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Home My WebLink About206-0867. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-39A Mill CIBP , Pull Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-086 50-029-22503-01-00 11650 Conductor Surface Intermediate Liner Liner 8856 80 3488 4259 4196 3496 11546 20" 13-3/8" 9-5/8" 7" 4-1/2" 8855 34 - 114 34 - 3522 31 - 4290 4124 - 8320 8157 - 11650 34 - 114 34 - 3522 31 - 4290 4124 - 8248 8093 - 8855 unknown , 11543 470 2260 4760 5410 7500 9000 1490 5020 6870 7240 8430 8339 - 11480 4-1/2" 12.6# 13Cr80 29 - 8157 8266 - 8856 Structural 4-1/2" Baker S-3 Perm , 8100 , 8046 No SSSV 8100 8046 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028306 29 - 8098 227 1171 30292 46997 70 4 0 0 986 1215 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:02 am, Mar 21, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.20 14:56:17 - 08'00' Bo York (1248) DSR-3/21/24WCB 2024-07-01 RBDMS 032824 JSB ACTIVITYDATE SUMMARY 2/17/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke Arrive to location, MIRU CTU, M/U YJ 2-7/8" milling BHA. PT PCE. Stack down for evening, daylight operations ***Continue to WSR on 2/18/24*** 2/18/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke RIH w/ YJ 2-7/8" milling BHA w/3.7" venturi burnshoe, Load well with Slick KCL w/SL, roll coil over to KCL RIH tag plug at 8975 CTMD. Mill plug and push/venturi down to 9,200' CTM. POOH. Recover 6 slips and apx 1/2 cup of small metal pieces. Make up venturi basket RIH. Perform well control drill. Venturi down to 100' above snap latch (10200' max depth). Recover 3 rubber pieces, 1 cup of metal fines and debris, 1 threaded ring and the top slip bushing, which had plugged off the bottom of the mule shoe. Begin BOPE Test. ***Job Continued to 2/19/24*** 2/19/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke BOPE Test. RIH w/YJ venturi, push plug down to snap latch while pumping, recip up and down. POOH. Recover full element from plug and 1/4 cup of small metal debris. RBIH with YJ Venturi. Almost no debris in basket, 1/4 cup of fines and shavings. Stack down to Change Packoffs, Inspect Injector. Trim 100' of Pipe. ***Job Continued to 2/20/24*** 2/20/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke RIH with YJ 4" GS Fishing BHA. No Latch after multiple attemps @ 10292'. Pump Max rate while recip at Fish Neck. POOH to inspect GS. BHA looks fine. Run smaller YJ 3.125" Venturi Mule Shoe. Still Nothing in Junk Basket. No Core Recovered. LD Tools, Secure Well, PT BOP Cap to 2500 psi. Start Weather Standby @ 1030. ***Job Continued to 2/21/24*** 2/21/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke Continue Weather Hold until 1700. Normal winter guidelines (end phase conditions). SLB using crew to Perform Pipe Swap for Conoco at SLB yard. 1700 start Zero Rate. No night WSS coverage due to flights being re-scheduled. ***Job Continued to 2/22/24*** Daily Report of Well Operations PBU 15-39A gg POOH. Recover full element from plug and 1/4 cup of small metal debris.g RBIH with YJ Venturi. Almost no debris in basket, 1/4 cup of fines and shavings g RIH tag plug at 8975 CTMD. Mill plug and push/venturi down to 9,200' CTM. POOH. Job Scope: Mill/recover 4.5 CIBP Daily Report of Well Operations PBU 15-39A 