbl's 10 ppg Bio Brine. CT Dart latched up at 40.6 bbl's and LW P landed at 50.2 bbl's. (All calculated values). SD and checked floats, OK. POOH replacing CT volume. The last 3 bbl of cement pumped up the backside, show evidence of hydration due to perm. /pros. of the formation. Circulated 10 bbl up the annulus POOH replacing CT voidage. Closed SV Crew change, PJSM on PU 84 jts 1"CSH, Review EMS info & Endicott emergency contact numbers. Pick up BOT 1.87 DSM & 1 11/16" motor. Locktite and torque all MT threads to spec - 500 ft/Ibs. Drift all & P/U 84 jts of 1" CSH and torque to spec - 500 fUlbs. Stab 2" coif to BHA & stab onto well. Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Page 24 of 25 ~ Operations Summary Report Legal Well Name: 1-39A/N-16 Common Well Name: 1-39A/N-16 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Spud Date: 2/12/2007 End: Date From - To ~ Hours i Task Code ~ NPT 4/14/2007 ~ 20:56 - 00:00 3.07 ~ EVAL P 4/15/2007 ~ 00:00 - 01:49 ( 1.82 ~ EVAL ~ P 01:49 - 02:00 ~ 0.181 EVAL ~ P 02:00 - 02:20 I 0.331 EVAL I P 02:20 - 03:17 0.95 EVAL P 03:17 - 03:21 0.07 EVAL P 03:21 - 03:26 0.08 EVAL P 03:26 - 04:23 0.95 EVAL P 04:23 - 05:00 I 0.62 I EVAL I P 05:00 - 06:20 I 1.331 EVAL I P 06:20 - 06:35 0.25 EVAL P 06:35 - 08:45 2.17 EVAL P 08:45 - 09:30 0.75 EVAL P 09:30 - 11:40 2.17 EVAL P 11:40 - 13:15 1.58 EVAL P 13:15 - 14:55 1.67 EVAL P 14:55 - 18:00 3.08 ~ EVAL P 18:00 - 18:45 0.751 EVAL P 18:45 - 21:00 2.25 EVAL P 21:00 ,- 21:15 0.25 EVAL P 21:15 - 22:56 1.681 EVAL ~ P Phase f Description of Operations LOWERI Set counters to 2618.7 ft, break circulation &RIH w/ cleant out BHA. SLB lab informed us that the cement has a 500 psi compressive strength ~ 23:50 & is building 200 psi per hr. LOW ER1 Continue RIH w/ cleanout BHA & pumping min rate. Swap to Bio pill while RIH ~ 6818 ft. LOW ER1 Compressive strength of cement = 900 lbs. Wt ck. 18.5k up, 13k down. Continue RIH. LOWERI Increase pump rate to 1.00 bpm before entering top of 2 3/8" liner. Op = 1.02 / 1.14 bpm, CTP = 3200 psi Density = 10.00 / 9.92 ppg Vp = 271 bbl's ROP = 30 fpm LOWERI CT depth is 10,000 ft &Bio is at bit. Continue RIH @ 30fpm to TD. Swap to 10.0 brine ~ 51.0 bbls away, all bio has been pumped down hole. LOWERI Wt ck ~ 11,800 ft, 22k up & 13.5 down. Continue RIH to TD. LOWERI Tag bottom twice @ 11,884.4 ft -solid tag, (75 psi motor work). LOWERI POH to top of liner. Divert & neutralize cement returns ~ 100 bbls returned (volume to top of liner w/ coil in hole). LOWERI Drop 1/2" ball to open circ sub & keep coil slowly moving in hole. Circ sub opened ~ 3800 psi. LOW ER1 POH to surface jetting GLM & jewelry @ 1.3 bbls/min ~ 3700psi. LOWERI Tagged up. Held PJSM on handling 1"CSH LOWERI POOH standing back 42 std 1" CSH LOWERI PJSM on RA Material handling and PU RIH with 1"CSH tubing LOWERI RIH with MCNL and 84 jts (42 stds) of 1" CSH. PU Injector with top BHA and stab on to well Talked with AOGCC and they wavered the bi-monthly BOP test due to status of the well. LOWERI Set counters with SLB Loggers. RIH and confirming depths with SLB logger LOWERI Wt check = 20.5k1bf Start logging down at 30 fpm from 9200 ft to 11,884.3ft PUH logging at 60 fpm and laying in pert pill. LOWERI POOH with logging tools Gave Nordic 2 rig tour to the DNV Junket from Houston, Texas LOWERI Flow check. PJSM &THA prior to standing back 1"CSH in derrick. Review EMS standard & information w/ Nordic &SLB crew. LOWERI POOH standing CSH in the derrick LOW ER1 Flow check while PJSM &THA prior to handling Radioactive source @ surface. LOW ER1 Ensure hole is full, close blinds. Pressure test Liner to 2000 psi using rig test pump via the kill line, chart & hold for 30 min. Cement = 2500 psi compressive strength. Time WHP IAP OAP Onset 0 20 5 0 2125 85 5 15 2091 89 5 Chart has flatlined, start test. 30 2091 89 5 45 2086 89 5 Clock on chart stopped, wind clock Printed: 4/19/2007 10:20:28 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 4/15/2007 ~ 21:15 - 22:56 1-39A/N-16 1-39A/N-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours I Task Code I NPT I Phase - -_ ~__ -~ 1.681 EVAL P ~LOWERI 22:56 - 23:15 0.32 PERFO P LOWERI 23:15 - 00:00 0.75 PERFO P LOWERI 4/16/2007 00:00 - 02:00 2.00 PERFO P LOWERI 02:00 - 02:20 0.33 PERFO P LOWERI 02:20 - 04:47 2.45 PERFO P LOW ER1 04:47 - 05:00 0.22 PERFO P LOWERI 05:00 - 05:21 I 0.35 I PERFOB P 05:21 - 05:51 0.50 PERFO P 05:51 - 06:10 0.32 PERFO P 06:10 - 08:15 2.08 PERFO P 08:15 - 11:30 3.25 PERFO P LOW ER1 LOW ER1 LOW ER1 LOW ER1 LOW ER1 11:30 - 12:00 ~ 0.50 PERFO~ P I LOWERI 12:00 - 13:00 1.00 PERFO P LOWERI 13:00 - 13:30 0.50 WHSUR P POST 13:30 - 14:30 ~ 1.00 WHSUR P POST 14:30 - 14:55 0.42 WHSUR P POST 14:55 - 16:45 1.83 WHSUR P POST 16:45 - 17:00 0.25 WHSUR P POST 17:00 - 18:00 1.00 DEMOB P POST 18:00 - 18:15 0.25 DEMOB P POST 18:15 - 21:30 fl 3.25 DEMOB P POST 21:30 - 00:00 2.50 DEMOB P POST 4/17/2007 00:00 - 00:15 0.25 DEMOB P POST 00:15 - 04:45 4.50 DEMOB P POST 04:45 - 05:00 0.25 DEMOB P POST 05:00 - 09:00 4.00 DEMOB P POST Page 25 of 25 Spud Date: 2/12/2007 End: Description of Operations 60 2079 92 5 75 2075 92 5 90 2074 93 5 Both SLB & Nordic charts have held for 30 min & are flatlined. Bleed off pressure. PJSM &THA prior to handling pert guns. Pick up 10 pert guns & 78 jts of 1"CSH. Finished picking up Perf BHA. Pick up injector, make upto BHA & stab injector onto well. Bump up, set counters to 2638.84' &RIH w/ pert BHA. Tag bottom twice ~ 11,880' (3k down), 17.7k RIH wt & 26k up wt. Pick coil upto break over point & set counters to 11,883' per Butch Gumminger (PBTD from SLB MCNL log). Pick upto 11648.7' (0.7' for bullnose on end of guns). Park coil ~ perf interval (11,448' to 11,648'). Swap to pert pill & pump down coil to verify circulation. 1.19 bbl/m @ 3611 psi for 10 bbls. Drop 1/2" steel ball with 10 bbls of pert pill followed by 10.0 ppg brine to activate firing head. 30 bbls away, reduce rate to 0.5 bbls/min. Ball tagged 35.7 bbl. Perforated at 3,600 psi using drive-by technique. POOH with pert guns Checked flow at top of liner (OK) POOH RIH with 3 stds CSH and POOH laying down 1" CSH above guns PJSM on handling pert guns LD Perf guns, guns fired as designed RU nozzle BHA and tried to inject fluid into wellbore. WHP = 800 psi.(flatlined) RIH to 800 ft to FP the wellbore Pump 18 bbl of diesel POOH laying in diesel freeze protection from 800 ft OOH, close swab valve. Pump SLB Pickle fluids for stacking coiled tubing N2 blow down on coiled tubing Installed BPV closed MV and SV and installing CIW wellhead control lines PU injector and make ready to RD for derrick down move PJSM &THA for unstabbing coil, cleaning pits & UD lubricator. Unstab 2" coil & dropped reel. Completed cleaning pits. Vac out cuttings box & T.T. UD 4 1/2" wireline lubricator & equipment. UD little jerk tongs. Blowed down & disconnected T.T. line from rig. PJSM &THA prior to riging down riser & B.O.P.'s UD 7" 5' lubricator. Unbolt drip pan from underside of rig floor.Pull upper & lower mouse hole. Dissconnect Kill & Choke lines & BOP Hyd lines. N/D B.O.P.'s. Secure stack for rig move. N/U tree cap and pressure test. Move off well. Lay down derrick & move to DS 04-01. Rig released @ 09:00 on 4-17-07 All future DIMS information will be on next well. DS 04-01. Start: 3/19/2007 Rig Release: 4/19/2007 Rig Number: Printed: 4/19/2007 10:20:28 AM .. Date: 4/19/2007 Time: 08:40:00 Page: 1 Co-ordinate(1VE) Reference: Well: 1-39/P-17, True North Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55.1 Section (VS) Reference: Well (O.OON,O.OOE,0.99Azi) Survey Calculation Method: Minimum Curvature Db: Oracle North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 3 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datmn: Mean Sea Level Geomagnetic Model: hggm2006 i • by BP Alaska Baker Hughes INTEQ Survey Report ~.^ ~. u~ a a~a{ Company: ___ BP Amoco Field: Endicott Site: End MPI li Well: 1-39/P-17 Wellpath: ~__ -- 1-39A/N-16 Field: Endicott Site: End MPI TR-12-16 UNITED STATES :North Slope Site Position: Northing: 5979337.49 ft Latitude: 70 20 38.358 N From: Map Fasting: 256681.13 ft Longitude: 147 58 30.505 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -1.86 deg Well: 1-39/P-17 Slot Name: 39 1-39/P-17 Well Position: +N/S 3040.87 ft Northing: 5982302.79 ft Latitude: 70 21 8.262 N +F1-W 2275.64 ft Fasting : 259054.20 ft Longitude: 147 57 23.994 W Position Uncertainty: 0.00 ft Wellpath: 1-39A/N-16 Drilled From: 1-39A/PBi Tie-oa Depth: 10430.28 ft Current Datum: 52:39 6/1 8/1 988 00:00 Height 55.10 ft Above System Datum: Mean Sea Level Magnetic Data: 4/9/2007 Declination: 24.36 deg Field Strength: 57693 nT Mag Dip Angle: 81.05 deg Vertical Section: Depth From (TVD) +N/S +F/-W Direction ft ft ft deg 40.60 0.00 0.00 0.99 Survey Program for Defhtitive Wellpath Date: 4/9/2007 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 94.00 10000.00 1 : Speny-Sun BOSS gyro multi 10097.50 10430.28 MWD (10097.50-11656.00) (1) 10440.00 11900.00 MWD (10440.00-11900.00) Annotation MD TVD ft ft 10430.28 10112.13 Tie to 0l-39A/N-i6P61 10440.00 10111.78 KOP BOSS-GYRO Sperry-Sun BOSS gyro multishot MWD MWD -Standard MWD MWD -Standard Snrvey - -----_ MD Incl Aum TVD Sys TVD ft deg deg ft ft 10430.28 92.37 355.85 10112.13 10057.03 10440.00 91.77 357.60 10111.78 10056.68 10470.52 96.67 353.87 10109.53 10054.43 10499.98 95.47 359.08 10106.42 10051.32 10548.29 93.78 7.58 10102.51 10047.41 10576.90 93.69 12.40 10100.65 10045.55 10609.31 95.17 18.99 10098.14 10043.04 10642.99 94.80 24.70 10095.21 10040.11 10670.20 93.93 29.54 10093.14 10038.04 10697.45 93.26 34.92 10091.43 10036.33 10730.90 94.21 40.56 10089.25 10034.15 N/S E!W ft ft 741.19 - ~-923.27 750.89 -923.83 781.23 -926.08 810.46 -927.88 858.48 -925.09 886.59 -920.13 917.68 -911.40 948.81 -898.92 972.95 -886.56 995.95 -872.06 1022.33 -851.63 MapN MapE ft ft - - - __ 5983073.26 258155.27 5983082.97 258155.03 5983113.37 258153.75 5983142.64 258152.89 5983190.54 258157.23 5983218.48 258163.09 5983249.27 258172.81 5983279.98 258186.29 5983303.71 258199.42 5983326.23 258214.65 5983351.94 258235.91 VS DLS _--- Tool ft deg/100ft 725.11 0.00 MW D 734.80 19.02 MWD 765.09 20.16 MW D 794.29 18.05 MWD 842.35 17.88 MWD 870.54 16.81 MWD 901.78 20.78 MWD 933.12 16.93 MW D 957.47 18.02 MW D 980.71 19.86 MW D 1007.45 17.06 MWD Survey: MWD Start Date: 4/11 /2007 Company: Baker Hughes INTEO Engineer: Tool: MW D;MW D -Standard Tied-to: From: Definitive Path ~~~-~~~ • ~ BP Alaska. t bP Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco FSeld: Endicott Site: End MPI Well: 1-39/P-17 Wetlpath: 1-39A/N-16 Date: 4/19/2007 Time: 08:40:00 Page: Co-ordinxte(NE) Reference: Well: 1-39/P-17, True North Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55.1 Section (VS) Reference: Well (O.OON,O.OOE,0.99Azi) Survey Calculation Method: Minimum Curvature Db: 2 racle Survey MD Incl A~ro TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100tt 10760.53 93.91 45.66 10087.15 10032.05 1043.90 -831.44 5983372.85 258256.79 1029.36 17.20 MWD 10790.04 93.72 50.62 10085.19 10030.09 1063.54 -809.52 5983391.78 258279.33 1049.38 16.78 MWD 10819.40 93.78 55.87 10083.27 10028.17 1081.07 -786.06 5983408.54 258303.34 1067.31 17.84 MWD 10853.78 92.83 61.79 10081.28 10026.18 1098.83 -756.70 5983425.34 258333.25 1085.57 17.41 MWD 10888.09 94.79 68.22 10079.00 10023.90 1113.28 -725.69 5983438.80 258364.71 1100.57 19.55 MWD 10925.95 94.83 74.62 10075.82 10020.72 1125.30 -689.95 5983449.65 258400.82 1113.20 16.85 MWD 10962.47 95.57 81.24 10072.51 10017.41 1132.90 -654.40 5983456.11 258436.59 1121.41 18.17 MWD 10992.67 95.48 87.52 10069.60 10014.50 1135.84 -624.50 5983458.09 258466.57 1124.87 20.70 MWD 11038.35 95.35 95.17 10065.28 10010.18 1134.78 -579.08 5983455.56 258511.94 1124.59 16.67 MWD 11068.09 94.64 100.56 10062.69 10007.59 1130.72 -549.74 5983450.57 258541.13 1121.04 18.21 MWD 11098.42 95.14 105.32 10060.10 10005.00 1123.96 -520.29 5983442.86 258570.34 1114.79 15.72 MWD 11128.42 95.02 105.95 10057.45 10002.35 1115.90 -491.52 5983433.88 258598.54 1107.24 2.13 MWD 11160.43 94.98 100.58 10054.65 9999.55 1108.59 -460.49 5983425.58 258629.61 1100.46 16.71 MWD 11192.65 93.99 94.71 10052.13 9997.03 1104.32 -428.67 5983420.28 258661.28 1096.74 18.42 MWD 11222.95 92.88 89.66 10050.32 9995.22 1103.17 -398.46 5983418.16 258691.44 1096.11 17.04 MWD 11259.41 90.18 84.03 10049.34 9994.24 1105.17 -362.08 5983419.00 258727.86 1098.75 17.12 MWD 11290.55 90.06 88.51 10049.28 9994.18 1107.20 -331.02 5983420.02 258758.97 1101.31 14.39 MW D 11320.74 90.18 94.35 10049.21 9994.11 1106.45 -300.85 5983418.30 258789.10 1101.08 19.35 MWD 11350.52 91.35 100.09 10048.82 9993.72 1102.71 -271.32 5983413.61 258818.49 1097.85 19.67 MW D 11381.70 90.18 106.16 10048.40 9993.30 1095.63 -240.97 5983405.56 258848.59 1091.30 19.82 MW D 11410.90 90.68 111.37 10048.18 9993.08 1086.24 -213.34 5983395.29 258875.91 1082.39 17.92 MW D 11442.48 92.64 118.26 10047.26 9992.16 1073.00 -184.70 5983381.14 258904.11 1069.65 22.67 MW D 11471.37 91.23 122.56 10046.29 9991.19 1058.39 -159.81 5983365.73 258928.52 1055.47 15.66 MWD 11500.59 91.66 127.16 10045.55 9990.45 1041.70 -135.85 5983348.28 258951.93 1039.19 15.81 MWD 11530.44 90.55 131.51 10044.97 9989.87 1022.79 -112.77 5983328.64 258974.38 1020.68 15.04 MWD 11556.66 90.25 135.25 10044.79 9989.69 1004.78 -93.72 5983310.03 258992.85 1003.01 14.31 MWD 11581.56 91.47 138.45 10044.42 9989.32 986.62 -76.69 5983291.33 259009.28 985.14 13.75 MWD 11612.19 90.03 142.84 10044.02 9988.92 962.94 -57.27 5983267.04 259027.92 961.81 15.08 MW D 11646.10 91.57 147.56 10043.54 9988.44 935.11 -37.93 5983238.60 259046.36 934.31 14.64 MWD 11687.83 91.91 154.69 10042.27 9987.17 898.61 -17.80 5983201.47 259065.31 898.17 17.10 MWD 11722.20 89.72 158.87 10041.78 9986.68 867.03 -4.25 5983169.48 259077.83 866.83 13.73 MWD 11766.70 88.89 167.51 10042.33 9987.23 824.48 8.60 5983126.54 259089.31 824.51 19.50 MWD 11799.34 89.45 172.73 10042.80 9987.70 792.34 14.20 5983094.23 259093.87 792.47 16.08 MWD 11834.38 91.07 178.87 10042.64 9987.54 757.41 16.76 5983059.24 259095.31 757.59 18.12 MW D 11863.27 91.38 183.56 10042.02 9986.92 728.54 16.15 5983030.41 259093.77 728.71 16.27 MW D 11900.00 91.77 189.52 10041.01 9985.91 692.08 11.97 5982994.10 259088.42 692.18 16.26 MW D • by BP Alaska Baker Hughes INTEQ Survey Report ~~~ ~s INTEQ Company: - - -- - - __ _ BP Amoco - _ __ - Date: 4/19/2007 _ - - - - Time 08:38:49 Page: 1 Field: Endicott Co-ordinate(NE) Reference: I Well: 1-39/P-17, True North Site: End MPI Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55.1 Well: 1-39/P-17 Section(VS)Reference: Well (O.OON,O.OOE,4.51Azi) Wellpath: L- 1-39A/PBi - - Survey Calculation Method: - __ -_ ___ _ - - Minimum Curvature Db: Oracle - -- __ _ - _ _-_ j Field: Endicott North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 3 ' Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: hggm2006 ~ Site: End MPI ' TR-12-16 j UNITED STATES :North Slope Site Position: Northing: 5979337.49 ft Latitude: 70 20 38.358 N From: Map Fasting: 256681.13 ft Longitude: 147.58 30.505 W Position Uncertainty: 0.00 ft North Reference: True ' Ground Level: 0.00 ft Grid Convergence: -1.86 deg j Well: 1-39/P-17 Slot Name: 39 1-39/P-17 Well Position; +N/-S 3040.87 ft Northing: 5982302.79 ft Latitude: 70 21 8.262 N +F/-W 2275.64 ft Fasting : 259054.20 ft Longitude: 147 57 23.994 W Position Uncertainty: 0.00 ft Wellpath: 1-39A/PBi Drilled From: 1-39/P-17 Tie-on Depth: 10000.00 ft Current Datum: 52:39 6/18/1988 00:00 Height 55.10 ft Above System Datum: Mean Sea level Magnetic Data: 12/15/2006 Declination: 24.50 deg Field Strength: 57689 nT Mag Dip Angle: 81.05 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ft ft ft deg 40.60 0.00 0.00 4.51 Survey Program for Definitive Wellpath Date: 3/27/2007 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 94.00 10000.00 1 : Speny-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro mukishot 10097.50 11656.00 MW D (10097.50-11656.00) MW D MW D -Standard Annotation MD TVD ft ft 10000.00 9866.83 TIP 10097.50 9962.03 KOP 11656.00 10065.96 TD Survey: MW D Start Date: 3/30/2007 Company: Baker Hughes INTEQ Engineer: Tool: MW D;MW D -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N/S E/W iViapN 11lapE ft deg deg ft ft ft ft ft ft 10000.00 12.65 320.50 9866.83 9811.73 503.57 -789.62 5982831.48 258281.21 10097.50 12.26 321.86 9962.03 9906.93 519.95 -802.81 5982848.27 258268.56 10123.03 17.34 320.78 9986.71 9931.61 525.04 -806.89 5982853.48 258264.64 10158.09 30.61 320.16 10018.67 9963.57 535.99 -815.95 5982864.72 258255.93 10187.31 39.89 319.89 10042.51 9987.41 548.89 -826.78 5982877.97 258245.53 10216.27 47.23 312.50 10063.49 10008.39 563.20 -840.63 5982892.72 258232.15 10243.28 52.67 323.35 10080.90 10025.80 578.56 -854.38 5982908.50 258218.90 10278.32 64.61 326.93 10099.10 10044.00 603.09 -871.40 5982933.57 258202.68 10305.74 73.49 329.65 10108.90 10053.80 624.86 -884.83 5982955.76 258189.95 10337.51 82.46 335.96 10115.52 10060.42 652.47 -898.98 5982983.81 258176.70 10363.32 91.07 339.07 10116.97 10061.87 676.25 -908.82 5983007.90 258167.63 VS DLS Tool ft deg/100ft , 439.99 0.00 - _ MW D 455.28 0.50 MW D 460.03 19.93 MWD 470.23 37.86 MWD 482.25 31.76 MW D 495.43 30.81 MW D 509.65 36.71 MWD 532.77 35.17 MWD 553.42 33.68 MWD 579.83 34.26 MWD 602.77 35.46 MW D ~p~- ~~ ~ • by BP Alaska Baker Hughes INTEQ Survey Report TE uv Q Company: BP Amoco Date: 4/19/2007 Time: 08:38:49 Page: 2 Field: Endicott Co-ordinate(NE) Reference: Well: 1-39/P-17, True North Site: End MPI Vertical (TVD) Reference: 52:39 6/1 8/1988 00:00 55.1 Well: 1-39/P-17 Sectio n(VS)Reference: Well (O.OON,O.OOE,4.51Azi) ~_ Wellpath: 1-39A/P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Atim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ', ft deg deg ft ft ft ft ft ft ft deg/100ft I 10394.62 96.52 346.91 10114.90 10059.80 706.08 -917.96 5983038.00 258159 46 631.79 30.45 MW D 10430.28 92.37 355.85 10112.13 10057.03 741.19 -923.27 5983073.26 258155.27 666.37 27.57 MWD 10457.19 90.71 0.68 10111.41 10056.31 768.07 -924.08 5983100.15 258155.33 693.10 18.97 MWD 10487.71 89.51 6.02 10111.35 10056.25 798.53 -922.30 5983130.53 258158.09 723.61 17.93 MWD 10515.75 90.74 12.97 10111.29 10056.19 826.17 -917.68 5983158.01 258163.60 751.52 25.17 MWD 10545.72 88.68 20.72 10111.44 10056.34 854.83 -909.00 5983186.37 258173.19 780.78 26.76 MWD 10575.83 90.00 27.54 10111.79 10056.69 882.29 -896.70 5983213.42 258186.37 809.12 23.07 MWD 10605.56 91.50 33.98 10111.40 10056.30 907.82 -881.51 5983238.45 258202.38 835.76 22.24 MW D 10637.09 91.29 42.55 10110.63 10055.53 932.54 -862.00 5983262.54 258222.66 861.94 27.18 MWD 10664.39 93.23 49.53 10109.55 10054.45 951.47 -842.38 5983280.82 258242.88 882.35 26.52 MWD 10704.10 96.15 60.49 10106.29 10051.19 974.13 -810.02 5983302.43 258275.96 907.49 28.47 MWD 10733.95 92.21 65.17 10104.12 10049.02 987.72 -783.54 5983315.16 258302.85 923.11 20.46 MWD 10759.53 91.01 68.23 10103.40 10048.30 997.83 -760.06 5983324.51 258326.65 935.04 12.84 MWD 10790.60 89.36 72.75 10103.30 10048.20 1008.20 -730.78 5983333.93 258356.24 947.68 15.49 MWD 10821.30 90.12 77.57 10103.44 10048.34 1016.06 -701.12 5983340.84 258386.15 957.84 15.89 MWD 10850.50 92.06 80.68 10102.88 10047.78 1021.57 -672.45 5983345.42 258414.97 965.59 12.55 MWD 10880.79 96.31 78.62 10100.67 10045.57 1026.99 -642.74 5983349.88 258444.84 973.33 15.58 MWD 10910.34 98.07 74.55 10096.97 10041.87 1033.79 -614.23 5983355.76 258473.55 982.34 14.91 MWD 10941.96 99.15 70.71 10092.24 10037.14 1043.12 -584.40 5983364.13 258503.67 993.99 12.48 MW D 10970.31 98.41 74.51 10087.91 10032.81 1051.49 -557.67 5983371.63 258530.66 1004.43 13.50 MW D 11000.64 99.52 79.94 10083.18 10028.08 1058.12 -528.46 5983377.32 . 258560.06 1013.33 18.06 MW D 11033.56 97.26 83.22 10078.37 10023.27 1062.88 -496.25 5983381.04 258592.41 1020.61 12.01 MWD 11060.90 96.43 87.55 10075.11 10020.01 1065.06 -469.20 5983382.35 258619.51 1024.91 16.01 MW D 11090.42 95.72 91.66 10071.99 10016.89 1065.27 -439.85 5983381.61 258648.85 1027.42 14.05 MW D 11120.83 94.70 95.65 10069.22 10014.12 1063.34 -409.64 5983378.71 258678.99 1027.87 13.49 MW D 11150.53 94.95 100.00 10066.73 10011.63 1059.31 -380.32 5983373.74 258708.15 1026.16 14.62 MW D 11185.12 93.28 105.69 10064.24 10009.14 1051.64 -346.70 5983365.00 258741.51 1021.15 17.10 MW D 11223.10 97.61 106.41 10060.64 10005.54 1041.19 -310.38 5983353.38 258777.48 1013.59 11.56 MW D 11252.68 96.24 104.70 10057.07 10001.97 1033.32 -282.09 5983344.61 258805.50 1007.96 7.37 MW D 11281.82 97.63 100.21 10053.55 9998.45 1027.08 -253.85 5983337.46 258833.52 1003.96 16.02 MW D 11311.34 96.83 97.79 10049.84 9994.74 1022.50 -224.93 5983331.95 258862.28 1001.67 8.57 MW D 11340.65 96.55 100.72 10046.42 9991.32 1017.82 -196.20 5983326.35 258890.84 999.26 9.97 MW D 11373.12 95.22 104.01 10043.09 9987.99 1010.90 -164.66 5983318.43 258922.14 994.84 10.88 MW D 11422.90 100.10 109.36 10036.45 9981.35 996.76 -117.43 5983302.77 258968.89 984.45 14.47 MW D 11451.60 92.83 110.19 10033.22 9978.12 987.11 -90.61 5983292.27 258995.39 976.94 25.49 MW D 11487.44 85.94 113.68 10033.61 9978.51 973.74 -57.39 5983277.83 259028.16 966.22 21.55 MWD 11534.17 80.38 121.97 10039.18 9984.08 952.12 -16.40 5983254.92 259068.43 947.89 21.25 MW D 11563.29 76.68 127.38 10044.97 9989.87 935.91 7.06 5983237.95 259091.35 933.57 22.20 MWD 11606.89 77.57 136.41 10054.71 9999.61 907.55 38.66 5983208.60 259122.02 907.78 20.29 MW D 11656.00 76.00 146.00 10065.96 10010.86 870.35 68.58 5983170.45 259150.73 873.04 19.28 MW D RT. ELEV =55. '~_ ~ BF. ELEV =16. MAX. DEV. = 19:06 7394' MD NT80-CYFE, BTRS. CSG 2504' NT80S XO TO 8357' NT95HS OP OF 9487' 7" LINER 9-5/8", 47#/ft, 9730' NT95HS, PERFORATION SUMMARY REF: LOG DLL- C~2 (7- 2- 88) CO. SIZE SPF INTERVAL G 2" 4 10200'-1021 ' 10 - 10260' ' 0302' - 10320' AWS 2-1/8 4 ' - 10070' 10115' - 45' 114/6' -11646' 2-7/8" WLEG 10, 300' I PBTD 10635' 7" - 29 #/ft, SM-110, 10716' BTRS-TKC DATE REV BY COMMENTS DATE REV BY COMMENT-S 10/25/88 JLH CORRECTED API NO 10/16/95 RAC ADPBZFS 03/29/96 RAC ADP6~FS 01/23/99 DB ELMDWLEG 01/03/06 DAV/P GLV C/O ,r3-3116" Liner 2-318" Liner -` -_t~ 10,400' MD cr 11,900' MD ._. ~ - -~ .. -- 7" OTIS "W D" PKR 10, 282' W/ 2-7/8" 'X' NIPPLES (2.313" MIN. ID) BVDICOTT UNIT WELL: 1-39 / R17 P02MfT No: ?? API No: 50-029-21827-00 SEC T N R E BP Exploration (Alaska) TREE: 4- 1/ 1~ 5000 psi / Nt;EVCN _LHEAD: 13- / 5000 psi / Wt;EVCN ' SSSV LANDING NIPPLE 1508 ID) Halliburton HXO SVLN {3 813" MIN . . 4-1f2", 12.6#Ift, 13Cr-80. Vam Top Tubing GAS LIFT MANDRELS (CACO-F03C,) ST MD TVD VLV LAT PORT DATE 5 3506 3449 4 6509 5452 3 7005 6943 2 $074 7861 1 9091 8933 4-1f2" "X° Nipple @ 9.320' 9-5J8" PACKER cz 9,351' ~ 2-3t8" Liner Top @ 9,395' 3-3116" Liner Top c(~x7 9,450' 4-112" "X" NIPPLE ~ 9,626` ~\ _ 4-1i2'" WLEG @ 9,650' ~\ . ~~~:~._,„...--Baker Whipsiack 10.098° MD i qqv~ ~T~~vv~~11 -r~~tt~~~~ ®~i ~~~+ A7 ~L~s7il~~~ii®1~ ~® ~s7~®1~ Greg Sarber CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, END 1-39A/ N-16 BP Exploration (Alaska) Inc. Permit No: 206-187 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 2113' FNL, 2147' FSL, SEC. 36, T12N, R16E, UM Bottomhole Location: 1304' FNL, 2154' FEL, SEC. 36, T12N, R16E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is .contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska) Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Co fission to witness any required test, contact the Commission's petroleum field ins cto at (907) 659-3607 (pager). DATED this~day of January, 2007 SARAH PALIAI, GOVERAIOR cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ,~~~ ' ~ ~ ALAS~IL AND GAS CONSERVATION COMMISJ'E"~N ~~ ~~ PERMIT TO DRILL 20 AAC 25.005 ~~~I~~~ ~ ~.~ ~~~ ~ ~ zd06 '~aas~a C~t ~C Gas Cans. Cofnfnissinn 1 a. Type of work ^ Drill °'® Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ MuRiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propose or: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. r 5. Bond: ®Blanket ^ Single Well Bond No. 6194193/ 11. Well Name and Number: END 1-39AIN-16 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11600 TVD 10069 12. Field /Pool(s): Endicott Field / Endicott Pool 4a. Location of Well (Governmental Section): Surface: 2113' FNL 2147 FSL SEC T12N R16E 36 UM ~ 7. Property Designation: ADL 034633 , , , . , , Top of Productive Horizon: 1624' FNL, 2923' FEL, SEC. 36, T12N, R16E, UM/ 8. Land Use Permit: 13. Approximate Spud Date: March 1, 2007 Total Depth: 1304' FNL, 2154' FEL, SEC. 36, T12N, R16E, um ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 7210' %1b. Location of Well (State Base Plane Coordinates): Surface: x-259055 y-5982302 Zone-ASP3 10. KB Elevation (Height above GL): 55.10 feet 15. Distance to Nearest well within Pool: 600' 16. Deviated Wells: Kickoff Depth: 10130 feet Maximum Hole An le: 94.23 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4369 Surface: 3369 18. Casin Pr .ram: S if ` n To - S ttin h - 60 om uanti of Ce ent c.f. or sa k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 3-3/16" 6.2# L-80 TCII 910' 9450 9333' 10360 10073 90 cu ft of Class 'G' 3" 2-3/8" 4.6# 13Cr8 STL 2200' 9400' 9285' 11600 10014' 9 u ft of Class'G' 1 g. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10716 Total Depth TVD (ft): 10569 Plugs (measured): 10292 Effective Depth MD (ft): 10635 Effective Depth TVD (ft): 10489 Junk (measured): None Casing 'Length Size' Cement Volume MD D Conductor /Structural 1 1' 3 Driven 131' 1 1' Surface 2504' 13-3/8" 4185 cu ft Perfmafrost 2504' 2502' Intermediate Pr i n 7 -5/ " 57 u ft Class'G' 730' 4' Liner 1229' 7" 547 cu ft Class'G' 9487' - 10716' 9369' - 10569' Perforation Depth MD (ft): 10200' - 10320' Perforation Depth TVD (ft): 10062' - 10180' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Greg Sarber, 564-4330 Printed Name G Sarber Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4330 Date - ~~ ~~ Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill Number:o?06- I~~ API Number; 50-029-21827-01-00 Permit Approval D te: ~ ' ~ See cover letter for oth r re uiremen Conditions of Approval: J If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: a1 Samples Req'd: .Yes ~ No Mud Log Req'd: ^ es ~f1 No t HZS Measures: ~ Yes No irectional Survey Req'd: (~es ^ No Other: Date ~~ ~~ Q ~ APPROVED BY THE COMMISSION COMMISSIONER Form 70-401 Revised 12/2005 ~ ii ~ ~ `~ Submit In Duplicate • • by ENDICOTT WELL 1-39A/N-16 (PRODUCER) CTD SIDETRACK SUMMARY PRE-RIG OPERATIONS: 1.1 PPPOT-T and IC. Function LDS. CMIT-IA x OA 1.2 Pull SSSV; Drift for Jet cut in 4-1/2" tubing 1.3 Set plug in 3-1 /2" XN nipple at 9491' 1.4 Punch circulation holes /string shot tubing; Jet cut 4-1/2" tubing in first full joint above packer. (Approximately 9335') 1.5 Load wellbore with KWF Brine circulating thru the chemical cut. FP T and IA with diesel 1.6 Run BPV. RIG WORKOVER OPERATIONS: 2.1 MIRU Nordic #2, Pull BPV 2.2 Circulate well to clean KWF thru tubing cut.; set TWC 2.3 ND tree / NU BO_ PE and Test; pull TWC 2.4 Pull 4-'/2" tubing from cut point (9,335') 2.5 Replace IC Packoffs 2.6 Recover seal stem from Packer. Recover Packer and 3-1 /2" tailpipe. 2.7 RU Eline. Run Junk basket/Gauge ring. Run USIT log 2.8 Run 4-1/2" 13Cr-80 VAM Top tubing string with new 9-5/8" packer. Packer ~ 9350' 2.9 Set packer, Test IA and Tubing. Circ in FP into top 2000' of annulus. 2.10 Set TWC. ND BOPE, NU Production tree and test. RIG SIDETRACK OPERATIONS: / ~ ®~ ° ~~.~ 3.1 NU 7-1/16" drilling BOPE & test. ~ ~ 3.2 RU Eline. Set whipstock with top at 10,130' 3.3 RU cementers. RIH with coil tubing. P&A existing perforations below whipstock. 3.4 Mill 3.80" window at 10,130' 3.5 Drill build section with 3.75 x 4.125" bi center bit, and land well at ~50 degrees inclination. 3.6 Run and cement 3-3/16" liner 3.7 Mill out float equipment with 2.80" mill and motor. 3.8 Drill horizontal hole with 2.75" x 3.0" bi center bit. Drill to TD ~~~ ~ ~~~ ~v ~~ 3.9 Run and cement 2.375" Cr80 liner. 3.10 Make cleanout run with mill and motor and SWS CNL Logging tool. 3.11 Perforate well (~ 400') QI 3.12 Circulate well to KWF brine. FP tubing to 'with diesel 3.13 Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 3.14 RDMO Nordic 2 Endicott 1-39/P-17 RWO Page 1 of 5 Sundry Notice / PTD #1880630 POST-RIG OPERATIONS: 4.1 Replace gas lift and p~duction flow lines. Set wellhouse. 4.2 Pull BPV. 4.3 Run live gas lift design 4.4 Pull ball and rod and RHC plug. 4.5 POP well. MUD PROGRAM: • Well kill: 8.9 ppg brine • Workover: 8.9 ppg KCL brine with biozan sweeps • Window milling/Drilling: 8.9 ppg Flo-pro drilling mud. DISPOSAL: • All drilling and completion fluids and all other Class II wastes will go to Grind and Inject. • All Class 1 wastes will go to Pad 3 for disposal. HOLE SIZE: • 4-1 /8" for the intermediate section of hole from 10,130' to 10,360'. • 3" for the production section of hole from 10,360'-11,600'. CASING PROGRAM: Fully cemented liners • Intermediate liner 3-3/16", L-80, 6.2# TCII 9,450' MD -10,360' MD • A minimum of 16 bbls of Class G cement will be used for the intermediate liner cementing. --~ ~~Z(,~ c,~owart. • TOC for the intermediate liner planned at 9450' MD. • Production liner 2-3/8", 13Cr-80, 4.6# STL 9,400' MD -11,600' MD ~~ ~ ~~~rt • A minimum of 7 bbls of Class G cement will be used for the production liner cementing. -~ ~~,54~~©~~w~ • TOC for the production liner is planned at 9400' MD. WELL CONTROL • BOP diagram for drilling phase is included. • Pipe rams, blind rams and the CT packoff will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 3500 psi. DIRECTIONAL • See the attached directional plan. The maximum planned hole angle is 94.23 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 7,210'. • Distance to nearest well within pool - 600 ft. LOGGING • MWD directional, Gamma Ray, and Resistivity will be run over all open hole sections. • A cased hole CNL-GR-CCL log will be run from PBTD to 9,400'. HAZARDS • The maximum recorded H2S level on Endicot MPI is 600 ppm on well END 2-14. • The lost circulation risk is low. No fault crossings expected. RESERVOIR PRESSURE • The maximum reservoir pressure has been measured at 4369 psi at 10,000' MD (8.40 ppg EMW) • The maximum surface pressure with gas (0.10 pis/ft) to surface is 3369 psi. Endicott 1-39/P-17 RWO Page 2 of 5 Sundry Notice / PTD #1880630 • Attachment 1 -END 1-39 ~ting Completion • Kf. Et_EV -55. 1' ~. ELEV =i$.57' MAX. DEV. = i9:fl6 7394' M D 13-318', 68#lft, NT84- GYFE. BTRS cSG z5o4' 9-5/8', 4T#4ft, 8357' NT80S XO TO NT95HS 7' LINER 9487" 9-5i8', 47#Ift, 9730' - NT95HS, PERT=ORATifNd SUIY4MARY F~F: LOC3 DLL- tit (7- 2- 88) CO. SIZE SPF INTERVAL C,p 2- 4 10240' - 10216' 14234' - 102$4° 14302' - 10320' AV'iS 2- 1 J 8 4 100$4' - 14070" 10115' -14145' 14184' -14244" TREE 4- 1l i 6' f 54~ ps! ! M: EVCT' VIELLF~AD: 13- 5! 8' J 5000 ps1 / L~EVCA' //'~~ SSSV LANDI NG NI PPLE 1512' t,./ (31'1 S (9. 813' M N I w sssv M N I . to 2.4" 4- 112° , 12. 6#t f t , L- 80, TDS TLlBI NG GAS LiT MA N[N~LS ICAMCO-KBNt01 5 6368 636'6 PoC ID 4 7851 78Qd Dt+ifY FCC 0 3 8823 6732 46+~T! t8C 4 2 9tY8F 88&6 L,1~1Y RK 0 1 9234 9125 DMY RFC U SLI1>ING SLEEVE - 4TIS "XA' 9340' (9.813' MIN. ID} - BAKER SBR (12' Long) 9398' 9-518' 94 i 1' PAp{ER - 9-it2", 92#Xt, L-84 TAILPIPE - 3-1l2" "X' NIPPLE 9459.• [{~TIS) (2.75{T ID) _ 3-i12' 'XN"NIPPLE 9491' [OTIS) [2.$3S ID) - 3-1J2' WLEG 9528" ELMD WLEG 9531' 7' OTIS "SWD" PKR 14, 2.82' I 1N/ 2-?l8" 'X' NIPPLES [2.313" MIN. ID) 2-7/8" 1AfLEG 14, 300° I PBTD 14635' 7' - 29 #eYt, SM-110, 1471$' BTRS-TKC 4ATE REV BY ~IINIBVIS DATE REV 8Y CXaluYutHJ7S 10d 5188 ,~H API AIO 1CAl16f95 Fb4C A4FF3~S 03P29/86 RAC ADF'S 01/23J88 DB F3.f~ WL£G 011031UG V tP GLV C;f0 BdDICOTf iNlft W~L: 1-39 t R17 PE1~1)T No: ?? API ~: 54-(329.2182F-0t6 SBC T N R E $P Exp1a atiat {Alaska) Endicott 1-39/P-17 RWO Page 3 of 5 Sundry Notice / PTD #1880630 Attachment 2- END 1-39 Prop~d Completion, Post CTD sidetrack BF. ELEV =16._. MAX. DEV. = 19.06 7394' MD NT80- CYHE. BTRS. CSG. 2 504' NT80S XO TO 83`'7' NT95HS OP OF 8487, 7" LINER 9-518", 47#rft. 9730' NT95HS: PERFORATION SUMMARY REF: LOG DLL- GR (7- 2- 88) CO. SIZE SPF INTERVAL GO 2" 4 10200' - 102 1 ~`~' 10234' - 10260' 10302' - 10320' A1Af+ 2- I! 8 4 10060' - 10070' 10115'-10145' 10184' - 10200' PBTD 10635' 7" - 29 #,•'ft, SM- 110. 107'16' BTRS-TKC TREE: 4- l! I6" % 5000 psi .' NtEVOY _LHEAD. 13-518" ! 5000 psi btEVC7Y SSSV LANDING NIPPLE 2000' O Halliburton HXO SVLN (3.813" MIN. ID) 4-1 %2", 12 6-; ft, 13C r-80, Vam Top Tubing cas ~ irr ra wew w s ~r-i r m~ra~c ~ YO TV 0 V LV LATCH PORT 17117E 6 '~ 5 ? 3 ^~ 2 ? 1 ? (OTIS) (2.635" ID) 4-1l2" "X" Nipple C~ 9,320' 9-5/8" PACKER @ 9,350' -2-3/8" Liner Top @ 9,400' • 3-3/16" Liner Top ~ 9,450' 4-112" "X" NIPPLE (~ 9,575' 1/2" WLEG ~ 9,650' Whipstock 10,130' MD H16" Liner 2-3/8" Liner 10.360' MD @ 11,600' MD 7" OTIS "W D" PKR W/ 2-718" 'X' NIPPLES (2.313" MIN. ID) 2-7;8" WLEG lL1TE REV BY OOYYEMiS (CITE REV BY OOYYENI3 tt766B JLH OORR~T®API ND it7/1685 RAC Al]PBiFS lIiL98fi RAC AOPERFS O1L~189 D8 EL YOMiLEC O1 Gla6 611VfPJC CLV CA 10, 282' 10, 300' ENO~DTT 1JNn' MrEll: 1~79f P-17 P ER YIT ~: ?~ API Me: ~-~g,21B21 ~ S~ T N R E BP ~pb~1b~ @1GiiG7~ Endicott 1-39/P-17 RWO Sundry Notice / PTD #1880630 Page 4 of 5 Figure 1 1-0 3/ P-16 '~ 1-39_and~ot st <Q~p_Grids> 1- 0 3 / P 16 P H Dev fated w ell - Wellbore path 2 34/P-14 WeIIID - 1-2 3/0-15 -.1-39AWP1, Prop. Sidetrack • 500292182700 Parent 1-39 well • / • '~\1 ~ ALL_End_tops <g~1D_Grids> \ , \ Deviated well -Wellbore path '~ ~ r Dewa[ed w ell -Wellbore path ,~ _ ~,~, , ~ 2-14/0-16 ~ To S ~ ~~;`, ~ p ~, A / ~ ~~ ~ ~~ ~~ ~ ~~~ ~' ~ ~ /~ ~ ~/ (Top Kekituk) 1000' away ~`~~. ~, ~ ~ ` f~~santicipated r ~ ~ ~ / ~ FIV w ~`~ i ~". i ~,, \ ~` i ~~ i • Fla __ • FII -~ "~~1, 2-14 Kekituk ~ FI -3 /P-17 ',~ l section is within 2-12/Q- 6 ,~' looo' away 1000' of proposed ~ ssAa \~ from anticipated Sldetl'aCk • S3A3 ,, , ; ~-~ ~ ~ ~ ~~ ~ f S3A 1 ~~,-_. ~~~ ..- -~.~`{, ,. I ,~, - _ • K2B (Proposed perfs~ _ _ -- • -__ - °~ _ ~ - -y- ~• _ - ._ - - - • - f ~,, ,~ ,- _~ _ - _ _ _ ,-___ ~' _'~--~ 'f~ ~; K1 _~ _. _ ,.- ;- '`~ 2-28A/0-19 2-28/P-19 1 .~ ' ~~ 500 0 500 1000 ~ 1500 ft 1:4800 /4 5~ 1-39/P-17 _ssoo -10000 -,0,00 2500E -102 f\LIYI 1- 9/P-17 TD=10716 500292182700 1574.9 ft Wei YA1l turn nea-horizorgai tyron encountering tM OWC. 2-14/0-16 Planned horizontal completion interval for 1-39a/N-16 Fi ure 2 3A2 -ssoo Upper 2B 2500E . . 1-39aWP11 TD=11600 1-39aWP~1 Lower 26 2M Shale -,0,00 P~ 52A3 2A Actively producing '-°` 's2A2 2A perforations S2A~ 2-14/G-16 TD=11104 500292163900 1-03/P-16 2-34/P-14 1-03/P16 PH 1-23/0-15 •~ ~ ~ --~ 2-14/Q~-16 _ \ g / ~ P-17 2-12/Q 6 ~ ~ .., . A 2-268,0-19 , ~~ 2-6210-17 2-28/P-19 2-28A10-19 r -- --- ,.eoo i :~ •~ A .~ .~ o P„ .~ ~' Figure 3 _ Distance from proposed 1-39a/N-16 Active well within 1000' 2-14/O 16 -Active Producer Horizontal distance in feet to T1 tar et in 1-39a/0-16 Horizontal distance in feet to TD of 1-39a/0-16 To Kekiktuk 551 433 To U er 2B never erf'd in 2-14 856 774 Top Lower 2B Historic Perfs, not currentl producin) 900 820 To 2A (currentl roducin) 994 919 TD 1335 1270 Parent Well 1-39/P-17 Parent well Horizontal distance in feet to T1 tar et in 1-39x/0-16 Horizontal distance in feet to TD of 1-39x/0-16 To Kekiktuk Sidetrackin below top Kekiktuk To U e r 2 B 752 854 TD 739 872 Next Nearest Active Well 1-03/P-16 Horizontal distance in feet to Horizontal distance in feet to T1 tar et in 1-39x/0-16 TD of 1-39a/0-16 To Kekiktuk 1216 1123 TD 1356 1620 • s ~~ ~....~ r bP BP Alaska Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 12/18/2008 Time: 12:03:18 Page: 1 Field: Endicott Co-ordinate(NE) Reference: Well: 1-39/P-17, True North Site: End MPI Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55.1 Well: 1-39/P-17 Section (VS) Reference: Well (O.OON,O.OOE,50.O OAzi) Wellpath: Plan 11, 01-39A/N-16 Survey Cakolation Method: Minimum Curvature Db: Orade Fiehi: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zoue: Alaska, Zone 3 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: End MPI TR-12-16 UNITED STATES :North Slope Site Position: Northing: 5979337.49 ft Latitude: 70 20 38.358 N From: Map Eastiug: 256681. 13 ft Longitude: 147 58 30.505 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -1.86 deg Well: 1-39/P-17 Slot Name: 39 1-39/P-17 Well Position: +N/-S 3040.87 ft Northing: 5982302. 79 ft Latitude: 70 21 8.262 N +E/-W 2275.64 ft Fasting : 259054. 20 ft Longitude: 147 57 23.994 W Position Uncertainty: 0.00 ft Wellpath: Plan 11, 01-39A/N-16 Drilled From: 1-39/P-17 Tie-on Depth: 10100.00 ft Current Datum: 52:39 6/18/1988 00:00 Height 55. 10 ft Above System Datum: Mean Sea Level Magnetic Data: 12/15/2006 Declination: 24.50 deg Field Strength: 57689 nT Mag Dip Angle: 81.05 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.60 0.00 0.00 50.00 Plan: Plan #11 Date Composed: 1 2/1 512 006 Copy Lamar's plan 11 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map 1/lap c--- Latitnde --> <- Longitude ---> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min. Sec Deg Min Sec Dip. I)ir. ft ft - ft ft ft 01-39AlN-16 Polygon 55.10 1272.60 -165.21 5983580.00 258930 .00 70 21 20.777 N 147 57 28.824 W -Polygon 1 55.10 1272.60 -165.21 5983580.00 258930 .00 70 21 20.777 N 147 57 28.824 W -Polygon 2 55.10 1236.18 -364.15 5983550.00 258730. 00 70 21 20.419 N 147 57 34.639 W -Polygon 3 55.10 749.96 -238.45 5983060.00 258840. 00 70 21 15.637 N 147 57 30.964 W -Polygon 4 55.10 796.05 -49.82 5983100.00 259030 .00 70 21 16.091 N 147 57 25.450 W 01-39A/N-16 Target3 10070.10 807.42 -7.17 5983110.00 259073 .00 70 21 16.203 N 147 57 24.204 W 01-39AlN-16 Target2 10095.10 1056.03 -614.50 5983378.00 258474 .00 70 21 18.647 N 147 57 41.957 W 01-39A/N-16 Targetl 10128.10 657.35 -877.82 5982988.00 258198 .00 70 21 14.726 N 147 57 49.653 W Annotation MD TVI) ft ft 10100.00 9964.48 TIP 10130.00 9993.80 KOP 10150.00 10013.28 End of 9 Deg/100' DLS 10361.29 10127.85 End of 38 Deg/100' DLS 10366.29 10127.50 End 5' Hold/Beg. 45 Deg/100' DLS 10466.29 10120.31 End of 45 Deg/100' DLS 10616.29 10110.49 7 10876.29 10094.84 8 11301.29 10074.74 9 11600.00 10069.47 TD • r by BP Alaska ~~~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 12/18/2006 Time: 12:03:18 Page: 2 Field: Endicott Co-ordinate(NE) Reference: Well: 1-39/P-1 7, True North Slte: End MPI Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55. 