2/22/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke Continue Zero Rate Standby until 0430. Crew arrives unit, start engines, begin digging out snow. Start Weather Rate @ 04:30. ***Job in Progress*** 2/23/2024 CTU #9: 1.75" CT 0.156 wall. Job Scope: Mill/recover 4.5 CIBP, Retrieve choke ***Job continued form 2/23/24*** MU YJ venturi basket with wire grab shoe. RIH. Tag at 10218 ctmd. Venturi above the snaplatch. Stack 10k and hit a jar lick down. POOH. Plug core recovered. RIH with 4" YJ GS Spear. Pulled Blank Choke (10292' CTM = 10316' MD) on first Overpull, 42k. 9.39' recovered. FP Tubing with Diesel 40 bbls total. 3 bpm @ 225 psi. RDMO. ***Job Completed*** MU YJ venturi basket with wire grab shoe. RIH. Tag at 10218 ctmd. Venturi abovegg the snaplatch. Stack 10k and hit a jar lick down. POOH. Plug core recovered. RIHjg with 4" YJ GS Spear. Pulled Blank Choke (10292' CTM = 10316' MD) on first Overpull, 42k. 9.39' recovered. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-086 6.50-029-22503-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11650 9000 8805 4136, 8100, 8162, 11543 , unknown 9000 4136, 8046, 8103, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34 - 114 34 - 114 1490 470 Surface 3488 13-3/8" 34 - 3522 34 - 3522 5020 2260 Intermediate 4259 9-5/8" 31 - 4290 31 - 4290 6870 4760 Liner 4196 7" 4124 - 8320 4124 - 8248 7240 5410 Perforation Depth: Measured depth: 8190 - 11559 feet True vertical depth:8129 - 8856 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 29 - 8157 29 - 8098 Packers and SSSV (type, measured and true vertical depth) Liner 3493 4-1/2" 8157 - 11650 8093 - 8855 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1223024382 5832709 0 36729 504 956 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564 -5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8856 Sundry Number or N/A if C.O. Exempt: n/a Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028306 PBU 15-39A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations no SSSV By Samantha Carlisle at 6:14 pm, Dec 03, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.12.03 16:23:40 -09'00' Bo York RBDMS HEW 12/4/2020 SFD 12/4/2020MGR22DEC2020DSR-12/7/2020 ACTIVITYDATE SUMMARY 10/31/2020 T/I/O = 2430/VAC/VAC. Temp = SI. T FL (e-line request). No AL. T FL @ 9420' (2nd set of perfs, 144 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30 11/3/2020 ...Well shut in on arrival... (HES Eline - CIBP and Adperf) SET NORTHERN SOLUTIONS ALPHA 4-1/2" CIBP MID-ELEMENT AT 9,000'. PERFORATE 8,362'-8,383' WITH 21' x 3-1/8", 6 SPF, 60 DEG PHASING HSC LOADED W/ 22.7GR GEODYNAMIX BASIX CHARGES. REFERENCE LOG HALLIBURTON MWD 6-SEP-2006. REFERNCE LOG PERFOATION DEPTHS 8,332' - 8,376'. ...Continued on 4-Nov-20... 11/3/2020 T/I/O-2407/vac/vac. Load and Kill for E-Line. Pumped 200 bbls of 70*F crude down Tbg. SwV, WV, SSV-Closed, MV-open, IA/OA-OTG. FWHP-130/vac/vac. 11/4/2020 ***JOB CONTINUED FROM 03-NOV-2020*** (HES E-Line Plug & Perforate) PERFORATE 8,339' - 8,360' W/ 3.125", 6 SPF, 60 DEG PHASE GUN. ALL LOGS CORRELATED TO SLB CNL DATED 17-NOV-2013. ***JOB COMPLETE, S/I ON DEPARTURE, TURNED OVER TO DSO*** Daily Report of Well Operations PBU 15-39A Image Project Well History File Cover 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 dire/c_t inspecatio/n~of the file. ~ ID - Q O Y~ Well History File Identifier Organizing (done> RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ...wo=,d~ iiuioiiu DIGITAL DATA (Diskettes, No. ^ Other, No/Type: iii Re,~a~~eeaee uuimiiiuiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ~ ^ Other:: /s/ ~~ Project Proofing III IIIIII (IIII II III BY: Maria Date: / ~ ~ /s/ Scanning Preparation d x 30 = ~~ + ~s =TOTAL PAGES , / / ' (Count does not include cover sheet) ~ BY: Maria Date: Q ~, p ~ /s/ ~ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: / ~/~1 ~~ ~ /s/ Stage 1 If NO In stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this paint unless rescanning is required. III II ~I II II II I I III ReScanned IIIIIIIIIII111 IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'I II ~II II'I III 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 � -- og �O January 6, 2012 d- " 15 3 P\ s‘,'N C Mr. Tom Alaska Oil and � and Gas Conservation Commission �.� ts �tti� 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 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 907 - 659 -5102. Sincerely, G r ~ tr bi EELS 7 2O1 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) DS-15 Date: 11/09/11 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 gal 15-01B 2042570 50029206960200 15-028 2060720 50029206970200 15-03 1820300 50029207220000 15-04B 2071380 50029207260200 15-05A 1950340 50029207310100 15-06A 1982540 50029207420100 15-07C 2030970 50029211660300 15-08C 2050050 50029211800300 15-09A 1931380 50029212010100 15-10A 1880850 50029205010100 15-118 2041460 50029206530200 15-12B 2060870 50029206650200 15-13A 1991240 50029206450100 15-14A 2042220 50029206820100 15-15C 2081820 50029206910300 15-16B 2011920 50029211150100 15-17 1840890 50029211260000 15-18A 2080830 50029222740100 0.4 NA 0.4 NA 5.1 11/9/2011 Additional treatment 15-19A 1990990 50029218290100 Dust Cover NA NA NA 10.2 11/9/2011 15-20C 2050930 50029211330300 15-21A 1990290 50029205030100 15-22 1800970 50029205090000 15-23A 2031110 _ 50029222250100 15-24 1911280 50029222230000 15-258 2080240 50029218420200 15-26B 2041590 50029222350200 15-27 1920060 50029222430000 15-28A 2031240 50029222470100 15-29B 2090380 50029222590200 0.1 NA 0.1 NA 3.4 11/9/2011 Additional treatment 15-30A 2020890 50029222820100 15-318 2050860 50029222850200 15-32A 2011840 50029224620100 15- 338 2031940 50029224480200 15-34A 2001370 50029224740100 15-35 1940880 50029224880000 15- 368 2060730 50029224800200 15-37B 2040190 50029224850200 15-38A 2030160 50029224960100 Dust Cover NA NA NA 3.4 11/5/2011 ..-ANNE.j 15-39A 2060860 50029225030100 0.3 NA 0.3 NA 3.4 11/5/2011 Additional treatment 15-40A 1980980 50029225110100 15-41B 2011460 50029224920200 15-42B 2090730 50029226240200 15-43 1960830 50029226760000 4 NA 4 NA 30.6 11/9/2011 15-44 1961100 50029226830000 15-458 2071790 50029226710200 15-46 2041030 50029226650000 15-47 1951740 50029226170000 15-488 2051660 50029226350200 15-498 2090640 50029226510200 i 4 "< - . i ~~. ~~ ~.~rw ;' ~ z r ~ ~ ~ ~' s s._ ~` . ~' ~r:t ~,..:~ #~~ .,~~ ~' ~ ..++~.' ~!; MICROFILMED 6/3:0/2010 DO NOT PLACE ANY .NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc U BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, by k~j~:. J~~ ,.