1 Well: 1-39/P-17 Section (VS) Reference: Well (O.OON,O. OOE,50.OOAzi ) Welipath: P lan 11, 01-3 9A/N-16 Survey Cakulatioe Methud: Minimum Curvature Db: Orade Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Buiid Turn TFO Target ft deg deg ft ft ft deg/100ft deg/t00ft degl100ft deg 10100.00 12.25 321.90 9964.48 520.37 -803.14 0.00 0.00 0.00 0.00 10130.00 12.14 323.08 9993.80 525.40 -806.99 0.91 -0.37 3.93 114.39 10150.00 13.92 324.38 10013.28 529.03 -809.66 9.00 8.88 6.50 10.00 10361.29 94.00 334.26 10127.85 668.17 -882.57 38.00 37.90 4.68 10.00 10366.29 94.00 334.26 10127.50 672.66 -884.73 0.00 0.00 0.00 0.00 10466.29 93.82 19.37 10120.31 769.70 -890.13 45.00 -0.18 45.11 88.60 10616.29 93.63 37.41 10110.49 900.83 -819.26 12.00 -0.12 12.02 90.00 10876.29 93.10 68.66 10094.84 1054.96 -614.45 12.00 -0.20 12.02 90.00 11301.29 91.95 119.70 10074.74 1024.95 -204.93 12.00 -0.27 12.01 90.00 11600.00 90.00 155.50 10068.47 807.97 -6.83 12.00 -0.65 11.98 92.70 Survey MD Inct ~zm SS TVD ' N/S E/W MapN MapE DLS VS TFO Tool ft deg deg , ft ft ft ft ft deg/100ft ft deg 10100.00 12.25 321.90 9909.38 520.37 -803.14 5982848.70 258268.24 0.00 -280.75 0.00 MWD 10125.00 12.16 322.88 9933.81 524.56 -806.36 5982852.99 258265.15 0.91 -280.53 114.39 MWD 10130.00 12.14 323.08 9938.70 525.40 -806.99 5982853.85 258264.55 0.91 -280.48 113.43 MWD 10150.00 13.92 324.38 9958.18 529.03 -809.66 5982857.57 258262.00 9.00 -280.18 10.00 MWD 10175.00 23.33 328.53 9981.85 535.71 -814.00 5982864.38 258257.87 38.00 -279.21 10.00 MWD 10200.00 32.79 330.37 10003.89 545.84 -819.95 5982874.70 258252.26 38.00 -277.25 6.05 MWD 10213.64 37.96 331.02 10015.00 552.73 -823.81 5982881.70 258248.62 38.00 -275.79 4.42 01-39 10225.00 42.27 331.46 10023.69 559.15 -827.33 5982888.23 258245.31 38.00 -274.36 3.89 MWD 10248.85 51.31 332.17 10040.00 574.45 -835.52 5982903.79 258237.61 38.00 -270.80 3.56 01-39 10250.00 51.75 332.20 10040.72 575.25 -835.94 5982904.60 258237.22 38.00 -270.61 3.07 MWD 10275.00 61.24 332.78 10054.50 593.72 -845.56 5982923.37 258228.20 38.00 -266.10 3.05 MWD 10300.00 70.73 333.25 10064.66 614.05 -855.90 5982944.02 258218.52 38.00 -260.96 2.73 MWD 10325.00 80.22 333.68 10070.93 635.68 -866.70 5982965.99 258208.42 38.00 -255.33 2.54 MWD 10350.00 89.71 334.08 10073.12 658.01 -877.65 5982988.66 258198.19 38.00 -249.36 2.43 MWD 10360.00 93.51 334.24 10072.84 667.01 -882.01 5982997.79 258194.13 38.00 -246.91 2.39 3 3/16" 10361.29 94.00 334.26 10072.75 668.17 -882.57 5982998.97 258193.61 38.00 -246.60 2.40 MWD 10366.29 94.00 334.26 10072.40 672.66 -884.73 5983003.53 258191.59 0.00 -245.37 180.00 MWD 10375.00 94.09 338.19 10071.79 680.61 -888.24 5983011.59 258188.34 45.00 -242.94 88.60 MWD 10400.00 94.23 349.47 10069.97 704.52 -895.17 5983035.70 258182.18 45.00 -232.88 88.88 MWD 10425.00 94.20 0.75 10068.13 729.32 -897.29 5983060.56 258180.86 45.00 -218.57 89.70 MWD 10450.00 94.02 12.02 10066.33 754.06 -894.52 5983085.20 258184.42 45.00 -200.55 90.53 MWD 10466.29 93.82 19.37 10065.21 769.70 -890.13 5983100.68 258189.31 45.00 -187.13 91.34 MWD 10475.00 93.82 20.42 10064.63 777.87 -887.17 5983108.76 258192.53 12.00 -179.61 90.00 MWD 10500.00 93.81 23.42 10062.97 801.01 -877.86 5983131.58 258202.58 12.00 -157.61 90.07 MWD 10525.00 93.79 26.43 10061.32 823.62 -867.35 5983153.85 258213.81 12.00 -135.01 90.27 MWD 10550.00 93.76 29.44 10059.67 845.66 -855.67 5983175.50 258226.20 12.00 -111.90 90.47 MWD 10575.00 93.72 32.44 10058.04 867.06 -842.84 5983196.47 258239.71 12.00 -88.32 90.67 MWD 10600.00 93.67 35.45 10056.43 887.75 -828.91 5983216.70 258254.29 12.00 -64.35 90.86 MWD 10616.29 93.63 37.41 10055.39 900.83 -819.26 5983229.47 258264.36 12.00 -48.55 91.06 MWD 10625.00 93.63 38.45 10054.84 907.69 -813.92 5983236.15 258269.92 12.00 -40.05 90.00 MWD 10650.00 93.62 41.46 10053.26 926.81 -797.89 5983254.74 258286.55 12.00 -15.48 90.07 MWD 10675.00 93.60 44.47 10051.69 945.06 -780.89 5983272.44 258304.13 12.00 9.28 90.26 MWD 10700.00 93.57 47.47 10050.12 962.40 -762.96 5983289.20 258322.61 12.00 34.16 90.45 MWD 10725.00 93.54 50.48 10048.57 978.78 -744.13 5983304.96 258341.95 12.00 59.11 90.63 MWD 10750.00 93.49 53.48 10047.04 994.15 -724.48 5983319.69 258362.09 12.00 84.04 90.82 MWD 10775.00 93.43 56.49 10045.53 1008.47 -704.04 5983333.34 258382.98 12.00 108.90 91.00 MWD 10800.00 93.36 59.49 10044.05 1021.69 -682.88 5983345.88 258404.55 12.00 133.61 91.19 MWD 10825.00 93.29 62.50 10042.60 1033.79 -661.06 5983357.27 258426.75 12.00 158.11 91.36 MWD 10850.00 93.20 65.50 10041.18 1044.73 -638.63 5983367.48 258449.52 12.00 182.33 91.54 MWD 10875.00 93.11 68.50 10039.81 1054.49 -615.65 5983376.49 258472.80 12.00 206.19 91.71 MWD by BP Alaska B~~s Baker Hughes INTEQ Planning Report lNTE Q Company: BP Amoco Date: 12/18/2006 Time: 12:03:18 Page: 3 Field: Endicott Co-ordinate(NE) Refemnce: Well: 1-39/P-17, True North Site: End MPI Vertical (TVD) Reference: 52:39 6/18/1988 00:00 55.1 Well: 1-39/P-17 Section (VS) Reference: Well (O.OON,O.OOE,50.OOAzi) Wellpath: Plan 11, 01-39A/N-16 Survey Calculation Method: Minimum Curvature Db: Orade Survev MD ft Tncl deg Azim deg SS TVD ft N/S ft 10876.29 93.10 68.66 10039.74 1054.96 10900.00 93.10 71.51 10038.45 1063.02 10925.00 93.09 74.51 10037.10 1070.32 10950.00 93.07 77.52 10035.76 1076.35 10975.00 93.04 80.52 10034.43 1081.10 11000.00 93.00 83.52 10033.11 1084.57 11025.00 92.95 86.53 10031.81 1086.73 11050.00 92.90 89.53 10030.54 1087.59 11075.00 92.84 92.53 10029.28 1087.14 11100.00 92.77 95.54 10028.06 1085.38 11125.00 92.69 98.54 10026.87 1082.33 11150.00 92.61 101.54 10025.71 1077.97 11175.00 92.52 104.54 10024.60 1072.34 11200.00 92.42 107.54 10023.52 1065.43 11225.00 92.31 110.54 10022.49 1057.28 11250.00 92.20 113.54 10021.50 1047.91 11275.00 92.08 116.54 10020.57 1037.34 11300.00 91.96 119.54 10019.69 1025.59 11301.29 91.95 119.70 10019.64 1024.95 11325.00 91.82 122.54 10018.86 1012.71 11350.00 91.67 125.54 10018.10 998.72 11375.00 91.51 128.54 10017.41 983.67 11400.00 91.36 131.53 10016.78 967.59 11425.00 91.20 134.53 10016.23 950.54 11450.00 91.03 137.53 10015.74 932.55 11475.00 90.86 140.52 10015.33 913.68 11500.00 90.70 143.52 10014.99 893.98 11525.00 90.52 146.51 10014.72 873.50 11550.00 90.35 149.51 10014.53 852.30 11575.00 90.18 152.50 10014.41 830.44 11600.00 90.00 155.50 10014.37 807.97 E/W AfapN ft ft -614.45 5983376.92 -592.20 5983384.27 -568.33 5983390.79 -544.10 5983396.04 -519.60 5983400.01 -494.88 5983402.67 -470.01 5983404.04 -445.06 5983404.09 -420.10 5983402.84 -395.19 5983400.28 -370.41 5983396.43 -345.82 5983391.29 -321.50 5983384.87 -297.50 5983377.20 -273.89 5983368.30 -250.73 5983358.18 -228.10 5983346.89 -206.06 5983334.44 -204.93 5983333.77 -184.65 5983320.87 -163.95 5983306.23 -144.00 5983290.55 -124.87 5983273.86 -106.60 5983256.23 -89.25 5983237.70 -72.86 5983218.31 -57.48 5983198.13 -43.15 5983177.20 -29.90 5983155.58 -17.79 5983133.34 -6.83 5983110.53 MapE DLS VS ft deg/100ft ft 258474.01 12.00 207.42 258496.52 12.00 229.65 258520.61 12.00 252.62 258545.01 12.00 275.06 258569.65 12.00 296.88 258594.47 12.00 318.05 258619.40 12.00 338.49 258644.36 12.00 358.15 258669.29 12.00 376.99 258694.13 12.00 394.94 258718.80 12.00 411.95 258743.23 12.00 427.99 258767.37 12.00 443.00 258791.13 12.00 456.95 258814.47 12.00 469.80 258837.30 12.00 481.51 258859.58 12.00 492.05 258881.24 12.00 501.39 258882.34 12.00 501.84 258902.22 12.00 509.50 258922.46 12.00 516.37 258941.91 12.00 521.98 258960.52 12.00 526.30 258978.23 12.00 529.33 258994.99 12.00 531.07 259010.76 12.00 531.49 259025.50 12.00 530.61 259039.17 12.00 528.42 259051.72 12.00 524.94 259063.13 12.00 520.17 259073.36 12.00 514.12 TFO Tool deg 91.87 MWD 90.00 MWD 90.15 MWD 90.32 MWD 90.48 MWD 90.64 MWD 90.80 MWD 90.95 MWD 91.11 MWD 91.26 MWD 91.40 MWD 91.55 MWD 91.68 MWD 91.82 MWD 91.95 MWD 92.07 MWD 92.19 MWD 92.30 MWD 92.41 MWD 92.70 MWD 92.79 MWD 92.88 MWD 92.97 MWD 93.04 MWD 93.11 MWD ' 93.17 MWD 93.22 MWD 93.26 MWD 93.29 MWD 93.31 MWD 93.33 2 3/8" • a ~ 'R ~11 r,+ ! 1 ~rtt r t F a+ (~~+ I~ I ~ II '1 -t a t ~ 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I sa; s _ I r r _. _ ~ 888 ~ :B ~ sr~~~aa;;a _ ~ I r .. _. - - - _ - I _t - 8 ass aaa?! ieaF$ ~'^ - - ~ ~ Nlnwzl uu~ igan,y. • by BP Alaska Anticollision Report ~.r s 1NTEQ Company: BP Amoco Date: 12/16/2006 Time: 20:37:34 Page: 1 Field: Endicott Reference Site: End MPI Co~ordinate(NE) Refe rence: Well: 1-39/P-17, True North Reference Wetl: 1-39/P-17 Vertical (T VD) Reference: 52:39 6/18/1988 00: 00 55.1 Reference Wellpath: Plan 11, 01-39AlN-16 Db: Orate NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan 8 PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8250.00 to 10240.00 ft Scan Method: Trav Cylinder North Maximum Radius: 3000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/15/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 94.00 10100.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 10100.00 11600.00 Planned: Plan #11 V4 MWD MWD -Standard Casing Points MI)? 1'VD Dirmeter Ho irSize Name ft `` ft in in 10360.00 10127.94 3.188 4.125 33/16" 11600.00 10069.47 2.375 3.000 2 3/8" Summary < - OlfsefWeltpath - --->` Reference Offset ' Ctr-Ctr No-Go Allowable Site R'ell Wellpath ` MD MD Distance Area Deviation Warning ft ft ft ft ft End MPI 1-03/P-16 1-03/P-16 V1 8281.65 8500.00 1702.87 105.41 1597.46 Pass: Major Risk End MPI 1-03/P-16 1-03/P16PH V5 8331.86 8500.00 1605.74 117.97 1487.77 Pass: Major Risk End MPI 1-03/P-16 Plan 01-03A/0-19 VO PI 10028.48 11200.00 1689.26 139.02 1550.24 Pass: Major Risk End MPI 1-39/P-17 1-39/P-17 V1 10100.00 10100.00 0.00 207.14 -207.14 FAIL: Major Risk End MPI 1-61/Q-20 Plan 1-61A/0-19 V 1 Pia 10063.23 11300.00 1617.02 149.49 1467.52 Pass: Major Risk End MPI 2-1210-16 2-12/0-16 V1 8261.80 8200.00 539.64 59.64 480.00 Pass: Major Risk End MPI 2-14/0-16 2-14/0-16 V1 8315.09 8300.00 377.56 111.96 265.60 Pass: Major Risk End MPI 2-28/P-19 2-28/P-19 V4 8261.58 8400.00 589.98 60.06 529.92 Pass: Major Risk End MPI 2-28/P-19 2-28A/0-19 V1 8261.58 8400.00 589.98 59.90 530.07 Pass: Major Risk End MPI 2-28/P-19 2-288/0-19 V15 8260.41 8400.00 593.46 59.49 533.97 Pass: Major Risk End MPI 2-34/P-14 2-34/P-14 V1 8314.21 8300.00 906.26 100.02 806.24 Pass: Major Risk End MPI 2-48/0-13 2-48/0-13 V1 9789.74 9600.00 1500.75 75.28 1425.47 Pass: Major Risk End MPI 2-48/0-13 2-48/013PH V3 9368.36 9100.00 1500.20 69.72 1430.48 Pass: Major Risk End MPI 2-62/Q-17 2-62/0-17 V1 8315.10 8400.00 612.92 110.45 502.47 Pass: Major Risk Site: End MPI Well: 1-03/P-1 6 Rule Assigned: Major Risk Wellpath: 1-03/P-1 6 V1 Inter-Site Error: 0.00 ft Reference Offsei Semi-Major Axis . Ctr-Ctr No-Go Allowable MD TVD MD rTVD Ref Offset TFO+AZI TFO-HS Casiog/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft tt ft 8281.65 8214.10 8500.00 8358.05 19.99 15.02 50.04 106.19 1702.87 105.41 1597.46 Pass 8382.06 8309.86 8600.00 8456.22 21.37 15.25 50.62 106.54 1726.47 109.79 1616.68 Pass 8485.87 8409.05 8700.00 8554.71 22.79 15.46 51.21 106.55 1748.14 114.25 1633.89 Pass 8589.08 8507.80 8800.00 8653.27 24.19 15.65 51.78 106.50 1769.26 118.66 1650.60 Pass 8689.68 8604.13 8900.00 8751.77 25.55 15.84 52.31 106.72 1790.50 122.98 1667.52 Pass 8788.14 8698.41 9000.00 8850.25 26.89 16.00 52.84 106.75 1811.51 127.24 1684.28 Pass 8891.51 8797.21 9100.00 8948.86 28.32 16.15 53.43 106.15 1832.38 131.77 1700.62 Pass 9002.47 8903.28 9200.00 9047.64 29.87 16.37 54.05 105.65 1852.50 136.66 1715.84 Pass 9102.29 8998.93 9300.00 9146.46 31.26 16.56 54.60 106.14 1872.20 140.99 1731.21 Pass 9206.55 9098.93 9400.00 9245.25 32.69 16.74 55.13 105.92 1891.24 145.51 1745.73 Pass 9316.16 9204.21 9500.00 9344.14 34.18 16.92 55.63 105.45 1908.22 150.26 1757.96. Pass 9437.19 9320.65 9600.00 9442.90 35.78 17.11 56.10 103.71 1922.81 155.49 1767.32 Pass 9576.86 9455.49 9700.00 9540.46 37.55 17.31 56.36 100.03 1930.30 161.69 1768.60 Pass 9706.57 9581.18 9800.00 9634.77 39.10 17.50 56.20 96.61 1930.27 167.73 1762.53 Pass 9814.78 9686.35 9900.00 9723.62 40.34 17.64 55.58 94.83 1919.71 173.25 1746.46 Pass 9903.03 9772.27 10000.00 9807.24 41.33 17.77 54.60 94.68 1905.26 178.31 1726.96 Pass 9999.32 9866.16 10100.00 9887.81 42.38 17.93 53.50 93.00 1888.64 183.85 1704.79 Pass • by BP Alaska Anticollision Report • ~.r ~+e ~s INTEQ Company: BP Amoco Date: 12/16/2006 Time: 20:37:34 Page: 2 Field: Endicott Reference Site: End MPI Co-ordiuate(NE) Reference: Well: 1-39/P-17, True North Reference Well: 1-391P-17 Vertical (TVD) Reference: 52:39 6/18/1988 00: 00 55.1 Reference Wellpath: Plan 11, 01-39A/N-16 Db: OraGe Site: End MPI Well: 1-03/P-16 Rule Assigned: Major Risk Welipath: 1-03/P16PH V5 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axiv Ctr-Clr No-C,o Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IISI)istance Area Deviation Warning ft ft ft ft ft ft deg .deg in ft ft ft 8331.86 8261.96 8500.00 8285.92 20.68 15.36 36.77 92.85 1605.74 117.97 1487.77 Pass 8433.62 8359.11 8600.00 8376.78 22.08 15.76 36.45 92.11 1624.18 123.43 1500.75 Pass 8536.82 8457.79 8700.00 8467.60 23.48 16.17 36.14 91.18 1642.41 128.95 1513.45 Pass 8638.81 8555.41 8800.00 8558.38 24.86 16.60 35.80 90.36 1660.06 134.51 1525.55 Pass 8740.04 8652.37 8900.00 8649.09 26.24 17.02 35.45 89.61 1677.66 140.05 1537.61 Pass 8845.87 8753.61 9000.00 8739.76 27.69 17.43 35.15 88.41 1695.07 145.78 1549.29 Pass 8954.82 8857.70 9100.00 8831.32 29.21 17.83 34.95 86.98 1711.07 151.43 1559.64 Pass 9056.47 8955.00 9200.00 8923.99 30.62 18.21 34.80 86.40 1726.89 156.52 1570.38 Pass 9158.99 9053.32 9300.00 9017.72 32.04 18.55 34.72 85.86 1741.50 161.59 1579.91 Pass 9264.17 9154.25 9400.00 9112.24 33.47 18.90 34.72 85.06 1754.96 166.75 1588.21 Pass 9373.31 9259.16 9500.00 9207.32 34.94 19.23 34.78 83.85 1767.64 172.04 1595.61 Pass 9495.36 9376.74 9600.00 9302.56 36.54 19.62 34.91 80.84 1780.24 177.81 1602.43 Pass 9616.23 9493.60 9700.00 9397.86 38.03 20.03 35.00 77.61 1792.40 183.41 1608.99 Pass 9729.77 9603.71 9800.00 9493.06 39.36 20.43 35.03 75.12 1804.26 188.49 1615.78 Pass 9829.51 9700.68 9900.00 9588.05 40.50 20.83 34.95 74.34 1816.58 192.85 1623.73 Pass 9921.34 9790.12 10000.00 9682.37 41.53 21.25 34.77 74.74 1830.19 196.87 1633.32 Pass Site: End MPI Well: 1-03/P-1 6 Rule Assigned: Major Risk Wellpath: Plan 01-03A/0-19 VO Plan: 01-03A/0-19 wp01 V1 Inter-Site Error: 0.00 ft Refereece Offset Semi-Major Aais Ctr-Ctr No-Go .Allowable MD'` TVD MD TVD Ref OtYset TFO+AZI TFO-HS Casing/HSDistaace .Area .Deviation Warning ft ft ft ft ft tt deg. .deg in ft ft ft 8281.65 8214.10 8500.00 8358.05 19.99 15.08 50.04 106.19 1702.87 105.43 1597.44 Pass 8382.06 8309.86 8600.00 8456.22 21.37 15.31 50.62 106.54 1726.47 109.81 1616.66 Pass 8485.87 8409.05 8700.00 8554.71 22.79 15.52 51.21 106.55 1748.14 114.28 1633.86 Pass 8589.08 8507.80 8800.00 8653.27 24.19 15.71 51.78 106.50 1769.26 118.69 1650.57 Pass 8689.68 8604.13 8900.00 8751.77 25.55 15.90 52.31 106.72 1790.50 123.01 1667.49 Pass 8788.14 8698.41 9000.00 8850.25 26.89 16.06 52.84 106.75 1811.51 127.27 1684.24 Pass 8891.51 8797.21 9100.00 8948.86 28.32 16.21 53.43 106.15 1832.38 131.80 1700.58 Pass 9002.47 8903.28 9200.00 9047.64 29.87 16.43 54.05 105.65 1852.50 136.70 1715.80 Pass 9102.29 8998.93 9300.00 9146.46 31.26 16.63 54.60 106.14 1872.20 141.03 1731.17 Pass 9206.55 9098.93 9400.00 9245.25 32.69 16.80 55.13 105.92 1891.24 145.56 1745.68 Pass 9316.16 9204.21 9500.00 9344.14 34.18 16.99 55.63 105.45 1908.22 150.31 1757.91 Pass 9437.19 9320.65 9600.00 9442.90 35.78 17.17 56.10 103.71 1922.81 155.55 1767.26 Pass 9576.86 9455.49 9700.00 9540.46 37.55 17.38 56.36 100.03 1930.30 161.75 1768.54 Pass 9706.62 9581.23 9800.00 9634.89 39.10 17.57 56.20 96.62 1930.56 167.76 1762.80 Pass 9817.10 9688.61 9900.00 9730.24 40.37 17.64 56.12 95.39 1922.50 172.50 1750.00 Pass 9907.51 9776.64 10000.00 9828.03 41.38 17.47 56.84 96.90 1906.26 175.41 1730.85 Pass 9994.69 9861.65 10100.00 9918.92 42.33 17.13 58.43 97.96 1884.77 177.11 1707.65 Pass 10063.58 9928.90 10200.00 9994,00 43.07 16.66 60.75 99.37 1862.00 177.18 1684.82 Pass 10103.13 9967.54 10300.00 10045,92 43.47 16.15 63.60 101.58 1842.65 175.49 1667.16 Pass 10109.01 9973.28 10400.00 10069.83 43.50 15.64 66.69 104.43 1830.47 172.25 1658.22 Pass 10098.34 9962.85 10500.00 10082.05 43.44 15.18 69.80 107.92 1824.62 168.59 1656.03 Pass 10087.93 9952.68 10600.00 10091.74 43.33 14.60 72.89 111.16 1808.42 164.18 1644.24 Pass 10077.87 9942.85 10700.00 10099.66 43.22 13.96 75.93 114.35 1779.93 159.78 1620.15 Pass 10068.06 9933.27 10800.00 10107.01 43.11 13.41 79.02 117.58 1750.88 155.77 1595.11 Pass 10058.21 9923.65 10900.00 10114.37 43.01 12.93 82.21 120.90 1727.09 151.69 1575.40 Pass 10048.34 9914.01 11000.00 10121.72 42.90 12.52 85.47 124.30 1708.78 147.54 1561.24 Pass 10038.42 9904.33 11100.00 10129.08 42.80 12.22 88.79 127.77 1696.13 143.30 1552.82 Pass 10028.48 9894.62 11200.00 10136.44 42.69 12.12 92.16 131.27 1689.26 139.02 1550.24 Pass 10018.49 9884.88 11300.00 10143.79 42.58 12.47 95.53 134.78 1688.25 134.69 1553.55 Pass • by BP Alaska Anticollision Report ~.r ~iuti~s INTEQ Company: BP Amoco Date: 1 2/1 612 0 0 6 Time: 20:37:34 Page: 3 Field: Endicott Reference Site: End MPI Co-ordinate(NE) Reference: Well: 1-39/P-17, True North Reference Well: 1-39lP-17 V ertical (TVD) Reference: 52:39 6/18!1988 00: 00 55.1 Reference Wellpath: Plan 11, 01 -39A/N-16 Db: Orade Site: End MPI Well: 1-03/P-16 Rule Assigned: Major Risk Wellpath: Plan 01-03A/0-19 VO Plan: 01-03A/0-19 wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aa-s Ctr-Ctr No-Co Allowable NiD TVD MD TVD Ret Offset TFO+AZI TFO-HS Casiag/HSUistaace Area Deviation Warning ft ft ft ft ft ft deg deg' in ft ft ft 10008.48 9875.10 11400.00 10151.15 42.48 13.27 98.90 138.29 1693.10 130.33 1562.77 Pass 9998.50 9865.37 11500.00 10158.50 42.37 14.26 102.24 141.75 1703.77 125.96 1577.81 Pass 9988.88 9855.98 11600.00 10165.86 42.27 15.34 105.53 145.10 1720.14 121.67 1598.48 Pass 9985.94 9853.11 11630.44 10168.10 42.23 15.69 106.52 146.10 1726.24 120.39 1605.85 Pass Site: End MPI Well: 1-39/P-17 Rule Assigned: Major Risk Wellpath: 1-39/P-17 V1 Inter-SiteError: 0.00 ft Reference OficeC Semi-Major Aais Ctr-Ctr No-Co Allowable MD : TVD MD TVD Ref Uffset- TFO+AZI TFO-HS Casing/fISflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8300.00 8231.58 8300.00 8231.58 20.24 20.24 303.83 0.00 0.00 106.17 -106.17 FAIL 8400.00 8326.99 8400.00 8326.99 21.62 21.62 304.14 0.00 0.00 110.65 -110.65 FAIL 8500.00 8422.57 8500.00 8422.57 22.98 22.98 304.74 0.00 0.00 115.29 -115.29 FAIL 8600.00 8518.25 8600.00 8518.25 24.33 24.33 305.33 0.00 0.00 120.00 -120.00 FAIL 8700.00 8614.02 8700.00 8614.02 25.69 25.69 305.64 0.00 0.00 124.66 -124.66 FAIL 8800.00 8709.75 8800.00 8709.75 27.05 27.05 306.18 0.00 0.00 129.48 -129.48 FAIL 8900.00 8805.31 8900.00 8805.31 28.44 28.44 307.37 0.00 0.00 134.92 -134.92 FAIL 9000.00 8900.92 9000.00 8900.92 29.84 29.84 308.40 0.00 0.00 140.51 -140.51 FAIL 9100.00 8996.74 9100.00 8996.74 31.23 31.23 308.44 0.00 0.00 145.15 -145.15 FAIL 9200.00 9092.65 9200.00 9092.65 32.60 32.60 309.16 0.00 0.00 150.54 -150.54 FAIL 9300.00 9188.68 9300.00 9188.68 33.96 33.96 309.98 0.00 0.00 156.14 -156.14 FAIL 9400.00 9284.84 9400.00 9284.84 35.30 35.30 311.36 0.00 0.00 162.51 -162.51 FAIL 9500.00 9381.21 9500.00 9381.21 36.60 36.60 314.20 0.00 0.00 170.97 -170.97 FAIL 9600.00 9477.89 9600.00 9477.89 37.83 37.83 317.00 0.00 0.00 179.54 -179.54 FAIL 9700.00 9574.81 9700.00 9574.81 39.02 39.02 319.50 0.00 0.00 187.69 -187.69 FAIL 9800.00 9671.96 9800.00 9671.96 40.17 40.17 320.90 0.00 0.00 194.05 -194.05 FAIL 9900.00 9769.32 9900.00 9769.32 41.30 41.30 319.90 0.00 0.00 196.11 -196.11 FAIL 10000.00 9866.83 10000.00 9866.83 42.39 42.39 320.50 0.00 0.00 200.84 -200.84 FAIL 10100.00 9964.48 10100.00 9964.48 43.45 43.45 321.90 0.00 0.00 207.14 -207.14 FAIL 10197.67 10057.01 10200.00 10062.26 42.54 43.45 152.35 182.11 9.94 151.50 -141.56 FAIL Site: End MPI Well: 1-61/Q-20 Rule Assigned: Major Risk Wellpath: Plan 1-61A/0-19 V1 Plan: 01-61 A/0-19 wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis . - Ctr-Ctc No-GO Allowable MD TVD MD TVD Ref Ofi'set TFO+AZI TFO-HS Casiaa/HSDistance Area Deviation Warning ft ft ft ft ft ft deg: deg in ft ft ft 8311.50 8242.55 8800.00 8729.78 20.40 13.22 123.43 179.57 1614.92 56.22 1558.70 Pass 8411.74 8338.21 8900.00 8828.90 21.78 13.39 123.40 179.19 1657.07 56.49 1600.58 Pass 8510.74 8432.84 9000.00 8928.02 23.13 13.55 123.39 178.59 1698.73 56.75 1641.99 Pass 8606.69 8524.66 9100.00 9027.18 24.42 13.71 123.39 178.04 1739.82 57.02 1682.79 Pass 8701.94 8615.88 9200.00 9126.33 25.72 13.87 123.38 177.73 1780.68 57.44 1723.24 Pass 8786.16 8696.51 9300.00 9225.47 26.86 14.04 123.38 177.31 1821.71 57.80 1763.92 Pass 8867.54 8774.32 9400.00 9324.61 27.99 14.20 123.42 176.43 1863.15 58.04 1805.11 Pass 8967.77 8870.08 9500.00 9423.71 29.39 14.37 123.49 175.39 1905.10 58.47 1846.63 Pass 9069.72 8967.71 9600.00 9521.77 30.81 14.63 123.52 175.12 1951.59 59.17 1892.42 Pass 9155.76 9050.22 9700.00 9616.52 31.99 15.03 123.58 174.74 2008.84 59.93 1948.92 Pass 9248.04 9138.76 9800.00 9711.51 33.25 15.35 123.43 173.90 2063.62 60.32 2003.30 Pass 9350.23 9236.97 9900.00 9807.95 34.63 15.47 122.92 172.30 2100.17 60.79 2039.38 Pass 9467.99 9350.33 10000.00 9900.26 36.18 15.39 122.13 168.87 2116.33 61.75 2054.57 Pass 9595.32 9473.36 10100.00 9982.95 37.78 15.12 121.08 164.22 2110.78 63.65 2047.13 Pass 9702.30 9577.04 10200.00 10051.11 39.05 14.73 119.73 160.20 2084.79 66.59 2018.20 Pass • by BP Alaska Anticollision Report C7 ~.r s INTEQ Company: BP Amoco Date: 12/16!2006 Time: 20:37;34 Page: 4 Field: Endicott Reference Site: End MPI Co-ordinate(NE) Reference: Well: 1-39/P-17, True North Reference Well: 139lP-17 V ertical (TVD) Reference: 52:39 6/18!1988 00: 00 55.1 Reference Wellpath: Plan 11, 01 -39A/N-16 Db: Orate Site: End MPI Well: 1-61/Q-20 Rule Assigned: Major Risk Wellpath: Plan 1-61A/0-19 V1 Plan: 01-61 A/0-19 wp01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go .411owable MD 7'VD MD TVD Ref Offset TFC?+AZI TF0.HS Casing/H~istance Area Deviation Warning ft ft ft R ft ft .deg: deg in ft ft ft 9790.07 9662.31 10300.00 10100.69 40.06 14.26 118.09 157.33 2041.16 70.68 1970.48 Pass 9844.35 9715.13 10400.00 10128.74 40.67 13.76 116.19 155.73 1983.66 75.45 1908.21 Pass 9879.19 9749.05 10500.00 10139.59 41.06 13.26 114.15 154.03 1919.04 80.84 1838.20 Pass 9913.07 9782.05 10600.00 10149.47 41.44 12.81 111.96 151.99 1856.52 87.08 1769.44 Pass 9947.50 9815.62 10700.00 10159.35 41.82 12.43 109.64 149.46 1796.80 94.24 1702.56 Pass 9979.93 9847.25 10800.00 10167.70 42.17 12.10 107.15 146.77 1739.84 102.21 1637.62 Pass 10002.75 9869.51 10900.00 10167.62 42.42 11.80 104.39 143.86 1687.16 110.45 1576.71 Pass 10022.90 9889.17 11000.00 10165.50 42.63 11.63 101.31 140.49 1647.23 119.37 1527.87 Pass 10039.67 9905.55 11100.00 10161.73 42.81 12.09 97.96 136.91 1621.87 129.29 1492.58 Pass 10052.97 9918.53 11200.00 10156.35 42.95 13.11 94.46 133.23 1612.13 139.49 1472.65 Pass 10063.23 9928.55 11300.00 10149.63 43.06 14.27 90.93 129.56 1617.02 149.49 1467.52 Pass 10073.09 9938.18 11400.00 10142.75 43.17 15.56 87.45 125.93 1629.04 159.48 1469.55 Pass 10082.92 9947.79 11500.00 10135.88 43.27 16.89 84.02 122.37 1647.00 168.97 1478.02 Pass 10092.72 9957.36 11600.00 10129.00 43.38 18.24 80.68 118.89 1670.71 177.87 1492.84 Pass 10102.96 9967.37 11700.00 10122.12 43.47 19.61 77.45 115.43 1699.94 186.11 1513.83 Pass 10114.66 9978.81 11800.00 10115.24 43.53 21.00 74.34 111.86 1734.39 193.52 1540.86 Pass 10126.54 9990.41 11900.00 10108.36 43.59 22.40 71.36 108.41 1773.76 200.25 1573.51 Pass 10134.83 9998.52 12000.00 10101.49 43.59 23.79 68.52 105.09 1817.73 206.18 1611.55 Pass 10142.96 10006.44 12100.00 10094.61 43.57 25.17 65.82 101.86 1866.00 211.36 1654.63 Pass 10154.28 10017.43 12200.00 10087.73 43.50 26.46 63.31 97.87 1918.22 216.01 1702.21 Pass 10159.46 10022.39 12223.65 10086.10 43.43 26.68 62.77 96.31 1931.10 216.90 1714.20 Pass Site: End MPI Well: 2-12/Q-16 Rule Assigned: Major Risk Wellpath: 2-12/Q-16 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go' - Allowable - MD- TVD MD TVD Ref Offset TFO+AZI TFO-HS Casin~/I35Uistaece Area. beviation Warning ft :. ft ft ft ft _ft deg deg in ft ft ft __. 8261.80 8195.19 8200.00 8036.01 19.71 7.08 289.83 345.92 539.64 59.64 480.00 Pass 8356.37 8285.34 8300.00 8124.27 21.02 7.36 288.53 344.53 558.64 61.40 497.23 Pass 8450.28 8375.02 8400.00 8212.32 22.30 7.65 287.26 342.82 578.81 63.55 515.26 Pass 8544.51 8465.15 8500.00 8300.18 23.58 7.93 286.03 341.02 600.15 66.00 534.15 Pass 8639.39 8555.97 8600.00 8388.31 24.87 8.22 284.89 339.44 621.57 68.67 552.89 Pass 8736.11 8648.61 8700.00 8476.70 26.18 8.51 283.80 337.98 642.92 71.58 571.34 Pass 8835.31 8743.52 8800.00 8565.14 27.54 8.79 282.71 336.09 664.18 74.80 589.38 Pass 8930.93 8834.85 8900.00 8653.59 28.87 9.08 281.56 333.85 685.40 78.26 607.14 Pass 9022.03 8922.02 9000.00 8742.33 30.15 9.37 280.45 332.05 706.93 81.83 625.10 Pass 9115.56 9011.66 9100.00 8831.28 31.44 9.66 279.40 330.85 728.89 85.53 643.35 Pass 9209.91 9102.16 9200.00 8920.44 32.73 9.94 278.43 329.19 750.91 89.34 661.57 Pass 9301.22 9189.85 9300.00 9010.04 33.98 10.23 277.54 327.55 772.72 93.08 679.64 Pass 9393.89 9278.96 9400.00 9100.15 35.22 10.50 276.72 325.52 794.18 96.93 697.25 Pass 9478.99 9360.94 9500.00 9190.41 36.32 10.77 275.99 322.40 816.39 100.57 715.82 Pass 9563.62 9442.68 9600.00 9280.57 37.38 11.04 275.29 319.34 840.38 104.24 736.14 Pass 9648.84 9525.19 9700.00 9370.74 38.41 11.31 274.64 316.44 865.77 107.98 757.79 Pass 9734.95 9608.74 9800.00 9460.90 39.42 11.59 274.00 314.03 892.44 111.76 780.68 Pass 9823.33 9694.67 9900.00 9550.85 40.44 11.88 273.42 312.75 920.58 115.50 805.08 Pass 9916.70 9785.59 10000.00 9641.02 41.48 12.17 272.88 312.88 948.70 119.18 829.51 Pass 10007.66 9874.30 10100.00 9732.30 42.47 12.44 272.43 311.83 974.60 122.67 851.93 Pass • by BP Alaska Anticollision Report • ~.r B ~t~9 1NTEQ Company: BP Amoco Date: 1 2 /1 612 0 06 Time: 20:37:34 Page: 5 Fiehl: Endicott Reference Site: End MPI Co-ordinate(NE) Refe rence: Well: 1- 39/P-17, True North Reference VF'eq: 1-39/P-17 V ertical (TVD) Reference: 52:39 6/18/1988 00: 00 55.1 Reference Wellpath: Plan 11, 01-39A/N-16 Db: Oracle Site: End MPI Well: 2-14/0-1 6 Rule Assigned: Major Risk Wellpath: 2-14/0-1 6 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD 1VID TVD Ref< Offset TFO+AZI TFO-HS, Casing/fISOistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8315.09 8245.97 8300.00 8269.74 20.45 6.93 45.93 102.05 377.56 111.96 265.60 Pass 8408.55 8335.16 8400.00 8364.11 21.74 7.10 47.86 103.66 413.61 115.48 298.13 Pass 8501.99 8424.47 8500.00 8457.96 23.01 7.29 49.47 104.72 451.52 118.99 332.53 Pass 8594.13 8512.63 8600.00 8550.78 24.25 7.53 50.83 105.52 492.55 122.60 369.95 Pass 8684.18 8598.86 8700.00 8642.26 25.48 7.86 51.95 106.37 537.06 126.42 410.64 Pass 8772.68 8683.61 8800.00 8732.26 26.68 8.33 52.69 106.68 584.18 130.75 453.43 Pass 8861.09 8768.15 8900.00 8820.55 27.90 8.78 53.17 106.24 633.89 135.20 498.68 Pass 8950.62 8853.68 9000.00 8907.76 29.15 9.23 53.55 105.63 685.14 139.70 545.45 Pass 9038.53 8937.82 9100.00 8993.89 30.37 9.71 53.77 105.37 737.68 144.26 593.43 Pass 9123.87 9019.63 9200.00 9078.61 31.55 10.18 53.85 105.24 792.21 148.69 643.52 Pass 9208.91 9101.20 9300.00 9162.46 32.72 10.37 54.06 104.84 848.91 152.19 696.72 Pass 9292.68 9181.64 9400.00 9245.08 33.86 10.55 54.54 104.65 908.92 155.34 753.58 Pass 9375.26 9261.04 9500.00 9326.22 34.97 10.88 55.15 104.19 971.61 158.69 812.91 Pass 9462.39 9344.93 9600.00 9405.04 36.11 11.39 55.72 102.61 1036.94 162.61 874.32 Pass 9550.64 9430.14 9700.00 9482.12 37.22 11.79 56.20 100.61 1103.50 166.30 937.20 Pass 9638.93 9515.59 9800.00 9559.06 38.30 12.33 56.61 98.65 1169.36 170.37 998.99 Pass 9719.92 9594.14 9900.00 9631.10 39.25 12.72 56.91 97.14 1239.86 173.63 1066.23 Pass 9798.02 9670.04 10000.00 9703.82 40.15 12.76 57.26 96.38 1309.77 175.82 1133.96 Pass 9868.19 9738.34 10100.00 9778.07 40.94 12.90 57.52 97.29 1377.98 177.99 1199.98 Pass 9941.85 9810.11 10200.00 9852.74 41.75 13.01 57.76 97.62 1445.86 179.99 1265.88 Pass 10020.03 9886.37 10300.00 9927.75 42.60 13.26 57.99 97.22 1513.24 182.62 1330.63 Pass 10101.94 9966.37 10400.00 10002.69 43.46 13.73 58.20 96.22 1580.40 185.78 1394.61 Pass Site: End MPI W'eli: 2-28/P-1 9 Rule Assigned: Major Risk Wellpath: 2-28/P-1 9 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-(Go Allowable MD' TVD MD TVD Ref Offset TFO+AZI TFO-HS Casinj;/HSDistance Area Deviation Warning ft ft ft ft ft ft deg dt3g in ft ft ft 8261.58 8194.97 8400.00 8371.66 19.71 5.99 113.91 170.00 7.000 589.98 60.06 529.92 Pass 8351.35 8280.55 8500.00 8469.32 20.95 6.34 115.10 171.12 7.000 638.01 60.85 577.16 Pass 8442.18 8367.28 8600.00 8567.10 22.19 6.71 116.17 171.78 7.000 685.23 61.80 623.43 Pass 8532.93 8454.07 8700.00 8664.99 23.43 7.07 117.14 172.20 7.000 731.60 62.83 668.77 Pass 8623.41 8540.67 8800.00 8763.03 24.65 7.41 118.01 172.61 7.000 777.13 63.96 713.18 Pass 8713.20 8626.67 8900.00 8861.19 25.87 7.77 118.80 173.09 7.000 821.99 65.25 756.73 Pass 8799.06 8708.85 9000.00 8959.54 27.04 8.06 119.51 173.34 7.000 866.21 66.27 799.94 Pass 8883.88 8789.92 9100.00 9058.13 28.22 8.32 120.17 172.98 7.000 909.80 67.12 842.68 Pass 8980.74 8882.49 9200.00 9156.87 29.57 8.66 120.80 172.55 7.000 952.67 68.51 884.17 Pass 9077.42 8975.09 9300.00 9255.74 30.91 9.06 121.38 172.98 7.000 993.96 70.23 923.73 Pass 9170.41 9064.27 9400.00 9354.71 32.19 9.38 121.95 173.01 7.000 1034.00 71.74 962.26 Pass 9268.30 9158.21 9500.00 9453.81 33.53 9.76 122.53 172.84 7.000 1072.68 73.59 999.09 Pass 9365.60 9251.75 9600.00 9553.00 34.84 10.17 123.14 172.31 5.500 1109.78 75.56 1034.22 Pass 9471.31 9353.54 9700.00 9652.29 36.22 10.40 123.78 170.42 5.500 1145.61 77.28 1068.33 Pass 9581.95 9460.42 9800.00 9751.62 37.61 10.32 124.43 167.96 5.500 1180.09 78.19 1101.90 Pass 9690.58 9565.67 9900.00 9851.04 38.91 10.42 125.04 165.79 5.500 1212.95 79.63 1133.32 Pass 9800.57 9672.52 10000.00 9950.56 40.18 10.62 125.59 164.69 5.500 1244.10 81.39 1162.71 Pass 9903.14 9772.38 10100.00 10050.20 41.33 10.74 125.99 166.07 5.500 1273.52 82.52 1191.00 Pass 10007.47 9874.12 10200.00 10149.89 42.47 10.75 126.35 165.75 5.500 1302.29 83.33 1218.95 Pass 10115.05 9979.18 10300.00 10249.59 43.53 10.97 126.73 164.24 5.500 1330.20 85.08 1245.12 Pass 10150.00 10013.28 10400.00 10349.33 43.56 11.10 127.14 162.76 5.500 1358.85 86.05 1272.79 Pass 10160.00 10022.90 10500.00 10449.08 43.42 10.94 127.68 161.13 5.500 1392.79 85.94 1306.85 Pass 10165.95 10028.54 10530.10 10479.11 43.31 10.89 127.89 160.43 5.500 1404.08 85.53 1318.54 Pass by BP Alaska Anticollision Report ~.r ~irles INTEQ Company: BP Amoco Date: 12/16!2006 Time: 20:37:34 Page: 6 Field: Endicott Reference Site: End MPI Co-ordinate(NE) Reference: WeA: 1-39/P-17, True North Reference Well: 1-39/P-17 Vertical (TVD) Reference: 52:39 6/18/1988 00: 00 55.1 Reference Wellpath: Plan 11, 01-39A/N-16 Db: Orade Site: End MPI Well: 2-28/P-1 9 Rule Assigned: Major Risk Wellpath: 2-28/P-1 9 V4 Inter-Site Error: 0.00 ft Reference O ffset Semi-Major Axis Ctr-Ctr No-Go Allowable 141D TVD MD TVD Ref Offset TFO+AZI 1'FO-HS Casing/HSflistance Area Deviation Warning Site: End MPI Well: 2-28/P-1 9 Rule Assigned: Major Risk Wellpath: 2-28A/0-19 V1 later-Site Error: 0.00 ft Reference O ffset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVA MII TVD Ref Offset- TFO+AZI TF0.H5 Casing/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8261.58 8194.97 8400.00 8371.66 19.71 5.99 113.91 170.00 589.98 59.90 530.07 Pass 8351.35 8280.55 8500.00 8469.32 20.95 6.34 115.10 171.12 638.01 60.69 577.32 Pass 8442.18 8367.28 8600.00 8567.10 22.19 6.71 116.17 171.78 685.23 61.65 623.59 Pass 8532.93 8454.07 8700.00 8664.99 23.43 7.07 117.14 172.20 731.60 62.67 668.93 Pass 8623.41 8540.67 8800.00 8763.03 24.65 7.41 118.01 172.61 777.13 63.80 713.33 Pass 8713.20 8626.67 8900.00 8861.19 25.87 7.77 118.80 173.09 821.99 65.10 756.89 Pass 8799.06 8708.85 9000.00 8959.54 27.04 8.06 119.51 173.34 866.21 66.11 800.09 Pass 8883.88 8789.92 9100.00 9058.13 28.22 8.32 120.17 172.98 909.80 66.96 842.84 Pass 8980.74 8882.49 9200.00 9156.87 29.57 8.66 120.80 172.55 952.67 68.35 884.33 Pass 9077.42 8975.09 9300.00 9255.74 30.91 9.06 121.38 172.98 993.96 70.08 923.89 Pass 9170.41 9064.27 9400.00 9354.71 32.19 9.38 121.95 173.01 1034.00 71.58 962.41 Pass 9268.30 9158.21 9500.00 9453.81 33.53 9.76 122.53 172.84 1072.68 73.43 999.25 Pass 9365.60 9251.75 9600.00 9553.00 34.84 10.17 123.14 172.31 1109.78 75.46 1034.32 Pass 9471.10 9353.33 9700.00 9652.23 36.22 10.37 123.79 170.43 1146.02 77.04 1068.98 Pass 9577.19 9455.81 9800.00 9750.03 37.55 10.38 124.55 168.21 1188.75 78.29 1110.47 Pass 9667.80 9543.57 9900.00 9840.68 38.64 10.42 124.94 166.27 1250.43 79.29 1171.13 Pass 9747.07 9620.51 10000.00 9922.07 39.56 10.52 124.28 164.14 1322.10 79.82 1242.28 Pass 9819.91 9691.34 10100.00 9997.13 40.40 10.67 123.00 162.30 1393.25 80.58 1312.67 Pass 9879.61 9749.46 10187.76 10060.30 41.07 10.80 121.44 161.34 1449.64 81.84 1367.80 Pass Site: End MPI Well: 2-28/P-1 9 Rule Assigned: Major Risk Wellpath: 2-28B/0-19 V15 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD ' TVD Ref Offset TFO+AZI TFO-SS CasioE/HSUistagce Area Deviation Warning ft -ft ft ft ft ft deg deg in ft - ft ft 8260.41 8193.86 8400.00 8371.03 19.69 5.60 112.89 168.98 4.500 593.46 59.49 533.97 Pass 8343.42 8272.99 8500.00 8463.84 20.84 5.65 111.66 167.71 4.500 651.32 60.53 590.80 Pass 8421.85 8347.86 8600.00 8551.29 21.92 5.72 109.47 165.20 4.500 711.70 62.73 648.96 Pass 8494.93 8417.71 8700.00 8634.63 22.91 5.86 107.42 162.72 4.500 777.93 65.44 712.49 Pass 8560.10 8480.06 8800.00 8712.96 23.79 6.23 105.64 160.54 4.500 850.97 68.30 782.67 Pass 8616.98 8534.50 8900.00 8785.31 24.56 6.83 104.24 158.86 4.500 931.39 70.95 860.43 Pass 8667.79 8583.17 9000.00 8854.11 25.25 7.56 103.49 157.96 4.500 1017.52 72.82 944.70 Pass 8718.66 8631.90 9100.00 8924.39 25.94 8.29 102.95 157.21 4.500 1102.99 74.46 1028.53 Pass 8771.84 8682.81 9200.00 8998.68 26.67 9.03 102.66 156.66 4.500 1186.13 75.85 1110.29 Pass 8828.42 8736.93 9300.00 9076.06 27.45 9.77 102.43 155.90 4.500 1266.59 77.31 1189.28 Pass 8887.44 8793.32 9400.00 9155.24 28.27 10.52 102.11 154.88 4.500 1344.68 79.01 1265.67 Pass 8959.23 8861.91 9500.00 9234.38 29.27 11.31 101.70 153.69 4.500 1421.73 81.28 1340.45 Pass 9026.98 8926.76 9600.00 9310.85 30.21 12.19 101.30 152.90 4.500 1501.06 83.59 1417.47 Pass 9089.89 8987.04 9700.00 9386.00 31.09 13.10 101.08 152.68 4.500 1582.53 85.51 1497.02 Pass 9149.57 9044.28 9800.00 9461.63 31.91 14.00 101.12 152.32 4.500 1664.47 86.95 1577.53 Pass 9213.17 9105.29 9900.00 9538.04 32.78 14.88 101.02 151.76 4.500 1744.86 88.75 1656.11 Pass 9276.38 9165.98 10000.00 9608.84 33.64 15.91 100.68 150.92 4.500 1828.20 91.10 1737.10 Pass 9335.03 9222.35 10100.00 9674.88 34.43 16.92 99.98 149.55 4.500 1910.40 94.04 1816.36 Pass 9393.61 9278.69 10200.00 9739.35 35.22 17.90 99.12 147.93 4.500 1990.35 97.33 1893.02 Pass • i by BP Alaska Anticollision Report ~.. INTEQ Company: BP Amoco Date: 12/16/2006 Time: 20:37:34 Page: 7 Field: Endicott Reference Site: End MPI Co-ordinateiNE) Reference: Well: 1-39/P-17, True North Reference Well: 1 39/P-17 Y erdcal (TVD) Reference: 52:39 6/18/1988 00: 00 55.1 Reference Welipath: Plan 11, 01-39AtN-16 Db: Orade Site: End MPI Well: 2-28/P-19 Rule Assigned: Major Risk Welipath: 2-28B/0-19 V15 Inter-Site Error: 0.00 ft Reference Offset Se-ni-Major Axis Ctr-Ctr No-Go Allowable ]4iD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglllSDistance Area Deviation Warning ft ft ft ft ft ft .deg deg ' in ft ft ft 9475.68 9357.75 10300.00 9804.46 36.28 18.87 98.36 144.87 4.500 2069.00 101.27 1967.73 Pass 9564.06 9443.11 10400.00 9871.63 37.39 19.82 97.71 141.74 4.500 2146.35 105.31 2041.04 Pass 9654.71 9530.88 10500.00 9942.72 38.48 20.76 97.29 138.94 4.500 2223.00 109.13 2113.87 Pass 9746.28 9619.74 10600.00 10016.74 39.55 21.68 96.91 136.78 4.500 2296.67 112.91 2183.75 Pass 9829.48 9700.65 10700.00 10092.02 40.50 22.61 96.58 135.97 4.500 2369.37 116.33 2253.05 Pass 9901.07 9770.37 10800.00 10168.19 41.31 23.54 96.32 136.41 4.500 2442.32 119.13 2323.19 Pass 9983.70 9850.92 10900.00 10246.69 42.21 24.43 96.13 135.73 4.500 2512.86 122.11 2390.75 Pass 10075.39 9940.43 11000.00 10326.70 43.19 25.24 95.96 134.41 2581.13 125.33 2455.81 Pass 10130.00 9993.80 11058.25 10373.60 43.60 25.48 95.88 132.80 2620.20 128.30 2491.90 Pass Site: End MPI Well: 2-34/P-14 Rule Assigned: Major Risk Welipath: 2-34/P-14 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais ` Ctr-Ctr No-Go Allowable YID TVD MD TVD ,Ref Otfset TFO+AZI TFO-HS Casing/H~istauce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft - - 8314.21 8245.13 8300.00 8011.08 20.44 11.43 334.95 31.08 906.26 100.02 806.24 --- - Pass 8407.15 8333.83 8400.00 8095.78 21.72 11.48 334.70 30.52 932.32 101.32 831.00 Pass 8501.11 8423.63 8500.00 8180.73 23.00 11.59 334.45 29.71 958.23 102.70 855.53 Pass 8596.72 8515.11 8600.00 8265.82 24.29 11.75 334.18 28.87 984.01 104.21 879.79 Pass 8691.49 8605.87 8700.00 8351.11 25.57 11.90 333.90 28.29 1009.52 105.59 903.93 Pass 8793.46 8703.50 8800.00 8436.41 26.96 12.36 333.63 27.52 1034.92 108.22 926.70 Pass 8899.32 8804.66 8900.00 8521.60 28.43 12.79 333.42 26.06 1059.95 110.75 949.20 Pass 8990.60 8891.92 9000.00 8606.71 29.71 13.24 333.22 24.86 1085.21 113.00 972.21 Pass 9081.41 8978.91 9100.00 8691.59 30.97 13.75 332.99 24.59 1111.63 115.50 996.13 Pass 9177.42 9070.99 9200.00 8776.09 32.29 14.32 332.80 23.81 1139.16 118.21 1020.95 Pass 9268.98 9158.87 9300.00 8860.24 33.54 14.87 332.61 22.91 1167.51 120.74 1046.77 Pass 9362.82 9249.08 9400.00 8944.42 34.80 15.20 332.44 21.65 1196.31 122.35 1073.97 Pass 9453.66 9336.52 9500.00 9028.75 35.99 15.51 332.31 19.45 1225.13 123.76 1101.37 Pass 9541.77 9421.56 9600.00 9113.39 37.11 15.75 332.14 16.80 1253.98 124.53 1129.46 Pass 9629.79 9506.73 9700.00 9198.65 38.19 16.02 331.95 14.23 1282.52 125.26 1157.26 Pass 9718.05 9592.33 9800.00 9284.59 39.23 16.31 331.75 12.01 1310.52 125.94 1184.58 Pass 9803.75 9675.62 9900.00 9371.23 40.21 16.64 331.56 10.69 1338.11 126.70 1211.40 Pass 9890.77 9760.33 10000.00 9458.26 41.19 17.01 331.36 11.37 1365.88 127.66 1238.22 Pass Site: End MPI Well: 2-48/0-13 Rule Assigned: Major Risk Welipath: 2-48/0-13 V1 Inter-Site Error: 0.00 ft Reference Offsef Senti-Major Aais Ctr-Ctr No-Go Allowable MD TV'D MD TVD Ref. Offset TFO+AZI TFO-HS Casing/H9Astance Area Deviation Warning ft ft ft ft ft ft deg deg in -ft fl ft 8318.30 8249.03 8000.00 7780.22 20.49 22.17 302.85 358.96 1556.07 - 64.04 - 1492.03 Pass 8409.86 8336.41 8100.00 7876.98 21.75 22.50 302.84 358.64 1551.26 64.38 1486.88 Pass 8502.43 8424.89 8200.00 7973.85 23.01 22.82 302.82 358.07 1546.51 64.69 1481.82 Pass 8598.00 8516.34 8300.00 8070.80 24.31 23.14 302.79 357.46 1541.81 65.07 1476.74 Pass 8693.40 8607.70 8400.00 8167.87 25.60 23.45 302.72 357.11 1536.92 65.56 1471.37 Pass 8800.88 8710.60 8500.00 8265.02 27.07 23.76 302.64 356.44 1531.54 66.06 1465.49 Pass 8907.99 8812.94 8600.00 8362.20 28.55 24.06 302.60 355.14 1525.52 66.46 1459.06 Pass 8995.57 8896.68 8700.00 8459.45 29.78 24.36 302.53 354.13 1519.44 66.85 1452.59 Pass 9086.93 8984.21 8800.00 8556.78 31.05 24.66 302.41 354.01 1513.66 67.44 1446.22 Pass 9184.56 9077.84 8900.00 8654.21 32.39 24.96 302.30 353.26 1507.87 68.16 1439.72 Pass 9274.91 9164.57 9000.00 8751.65 33.62 25.25 302.16 352.41 1502.34 68.86 1433.48 Pass by BP Alaska Anticollision Report • ~.r s INTEQ Company: BP Amoco Date: 12/16/2006 Time: 20:37:34 Page: 8 Field: Endicott Reference Site: End MPI Co-ordinate(NE) Reference: Well: 1- 39/P-17, True North Reference Wei{: 1- 39/P-17 Vertical (TVD}Reference: 52:39 8!18!1988 00: 00 55.1 Reference Wellpath: Pl an 11, 01- 39A1N-16 Db: Oracle Site: End MPI Well: 2-48/0-13 Rule Assigned: Major Risk Wellpath: 2-48/0-13 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Azis Ctr-Ctr No-Go .411owable hID TVD MD TVD Rei Offset TFO+A2I TFO-HS Casing/HSflistance Area Deviation Warning ft R ft ft ft ft deg deg in ft ft ft 9368.35 9254.39 9100.00 8848.51 34.88 25.55 302.06 351.20 1499.86 69.71 1430.15 Pass 9454.34 9337.17 9200.00 8944.89 36.00 25.88 302.00 349.13 1499.78 70.56 1429.22 Pass 9537.01 9416.96 9300.00 9041.49 37.05 26.21 301.88 346.67 1500.07 71.45 1428.62 Pass 9620.05 9497.30 9400.00 9138.50 38.07 26.52 301.66 344.18 1499.82 72.57 1427.25 Pass 9705.05 9579.71 9500.00 9235.71 39.08 26.82 301.40 341.83 1499.84 73.88 1425.96 Pass 9789.74 9661.99 9600.00 9332.95 40.05 27.12 301.12 340.37 1500.75 75.28 1425.47 Pass 9881.19 9751.00 9700.00 9429.93 41.09 27.44 300.82 340.72 1503.54 76.66 1426.88 Pass 9971.81 9839.33 9800.00 9524.27 42.08 27.86 300.72 340.40 1515.58 78.00 1437.58 Pass Site: End MPI Well: 2-48/0-13 Rule Assigned: Major Risk Wellpath: 2-48/O13PH V3 Inter-Site Error: 0.00 ft Reference Offset: Semi-.Major Axis .