~ ` J t`i lei v ~ U s v i s - a y,q Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 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, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-046 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-O6A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-256 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-29B 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-318 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29!2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9!2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8!2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 12/19/07 ~chlumb~rg~r Alaska Data & Consulting Seroices 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll ~.,i. ~t NO. 4525 ~+~;vr~'s~~~~ ~~.1:_ •- ~ ~~~~' Company: StateofAlaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken ~~~.i ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Lisburne ~ .... n.. ..:..u_ 15-39A 11661174 MCNL ~' ~ 09/24/07 1 14-32 11676961 RST 09/14/07 1 X-30A 11649992 CH EDIT PDC GR (JEWELRY LOG ~ y 10/06/07 1 03-36A 11745217 CH EDIT PDC GR (USIT) • ( U~- 05/03/07 1 75-30A 11767139 MCNL ~ 09/05/07 2 1 18-12B 11216204 MCNL 07/04/06 2 1 E-21B 11133205 MCNL -/L~ 12107105 2 1 P2-56 11686777 RST - 08/08/07 2 1 H-33 11686792 RST 9rL ,.. 10/20/07 2 1 06-16 11686797 RST '- ~ 11/15/07 2 1 L2-16 11626482 RST 05/10/07 2 1 D-22B 71661167 MCNL Q j 5 08/26/07 2 1 03-14A 11212846 CH EDIT SDCL GR (USITI ~~ - fj8 g ( 04/24/06 2 1 MPB-21 PROD 11628749 MCNL (MEM PPROF) -~~ ~~~ ~'(~. _ 01/15/07 2 1 C-22A 40013486 OH MWD/LWD EDIT (~ -p ~ ~f~ 05/10/06 2 1 E-15C 40013555 OH MWD/LWD EDIT p~(o (~ * '}~~ 06/03/06 2 1 .~~.~+v.. .+..r...v.•...~vv~ .~~v~~r ~ o ~ J~V~~1~~V F~IrV RC 1 UR1711717 l/1YC VVrT CHtil'7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 , i~~~~~ ~~ ~~ 900 E. Benson Bivd. ; 11 "!l ~S~ il__ ;~ ' Anchorage,Alaska 99508 ~,..,..:, ,a .~ "'i~i,~~ Date Delivered: _ __ __ ~ :~ t ~ {, p, ~ Alaska Data & Consulting Services 2525 Gambet! Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~i ;;; L. ;. Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 23, 2008 8:16 AM To: 'Preble, Gary B (SAIC)' Subject: RE: DS 15-39A (206-086) Thanks Gary. Is the plan to pull the plug in 15-39A anytime soon? If not, it may be appropriate to update the "perP' sheet. Tom From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Wednesday, October 22, 2008 3:16 PM To: Maunder, Thomas E (DOA) a~~~1~'°~: ~~~~ .. ~`, ~oo~ Subject: RE: DS 15-39A (206-086) and D-24 (185-299) Tom, The WRP has not been pulled yet on well 15-39A (206-086) The attachment contains the revised work summary for the patch job on D-24 (185-299) From: Maunder, Thomas E (DOA} (mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 21, 2008 8:34 AM To: Preble, Gary B (SAIC) Subject: DS 15-39A (206-086) and D-24 (185-299} Gary, I am reviewing 404s recently submitted for these wells. DS D-24 -The attachment to this 404 is the procedure for setting the patch, not the report of what was accomplished. Would you please send the operations report? Email is fine. 15-39A - In the operations report, setting a WRP (wireline retrievable plug) is mentioned. Nothing is mentioned about pulling the plug and the new perfs are substantially shallower than the setting depth