- ` Ctr-Ctr No-Go Allowable '14ID TVD `MD TVD Ref OtI'set TFO+A71 TF0-HS Casing/HSflistaace Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8318.30 8249.03 8000.00 7780.22 20.49 22.17 302.85 358.96 1556.07 64.04 1492.03 Pass 8409.86 8336.41 8100.00 7876.98 21.75 22.50 302.84 358.64 1551.26 64.38 1486.88 Pass 8502.43 8424.89 8200.00 7973.85 23.01 22.82 302.82 358.07 1546.51 64.69 1481.82 Pass 8598.00 8516.34 8300.00 8070.80 24.31 23.14 302.79 357.46 1541.81 65.07 1476.74 Pass 8693.40 8607.70 8400.00 8167.87 25.60 23.45 302.72 357.11 1536.92 65.56 1471.37 Pass 8800.88 8710.60 8500.00 8265.02 27.07 23.76 302.64 356.44 1531.54 66.06 1465.49 Pass 8907.99 8812.94 8600.00 8362.20 28.55 24.06 302.60 355.14 1525.52 66.46 1459.06 Pass 8995.57 8896.68 8700.00 8459.45 29.78 24.36 302.53 354.13 1519.44 66.85 1452.59 Pass 9086.93 8984.21 8800.00 8556.78 31.05 24.66 302.41 354.01 1513.66 67.44 1446.22 Pass 9184.56 9077.84 8900.00 8654.21 32.39 24.96 302.30 353.26 1507.87 68.16 1439.72 Pass 9274.91 9164.57 9000.00 8751.65 33.62 25.25 302.16 352.41 1502.34 68.86 1433.48 Pass 9368.36 9254.40 9100.00 8848.41 34.88 25.56 302.07 351.21 1500.20 69.72 1430.48 Pass 9454.34 9337.17 9200.00 8943.96 36.00 25.93 302.06 349.19 1503.02 70.58 1432.44 Pass 9536.77 9416.72 9300.00 9038.17 37.05 26.35 302.06 346.85 1511.13 71.48 1439.65 Pass 9619.00 9496.28 9400.00 9130.39 38.06 26.85 302.07 344.61 1525.69 72.65 1453.04 Pass 9702.05 9576.80 9500.00 9219.88 39.04 27.45 302.13 342.60 1547.46 73.97 1473.49 Pass 9782.85 9655.29 9600.00 9305.97 39.97 28.15 302.27 341.62 1576.49 75.32 1501.17 Pass 9866.97 9737.15 9700.00 9388.31 40.93 28.97 302.44 342.20 1612.61 76.59 1536.02 Pass 9949.31 9817.39 9800.00 9467.09 41.83 29.87 302.67 342.48 1654.56 77.82 1576.74 Pass Site: End MPI Well: 2-62/Q-17 Rule Assigned: Major Risk Wellpath: 2-62/(1-17 V1 Inter-Site Error: 0.00 ft Reference..' Offset Semi-MajorAzis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS 'Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8315.10 8245.98 8400.00 8324.24 20.45 6.71 188.82 244.95 612.92 110.45 502.47 Pass 8408.72 8335.32 8500.00 8418.14 21.74 7.12 188.70 244.50 649.35 115.01 534.34 Pass 8501.20 8423.71 8600.00 8511.15 23.00 7.59 188.87 244.12 686.51 119.72 566.79 Pass 8592.44 8511.01 8700.00 8603.19 24.23 8.07 189.24 243.94 724.88 124.47 600.41 Pass 8684.11 8598.80 8800.00 8694.37 25.47 8.56 189.73 244.15 764.21 129.35 634.86 Pass 8772.46 8683.40 8900.00 8784.56 26.68 9.05 190.33 244.32 804.85 134.14 670.71 Pass 8857.83 8765.03 9000.00 8874.25 27.85 9.29 190.96 244.08 846.13 138.08 708.04 Pass 8945.40 8848.69 9100.00 8964.13 29.08 9.37 191.54 243.68 887.39 141.60 745.79 Pass 9036.79 8936.15 9200.00 9054.21 30.35 9.39 192.09 243.69 928.41 145.10 783.31 Pass 9128.85 9024.41 9300.00 9145.05 31.62 9.43 192.54 243.90 967.93 148.62 819.31 Pass 9219.42 9111.28 9400.00 9236.95 32.86 9.48 192.91 243.60 1005.58 152.03 853.55 Pass 9311.56 9199.79 9500.00 9329.64 34.11 9.56 193.22 243.10 1041.74 155.52 886.22 Pass by BP Alaska Anticollision Report ~.r INTEQ Company: BP AmoCA Date: 12/16/2006 Time: 20:37:34 Page: 9 Field: Endicott Reference Site: End MPl Co-ordinate~NE) Reference: Well: 1-39/P-17, True North Reference Well: 1-39/P-17 Vertical (TVD)Reference: 52:39 6/18/1988 00: 00 55.1 Reference Weiipath: Plan 11, 01 -39AlN-16 Db: Orade Site: End MPI Well: 2-62/Q-17 Rule Assigned: Major Risk Wellpath: 2-62/Q-17 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr lYo-Go Allowable MD TVD MD TVD Ref Offset TFO+A2;I TF0.HS Casiag/HSDistance Area Deviation Warning ft ft ft ft ft ft deg dt3g in ft ft ft 9401.36 9286.14 9600.00 9423.31 35.32 9.65 193.48 242.08 1075.88 158.88 917.00 Pass 9490.14 9371.70 9700.00 9517.86 36.47 9.76 193.74 239.83 1108.30 162.08 946.22 Pass 9580.25 9458.78 9800.00 9613.14 37.59 9.88 193.98 237.55 1139.42 165.20 974.22 Pass 9671.15 9546.83 9900.00 9708.83 38.68 10.05 194.23 235.46 1169.66 168.40 1001.26 Pass 9766.44 9639.33 10000.00 9804.81 39.79 10.23 194.48 234.06 1198.97 171.71 1027.26 Pass 9868.85 9738.98 10100.00 9900.93 40.95 10.38 194.69 234.48 1227.56 175.11 1052.45 Pass 9968.93 9836.52 10200.00 9997.08 42.05 10.61 194.93 234.62 1255.58 178.71 1076.87 Pass 10065.38 9930.65 10300.00 10093.29 43.08 10.81 195.19 233.79 1283.29 181.97 1101.33 Pass 10141.22 10004.75 10400.00 10189.61 43.58 11.00 195.50 231.65 1310.93 183.91 1127.02 Pass 10160.00 10022.90 10500.00 10285.93 43.42 11.01 195.71 229.16 1342.10 184.01 1158.09 Pass 10170.00 10032.33 10600.00 10382.56 43.24 10.99 195.68 227.70 1377.63 183.78 1193.85 Pass 10180.00 10041.51 10700.00 10479.26 43.02 10.98 195.46 226.46 1418.14 183.26 1234.88 Pass 10193.64 10053.57 10800.00 10575.77 42.66 10.82 195.14 225.14 1463.86 181.45 1282.41 Pass 10203.60 10061.99 10900.00 10672.24 42.36 10.75 194.69 224.13 1514.38 180.01 1334.37 Pass 10210.00 10067.21 10956.89 10727.12 42.16 10.70 194.40 223.53 1545.04 178.83 1366.21 Pass ~ • • a Attachment 3-Coil Tubing Dri1R~g Stack Configuration ., BOP-Tree .00 ---. 7-1h6" 5000 psi BOP's lD = 7.06" 7.73 -~ 8.23 _~ ~ 9.17 -----. Choke 11.°.0 ~ ~ 12.85 -~ ~ 22.50 Tree Size 0 ar ~_ 4 1116 SC.u: rs (~X-3-.. Swab Valve No Turns 23-112 . ~~ ~~ :n~,ut ~ turns SSV 24.50 T`-"'~ Master Valve No Turns 23-112 nput $ turns ~~ Tubing Hanger 26.50 Base Flange Kill Endicott 1-39/P-17 RWO Sundry Notice / PTD #1880630 Page 5 of 5 ' ' -Alaska Department of Natural Resources Land Administration System Page 1 of 6 ` .~(aska Mapper Land RecordslStatus Fiats Recorder's Search State Cabins +'~~` eS€tEAPCeS Alaska D Case srct File Type: ADL File Number:... 34633 [Printable Case File Abstract See Township, Range, Section and Acreage? C- Yes No New Search LA_S____Menu_ i Case Summary ~ Case Detail ~ Land Abstract File: ADL 34633 `~`'~''~ As of 12/26/2006 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 03/13/1967 Total Acres: 2560.000 Date Initiated: 12/23/1966 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/31/2002 Case Subtype: NS NORTH SLOPE Last Transac Meridian: U Plats Meridian: U Meridian: U Meridian: U Lion: CDESTAND Township: 012N Township: 012N Township: 012N Township: 012N STATUS CODE STANDARDIZED Range: 016E Section: 25 Section Acres: 640 Search Range: 016E Section: 26 Section Acres: 640 Range: 016E Section: 35 Section Acres: 640 Range: 016E Section: 36 Section Acres: 640 Case Actions 12-23-1966 TRACT DEFINED SALE DATE O 1-24-1967 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 18 TRACT NUMBER 12 FORM NUMBER 5 DL-lOCTOBER 1963 CONDITIONAL Y/N N PRIMARY TERM 10 http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=034633... 12/26/2006 ~~ Alaska Department of Natural Resources Land Administration System 01-24-1967 BID RECEIVED STATUS (12) 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE TOTAL BONUS BID 6476.800000 DEPOSIT AMOUNT 1295.360000 ROYALTY SHARE % 12.500000 BP EXPLORATION USA INC., 100% 01-24-1967 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER OLD CID # (SALE NO) 4566 01-24-1967 INITIAL OWNER SEGMENT CODE 1 107377 BP EXPLORATION USA I SALE 18 CID NUMBER 000107377 BP EXPLORATION USA I WORKING INTEREST % 100 ROYALTY INTEREST % 87.500000 01-24-1967 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000004566 SALE 18 ROYALTY INTEREST % 12.500000 01-26-1967 LEASE AWARDED STATUS (13) 13 LEASE AWARDED 03-13-1967 LEASE ISSUED EFFECTIVE DATE 04-01-1967 EXPIRATN DATE 03-31-1977 STATUS (20) 20 ACTIVE 02-17-1969 CUSTOMER CHANGED NAME NEW NAME: BP OIL CORPORATION OLD NAME: BP EXPLORATION USA INC 01-28-1974 CUSTOMER CHANGED NAME NEW NAME: SOHIO PETROLEUM COMPANY OLD NAME: BP OIL CORPORATION 04-08-1974 COMMENTS NOTICE TO LESSEE: PATENT RECEIVED EFFECTIVE 03-27-1974 AND LEASE TERM FOR ADL 34633 EXTENDED TO EXPIRE 03-27-1984. 08-29-1974 COMMENTS Page 2 of 6 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=034633... 12/26/2006 "° Alaska Department of Natural Resources Land Administration System Page 3 of 6 NOTICE OF 04-08-74 VACATED IN PART. ADL 34633 IS ALL TIDE & SUBMERGED LAND AND PATENT WILL NOT EFFECT TERM OF LSE. LSE EXPIRES 03-31- 77. 04-12-1977 COMMENTS DRILLING COMMENCED ON SAG DELTA NO. 4 (36-12-16) ON 03-30-1977. THEREFORE, LEASE EXTENDED PER LESSEE REQUEST. 02-26-1979 CUSTOMER CHANGED NAME NEW NAME: SOHIO NATURAL RESOURCE COMPANY OLD NAME: SOHIO PETROLEUM COMPANY 02-21-1980 CUSTOMER CHANGED NAME NEW NAME: SOHIO ALASKA PETROLEUM COMPANY OLD NAME: SOHIO NATURAL RESOURCE COMPANY 08-28-1981 UNITIZED EFFECTIVE DATE 04-01-1977 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNIT ACRES 2560 LEASE TERM EXTENDED PER ARTICLE 3.4 OF UNIT AGREEMENT. 09-19-1985 ELIMINATED FROM UNIT EFFECTIVE DATE 02-22-1985 EXPIRATN DATE 01-01-1901 UNIT CODE PB PRUDHOE BAY ADL 34633 ELIMINATED FROMPRUDHOE BAY UNIT & SIMULTANEOULSY COMMITTED TO DUCK ISLAND UNIT, HENCE NO EXPIRATION DATE. 09-19-1985 UNITIZED EFFECTIVE DATE 02-22-1985 UNIT CODE DI DUCK ISLAND TOTAL ACRES 2560 UNIT ACRES 2560 LEASE TERM EXTENDED PER PARAGRAPH S OF LEASE. 09-19-1985 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 02-22-1985 UNIT CODE DI DUCK ISLAND TOTAL ACRES 2560 UNITIZED ACRES 2560 PARTICIPATING ACRES 2560 LEASE ENTIRELY WITHIN ENDICOTT PARTICIPATING AREA. MINIMUM ROYALTY http://www.dnr.state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=034633... 12/26/2006 "` Alaska Department of Natural Resources Land Administration System Page 4 of 6 ~ i FOR PERIOD 04-01-86 TO 04-01-87 DUE BY 04-01-87. 03-25-1986 CUSTOMER CHANGED NAME NEW NAME: STANDARD ALASKA PRODUCTION COMPANY OLD NAME.• SOHIO ALASKA PETROLEUM COMPANY 09-09-1987 COMMENTS PUBLIC NOTICE THAT STANDARD ALASKA PRODUCTION COMPANYHAS FILED AN APPLICATION FOR REDUCED ROYALTYRATE ONSAG DELTA NO. 4 DISCOVERY WELL 09-OZ-1988 COMMENTS SAG DELTA 34633 NO. 4 WELL CERTIFIED AS DISCOVERY WELL, LEASE GRANTED FIVE PERCENT DISCOVERYROYALTYRATE MARCH 1, 1978 THRUFEB. 29, 1988. 09-02-1988 WELL CERTIFIED CAPABLE OF PRODUCING EFFECTIVE DATE 02-15-1978 SAG DELTA NO. 4 DISCOVERY WELL ENDICOTT STRUCTURE. 10-06-1988 COMMENTS LETTER FROM STANDARD ALASKA PRODUCTION. THEY FIGURED THE TOTAL ADJUSTMENT FOR DISCOVERY ROYALTY TO BE $2.4 MILLION. 01-31-1989 CUSTOMER CHANGED NAME NEW NAME: BP EXPLORATION (ALASKA) INC OLD NAME: STANDARD ALASKA PRODUCTION COMPANY 12-09-1989 COMMENTS BP EXPLORATION (ALASKA.) INC. HAS FILED WITHAOGCC, ANAPPLICATION FOR EXCEPTION TO 20 AAC 25.055. 12-28-1989 COMMENTS BP (ALASKA) EXPLORATION INC'S APPLICATION FOR EXCEPTION TO 20 AAC ZS.OSS HAS BEENAPPROVED. 04-26-1990 COMMENTS SAG DELTA WELL #9 LEASE PLAN OF OPERATIONS INTERIM ALLOCATION OF COSTS AND PRODUCTION D URING LONG TERM TESTING. 09-20-1991 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 08-12-1991 UNIT CODE DI DUCK ISLAND TOTAL ACRES 2560 UNITIZED ACRES 2560 PARTICIPATING ACRES 159.790000 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=034633... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 5 of 6 FORMATION OF THE SAG DELTA NORTH PA- LEASE PARTIALLY WITHIN PA -ACREAGE UPDATED WITH BP PLAT 10/91 12-19-1996 COMMENTS UPPER NET PROFITS ROYALTYINTEREST (NPRI) CONVEYANCE BETWEEN BP ALASKA INC. AND BP EXPLORATION (ALASKA) INC. PLACED IN CASE FILE. 02-19-1998 AOGCC APPLICATION RECEIVED BP REQUESTED AN EXCEPTION TO 20AAC25.055 ON 2/9/98 FOR DRILLING AN EXPLORATORY WELL WHOSE SURFACE LOCATIONIS WITHIN THIS LEASE. 08-08-2000 COMMENTS CONVEYANCE & MERGER (UPPER LOWER NPRI & UPPER NPRI) DOC. DATED 6/30/00 BETWEEN STANDARD OIL & BP EXPLORATION WAS PLACED IN THE CASE FILE. 01-02-2001 COMMENTS OVERRIDING ROYALTYINTERESTSARE NOT TRACKED AFTER INITIAL SEPARATION FROM THE WORKING INTEREST. CHECK THE APPROPRIATE RECORDER'S OFFICE. 12-31-2002 STATUS CODE STANDARDIZED STATUS CODE 35 ISS/APPRV/ACTV AUTH * * * * * STATUS CODE STANDARDIZATION * STATUS CODE CHANGED BYBATCH UPDATE Legal Description 12-23-1966 * * * SALE NOTICE LEGAL DESCRIPTION C18-12 T. 12N., R. 16E., U.M. SECTION 25: ALL 640 ACRES SECTION 26: ALL 640 ACRES SECTION 35: ALL 640 ACRES SECTION 36: ALL 640 ACRES CONTAINING 2, 560 ACRES, MORE OR LESS. ********************************************************************** 9-20-91 * *PARTICIPATING AREA LEGAL DESCRIPTION* http:/1www. dnr.state. ak.us/las/Case_Abstract. cfm?FileType=ADL&FileNumber=034633... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 6 of 6 DUCK ISLAND UNIT- PORTION OF TRACT 13 WITHIN THE SAG DELTA NORTH PA T12N, R16E, UM SECTION 25: NEI/4; CONTAINING 159.79 ACRES, MORE OR LESS. t1 Cc"iS+@ $~1"c'6C~ Last updated on 12/26/2006. Not sure who to contact? Have a question about DNR? Visit the 3'ubiie Ini"ormaton Center. Report technical problems with this page to the Web~r~aster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all _C___QflKIES must be accepted. Sta#e otAlaska Natural Resources LAS Name Copyright Privacy System Status http: //www.dnr.state. ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=03463 3... 12/26/2006 Re: MPD on Endicott 1-39 (206-187) Subject: Re: MPD on Endicott 1-39 (206-187) From: Thomas Maunder <tom_maunder cr admin.state.ak.us% Date: Wed, 03 Jan 2007 1.03.0:29 -0900 ~I'o: "Sather. Gr~~T J" °~=Sarher.iG~c~.BP.com> Greg, Thanks for the information. Interesting application. Sort of a reverse on MPD as previously accomplished. Your experience with the benefit of higher mud weights is similar to one of the management techniques for the problematic Cook Inlet coals. I will include a copy of this message in the file. Nothing further is needed. Good luck with the operations. Tom Maunder, PE AOGCC Sarber, Greg J wrote, On 1/3/2007 10:16 AM: ', Tom, You may have received the permit to drill application for Endicott 1-39. One thing that I did not '; include in the PTD application is the fact that we are considering using MPD techniques while drilling this well. The reasons for using this technique are based on our last CTD drilling program at Endicott in 2004. In 2004 we planned to drill 3 CTD sidetracks from 3 parent wells; 1 lateral from each parent wellbore. It took a total of 8 lateral attempts to deliver the 3 complete lateral sections. The reasons for the extra laterals were due to hole instability problems. These problems were apparent in both the coal and shale sections of the hole. We had inadvertent sidetracks at washouts. We had hole caving which caused sticking problems, and in 1 case caused us to lose a BHA. There were very challenging drilling conditions encountered during this program. It was our first attempt to drill in the Endicott field with coil tubing, and we did learn quite a bit about how to drill in this reservoir. Some improvement was seen by increasing mud weight during the course of the drilling program. However, even with mud weight @ 10, ppg, which was above the original formation reservoir pressure, there were still some problems experienced with the coals and shales. For Endicott 1-39 we plan a 2 stage approach to preventing a repeat of the problems seen in 2004. First, we plan to mill a 3.80" window in the parent wellbore and drill the build section with a 3.75" x 4.125" bi-center bit. The build section will cross several known problematic coal and shale intervals. We will TD the 4.125" hole in the K2B sand which is our target sand. The length of the build section will be short, and this should minimize the time that the problematic intervals are exposed. Once we TD the build section we will run and cement a 3-3/16" protection liner, then drill to TD with a 2.70" x 3.0" bi-center bit. This strategy should minimize the exposure to the coals, however there is the chance to encounter small 1'-2' shales within the target sand. These small shales were also problematic in the 2004 campaign. There is also the possibility of exiting the target sand either from sub seismic faulting, or due to unforeseen formation dip changes. To mitigate these risks, we are considering using MPD techniques to minimize the pressure surges the exposed shales and coals are exposed to. The current reservoir pressure is 4369 psi at 10,000' (8.4 ppg). The original reservoir pressure was 4850 psi (9.3 ppg). In the 2004 campaign, they used 10 ppg mud on the final well with better hole conditions observed. The ECD when drilling with this mud was 11.0 ppg. There were no fluid losses to the formation at this ECD. It is our intention to maintain 11.0 ppg on the formation during 1 of 2 1/3/2007 10:44 AM Re: MPD on Endicott 1-39 (206-187) '! the drilling phase on both the 4.125" and 3" open hole sections. This will be accomplished by using a near 10 ppg Flopro mud system, and using the MPD drilling choke currently a part of the rig kit for drilling in Kuparuk. The technique will be to adjust mud weight so that with pumps on we have 0 choke pressure at surface, and 11.0 ppg ECD at TD. When the pumps are shut down, and when tripping we will use the surface drilling choke to maintain a constant bottom hole pressure. It is planned that this constant bottom hole pressure at 11.0 ppg (5720 psi at 10,000') will provide the best possible hole conditions for drilling this well. It should be mentioned that unlike the current Kuparuk MPD drilling campaign, we will have KWF in the hole at all times. There should be no need for additional tankage of KWF at location. The main purpose of the MPD drilling technique on this well is to provide a constant bottom hole pressure higher than the original reservoir pressure to maintain control of the coals and shales. Please let me know if you see any problems with this technique, or need any clarification. Cheers, Greg Sarber - PE Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberlq(c~bp.com 2 oft 1/3/2007 10:44 AM Terri L. Hu~~le BP Exploration AK Inc.... PO Box 1-96612 MB 7-5 Anchorage, AK 99519 "Mastercard Check" ss-sn z52 319: `~ 2~ v~ DATE • • TRAYS1d~IT~'AL LET'I'E12 CHECKLIST' WELL >r'AN[E E~Y4 1-39A~i/-I6 PTD# ao6 - ~p~ ~ ®evelopment Service Exploratory Stratlgraphic Test iYon-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK + ADD-ONS WHAT ~ (OPTIONS) APPLES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ well j ~~ (If last two digits in Permit No. , AP[ No. ~0- - - i API number are Production should continue to be reported as a function of the between 60-69) ~ I original API number stated above. i ' - iPILOT HOLE (n accordance with 20 AAC 2~.00~(f), all records, data and logs I ;acquired for the pilot hole must be clearly differentiated in both j i ;well name ( PH) and API number ~ ! ; (30_ _ -_~ from records, data and logs ~ acquired for well i SPACING The permit is approved subject to full compliance with 20 AAC ~ ay~~y ,' EXCEPTION ~ 25.055. Approval to perforate and produce /inject is contingent I ~~~ ~~lG i I upon issuance of a conservation order approving a spacing j ~~~ ~a~.Q~ I exception. assumes the ~ ~~ i liability of any protest to the spacing exception that may occur. t ,DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in SA!~tPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. ;Please note the following special condition of this permi*__ Non-Conventional ' I ~ production or production testing of coal bed methane is not allowed j Well ~ for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data ,' on water quality and quantity. (Company Name) must contact the 'Commission to obtain advance approval of such water well testing I _ program. ! Rev: t 2~i06 C ^ jody~transmittal_checkl ist • • -1 ~1 : I ~ a, o i a N N : ~ a~ D . ~ ~ ~ ~ Q ~ N, : , c ~ O ~ m 3' ~ f0 ~ '~ rn c ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ c ~ ~ cn ° u.l 3. v; a ~ ' n pi O a>' > ~ c' i ! L~ O. O, ~ 7 E O c. ~ •o: ~ ~ ~ , ~ 3. t, ~ o? c~ c. . o . , a~, ~, ~ c. c. ~, ~ : o ~ ~ i ~ c = ~ ~ ~~ ~ _ ~ 4 t ~~ ~ a ~i av ~, ~ ~ ~ ~ Z a _ ~ ~~ : ~ O, W' ` ~ 4. , ~ ~ i y o o' o. , ~~ >o o. y N, ~ 'Q o i v g ~ ~ a ~ ~ ~ ~ ~ W. ~ ~. ~ ~ ' ~ o, ~ U, ~ N' ~~ ~ L: O. ~ ~ ~ N O ~ N c ~~ O' ~: f0 ~ O, ~ ~ ~~ O ~ f6 Z fA •C. . ~ N ~ ~ I M• M. M: ' r .S ~ ~~ , O: O. ~ ~ O M ~ 0. U O ~ r ~ C' c• a •- h N, : N' -O w, ' ~ M• ~ L .w m =I ~ a. ~ o o i •- ~ rn c t, fl, m, ~: m l : m ~ ~ ~ 0 ~ (0• U: ~ ~ ~ N > ( f0 (0 Y O Zi ~ ~ ~ ~ N. ~ ~ . N. ~ ~ O• O~ ~~ N. ~ ~ ~~ O, O• f0• ~ Q, ~ ~ N• : j ~ ~, W~ ~ ~ f/A N: N~ f/D ~ N~ N~ y: ~ ~: ~ ~ o, ~, ~ ~ Z ~ ~- ~' (p. 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U, ~ ~', ~ a, 0, ~, ~ U. ~~ w ~ = O .- N M rr M CO f~ I a0 O O ~ N M~ tfj (O f~ N O O e- N M V ~ LL~ M r M O _` Q ~ N M V ~ (O I~ M O ~ ~ ~ .- r e- e^ ~ ~ N N N N N N N N N N M M M M M M _M _ M M M ~ U O ~', ~ ~~1 p y N . ': w O O w N N U c M y ~ ~ ~ O M ~ N O y 'v^, w ^ LL ~ N ~ _ •L O ~ ~ O - J 0 N wo tll C a ¢ I y d ~ i T ~ ¢ ^^ CC V G ,, O U a Q W ~ Q ~ a I w t9 C~ 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 Wetl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. ~ ~ **** REEL HEADER **** MWD 08/06/02 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/04/06 1365739 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 '~!~!!!!!! !!!!!!!~! Extract File: ldwg.las Version I nformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 10088.0000: Starting Depth STOP.FT 11654.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 1-39APB1 FLD FIELD: Endicott LOC LOCATION: 70 deg 21' 8.262"N 147 deg 57' 23.994"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK & 2.375" CTK DATE. LOG DATE: 06 Apr 2007 API API NUMBER: 500292182770 Parameter Information Block #MNEM.UNIT Value Description SECT. 36 Section TOWN.N T12N Township RANG. R16E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF KB Log Measured from FAPD.F 55 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 55 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are Subsea corrected. (4j All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth adjusted to a PDCL (Primary Depth Control Log) run by Schlumberger dated 15 Apr 2007 per Joe Turak with BP Exploration (Alaska), Inc. (8) Tied to 1-39 at 10097.5 feet MD (9906.93 feet TVDSS) (9) Runs 1 though 5 were used to set and mill a whipstock at 10097 feet MD (9906 feet TVDSS). (10) Runs 7 and 8 were used to run 3 3/16 inch liner and mill out the liner shoe. (11) Run 10 failed to test at surface due to an electrical pin contact within tool. (12) The sidetrack was drilled from 1-39 through a milled window in a 7 inch liner. Top of Window 10102.5 feet MD (9911.81 feet TVDSS) Bottom of Window 10109.5 feet MD (9918.60 feet TVDSS) (13) The interval from 11622 feet MD to 11656 feet MD (10002.87 feet to 10010.19 feet TVDSS) was not logged due to sensor to bit offset. (14) The bottom of the 3 3/16 inch liner was set at 10400 feet MD (10059 feet TVDSS). MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Compensated Resistivity Borehole Corrected(LS)(AT) (400kHz),Ohm-m RACHX -> Compensated Resistivity Borehole Corrected (LS)(AT) (2MHz),Ohm-m RPCLX -> Compensated Resistivity Borehole Corrected (LS)(PD) (400kHz),Ohm-m RPCHX -> Compensated Resistivity Borehole Corrected (LS)(PD) (2MHz),Ohm-m TVD -> Subsea True Vertical Depth CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10089.1, 10087.4, ! -1.72168 10091, 10089.3, ! -1.72168 10093.1, 10092.1, ! -1.0332 10094.1, 10093.8, ! -0.344727 10096, 10096.9, ! 0.861328 10098.3, 10098.3, ! 0 10101.4, 10102.2, ! 0.860352 10106.7, 10107.1, ! 0.344727 10107.2, 10108.3, ! 1.0332 10109.1, 10110, ! 0.860352 10112.5, 10112.6, ! 0.172852 10113.6, 10115.3, ! 1.72168 10114, 10116.4, ! 2.41113 10117.2, 10119.1, ! 1.89453 10118.1, 10120.8, ! 2.75488 10119.8, 10121.7, ! 1.89355 10124.1, 10124.1, ! 0 10125, 10125.5, ! 0.516602 10125.7, 10126.5, ! 0.861328 10127.2, 10128.1, ! 0.861328 10129.1, 10129.5, ! 0.344727 C 10131.8, 10132.3, 10133.3, 10133.5, 10134.8, 10135.1, 10136.3, 10136.2, 10138.2, 10137, 10139.8, 10138.9, 10142.3, 10142.1, 10144, 10144, 10144.9, 10145, 10146.1, 10146.6, 10150.9, 10150.9, 10152.3, 10152.6, 10153.7, 10153.8, 10155, 10155.2, 10156, 10156.6, 10158.6, 10159.1, 10160.5, 10160.7, 10162.6, 10162.9, 10168.1, 10167.4, 10169, 10169.1, 10171.4, 10171.4, 10173.1, 10173.1, 10174.7, 10176.4, 10175.9, 10177.9, 10180, 10180.3, 10181.5, 10182.5, 10191.5, 101.92.5, 10193.7, 10194.1, 10195.5, 10196, 10198.9, 10197.4, 10200.5, 10198.4, 10205.5, 10205.8, 10207.2, 10207, 10208.9, 10209.1, 10214.4, 10214.4, 10218.4, 10218.4, 10220.4, 10219.9, 10221.6, 10221.5, 10223.2, 10222.8, 10225.1, 10225.3, 10230.1, 10230.8, 10232.2, 10232, 10233.4, 10233.5, 10235.4, 10235.6, 10237.5, 10237.7, 10242.5, 10242.8, 10247.1, 10248.2, 10253.5, 10254.9, 10258.2, 10257.6, 10259.7, 10259.4, 10261.6, 10262.1, 10262.6, 10263.5, 10264.2, 10264.7, 10267.1, 10267.1, 10269.5, 10270, 10272.3, 10271.9, 10274.5, 10273.9, 10276.1, 10275.4, 10279, 10278.5, 10281.3, 10280.4, 10282.6, 10283.5, 10287.6, 10287.5, 10291.1, 10292, 10296.6, 10296.6, 10298, 10298.3, 10299, 10300.2, 10301.4, 10300.9, 0.516602 0.171875 0.34375 -0.171875 -1.20508 -0.861328 -0.171875 0 ! 0.171875 ! 0.516602 ! p ! 0.34375 ! 0.172852 ! 0.171875 ! 0.516602 ! 0.516602 ! 0.172852 ! 0.344727 ! -0.688477 ! 0.171875 ! 0 ! 0 ! 1.72168 ! 2.06641 ! 0.344727 ! 1.0332 ! 1.03223 ! 0.34375 ! 0.516602 ! -1.5498 ! -2.06641 ! 0.344727 ! -0.171875 ! 0.171875 ! 0 ! 0 ! -0.516602 ! -0.171875 ! -0.344727 ! 0.171875 ! 0.688477 ! -0.172852 ! 0.171875 ! 0.172852 ! 0.171875 ! 0.344727 ! 1.0332 ! 1.37695 ! -0.516602 ! -0.344727 ! 0.516602 ! 0.861328 ! 0.516602 ! 0 ! 0.516602 ! -0.34375 ! -0.689453 ! -0.688477 ! -0.516602 ! -0.861328 ! 0.861328 ! -0.171875 ! 0.860352 ! 0 ! 0.344727 ! 1.20508 ! -0.516602 10303.5, 10304.3, ! 0.860352 10305.7, 10305.4, ! -0.344727 10309.9, 10310, ! 0.172852 10310.5, 10311.1, ! 0.515625 10312.3, 10312.4, ! 0.171875 10314.6, 10315, ! 0.344727 10322.3, 10321.5, ! -0.861328 10325.6, 10327.3, ! 1.72168 10330.8, 10330.5, ! -0.34375 10332.9, 10334.1, ! 1.20605 10335.6, 10336.1, ! 0.516602 10337.2, 10338.2, ! 1.0332 10340.1, 10340.1, ! 0 10344.1, 10343, ! -1.03223 10346.6, 10345.1, ! -1.5498 10347.3, 10346.8, ! -0.516602 10349.7, 10349.9, ! 0.171875 10350.7, 10351.9, ! 1.20605 10352.7, 10353.2, ! 0.516602 10354.7, 10355.4, ! 0.688477 10355.9, 10357.7, ! 1.72168 10357.7, 10359.6, ! 1.89355 10359.9, 10361.8, ! 1.89355 10360.9, 10363.2, ! 2.23828 10363.7, 10364.5, ! 0.860352 10365.9, 10366.4, ! 0.515625 10386.6, 10385.9, ! -0.688477 10387.7, 10389, ! 1.37793 10388.7, 10390.3, ! 1.5498 10395.3, 10394.1, ! -1.20508 10397.4, 10398, ! 0.688477 10401.5, 10400.6, ! -0.861328 10403.6, 10401.8, ! -1.72168 10405.1, 10404.9, ! -0.171875 10406, 10406.5, ! 0.516602 10408.2, 10407.7, ! -0.516602 10409.9, 10409.1, ! -0.860352 10411.8, 10412.2, ! 0.344727 10417, 10414.6, ! -2.41113 10418.5, 10416, ! -2.58203 10422.3, 10422, ! -0.34375 10426.1, 10427, ! 0.861328 10427.7, 10428, ! 0.34375 10432.1, 10430.4, ! -1.72168 10433, 10431.6, ! -1.37695 10437.1, 10435.4, ! -1.72168 10438.7, 10438, ! -0.688477 10440.5, 10439.4, ! -1.0332 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 214 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1-39APB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 1-39APB1 APIN FN Endicott COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!~~!~~~~!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL run by Schlumberger dated 15 Apr 2007 per Joe Turak with BP Exploration (Alaska) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= O) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 88 Tape File Start Depth = 10088.000000 Tape File End Depth = 11654.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 101 records... Minimum record length: 34 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN 1-39APBl.xtf LCC 150 CN BP Exploration (Alaska) WN 1-39APB1 APIN FN Endicott COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: LIFO MNEM ---- CHAN DIMT ------------------- CNAM -------- ODEP GR GR --- GRAX ------------------ 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Cur Name 1 GR 2 RAD 3 RAS 4 RPD 5 RPS ves: Tool MWD MWD MWD MWD MWD Code Samples Units 68 1 AAPI 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 150 Size Length 4 4 4 4 4 4 4 4 4 4 20 Tape File Start Depth = 10086.750000 Tape File End Depth = 11654.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 162 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/04/06 1365739 Ol **** REEL TRAILER **** MWD 08/06/02 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 10088.0000 89.8000 -999.250C -999.2500 -999.2500 10088.5000 82.4000 -999.250C -999.2500 -999.2500 10100.0000 70.4000 -999.250C -999.2500 -999.2500 10200.0000 87.5000 25.2000 -999.2500 -999.2500 10300.0000 28.4000 42.4000 -999.2500 -999.2500 10400.0000 27.5000, 43.1000 0.2480 98641.8906 10500.0000 40.8000 31.0000 32.9480 29.6710 10600.0000 47.9000 76.7000 29.2380 31.1890 10700.0000 61.4000 50.9000 90.9660 218.1290 10800.0000 230.8000 33.3000 22.9600 23.2190 10900.0000 216.3000 42.8000 12.0880 14.4010 11000.0000 36.8000 51.0000 22.0280 21.9410 11100.0000 74.1000 47.2000 35.5690 49.3380 11200.0000 44.7000 65.8000 15.6110 17.5350 11300.0000 40.7000 117.7000 32.3710 57.0840 11400.0000 172.5000 46.9000 111.8990 177.6340 11500.0000 25.7000 84.9000 53.3100 48.8030 11600.0000 63.9000 56.5000 99.8320 183.0260 11654.0000 -999.2500 87.9000 -999.2500 -999.2500 Tape File Start Depth = 10088.000000 Tape File End Depth = 11654.000000 Tape File Level Spacing = 0.500000 • RAD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2162.8501 27.3770 18.7010 17.8130 18.8270 9.6920 16.4300 13.9180 12.2200 12.3170 30.1290 76.6100 25.5200 -999.2500 RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6933.3096 50.4880 28.4350 43.0350 22.5510 9.4850 25.2040 19.3100 13.7650 18.0170 57.4820 62.4080 43.3580 -999.2500 • . Tape File Depth Units = feet • Tape Subfile 3 is type: LIS DEPTH GR RAD RPS 10086.7500 -999.2500 -999.2500 -999.2500 10087.0000 -999.2500 -999.2500 -999.2500 10100.0000 70.4000 -999.2500 -999.2500 10200.0000 87.5000 -999.2500 -999.2500 10300.0000 28.4000 -999.2500 -999.2500 10400.0000 27.5000 2162.8501 98641.8906 10500.0000 43.0000 27.5310 29.6710 10600.0000 58.3000 20.0620 30.1640 10700.0000 62.7000 17.9810 234.9610 10800.0000 229.1000 18.8270 23.9010 10900.0000 223.2000 9.9930 13.8410 11000.0000 36.1000 17.3220 18.9260 11100.0000 82.8000 18.5850 7.3850 11200.0000 41.6000 12.2200 18.2110 11300.0000 40.9000 12.4170 55.7080 11400.0000 181.2000 29.1940 195.1290 11500.0000 22.9000 79.0310 47.7370 11600.0000 80.4000 26.9120 172.2420 11654.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10086.750000 Tape File End Depth = 11654.000000 Tape File Level Spacing = 0.250000 • RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6933.3096 47.5840 32.0880 47.5840 23.9370 9.7150 27.6600 20.5450 13.5680 17.7190 53.4360 58.1010 42.8380 -999.2500 RPD -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.2480 32.3710 29.2380 90.9660 23.6170 11.7970 20.0760 10.3740 15.9650 31.8110 114.5730 51.9600 99.8320 -999.2500 • Tape File Depth Units = feet • Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 08/05/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/04/13 1365739 Ol 3" CTK *** LIS COMMENT RECORD *** !!'~~!!!! !!!!!!!!!! Remark File Version 1.000 !!!!!!!!! !!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10086.0000: Starting Depth STOP.FT 11870.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 1-39A/N16 FLD FIELD: Endicott LOC LOCATION: 70 deg 21' 8.262"N 147 deg 57' 23.994"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 13 Apr 2007 API API NUMBER: 500292182701 Parameter Information Block #MNEM.UNIT Value SECT. 36 TOWN.N T12N . RANG. R16E . PDAT. MSL . EPD .F 0 LMF KB FAPD.F 55 DMF KB EKB .F 0 . EDF .F 55 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ao~ L~ ~ G~OS-G~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth adjusted to a PDCL (Primary Depth Control Log) run by Schlumberger MCNL dated 15 Apr 2007 per Joe Turak with BP Exploration (Alaska), Inc. (8) Tied to END 1-39 at 10097.5 feet MD (9906.93 feet TVDSS) (9) Runs 1 though 5 were used to set and mill a whipstock at 10097 feet MD (9906 feet TVDSS). (10) Runs 7 and 8 were used to run 3 3/16 inch liner and mill out the liner shoe. (11) Runs 14, 15 and 17 were clean out liner runs. (12) Run 19 open hole sidetracked off aluminum billet at 10440 feet MD (10056.7 feet TVDSS) from END 1-39APB1/N16. (13) The interval from 11874 feet MD to 11900 feet MD (9987 feet to 9986 feet TVDSS) was not logged due to sensor to bit offset. (14) The bottom of the 3 3/16 inch liner was set at 10400 feet MD (10059 feet TVDSS). (15) The resistivity interval from 10668 feet to 10694 feet Md (10038 feet to 10036 feet TVDSS) was logged 11.5 hours after being drilled. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Compensated Resistivity Borehole Corrected(LS)(AT) (400kHz),Ohm-m RACHX -> Compensated Resistivity Borehole Corrected (LS)(AT) (2MHz),Ohm-m RPCLX -> Compensated Resistivity Borehole Corrected (LS)(PD) (400kHz),Ohm-m RPCHX -> Compensated Resistivity Borehole Corrected (LS)(PD) (2MHz) ,Ohm-m TVD -> Subsea True Vertical Depth CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10089.1, 10087.4, ! -1.72168 10091, 10089.3, ! -1.72168 10093.1, 10092.1, ! -1.0332 10094.1, 10093.8, ! -0.344727 10096, 10096.9, ! 0.861328 10098.3, 10098.3, ! 0 10101.4, 10102.2, ! 0.860352 10106.7, 10107.1, ! 0.344727 10107.2, 10108.3, ! 1.0332 10109.1, 10110, ! 0.860352 10112.5, 10112.6, ! 0.172852 10113.6, 10115.3, ! 1.72168 10114, 10116.4, ! 2.41113 10117.2, 10119.1, ! 1.89453 10118.1, 10120.8, ! 2.75488 10119.8, 10121.7, ! 1.89355 10124.1, 10124.1, ! 0 10125, 10125.5, ! 0.516602 10125.7, 10126.5, ! 0.861328 10127.2, 10128.1, ! 0.861328 U 10129.1, 10129.5, 10131.8, 10132.3, 10133.3, 10133.5, 10134.8, 10135.1, 10136.3, 10136.2, 10138.2, 10137, 10139.8, 10138.9, 10142.3, 10142.1, 10144, 10144, 10144.9, 10145, 10146.1, 10146.6, 10150.9, 10150.9, 10152.3, 10152.6, 10153.7, 10153.8, 10155, 10155.2, 10156, 10156.6, 10158.6, 10159.1, 10160.5, 10160.7, 10162.6, 10162.9, 10168.1, 10167.4, 10169, 10169.1, 10171.4, 10171.4, 10173.1, 10173.1, 10174.7, 10176.4, 10175.9, 10177.9, 10180, 10180.3, 10181.5, 10182.5, 10191.5, 10192.5, 10193.7, 10194.1, 10195.5, 10196, 10198.9, 10197.4, 10200.5, 10198.4, 10205.5, 10205.8, 10207.2, 10207, 10208.9, 10209.1, 10214.4, 10214.4, 10218.4, 10218.4, 10220.4, 10219.9, 10221.6, 10221.5, 10223.2, 10222.8, 10225.1, 10225.3, 10230.1, 10230.8, 10232.2, 10232, 10233.4, 10233.5, 10235.4, 10235.6, 10237.5, 10237.7, 10242.5, 10242.8, 10247.1, 10248.2, 10253.5, 10254.9, 10258.2, 10257.6, 10259.7, 10259.4, 10261.6, 10262.1, 10262.6, 10263.5, 10264.2, 10264.7, 10267.1, 10267.1, 10269.5, 10270, 10272.3, 10271.9, 10274.5, 10273.9, 10276.1, 10275.4, 10279, 10278.5, 10281.3, 10280.4, 10282.6, 10283.5, 10287.6, 10287.5, 10291.1, 10292, 10296.6, 10296.6, 10298, 10298.3, 10299, 10300.2, ! 0.344727 ! 0.516602 ! 0.171875 ! 0.34375 ! -0.171875 -1.20508 ! -0.861328 ! -0.171875 0 0.171875 0.516602 0 0.34375 0.172852 0.171875 0.516602 0.516602 0.172852 0.344727 -0.688477 0.171875 0 0 1.72168 2.06641 0.344727 1.0332 1.03223 0.34375 0.516602 -1.5498 -2.06641 0.344727 -0.171875 0.171875 0 0 -0.516602 -0.171875 -0.344727 0.171875 0.688477 -0.172852 0.171875 0.172852 0.171875 0.344727 1.0332 1.37695 -0.516602 -0.344727 0.516602 0.861328 0.516602 0 0.516602 -0.34375 -0.689453 -0.688477 -0.516602 -0.861328 0.861328 -0.171875 0.860352 0 0.344727 1.20508 ~~ 10301.4, 10300.9, 10303.5, 10304.3, 10305.7, 10305.4, 10309.9, 10310, 10310.5, 10311.1, 10312.3, 10312.4, 10314.6, 10315, 10322.3, 10321.5, 10325.6, 10327.3, 10330.8, 10330.5, 10332.9, 10334.1, 10335.6, 10336.1, 10337.2, 10338.2, 10340.1, 10340.1, 10344.1, 10343, 10346.6, 10345.1, 10347.3, 10346.8, 10349.7, 10349.9, 10350.7, 10351.9, 10352.7, 10353.2, 10354.7, 10355.4, 10355.9, 10357.7, 10357.7, 10359.6, 10359.9, 10361.8, 10360.9, 10363.2, 10363.7, 10364.5, 10365.9, 10366.4, 10386.6, 10385.9, 10387.7, 10389, 10388.7, 10390.3, 10395.3, 10394.1, 10397.4, 10398, 10401.5, 10400.6, 10403.6, 10401.8, 10405.1, 10404.9, 10406, 10406.5, 10408.2, 10407.7, 10409.9, 10409.1, 10411.8, 10412.2, 10417, 10414.6, 10418.5, 10416, 10422.3, 10422, 10426.1, 10427, 10427.7, 10428, 10432.1, 10430.4, 10433, 10431.6, 10437.1, 10435.4, 10438.7, 10438, 10440.5, 10439.4, 10443.2, 10441.4, 10443.9, 10442.9, 10444.6, 10444.1, 10447.7, 10448.4, 10451.2, 10452.4, 10455.1, 10455, 10457, 10456.5, 10458, 10457.5, 10460.9, 10460.8, 10463.3, 10463.3, 10464.4, 10464, 10467, 10467.7, 10470.2, 10469.4, 10471.1, 10470.4, 10473, 10472, 10474.9, 10473.3, 10484.1, 10484.8, 10485.5, 10486.3, -0.516602 0.860352 -0.344727 0.172852 0.515625 0.171875 0.344727 -0.861328 1.72168 -0.34375 1.20605 0.516602 1.0332 0 -1.03223 -1.5498 -0.516602 0.171875 1.20605 0.516602 0.688477 1.72168 1.89355 1.89355 2.23828 0.860352 0.515625 -0.688477 1.37793 1.5498 -1.20508 0.688477 -0.861328 -1.72168 -0.171875 0.516602 -0.516602 -0.860352 0.344727 -2.41113 -2.58203 -0.34375 0.861328 0.34375 -1.72168 -1.37695 -1.72168 -0.688477 -1.0332 -1.89355 -1.0332 -0.516602 0.688477 1.20508 -0.171875 -0.516602 -0.516602 -0.172852 0 -0.344727 0.689453 -0.860352 -0.688477 -1.03223 -1.5498 0.688477 0.861328 10486.8, 10487.9, ! 1.0332 10488, 10489.4, ! 1.37695 10488.9, 10490.5, ! 1.5498 10489.9, 10491.7, ! 1.72168 10490.6, 10492.9, ! 2.23828 10492.5, 10493.6, ! 1.0332 10497.2, 10498.4, ! 1.20508 10497.8, 10499.9, ! 2.06543 10500.3, 10502.2, ! 1.89355 10503.2, 10503, ! -0.171875 10504.1, 10504.7, ! 0.689453 10507.5, 10507, ! -0.516602 10507.8, 10508.7, ! 0.861328 10510.1, 10510.4, ! 0.34375 10512.1, 10512.3, ! 0.172852 10514, 10514.4, ! 0.34375 10515.4, 10515.8, ! 0.34375 10517.7, 10517.3, ! -0.344727 10519.6, 10519.2, ! -0.34375 10520.8, 10520.6, ! -0.171875 10525, 10525.4, ! 0.344727 10525.9, 10526.4, ! 0.516602 10526.6, 10527.1, ! 0.516602 10530.1, 10531, ! 0.861328 10532.4, 10532.4, ! 0 10543, 10542.9, ! -0.171875 10545.6, 10546.1, ! 0.516602 10549.8, 10550.3, ! 0.516602 10551.1, 10551, ! -0.171875 10552.3, 10552.5, ! 0.171875 10553.2, 10553.4, ! 0.171875 10554.6, 10554.9, ! 0.34375 10557.3, 10557.2, ! -0.171875 10558.7, 10558.9, ! 0.171875 10560.1, 10560.4, ! 0.344727 10562.2, 10561.3, ! -0.860352 10563.5, 10563, ! -0.516602 10565.2, 10565.1, ! -0.171875 10567, 10566.5, ! -0.516602 10568.4, 10567.7, ! -0.688477 10569.1, 10568.9, ! -0.171875 10570.1, 10570.9, ! 0.861328 10571.1, 10572.3, ! 1.20508 10573.4, 10574.4, ! 1.0332 10577.3, 10576.5, ! -0.860352 10578.5, 10578, ! -0.516602 10579, 10578.9, ! -0.171875 10580.2, 10580.9, ! 0.689453 10581.2, 10582, ! 0.861328 10585.1, 10585.6, ! 0.516602 10594.1, 10593, ! -1.0332 10598.1, 10596, ! -2.06543 10603.1, 10603.2, ! 0.171875 10604.4, 10604.6, ! 0.172852 10605.1, 10605.1, ! 0 10606.3, 10606, ! -0.349727 10607.9, 10607.5, ! -0.344727 10608.9, 10609.6, ! 0.688477 10614.9, 10616, ! 1.0332 10615.8, 10616.7, ! 0.860352 10617.2, 10617.9, ! 0.688477 10617.9, 10618.5, ! 0.689453 10618.5, 10620.4, ! 1.89355 10622.2, 10622.9, ! 0.688477 10624.1, 10625.4, ! 1.37793 10625.8, 10627.5, ! 1.72168 10628, 10628.7, ! 0.688477 10630.3, 10631.6, 10632.7, 10633.9, 10633.7, 10634.7, 10634.9, 10636.1, 10639.4, 10640.1, 10644.1, 10642.9, 10644.8, 10644.4, 10647, 10647.3, 10648.7, 10649.2, 10652.5, 10651.8, 10654.9, 10653.9, 10658.2, 10658, 10658.9, 10659.6, 10659.4, 10659.9, 10661.3, 10660.6, 10664.1, 10663.4, 10665.1, 10665.4, 10667.2, 10666.8, 10669.8, 10669.2, 10670.6, 10670.3, 10672.5, 10671.6, 10673.7, 10674.4, 10678.9, 10676.3, 10681.8, 10680.9, 10683.5, 10683.9, 10684.4, 10684.6, 10685.4, 10685.9, 10690.2, 10689, 10691.6, 10690.6, 10692.8, 10692.7, 10695.1, 10693.9, 10697.6, 10695.7, 10699.6, 10699.1, 10702.1, 10700.4, 10703.1, 10702, 10706.2, 10703.4, 10706.9, 10705, 10710, 10708.1, 10710.1, 10708.7, 10711, 10710.5, 10716.7, 10715.5, 10720.6, 10719.1, 10723.4, 10721, 10723.9, 10722.5, 10729.3, 10727.8, 10730.4, 10729.5, 10731.7, 10731.4, 10732.5, 10732.9, 10734.3, 10734.1, 10738.6, 10738.4, 10739.1, 10739.9, 10744.8, 10744.8, 10746.7, 10747.3, 10751.7, 10750.9, 10753, 10751.6, 10759.2, 10759.1, 10761.9, 10760.4, 10763.3, 10764, 10765.5, 10765.5, 10768.4, 10768.4, 10773.9, 10771.8, 10777.6, 10776.5, 10779.8, 10778.1, 10782.3, 10779.4, 10787.1, 10786.1, 10792.5, 10791.8, 10793.5, 10793.5, 1.37695 1.20508 1.0332 1.20508 0.689453 -1.20605 -0.344727 0.34375 0.516602 -0.688477 -1.0332 -0.171875 0.688477 0.516602 -0.688477 -0.688477 0.34375 -0.344727 -0.516602 -0.344727 -0.860352 0.689453 -2.58301 -0.861328 0.344727 0.171875 0.516602 -1.20508 -1.0332 -0.171875 -1.20508 -1.89453 -0.516602 -1.72168 -1.0332 -2.75488 -1.89355 -1.89453 -1.37695 -0.516602 -1.20508 -1.5498 -2.41016 -1.37793 -1.54883 -0.860352 -0.34375 0.344727 -0.171875 -0.172852 0.860352 0 0.688477 -0.861328 -1.37793 -0.171875 -1.54883 0.688477 0 0 -2.06641 -1.03223 -1.72168 -2.92676 -1.0332 -0.688477 0 i 10795, 10795, ! 