of the WRP. It would appear that the WRP closed access to the perfs from 10550 -11230 and 11330-11480. if this is so, it is appropriate to send a revision of the "pert" sheet. Again, email is fine. Thanks in advance, Tom Maunder, PE AOGCC 10/23/2008 Q~ io ao-o~ ~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q , Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' ~ Exploratory 2o6-os6o - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22503-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.2 KB PBU 15-39A - 8. Property Designation: 10. Field/Pool(s): ADLO-028306 i PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11650.42 ~ feet Plugs (measured) 0 true vertical 8855.69 - feet Junk (measured) 11543' Effective Depth measured 11543 feet true vertical 8855 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 Surface - 110' Surface - 110' 1490 470 Surface 3524' 13-3/8" 68# NT80 Surface - 3524' Surface - 3524' 5020 2270 Production 4290' 9-5/8" 47# NT-80S Surface - 4290' Surface - 4290' 6870 4760 Liner 4196' 7" 26# L-80 4124' - 8320' 4124' - 8248' 7240 5410 Liner 3499' 4-1/2" 12.6# L-80 8151' - 11650' 8093' - 8856' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 8157 0 0 - Packers and SSSV (type and measured depth) 4-1/2" BKR S-3 PKR 8100' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~p~y{j'y~+~ r;C - r/7 r: ~: 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: SI Subsequent to operation: 433 32551 3 1943 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development i~;,, - 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 Date 10/8/2008 Form 10-404 R ised 04/2006 ! ~ ~ ~ ~ ~ ~ ~ ~ ~ Submit Original Only (,~~~ 15-39-A (206-086) Page 1 of 1 I • • Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Thursday, October 23, 2008 10:03 AM To: Maunder, Thomas E (DOA) Subject; 15-39-A (206-086) Attachments: 15-39A-PERF-ATTACHM ENT. PDF Tom, The WRP was set for agas-shut-off. It maybe removed at a latter date. I went ahea nd revised the pert attachment to reflect it being set~j ~~~~("~ S~~ ~~~s~_ «95-39A-PERF-ATi"ACHMENT.PDF>~ Gary Prehle ~~ /nformation Technology and Services ~~~~ Petrotechnical Data Team Coordinator SAIC 907-564-4944 907-350-6879 10123/2008 • ~ r' i r?<7,'i7;'n;"C£W' cn~cnlrr, cn;csitri,cr~ cr~r~ ~3N~~~ =o'V~;"D 'R~ i WWIWiW'W~W'W~WI j ~ J I '~%~[~i~Q~~~~iW ~ z i ~ ~aa~a~a~aia=a;af~ f ~ ' ifD ~ € , i i.. r%im~m;mr~>;=;~~~o;v~oo -~ ~ nnn~rr~ sppa~ '$ ozz z ti~lrnv„j~lo~ ~~ ~"'C?=nIC)( jZ3r-jr-~`TtI~~ ~0~<<D~t„~~~A~tO lAitt3! ~.; •.. ~+. ~ ~.. i ~. D m!~a"`ila"'1a`i t ~ Cj i0~ r=+.j~o'QiO~~[~~Cj~. . , ,r-.N;~~ icr~ ; tD - ~ , E , . I r ~~~~`OaD~O~OrO~S ~i~ ~~ ~~.~, ........: 3 ......... - _-._ .- .. ..- _ -. i C~" ,r i-f-i: r ?ml ~ , j 1 ~ r.~i f ~ 1 1 ' k s I i IG1 i jmi ~ ~ i F ~ ~ ~ ; I i._w ~ rte; ~ ~ ~ ~ i I ~~ i io 1 ! i ~ t ~ i ~ 33 G= ~ ~ ~ ~ ~ i ~ i r n Zvi ~ f ; ~$ ~r ., rm i .. --~ f... ' . s.. i ~ : .I....'.. .'. ~... f- . _~. . ' ~ : ~y ~ _ ~ ~ ~aa ~WIOD'N~OD~W CTt tD~W~p = ~ ~ , o!o . ray, ;oioro:oo ;. -- - ~ ! •. i i03t~NI~n'tn;ao i~rr:7o ~ i ~ i 4 id i € 3 i i I~ i ; ~ ; j ~ i i ~ r 1 ~ ! i ~ I r I I I = I ~~ I 1 ~ r ~Ji '~•'J~~r E~ ; t i O~ido~N~dOi..pp;NNIV€y ~ i ~ i ~W~W~OD~O>;CoWl7>IICitIN i i l 1 i ~ i 0 .