0 10797.3, 10796.1, ! -1.20508 10799.5, 10799.3, ! -0.172852 10800.9, 10800.4, ! -0.516602 10801.6, 10801.8, ! 0.172852 10803, 1 0802.6, ! -0.344727 10804.3, 10804.3, ! 0 10805, 1 0805, ! 0 10806.4, 10807.6, ! 1.20508 10809.7, 10809.5, ! -0.171875 10811.2, 10810.5, ! -0.688477 10812.4, 10812.4, ! 0 10815.9, 10814.7, ! -1.20508 10817.1, 10815.5, ! -1.5498 10819.5, 10818.1, ! -1.37793 10820.3, 10820, ! -0.34375 10823.8, 10822.8, ! -1.0332 10825, 10825.2, ! 0.171875 10827.3, 10826.9, ! -0.344727 10828.8, 10828.6, ! -0.171875 10830.7, 10830.2, ! -0.516602 10832.4, 10831.9, ! -0.516602 10834.3, 10832.9, ! -1.37793 10836.7, 10835.5, ! -1.20508 10837.9, 10837.4, ! -0.516602 10850, 10848.1, ! -1.89453 10852.4, 10850.7, ! -1.72168 10853.6, 10851.9, ! -1.72168 10855.1, 10853.6, ! -1.5498 10855.8, 10855.1, ! -0.688477 10859.8, 10857, ! -2.75488 10862.2, 10859.1, ! -3.09961 10869.1, 10866.5, ! -2.58301 10869.8, 10868.6, ! -1.20508 10874.6, 10875.3, ! 0.688477 10879.1, 10880.3, ! 1.20508 10880.8, 10881.7, ! 0.860352 10882.2, 10883.4, ! 1.20508 10883.4, 10885.6, ! 2.23828 10886, 10887, ! 1.0332 10886.8, 10887.9, ! 1.03223 10896.7, 10897.6, ! 0.861328 10900, 10899.5, ! -0.516602 10901, 10900.9, ! -0.172852 10902.4, 10902.6, ! 0.171875 10902.9, 10904, ! 1.0332 10905.7, 10906, ! 0.344727 10909.9, 10908, ! -1.89355 10912.4, 10912.6, ! 0.171875 10913.1, 10913.8, ! 0.688477 10914.3, 10915, ! 0.689453 10918.1, 10918.6, ! 0.516602 10925.7, 10925.5, ! -0.172852 10931, 10930.5, ! -0.516602 10933.8, 10933.5, ! -0.344727 10936.9, 10937.8, ! 0.861328 10937.9, 10939.3, ! 1.37793 10939.1, 10941.2, ! 2.06641 10940.9, 10942.6, ! 1.72168 10944, 10944.5, ! 0.516602 10944.8, 10946, ! 1.20605 10946.5, 10947.4, ! 0.860352 10951.1, 10949.6, ! -1.5498 10952.7, 10951.5, ! -1.20605 10955.4, 10954.3, ! -1.0332 10959.5, 10958.3, ! -1.20508 10963.1, 10962.4, ! -0.689453 C~ J 10971.5, 10970.2, ! -1.37793 10972.1, 10971.5, ! -0.516602 10974, 10973.6, ! -0.344727 10975.7, 10974.4, ! -1.37793 10976.8, 10975.9, ! -0.861328 10981.1, 10979.9, ! -1.20508 10982.8, 10982.8, ! 0 10985.5, 10985.8, ! 0.34375 10986.5, 10987.4, ! 0.860352 10987.6, 10988.8, ! 1.20508 10991.9, 10991.5, ! -0.344727 10993.8, 10992.3, ! -1.5498 10995.2, 10994.2, ! -1.03223 10996.1, 10995, ! -1.0332 10998.1, 10996.5, ! -1.5498 11000.1, 10998.9, ! -1.20508 11000.7, 11000.5, ! -0.172852 11002.2, 11001.5, ! -0.689453 11002.9, 11003.1, ! 0.171875 11007, 11005.8, ! -1.20508 11008.1, 11007.9, ! -0.171875 11009.3, 11009.1, ! -0.171875 11014.1, 11012.9, ! -1.20508 11026.4, 11025.7, ! -0.688477 11030.4, 11029.3, ! -1.0332 11032.1, 11031.8, ! -0.34375 11038.8, 11038.4, ! -0.344727 11040.7, 11039.8, ! -0.861328 11052.2, 11050.8, ! -1.37793 11053.1, 11052, ! -1.0332 11054.1, 11054.6, ! 0.516602 11055.5, 11056.7, ! 1.20605 11058.6, 11058.3, ! -0.344727 11059.6, 11060.1, ! 0.516602 11060, 11061.3, ! 1.37793 11069.8, 11070.1, ! 0.344727 11071.7, 11071.8, ! 0.172852 11073.9, 11073.7, ! -0.171875 11075.1, 11075.1, ! 0 11077, 11076.1, ! -0.861328 11077.6, 11077.5, ! -0.171875 11080.2, 11079.4, ! -0.860352 11080.9, 11081.4, ! 0.515625 11082.1, 11082.6, ! 0.516602 11089.9, 11088.9, ! -1.03223 11091.8, 11090.1, ! -1.72168 11092.7, 11093, ! 0.344727 11094.6, 11094.6, ! 0 11099.4, 11099.2, ! -0.171875 11101, 11101, ! 0 11102.2, 11102.5, ! 0.344727 11103.5, 11103.4, ! -0.172852 11104.9, 11105.6, ! 0.688477 11106.3, 11107.2, ! 0.860352 11109.7, 11109.1, ! -0.689453 11112.1, 11113.5, ! 1.37793 11119.7, 11118.8, ! -0.861328 11124.4, 11124, ! -0.344727 11125.4, 11125.4, ! 0 11126.4, 11127, ! 0.515625 11127.1, 11128.5, ! 1.37695 11127.8, 11130.1, ! 2.23828 11132..5, 11132.5, ! 0 11134.9, 11134, ! -0.861328 11136.3, 11135.9, ! -0.344727 11137.1, 11136.9, ! -0.172852 11138.2, 11137.8, ! -0.34375 11140, 11140.4, 11141, 11141.6, 11142.1, 11142.6, 11151.2, 11150.6, 11153, 11151.9, 11158.5, 11157.5, 11159.6, 11159.6, 11160.8, 11161, 11165.5, 11163.8, 11168.6, 11168.9, 11170.7, 11170.7, 11171, 11172, 11173.9, 11173.4, 11181.7, 11181, 11183.9, 11182.5, 11186, 11184.8, 11186.5, 11187, 11189, 11188.5, 11197.5, 11196.3, 11198..6, 11198.6, 11199.6, 11199.9, 11202.6, 11202.6, 11204.8, 11203.8, 11206.7, 11205.8, 11208.4, 11207.9, 11210.3, 11209.5, 11212, 11211.5, 11215.6, 11216.8, 11220.6, 11221.3, 11227, 11229.1, 11229.3, 11230.7, 11231.2, 11232.7, 11236.5, 11235.8, 11239.1, 11238.6, 11243.1, 11242.6, 11246.6, 11246.6, 11249.4, 11248.3, 11252.8, 11251.8, 11256.1, 11253.9, 11259.4, 11259.2, 11260.6, 11261.3, 11266.4, 11265.7, 11268.4, 11269.2, 11273.5, 11272.8, 11276.2, 11278.6, 11277.6, 11279.5, 11285.2, 11286.9, 11288.8, 11288.3, 11289.9, 11290.4, 11291.9, 11292.6, 11298.8, 11298.4, 11303.4, 11301.3, 11305.7, 11303.1, 11309.6, 11310, 11313.7, 11313.7, 11315.5, 11314.7, 11318, 11316.8, 11320.3, 11319.1, 11322.5, 11321.8, 11324.2, 11325.3, 11326.8, 11327.3, 11328.7, 11328.4, 11332.9, 11332, 11335.4, 11334.9, 11338.4, 11336.6, 11341.6, 11340.4, 11342.7, 11341.8, 0.344727 0.516602 0.516602 -0.688477 -1.0332 -1.0332 0 0.171875 -1.72266 0.344727 0 0332 -0.516602 -0.688477 -1.37695 -1.20508 0.516602 -0.516602 -1.20508 0 0.344727 0 -1.0332 -0.861328 -0.516602 -0.860352 -0.516602 1.20508 0.688477 2.06641 1.37695 1.54883 -0.688477 -0.515625 -0.516602 0 -1.03223 -1.0332 -2.23828 -0.171875 0.689453 -0.688477 0.861328 -0.688477 2.41016 1.89355 1.72168 -0.516602 0.515625 0.688477 -0.344727 -2.06641 -2.58301 0.344727 0 -0.861328 -1.20508 -1.20508 -0.688477 1.0332 0.516602 -0.34375 -0.861328 -0.515625 -1.72168 -1.20605 -0.860352 i i i 1 i 11343.7, 11343.5, 11344.9, 11344.2, 11347.7, 11347.5, 11349.9, 11351.1, 11351.1, 11352, 11352.9, 11353.3, 11356.5, 11355.6, 11358.6, 11357.4, 11359.8, 11358.9, 11363.1, 11361.3, 11366, 11364.9, 11369.7, 11369.9, 11372, 11371.8, 11373, 11373.4, 11377, 11375.5, 11378.3, 11377.5, 11380.6, 11379.9, 11381.4, 11381.1, 11383.5, 11383, 11384, 11384.5, 11384.9, 11386.4, 11387.1, 11388.7, 11388.5, 11390.2, 11392.6, 11393.5, 11395.8, 11398.4, 11397.5, 11399.5, 11400, 11400.4, 11402.8, 11403.8, 11406.6, 11407.1, 11413.5, 11411.9, 11414.5, 11413, 11415, 11414.3, 11418.1, 11415.5, 11419.7, 11418, 11421.6, 11419.3, 11424, 11421.2, 11425.6, 11422.9, 11426.5, 11424.8, 11427.9, 11427.4, 11430.8, 11429.9, 11432.4, 11433, 11434.6, 11434.4, 11435.8, 11435.5, 11439.6, 11438.4, 11446.6, 11445.4, 11448, 11446.8, 11452, 11450.6, 11453, 11451.5, 11454.2, 11452.5, 11457.3, 11454.9, 11459.7, 11458.5, 11460.8, 11459.4, 11463.3, 11461.1, 11468, 11465.9, 11475.2, 11474.8, 11478.1, 11476.5, 11479.3, 11477.2, 11481.9, 11480.1, 11485.1, 11482.9, 11486.2, 11484.6, 11488.1, 11486.9, 11490.1, 11487.5, 11490.5, 11489.1, 11491.5, 11490.5, 11492.5, 11491.3, 11494.1, 11492.5, 11495, 11494.4, ! -0.171875 ! -0.688477 ! -0.171875 ! 1.20508 0.861328 ! 0.344727 ! -0.861328 ! -1.20508 ! -0.860352 ! -1.72168 -1.0332 ! 0.171875 -0.172852 0.344727 -1.5498 ! -0.861328 ! -0.688477 ! -0.34375 -0.516602 0.516602 ! 1.54883 ! 1.54883 ! 1.72168 ! 0.861328 ! 2.58203 ! 2.06641 0.34375 ! 1.03223 ! 0.516602 ! -1.5498 -1.5498 -0.689453 ! -2.58203 -1.72168 ! -2.23828 -2.75488 ! -2.75488 ! -1.72168 -0.516602 ! -0.861328 0.688477 -0.172852 -0.344727 -1.20605 ! -1.20508 -1.20605 -1.37793 -1.5498 ! -1.72168 -2.41113 -1.20605 -1.37695 -2.23828 -2.06641 -0.34375 -1.5498 -2.06641 -1.72168 -2.23828 -1.5498 -1.20605 -2.58203 -1.37793 -1.0332 -1.20605 -1.54883 -0.516602 • 11495.5, 11496.3, ! 0.860352 11496, 11497.9, ! 1.89355 11502.3, 11502.7, ! 0.344727 11503, 11504.4, ! 1.37695 11504.9, 11505.6, ! 0.688477 11505.9, 11506.1, ! 0.171875 11506.6, 11507.5, ! 0.861328 11507.8, 11509.7, ! 1.89453 11509.6, 11511.5, ! 1.89453 11514.1, 11513.2, ! -0.861328 11519.6, 11518.9, ! -0.688477 11523.7, 11522.8, ! -0.860352 11526.8, 11524, ! -2.75488 11533.9, 11532.9, ! -1.0332 11541.3, 11540.6, ! -0.688477 11542.2, 11541, ! -1.20605 11543.5, 11541.5, ! -2.06641 11546.8, 11546, ! -0.860352 11551.3, 11548.7, ! -2.58301 11558.7, 11559.6, ! 0.861328 11566.3, 11566.1, ! -0.171875 11568, 11567.1, ! -0.861328 11575.1, 11574.9, ! -0.172852 11577, 11575.8, ! -1.20508 11583, 11582.3, ! -0.689453 11587.2, 11585.4, ! -1.72168 11587.7, 11586.5, ! -1.20508 11589.2, 11587.9, ! -1.37793 11598.4, 11599.1, ! 0.688477 11601, 11600.4, ! -0.515625 11601.7, 11602.2, ! 0.516602 11608.6, 11610.4, ! 1.72168 11610.7, 11611.4, ! 0.688477 11613.9, 11613.9, ! 0 11620.1, 11620.4, ! 0.344727 11621.5, 11622, ! 0.516602 11624.6, 11624.2, ! -0.34375 11627.3, 11626.8, ! -0.516602 11631, 11628.9, ! -2.06543 11632.9, 11632.3, ! -0.516602 11636.6, 11634.1, ! -2.58301 11637.8, 11635.7, ! -2.06641 11641.3, 11641.9, ! 0.688477 11643, 11643, ! 0 11645.1, 11643.9, ! -1.20508 11651.6, 11650.6, ! -1.03223 11656.9, 11655.9, ! -1.0332 11658.1, 11657.5, ! -0.688477 11661.2, 11659.3, ! -1.89453 11664.5, 11663.1, ! -1.37793 11668, 11665.6, ! -2.41113 11670.1, 11668, ! -2.06543 11672.7, 11671.3, ! -1.37793 11675.3, 11673.4, ! -1.89453 11676.8, 11674.6, ! -2.23828 11679, 11676.6, ! -2.41016 11681.6, 11679.6, ! -2.06641 11682.5, 11680.4, ! -2.06543 11684.2, 11682.5, ! -1.72266 11686.3, 11685.1, ! -1.20508 11687.8, 11685.8, ! -2.06641 11691.5, 11689.4, ! -2.06641 11692.3, 11690.8, ! -1.5498 11693.5, 11692.7, ! -0.860352 11695.2, 11695.1, ! -0.171875 11696.3, 11695.8, ! -0.516602 11698.9, 11697.3, ! -1.54883 11700.3, 11699.6, ! -0.688477 11702.2, 11701.7, ! -0.516602 11706.8, 11706.1, ! -0.688477 11708.2, 11707.9, ! -0.344727 11714, 11713, ! -1.0332 11718, 11716.6, ! -1.37695 11732.1, 11730.1, ! -2.06641 11733.2, 11731.6, ! -1.5498 11734.5, 11732.6, ! -1.89355 11735.7, 11734.4, ! -1.37695 11741.4, 11739.4, ! -2.06543 11743.4, 11742.2, ! -1.20605 11745, 11742.9, ! -2.06543 11746.8, 11746.6, ! -0.171875 11748.7, 11748.1, ! -0.516602 11755, 11753.6, ! -1.37793 11756, 11754.4, ! -1.5498 11757.8, 11756.1, ! -1.72168 11772, 11771.3, ! -0.688477 11774.9, 11775.8, ! 0.860352 11775.8, 11776.8, ! 1.0332 11777.8, 11778, ! 0.171875 11785.5, 11784.3, ! -1.20508 11788.2, 11786.8, ! -1.37695 11789.2, 11788.4, ! -0.861328 11790.6, 11789.4, ! -1.20508 11791.7, 11790.6, ! -1.0332 11793.5, 11791.7, ! -1.89453 11794.9, 11793.4, ! -1.5498 11796.3, 11794.9, ! -1.37793 11797.9, 11796.8, ! -1.0332 11798.6, 11799.6, ! 1.0332 11801.1, 11800.6, ! -0.516602 11804.2, 11804.6, ! 0.34375 11807.3, 11807.2, ! -0.171875 11811.1, 11809.2, ! -1.89355 11812.3, 11811.1, ! -1.20605 11820.4, 11822.3, ! 1.89355 11822.9, 11824.1, ! 1.20665 11825.4, 11824.9, ! -0.516602 11837.1, 11836.6, ! -0.516602 11844.2, 11842.8, ! -1.37695 11844.9, 11844.4, ! -0.516602 11845.9, 11846.3, ! 0.34375 11848.8, 11849.2, ! 0.34375 11851.4, 11851.3, ! -0.171875 11855.1, 11854, ! -1.0332 11857.3, 11856.6, ! -0.689453 11858.3, 11857.9, ! -0.34375 11859.1, 11858.8, ! -0.344727 11861.1, 11859.9, ! -1.20508 11861.6, 11861, ! -0.688477 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 754 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 • 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1-39AN16 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 1-39A/N16 APIN FN Endicott COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL run by Schlumberger MCNL dated 15 Apr 2007 per Joe Turak with BP Exploration (A1 *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM ---- ---- ODEP - GR GR ---- GRAX --------- ------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 • 24 Total Data Records: 101 Tape File Start Depth = 10086.000000 Tape File End Depth = 11899.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 114 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1-39AN16.xtf LCC 150 CN BP Exploration (Alaska) WN 1-39A/N16 APIN FN Endicott COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!! " '!!'!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0. 250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Su b-ty pe is: 1 FRAME SPACE = 0. 250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 202 Tape File Start Depth = 10086.750000 Tape File End Depth = 11899.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 215 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/04/13 1365739 O1 **** REEL TRAILER **** MWD 08/05/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10086.0000 89.5314 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10086.5000 88.2485 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 70.6789 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 130.0207 24.7676 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 29.8261 43.0632 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 24.8073 38.7647 117.7756 377.3723 0.2343 2000.0000 10500.0000 45.1360 25.0059 25.9367 22.1622 32.0090 35.9418 10600.0000 26.3338 29.2718 24.2630 32.4496 37.9300 42.8340 10700.0000 31.0922 27.0379 22.2381 33.8615 54.2938 78.6749 10800.0000 28.7527 53.2782 67.1331 33.6111 30.0307 25.6107 10900.0000 23.0856 34.3000 14.1800 21.2872 32.4217 54.4057 11000.0000 30.3648 61.0025 35.2172 36.8512 31.4422 27.0406 11100.0000 28.5000 63.6447 19.8079 23.6557 28.2027 32.9489 11200.0000 31.6802 49.2841 25.9922 19.2771 26.2270 27.7328 11300.0000 53.1454 82.9055 19.7078 28.1348 39.8842 49.3079 11400.0000 64.6479 81.6340 16.2207 24.9580 38.7957 61.3958 11500.0000 21.6023 88.6235 28.7426 80.5893 193.7360 434.5217 11600.0000 29.2606 89.1195 27.2855 62.0257 207.3440 555.2078 11700.0000 147.1074 35.6546 29.0389 50.4268 99.9277 152.6559 11800.0000 33.2805 58.8391 24.8574 22.0737 30.0787 29.8694 11899.5000 -999.2500 -999.2500 -999.2500 -999.2500 i -999.2500 -999.2500 Tape File Start Depth = 10086.000000 Tape File End Depth = 11899.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10086.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10087.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 70.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 87.5000 25.2000 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 28.4000 42.4000 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 27.5000 43.1000 2162.8501 6933.3096 0.2480 98641.8906 10500.0000 41.6000 21.2000 26.5250 22.9460 33.7970 38.1450 10600.0000 22.5000 30.2000 23.6200 31.1430 37.1830 42.5080 10700.0000 30.4000 27.5000 22.5940 37.9390 61.1110 91.6560 10800.0000 29.3000 53.2000 64.7390 33.3820 30.6390 26.2260 10900.0000 22.8000 34.3000 14.0850 21.3250 32.0090 53.4860 11000.0000 35.1000 61.9000 35.9060 37.7660 30.9040 26.6330 11100.0000 28.5000 63.4000 19.7770 23.7870 28.4040 33.2630 11200.0000 30.0000 49.4000 25.5200 19.3020 26.2270 27.4790 11300.0000 53.3000 82.8000 19.9160 28.1530 37.5570 44.2970 11400.0000 59.5000 81.4000 16.2070 23.6130 38.1300 60.0300 11500.0000 23.7000 88.9000 28.2740 77.8740 200.3880 481.1090 11600.0000 29.9000 88.6000 27.8110 58.1940 209.1260 547.4619 11700.0000 124.7000 47.0000 28.9680 51.2280 109.9200 180.4400 11800.0000 33.6000 58.2000 23.2550 22.8350 30.2600 28.7470 11899.7500 -999.2500 -999.2500 -999.2500 -999.2500 • -999.2500 -999.2500 Tape File Start Depth = 10086.750000 Tape File End Depth = 11899.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet U • Tape Subfile 4 is type: LIS z **** REEL HEADER **** MWD 08/03/13 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/04/13 1365739 01 3" CTK *** LIS COMMENT RECORD *** !!ii!!!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 10120.0000: Starting Depth STOP.FT 11900.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: END 1-39A / N16 FLD FIELD: Endicott LOC LOCATION: 70 deg 21' 8.262"N 147 deg 57' 23.994"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 13 Apr 2007 API API NUMBER: 50029218270100 Parameter Information Block #MNEM.UNIT Value Description SECT. 36 Section TOWN.N T12N Township RANG. R16E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF KB Log Measured from FAPD.F 55 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 55 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. • (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth adjusted to a PDCL (Primary Depth Control Log) run by Schlumberger dated 15 Apr 2007. (8) Tied to END 1-39 at 10097.5 feet MD (9906.93 feet TVDSS) (9) Runs 1 though 5 were used to set and mill a whipstock at 10097 feet MD (9906 feet TVDSS). (10) Runs 7 and 8 were used to run 3 3/16 inch liner and mill out the liner shoe. (11) Runs 14, 15 and 17 were clean out liner runs. (12) Run 19 open hole sidetracked off aluminum billet at 10440 feet MD (10056.7 feet TVDSS) from END 1-39A PBl/N16. (13) The interval from 11874 feet MD to 11900 feet MD (9987 feet to 9986 feet TVDSS) was not logged due to sensor to bit offset. (14) The bottom of the 3 3/16 inch liner was set at 10400 feet MD (10059 feet TVDSS). (15) The resistivity interval from 10668 feet to 10694 feet Md (10038 feet to 10036 feet TVDSS) was logged 11.5 hours after being drilled. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Compensated Resistivity Borehole Corrected(LS)(AT) (400kHz),Ohm-m RACHX -> Compensated Resistivity Borehole Corrected (LS)(AT) (2MHz),Ohm-m RPCLX -> Compensated Resistivity Borehole Corrected (LS)(PD) (400kHz),Ohm-m RPCHX -> Compensated Resistivity Borehole Corrected (LS)(PD) (2MHz),Ohm-m TVD -> Subsea True Vertical Depth CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10089.1, 10087.4, ! -1.72168 10091, 10089.3, ! -1.72168 10093.1, 10092.1, ! -1.0332 10094.1, 10093.8, ! -0.344727 10096, 10096.9, ! 0.861328 10098.3, 10098.3, ! 0 10101.4, 10102.2, ! 0.860352 10106.7, 10107.1, ! 0.344727 10107.2, 10108.3, ! 1.0332 10109.1, 10110, ! 0.860352 10112.5, 10112.6, ! 0.172852 10113.6, 10115.3, ! 1.72168 10114, 10116.4, ! 2.41113 10117.2, 10119.1, ! 1.89453 10118.1, 10120.8, ! 2.75488 10119.8, 10121.7, ! 1.89355 10124.1, 10124.1, ! 0 10125, 10125.5, ! 0.516602 10125.7, 10126.5, ! 0.861328 10127.2, 10128.1, ! 0.861328 10129.1, 10129.5, ! 0.344727 10131.8, 10132.3, 10133.3, 10133.5, 10134.8, 10135.1, 10136.3, 10136.2, 10138.2, 10137, 10139.8, 10138.9, 10142.3, 10142.1, 10144, 10144, 10144.9, 10145, 10146.1, 10146.6, 10150.9, 10150.9, 10152.3, 10152.6, 10153.7, 10153.8, 10155, 10155.2, 10156, 10156.6, 10158.6, 10159.1, 10160.5, 10160.7, 10162.6, 10162.9, 10168.1, 10167.4, 10169, 10169.1, 10171.4, 10171.4, 10173.1, 10173.1, 10174.7, 10176.4, 10175.9, 10177.9, 10180, 10180.3, 10181.5, 10182.5, 10191.5, 10192.5, 10193.7, 10194.1, 10195.5, 10196, 10198.9, 10197.4, 10200.5, 10198.4, 10205.5, 10205.8, 10207.2, 10207, 10208.9, 10209.1, 10214.4, 10214.4, 10218.4, 10218.4, 10220.4, 10219.9, 10221.6, 10221.5, 10223.2, 10222.8, 10225.1, 10225.3, 10230.1, 10230.8, 10232.2, 10232, 10233.4, 10233.5, 10235.4, 10235.6, 10237.5, 10237.7, 10242.5, 10242.8, 10247.1, 10248.2, 10253.5, 10254.9, 10258.2, 10257.6, 10259.7, 10259.4, 10261.6, 10262.1, 10262.6, 10263.5, 10264.2, 10264.7, 10267.1, 10267.1, 10269.5, 10270, 10272.3, 10271.9, 10274.5, 10273.9, 10276.1, 10275.4, 10279, 10278.5, 10281.3, 10280.4, 10282.6, 10283.5, 10287.6, 10287.5, 10291.1, 10292, 10296.6, 10296.6, 10298, 10298.3, 10299, 10300.2, 10301.4, 10300.9, ! 0.516602 ! 0.171875 ! 0.34375 ! -0.171875 ! -1.20508 ! -0.861328 ! -0.171875 0 ! 0.171875 ! 0.516602 ! p ! 0.34375 ! 0.172852 ! 0.171875 ! 0.516602 ! 0.516602 ! 0.172852 ! 0.344727 ! -0.688477 ! 0.171875 ! 0 I 0 ! 1.72168 ! 2.06641 ! 0.344727 ! 1.0332 ! 1.03223 ! 0.34375 ! 0.516602 ! -1.5498 ! -2.06641 ! 0.344727 ! -0.171875 ! 0.171875 ! 0 ~ 0 ! -0.516602 ! -0.171875 ! -0.344727 ! 0.171875 ! 0.688977 ! -0.172852 ! 0.171875 ! 0.172852 ! 0.171875 ! 0.344727 ! 1.0332 ! 1.37695 ! -0.516602 ! -0.344727 ! 0.516602 ! 0.861328 ! 0.516602 ! 0 ! 0.516602 ! -0.34375 ! -0.689453 ! -0.688477 ! -0.516602 ! -0.861328 ! 0.861328 ! -0.171875 ! 0.860352 ! 0 ! 0.344727 ! 1.20508 ! -0.516602 10303.5, 10304.3, ! 0.860352 10305.7, 10305.4, ! -0.344727 10309.9, 10310, ! 0.172852 10310.5, 10311.1, ! 0.515625 10312.3, 10312.4, ! 0.171875 10314.6, 10315, ! 0.344727 10322.3, 10321.5, ! -0.861328 10325.6, 10327.3, ! 1.72168 10330.8, 10330.5, ! -0.34375 10332.9, 10334.1, ! 1.20605 10335.6, 10336.1, ! 0.516602 10337.2, 10338.2, ! 1.0332 10340.1, 10340.1, ! 0 10344.1, 10343, ! -1.03223 10346.6, 10345.1, ! -1.5498 10347.3, 10346.8, ! -0.516602 10349.7, 10349.9, ! 0.171875 10350.7, 10351.9, ! 1.20605 10352.7, 10353.2, ! 0.516602 10354.7, 10355.4, ! 0.688477 10355.9, 10357.7, ! 1.72168 10357.7, 10359.6, ! 1.89355 10359.9, 10361.8, ! 1.89355 10360.9, 10363.2, ! 2.23828 10363.7, 10364.5, ! 0.860352 10365.9, 10366.4, ! 0.515625 10386.6, 10385.9, ! -0.688477 10387.7, 10389, ! 1.37793 10388.7, 10390.3, ! 1.5498 10395.3, 10394.1, ! -1.20508 10397.4, 10398, ! 0.688477 10401.5, 10400.6, ! -0.861328 10403.6, 10401.8, ! -1.72168 10405.1, 10404.9, ! -0.171875 10406, 10406.5, ! 0.516602 10408.2, 10407.7, ! -0.516602 10409.9, 10409.1, ! -0.860352 10411.8, 10412.2, ! 0.344727 10417, 10414.6, ! -2.41113 10418.5, 10416, ! -2.58203 10422.3, 10422, ! -0.34375 10426.1, 10427, ! 0.861328 10427.7, 10428, ! 0.34375 10432.1, 10430.4, ! -1.72168 10433, 10431.6, ! -1.37695 10437,1, 10435.4, ! -1.72168 10438.7, 10438, ! -0.688477 10440.5, 10439.4, ! -1.0332 10443.2, 10441.4, ! -1.89355 10443.9, 10442.9, ! -1.0332 10444.6, 10444.1, ! -0.516602 10447.7, 10448.4, ! 0.688477 10451.2, 10452.4, ! 1.20508 10455.1, 10455, ! -0.171875 10457, 10456.5, ! -0.516602 10458, 10457.5, ! -0.516602 10460.9, 10460.8, ! -0.172852 10463.3, 10463.3, ! 0 10464.4, 10464, ! -0.344727 10467, 10467.7, ! 0.689453 10470.2, 10469.4, ! -0.860352 10471.1, 10470.4, ! -0.688477 10473, 10472, ! -1.03223 10474.9, 10473.3, ! -1.5498 10484.1, 10484.8, ! 0.688477 10485.5, 10486.3, ! 0.861328 10486.8, 10487.9, ! 1.0332 • • 10488, 10489.4, ! 1.37695 10488.9, 10490.5, ! 1.5498 10489.9, 10491.7, ! 1.72168 10490.6, 10492.9, ! 2.23828 10492.5, 10493.6, ! 1.0332 10497.2, 10498.4, ! 1.20508 10497.8, 10499.9, ! 2.06543 10500.3, 10502.2, ! 1.89355 10503.2, 10503, ! -0.171875 10504.1, 10504.7, ! 0.689453 10507.5, 10507, ! -0.516602 10507.8, 10508.7, ! 0.861328 10510.1, 10510.4,. ! 0.34375 10512.1, 10512.3, ! 0.172852 10514, 10514.4, ! 0.34375 10515.4, 10515.8, ! 0.34375 10517.7, 10517.3, ! -0.344727 10519.6, 10519.2, ! -0.34375 10520.8, 10520.6, ! -0.171875 10525, 10525.4, ! 0.344727 10525.9, 10526.4, ! 0.516602 10526.6, 10527.1, ! 0.516602 10530.1, 10531, ! 0.861328 10532.4, 10532.4, ! 0 10543, 10542.9, ! -0.171875 10545.6, 10546.1, ! 0.516602 10549.8, 10550.3, ! 0.516602 10551.1, 10551, ! -0.171875 10552.3, 10552.5, ! 0.171875 10553.2, 10553.4, ! 0.171875 10554.6, 10554.9, ! 0.34375 10557.3, 10557.2, ! -0.171875 10558.7, 10558.9, ! 0.171875 10560.1, 10560.4, ! 0.344727 10562.2, 10561.3, ! -0.860352 10563.5, 10563, ! -0.516602 10565.2, 10565.1, ! -0.171875 10567, 10566.5, ! -0.516602 10568.4, 10567.7, ! -0.688477 10569.1, 10568.9, ! -0.171875 10570.1, 10570.9, ! 0.861328 10571.1, 10572.3, ! 1.20508 10573.4, 10574.4, ! 1.0332 10577.3, 10576.5, ! -0.860352 10578.5, 10578, ! -0.516602 10579, 10578.9, ! -0.171875 10580.2, 10580.9, ! 0.689453 10581.2, 10582, ! 0.861328 10585.1, 10585.6, ! 0.516602 10594.1, 10593, ! -1.0332 10598.1, 10596, ! -2.06543 10603.1, 10603.2, ! 0.171875 10604.4, 10604.6, ! 0.172852 10605.1, 10605.1, ! 0 10606.3, 10606, ! -0.344727 10607.9, 10607.5, ! -0.344727 10608.9, 10609.6, ! 0.688477 10614.9, 10616, ! 1.0332 10615.8, 10616.7, ! 0.860352 10617.2, 10617.9, ! 0.688477 10617.9, 10618.5, ! 0.689453 10618.5, 10620.4, ! 1.89355 10622.2, 10622.9, ! 0.688477 10624.1, 10625.4, ! 1.37793 10625.8, 10627.5, ! 1.72168 10628, 10628.7, ! 0.688477 10630.3, 10631.6, ! 1.37695 10632.7, 10633.9, 10633.7, 10634.7, 10634.9, 10636.1, 10639.4, 10640.1, 10644.1, 10642.9, 10644.8, 10644.4, 10647, 10647.3, 10648.7, 10649.2, 10652.5, 10651.8, 10654.9, 10653.9, 10658.2, 10658, 10658.9, 10659.6, 10659.4, 10659.9, 10661.3, 10660.6, 10664.1, 10663.4, 10665.1, 10665.4, 10667.2, 10666.8, 10669.8, 10669.2, 10670.6, 10670.3, 10672.5, 10671.6, 10673.7, 10674.4, 10678.9, 10676.3, 10681.8, 10680.9, 10683.5, 10683.9, 10684.4, 10684.6, 10685.4, 10685.9, 10690.2, 10689, 10691.6, 10690.6, 10692.8, 10692.7, 10695.1, 10693.9, 10697.6, 10695.7, 10699.6, 10699.1, 10702.1, 10700.4, 10703.1, 10702, 10706.2, 10703.4, 10706.9, 10705, 10710, 10708.1, 10710.1, 10708.7, 10711, 10710.5, 10716.7, 10715.5, 10720.6, 10719.1, 10723.4, 10721, 10723.9, 10722.5, 10729.3, 10727.8, 10730.4, 10729.5, 10731.7, 10731.4, 10732.5, 10732.9, 10734.3, 10734.1, 10738.6, 10738.4, 10739.1, 10739.9, 10744.8, 10744.8, 10746.7, 10747.3, 10751.7, 10750.9, 10753, 10751.6, 10759.2, 10759.1, 10761.9, 10760.4, 10763.3, 10764, 10765.5, 10765.5, 10768.4, 10768.4, 10773.9, 10771.8, 10777.6, 10776.5, 10779.8, 10778.1, 10782.3, 10779.4, 10787.1, 10786.1, 10792.5, 10791.8, 10793.5, 10793.5, 10795, 10795, 1.20508 1.0332 1.20508 0.689453 -1.20605 -0.344727 0.34375 0.516602 -0.688477 -1,0332 -0.171875 0.688477 0.516602 -0.688477 -0.688477 0.34375 -0.344727 -0.516602 -0.344727 -0.860352 0.689453 -2.58301 -0.861328 0.344727 0.171875 0.516602 -1.20508 -1.0332 -0.171875 -1.20508 -1.89453 -0.516602 -1.72168 -1.0332 -2.75488 -1.89355 -1.89453 -1.37695 -0.516602 -1.20508 -1.5498 -2.41016 -1.37793 -1.54883 -0.860352 -0.34375 0.344727 -0.171875 -0.172852 0.860352 0 0.688477 -0.861328 -1.37793 -0.171875 -1.54883 0.688477 0 0 -2.06641 -1.03223 -1.72168 -2.92676 -1.0332 -0.688477 0 0 10797.3, 10796.1, 10799.5, 10799.3, 10800.9, 10800.4, 10801.6, 10801.8, 10803, 10802.6, 10804.3, 10804.3, 10805, 10805, 10806.4, 10807.6, 10809.7, 10809.5, 10811.2, 10810.5, 10812.4, 10812.4, 10815.9, 10814.7, 10817.1, 10815.5, 10819.5, 10818.1, 10820.3, 10820, 10823.8, 10822.8, 10825, 10825.2, 10827.3, 10826.9, 10828.8, 10828.6, 10830.7, 10830.2, 10832.4, 10831.9, 10834.3, 10832.9, 10836.7, 10835.5, 10837.9, 10837.4, 10850, 10848.1, 10852.4, 10850.7, 10853.6, 10851.9, 10855.1, 10853.6, 10855.8, 10855.1, 10859.8, 10857, 10862.2, 10859.1, 10869.1, 10866.5, 10869.8, 10868.6, 10874.6, 10875.3, 10879.1, 10880.3, 10880.8, 10881.7, 10882.2, 10883.4, 10883.4, 10885.6, 10886, 10887, 10886.8, 10887.9, 10896.7, 10897.6, 10900, 10899.5, 10901, 10900.9, 10902.4, 10902.6, 10902.9, 10904, 10905.7, 10906, 10909.9, 10908, 10912.4, 10912.6, 10913.1, 10913.8, 10914.3, 10915, 10918.1, 10918.6, 10925.7, 10925.5, 10931, 10930.5, 10933.8, 10933.5, 10936.9, 10937.8, 10937.9, 10939.3, 10939.1, 10941.2, 10940.9, 10942.6, 10944, 10944.5, 10944.8, 10946, 10946.5, 10947.4, 10951.1, 10949.6, 10952.7, 10951.5, 10955.4, 10954.3, 10959.5, 10958.3, 10963.1, 10962.4, 10971.5, 10970.2, 1 I i -1.20508 -0.172852 -0.516602 0.172852 -0.344727 0 1.20508 -0.171875 -0.688477 0 -1.20508 -1.5498 -1.37793 -0.34375 -1.0332 0.171875 -0.344727 -0.171875 -0.516602 -0.516602 -1.37793 -1.20508 -0.516602 -1.89453 -1.72168 -1.72168 -1.5498 -0.688477 -2.75488 -3.09961 -2.58301 -1.20508 0.688477 1.20508 0.860352 1.20508 2.23828 0332 1.03223 0.861328 -0.516602 -0.172852 0.171875 1.0332 0.344727 -1.89355 0.171875 0.688477 0.689453 0.516602 -0.172852 -0.516602 -0.344727 0.861328 1.37793 2.06641 1.72168 0.516602 1.20605 0.860352 -1.5498 -1.20605 -1.0332 -1.20508 -0.689453 -1.37793 10972.1, 10971.5, 10974, 10973.6, 10975.7, 10974.4, 10976.8, 10975.9, 10981.1, 10979.9, 10982.8, 10982.8, 10985.5, 10985.8, 10986.5, 10987.4, 10987.6, 10988.8, 10991.9, 10991.5, 10993.8, 10992.3, 10995.2, 10994.2, 10996.1, 10995, 10998.1, 10996.5, 11000.1, 10998.9, 11000.7, 11000.5, 11002.2, 11001.5, 11002.9, 11003.1, 11007, 11005.8, 11008.1, 11007.9, 11009.3, 11009.1, 11014.1, 11012.9, 11026.4, 11025.7, 11030.4, 11029.3, 11032.1, 11031.8, 11038.8, 11038.4, 11040.7, 11039.8, 11052.2, 11050.8, 11053.1, 11052, 11054.1, 11054.6, 11055.5, 11056.7, 11058.6, 11058.3, 11059.6, 11060.1, 11060, 11061.3, 11069.8, 11070.1, 11071.7, 11071.8, 11073.9, 11073.7, 11075.1, 11075.1, 11077, 11076.1, 11077.6, 11077.5, 11080.2, 11079.4, 11080.9, 11081.4, 11082.1, 11082.6, 11089.9, 11088.9, 11091.8, 11090.1, 11092.7, 11093, 11094.6, 11094.6, 11099.4, 11099.2, 11101, 11101, 11102.2, 11102.5, 11103.5, 11103.4, 11104.9, 11105.6, 11106.3, 11107.2, 11109.7, 11109.1, 11112.1, 11113.5, 11119.7, 11118.8, 11124.4, 11124, 11125.4, 11125.4, 11126.4, 11127, 11127.1, 11128.5, 11127.8, 11130.1, 11132.5, 11132.5, 11134.9, 11134, 11136.3, 11135.9, 11137.1, 11136.9, 11138.2, 11137.8, 11140, 11140.4, ! -0.516602 ! -0.344727 ! -1.37793 ! -0.861328 ! -1.20508 ! 0 ! 0.34375 ! 0.860352 ! 1.20508 ! -0.344727 ! -1.5498 ! -1.03223 ! -1.0332 ! -1.5498 ! -1.20508 ! -0.172852 ! -0.689453 ! 0.171875 ! -1.20508 ! -0.171875 ! -0.171875 ! -1.20508 ! -0.688477 ! -1.0332 ! -0.34375 ! -0.344727 ! -0.861328 ! -1.37793 ! -1.0332 ! 0.516602 ! 1.20605 ! -0.344727 ! 0.516602 ! 1.37793 ! 0.344727 ! 0.172852 ! -0.171875 ! 0 ! -0.861328 ! -0.171875 ! -0.860352 ! 0.515625 ! 0.516602 ! -1.03223 ! -1.72168 ! 0.344727 ! 0 ! -0.171875 0 ! 0.344727 ! -0.172852 ! 0.688477 ! 0.860352 ! -0.689453 ! 1.37793 ! -0.861328 ! -0.344727 ! 0 ! 0.515625 ! 1.37695 ! 2.23828 ! 0 ! -0.861328 ! -0.344727 ! -0.172852 ! -0.34375 ! 0.344727 11141, 11141.6, 11142.1, 11142.6, 11151.2, 11150.6, 11153, 11151.9, 11158.5, 11157.5, 11159.6, 11159.6, 11160.8, 11161, 11165.5, 11163.8, 11168.6, 11168.9, 11170.7, 11170.7, 11171, 11172, 11173.9, 11173.4, 11181.7, 11181, 11183.9, 11182.5, 11186, 11184.8, 11186.5, 11187, 11189, 11188.5, 11197.5, 11196.3, 11198.6, 11198.6, 11199.6, 11199.9, 11202.6, 11202.6, 11204.8, 11203.8, 11206.7, 11205.8, 11208.4, 11207.9, 11210.3, 11209.5, 11212, 11211.5, 11215.6, 11216.8, 11220.6, 11221.3, 11227, 11229.1, 11229.3, 11230.7, 11231.2, 11232..7, 11236.5, 11235.8, 11239.1, 11238.6, 11243.1, 11242.6, 11246.6, 11246.6, 11249.4, 11248.3, 11252.8, 11251.8, 11256.1, 11253.9, 11259.4, 11259.2, 11260.6, 11261.3, 11266.4, 11265.7, 11268.4, 11269.2, 11273.5, 11272.8, 11276.2, 11278.6, 11277.6, 11279.5, 11285.2, 11286.9, 11288.8, 11288.3, 11289.9, 11290.4, 11291.9, 11292.6, 11298.8, 11298.4, 11303.4, 11301.3, 11305.7, 11303.1, 11309.6, 11310, 11313.7, 11313.7, 11315.5, 11314.7, 11318, 11316.8, 11320.3, 11319.1, 11322.5, 11321.8, 11324.2, 11325.3, 11326.8, 11327.3, 11328.7, 11328.4, 11332.9, 11332, 11335.4, 11334.9, 11338.4, 11336.6, 11341.6, 11340.4, 11342.7, 11341.8, 11343.7, 11343.5, 0.516602 0.516602 -0.688477 -1.0332 -1.0332 0 0.171875 -1.72266 0.344727 0 1.0332 -0.516602 -0.688477 -1.37695 -1.20508 0.516602 -0.516602 -1.20508 0 0.344727 0 -1.0332 -0.861328 -0.516602 -0.860352 -0.516602 1.20508 0.688477 2.06641 1.37695 1.54883 -0.688477 -0.515625 -0.516602 0 -1.03223 -1.0332 -2.23828 -0.171875 0.689453 -0.688477 0.861328 -0.688477 2.41016 1.89355 1.72168 -0.516602 0.515625 0.688477 -0.344727 -2.06641 -2.58301 0.344727 0 -0.861328 -1.20508 -1.20508 -0.688477 1.0332 0.516602 -0.34375 -0.861328 -0.515625 -1.72168 -1.20605 -0.860352 -0.171875 • 11344.9, 11344.2, 11347.7, 11347.5, 11349.9, 11351.1, 11351.1, 11352, 11352.9, 11353.3, 11356.5, 11355.6, 11358.6, 11357.4, 11359.8, 11358.9, 11363.1, 11361.3, 11366, 11364.9, 11369.7, 11369.9, 11372, 11371.8, 11373, 11373.4, 11377, 11375.5, 11378.3, 11377.5, 11380.6, 11379.9, 11381.4, 11381.1, 11383.5, 11383, 11384, 11384.5, 11384.9, 11386.4, 11387.1, 11388.7, 11388.5, 11390.2, 11392.6, 11393.5, 11395.8, 11398.4, 11397.5, 11399.5, 11400, 11400.4, 11402.8, 11403.8, 11406.6, 11407.1, 11413.5, 11411.9, 11414.5, 11413, 11415, 11414.3, 11418.1, 11415.5, 11419.7, 11418, 11421.6, 11419.3, 11424, 11421.2, 11425.6, 11422.9, 11426.5, 11424.8, 11427.9, 11427.4, 11430.8, 11429.9, 11432.4, 11433, 11434.6, 11434.4, 11435.8, 11435.5, 11439.6, 11438.4, 11446.6, 11445.4, 11448, 11446.8, 11452, 11450.6, 11453, 11451.5, 11454.2, 11452.5, 11457.3, 11454.9, 11459.7, 11458.5, 11460.8, 11459.4, 11463.3, 11461.1, 11468, 11465.9, 11475.2, 11474.8, 11478.1, 11476.5, 11479.3, 11477.2, 11481.9, 11480.1, 11485.1, 11482.9, 11486.2, 11484.6, 11488.1, 11486.9, 11490.1, 11487.5, 11490.5, 11489.1, 11491.5, 11490.5, 11492.5, 11491.3, 11494.1, 11492.5, 11495, 11494.4, 11495.5, 11496.3, ! -0.688477 ! -0.171875 ! 1.20508 ! 0.861328 ! 0.344727 ! -0.861328 ! -1.20508 ! -0.860352 ! -1.72168 ! -1.0332 ! 0.171875 ! -0.172852 ! 0.344727 ! -1.5498 ! -0.861328 ! -0.688477 ! -0.34375 ! -0.516602 ! 0.516602 ! 1.54883 ! 1.54883 ! 1.72168 ! 0.861328 ! 2.58203 ! 2.06641 ! 0.34375 ! 1.03223 ! 0.516602 ! -1.5498 ! -1.5498 ! -0.689453 ! -2.58203 -1.72168 ! -2.23828 -2.75488 ! -2.75488 ! -1.72168 ! -0.516602 ! -0.861328 0.688477 ! -0.172852 ! -0.344727 ! -1.20605 ! -1.20508 -1.20605 -1.37793 -1.5498 ! -1.72168 ! -2.41113 ! -1.20605 ! -1.37695 ! -2.23828 -2.06641 ! -0.34375 ! -1.5498 ! -2.06641 ! -1.72168 ! -2.23828 ! -1.5498 ! -1.20605 ! -2.58203 ! -1.37793 ! -1.0332 ! -1.20605 ! -1.54883 -0.516602 ! 0.860352 11496, 11497.9, 11502.3, 11502.7, 11503, 11504.4, 11504.9, 11505.6, 11505.9, 11506.1, 11506.6, 11507.5, 11507.8, 11509.7, 11509.6, 11511.5, 11514.1, 11513.2, 11519.6, 11518.9, 11523.7, 11522.8, 11526.8, 11524, 11533.9, 11532.9, 11541.3, 11540.6, 11542.2, 11541, 11543.5, 11541.5, 11546.8, 11546, 11551.3, 11548.7, 11558.7, 11559.6, 11566.3, 11566.1, 11568, 11567.1, 11575.1, 11574.9, 11577, 11575.8, 11583, 11582.3, 11587.2, 11585.4, 11587.7, 11586.5, 11589.2, 11587.9, 11598.4, 11599.1, 11601, 11600.4, 11601.7, 11602.2, 11608.6, 11610.4, 11610.7, 11611.4, 11613.9, 11613.9, 11620.1, 11620.4, 11621.5, 11622, 11624.6, 11624.2, 11627.3, 11626.8, 11631, 11628.9, 11632.9, 11632.3, 11636.6, 11634.1, 11637.8, 11635.7, 11641.3, 11641.9, 11643, 11643, 11645.1, 11643.9, 11651.6, 11650.6, 11656.9, 11655.9, 11658.1, 11657.5, 11661.2, 11659.3, 11664.5, 11663.1, 11668, 11665.6, 11670.1, 11668, 11672.7, 11671.3, 11675.3, 11673.4, 11676.8, 11674.6, 11679, 11676.6, 11681.6, 11679.6, 11682.5, 11680.4, 11684.2, 11682.5, 11686.3, 11685.1, 11687.8, 11685.8, 11691.5, 11689.4, 11692.3, 11690.8, 11693.5, 11692.7, 11695.2, 11695.1, 11696.3, 11695.8, 11698.9, 11697.3, 11700.3, 11699.6, 1.89355 0.344727 1.37695 0.688477 0.171875 0.861328 1.89453 1.89453 -0.861328 -0.688477 -0.860352 -2.75488 -1.0332 -0.688477 -1.20605 -2.06641 -0.860352 -2.58301 0.861328 -0.171875 -0.861328 -0.172852 -1.20508 -0.689453 -1.72168 -1.20508 -1.37793 0.688477 -0.515625 0.516602 1.72168 0.688477 0 0.344727 0.516602 -0.34375 -0.516602 -2.06543 -0.516602 -2.58301 -2.06.641 0.688477 -1.20508 -1.03223 -1.0332 -0.688477 -1.89453 -1.37793 -2.41113 -2.06543 -1.37793 -1.89453 -2.23828 -2.41016 -2.06641 -2.06543 -1.72266 -1.20508 -2.06641 -2.06641 -1.5498 -0.860352 -0.171875 -0.516602 -1.54883 -0.688477 -. ~ ~ 11702.2, 11701.7, ! -0.516602 11706.8, 11706.1, ! -0.688477 11708.2, 11707.9, ! -0.344727 11714, 1 1713, ! -1.0332 11718, 1 1716.6, ! -1.37695 11732.1, 11730.1, ! -2.06641 11733.2, 11731.6, ! -1.5498 11734.5, 11732.6, ! -1.89355 11735.7, 11734.4, ! -1.37695 11741.4, 11739.4, ! -2.06543 11743.4, 11742.2, ! -1.20605 11745, 1 1742.9, ! -2.06543 11746.8, 11746.6, ! -0.171875 11748.7, 11748.1, ! -0.516602 11755, 1 1753.6, ! -1.37793 11756, 1 1754.4, ! -1.5498 11757.8, 11756.1, ! -1.72168 11772, 11771.3, ! -0.688477 11774.9, 11775.8, ! 0.860352 11775.8, 11776.8, ! 1.0332 11777.8, 11778, ! 0.171875 11785.5, 11784.3, ! -1.20508 11788.2, 11786.8, ! -1.37695 11789.2, 11788.4, ! -0.861328 11790.6, 11789.4, ! -1.20508 11791.7, 11790.6, ! -1.0332 11793.5, 11791.7, ! -1.89453 11794.9, 11793.4, ! -1.5498 11796.3, 11794.9, ! -1.37793 11797.9, 11796.8, ! -1.0332 11798.6, 11799.6, ! 1.0332 11801.1, 11800.6, ! -0.516602 11804.2, 11804.6, ! 0.34375 11807.3, 11807.2, ! -0.171875 11811.1, 11809.2, ! -1.89355 11812.3, 11811.1, ! -1.20605 11820.4, 11822.3, ! 1.89355 11822.9, 11824.1, ! 1.20605 11825.4, 11824.9, ! -0.516602 11837.1, 11836.6, ! -0.516602 11844.2, 11842.8, ! -1.37695 11844.9, 11844.4, ! -0.516602 11845.9, 11846.3, ! 0.34375 11848.8, 11849.2, ! 0.34375 11851.4, 11851.3, ! -0.171875 11855.1, 11854, ! -1.0332 11857.3, 11856.6, ! -0.689453 11858.3, 11857.9, ! -0.34375 11859.1, 11858.8, ! -0.344727 11861.1, 11859.9, ! -1.20508 11861.6, 11861, ! -0.688477 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 754 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1-39A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN END 1-39A/N16 APIN FN Endicott COUN North Slope Borough STAT Alaska *** LIS COMMENT RECORD *** • !!~!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL run by Schlumberger dated 15 Apr 2007. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RAD MWD 68 1 OHMM 3 RAS MWD 68 1 OHMM 4 RPD MWD 68 1 OHMM 5 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 20 Total Data Records: 87 Tape File Start Depth = 10086.000000 Tape File End Depth = 11899.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 99 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1-39A.xtf LCC 150 CN BP Exploration (Alaska) WN END 1-39A/N16 APIN FN Endicott COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!~~!~~!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM ------ ODEP GRAX GRAX ------ GRAX ----------------- 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F w ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 RACL MWD 68 1 OHMM 3 RACH MWD 68 1 OHMM 4 RPCL MWD 68 1 OHMM 5 RPCH MWD 68 1 OHMM Total Data Records: 173 Size Length 4 4 4 4 4 4 4 4 4 4 20 Tape File Start Depth = 10086.750000 Tape File End Depth = 11899.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 185 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/04/13 1365739 Ol **** REEL TRAILER **** MWD 08/03/13 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RAD RAS RPD RPS 10086.0000 89.5314 -999.2500 -999.2500 -999.2500 -999.2500 10086.5000 88.2485 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 70.6789 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 130.0207 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 29.8261 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 24.8073 117.7756 377.3723 0.2343 54688.4922 10500.0000 45.1360 25.9367 22.1622 32.0090 35.9418 10600.0000 26.3338 24.2630 32.4496 37.9300 42.8340 10700.0000 31.0922 22.2381 33.8615 54.2938 78.6749 10800.0000 28.7527 67.1331 33.6111 30.0307 25.6107 10900.0000 23.0856 14.1800 21.2872 32.4217 54.4057 11000.0000 30.3648 35.2172 36.8512 31.4422 27.0406 11100.0000 28.5000 19.8079 23.6557 28.2027 32.9489 11200.0000 31.6802 25.9922 19.2771 26.2270 27.7328 11300.0000 53.1454 19.7078 28.1348 39.8842 49.3079 11400.0000 64.6479 16.2207 24.9580 38.7957 61.3958 11500.0000 21.6023 28.7426 80.5893 193.7360 434.5217 11600.0000 29.2606 27.2855 62.0257 207.3440 555.2078 11700.0000 147.1074 29.0389 50.4268 99.9277 152.6559 11800.0000 33.2805 24.8574 22.0737 30.0787 29.8694 11899.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10086.000000 Tape File End Depth = 11899.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX RACL RACH RPCL RPCH 10086.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10087.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 70.4000 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 87.5000 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 28.4000 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 27.5000 2162.8501 6933.3096 0.2480 98641.8906 10500.0000 41.6000 26.5250 22.9460 33.7970 38.1450 10600.0000 22.5000 23.6200 31.1430 37.1830 42.5080 10700.0000 30.4000 22.5940 37.9390 61.1110 91.6560 10800.0000 29.3000 64.7390 33.3820 30.6390 26.2260 10900.0000 22.8000 14.0850 21.3250 32.0090 53.4860 11000.0000 35.1000 35.9060 37.7660 30.9040 26.6330 11100.0000 28.5000 19.7770 23.7870 28.4040 33.2630 11200.0000 30.0000 25.5200 19.3020 26.2270 27.4790 11300.0000 53.3000 19.9160 28.1530 37.5570 44.2970 11400.0000 59.5000 16.2070 23.6130 38.1300 60.0300 11500.0000 23.7000 28.2740 77.8740 200.3880 481.1090 11600.0000 29.9000 27.8110 58.1940 209.1260 547.4619 11700.0000 124.7000 28.9680 51.2280 109.9200 180.4400 11800.0000 33.6000 23.2550 22.8350 30.2600 28.7470 11899.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10086.750000 Tape File End Depth = 11899.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