~E O F~I d i Q j~ ~~ r ,,AA ,A .. ,^ ....... . ~FIV;D a, al rlm=rni ? I F ...I 3 ' C ~~ ~'CI C-z'z~oj~D~~l ~ i 1 fl. lv~v~m~miv`~v;m.~oi ~ i i,a ~CJ~oNsNrr-:r-, I'~7 Oo ~C+a0o40ojG~~U~ NCO ~Co,.« rir_rnmccsp~ i iaooo;ooEw;"w~ooraoa~;~' €m.m€ '~Q; ,i7sr' f ;V:'~1~CA~'~1349iVOC1~i~ :_. a a; I rrim;rnrm; ,~.i~ ~ . f ;m,~ ~;. v ~ ~ ~ i V;oi i £pi I ~ ~ i ~ ? ~ 1 i~ rn I N i ~ ~ '• i s ! i ' ; ; 'tf ~ i ~ ! t :zip; i i ~ i0DaU0;Cp000D~ODjODj00~~ ~ j •~i~:, Od,~i04100iW1~~~ i ~~1~f11j W i W ~Jti Cf~ N: W itA ~ i. '~Im' ,,;oarcn,N o~jb;m raaoo;a~~ao,vi; o -' ~' `~" oW ~ ~ ~, a • C 15-39A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ACTIVITYDATE SUMMARY 9/29/2008WELL SHUT-IN ON ARRIVAL. T/I/O. 1700/500/0. LRS LOADING WELL :WITH CRUDE. RU ELINE FOR D&T, PERFS WITH WELLTEC TRACTOR. °.D&T TO 11,300 FT WITH DUMMY 3-3/8" GUN. ***JOB IN PROGRESS AND CONTINUED ON 30-SEP-08 WSR**" 9/30/2008"*"*CONTINUED FROM 39-SEP-08*** `ELINE SETTING 3.69" WEATHERFORD WRP AT 11 270 FT. `:PERFORATED FROM 9850-9860 FT WITH 3.375" HSD PJ 3806 GUN, 6 UNABLE TO ADRESS SWITCHES AFTER LOGGING INTO POSITION TO PERFORATE 9830-9850 FT. "**JOB CONTINUES 01-OCT-2008*** 10/1/2008"°";***CONTINUED FROM 30-SEP-08**'` ~'ERFORATED FROM 9830-9850 FT WITH 3.375" HSD PJ 3806 GUN, 6 ``SPF. PERFORATED 9810-9830 FT WITH 2-7/8" PJ OMEGA 2906, 6 SPF. :WELL LEFT SHUT-IN. FINAL T/I/O 660/1150/0. `'"**'JOB COMPLETE"'`'' FLUIDS PUMPED BBLS 1 diesel 1 Total ~ ~ ~. o ~`8 DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2060860 Well Name/No. PRUDHOE BAY UNIT 15-39A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22503-01-00 MD 11650 TVD 8856 Completion Date 9/2/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIE / GR /RES / PWD, DIR ! GR /RES / NEU / ABI (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments 9 _ _ _ _- -- - ------- ----- - --- - i I„Yog Cement Evaluation 5 Col 1 G~"' D Asc Directional Survey j~D C Las 15432 See Notes Production 25 Blu 1 C Lis 15727 Induction/Resistivity ~'I Rpt 15727 LIS Verification C Lis 15785 Neutron Neutron Blu C 15853 Induction/Resistivity Cog Production 5 Blu 8000 11540 Case 10/10/2006 SCMT, Spin, Temp, GR, CCL, Maxtrac Conveyance System 16-Sep-2006 ~- 4259 11650 Open 10/19/2006 9650 10416 Open 9/17/2007 Field Data LAS, GR, Dep w/EMF Graphics 8180 11530 Case 10/3/2007 Mem PPL, GR< CCL, Temp, Pres, Spin 23-Sep- . 2007 3962 11584 Case 12/7/2007 LIS Veri, GR, FET, RPD, RPS, ROP, NPHI, FCNT, NCNT, RHOB, DRHO 3962 11584 Case 12/7/2007 LIS Veri, GR, FET, RPD, RPS, ROP, NPHI, FCNT, NCNT, RHOB, DRHO 8152 11530 Case 12/21/2007 LIS Veri, GR, CNT w/PDS and TIF graphics 8152 11540 Case 12/21/2007 MCNL, GR, CCL, CNL 24- Sep-2007 4290 11650 Case 1/31/2008 TVD and MD EWR-Phase 4, DGR, ROP, CTN, ALD, Mad pass presentation and horizontal presentation in PDF, EMF and CGM graphics 8100 9155 Case 6/6/2008 PPL, GR, CCL, Temp, Pres, Gradio, Spin 28-May- 2008__ DATA SUBMITTAL COMPLIANCE REPORT 9/12/2008 Permit to Drill 2060860 Well Name/No. PRUDHOE BAY UNIT 15-39A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22503-01-00 MD 11650 TVD 8856 Completion Date 9/2/2006 Completion Status 1-OIL Current Status 1-OIL UIC N ED C Pds 16410 Production 8100 9155 Case 6/6/2008 PPL, GR, CCL, Temp, Pres, Gradio, Spin 28-May- 2008 i Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? vC.Ld, Analysis Y / N Received? Comments: Daily History Received? ~ / N Formation Tops ~N Compliance Reviewed By: Date: 05/30/08 ~chtumber~ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh S N0.4727 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn r)acrriniinn 11sfn RI (`ninr ('rl Z-03 11975773 SFRT ,- (~ 05/20/08 1 1 P2-32 12066522 MEM TEM SURVEY 05/19/08 1 1 18-13B 12021159 MEM PROD PROFILE - ~ ~ 05/18/08 1 1 Z-03 11975773 USIT - G(~3 05/19/08 1 1 W-29 11999017 INJECTION PROFILE (,( 05/26/08 1 1 15-39A 11999018 PRODUCTION PROFILE - 05/28/08 1 1 07-30A 11963095 SCMT - ~ 05/27/08 1 1 14-096 11982432 PROD PROFILE W/FSI - ~ p 05/27/08 1 1 A-34A 12057614 USIT - p '~ /(pL/d~- 05/26/08 1 1 GNI-04 11824353 OH LDWG EDIT (DSI) UZ _I ( (, 11/07/07 1 1 rLtASt AI:RNUVVLtUIit titlalr l IiY SItaNINCi ANU Mt l UHNING UNt LUNY tA(:M I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , Anchorage, Alaska 99508 Date Delivered: "~' ; i(h Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 ! / ATTN: Beth /'~~ // Received by: IJL/~ • • WELL LOG TRANSMITTAL To: State of Alaska January 1 1, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 15-39A AK-MW-4580096 15-39A: Digital Log Images: 50-029-22503-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska_99518 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ ao~ -off c~ ~` rS~s S3 WELL LOG TRANSMITTAL To: State of Alaska November 12, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-39A AK-MW-4580096 1 LDWG formatted CD rom with verification listing. API#: 50-029-22503-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ ,,,-~,-; ~., ,_, _ _ v ~ :~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: j~ 09/28/07 ~~~~~mb~~~~~ NO.4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Wall .Inh $ 1 nn rlncr rin}inn Ilse QI /~..1... rn 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 W-42 11745235 MEM SBHPS/TEMP 09/14/07 1 Z-07A N/A SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE d 08/31/07 1 X-33 11849931 SBHP SURVEY ~ _ [. jG 08/31/07 1 E-14A 11686784 LDL -~ 09/23/07 1 01-15A 11855509 DDL ~ ~ 09/22/07 1 D-21 11626119 PRODUCTION PROFILE ~ja - 09/11/07 1 K-07D 11745234 MEM PROD PROFILE ~- - 09/06/07 1 11-32 11630498 PRODUCTION PROFILE ` L _ 09/03/07 1 L-01 11745233 MEM LDL aU ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ZLi 09/05/07 1 Z-16 N/A SBHPS/JEWELRY / 09/13/07 1 14-26 11676959 LDL ..-/j 09/09/07 1 04-02A 11630504 LDL j 09/11/07 1 14-37 11695075 LDL 09/13/07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09/09/07 1 r LGNJG FllinnVYY{.CV~,7C RCV CIr'1 of .71ta IVIrvV HIYV.RC~U~f,.~li1Vl~-GIVt liVl'r tAlirl IU: i ~ t7l ~ kro ,, BP Exploration (Alaska) Ina - °A i d' , Petrotechnical Data Center LR2-1 - ' 900 E. Benson Blvd. Anchorage, Alaska 99508 r ~~~°+° ~, ~~ ~~~~~~ v Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 . Anchorage, AK 99503-28 ~ ATTN: Beth Received by: ~c lzflO-G~ STATE OF ALASKA NOS 3 0 1U(i~ ALASKA AND GAS CONSERVATION COMMI ION A;aska Oil & Gas Cons. Culnmission WELL COMPLETION OR RECOMPLETION REPORT AND LOG Anchorage Revised: 11/29/06, Put on Production 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 2oAa,czs.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Wefl Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/21/2006 12. Permit to Drill Number 206-086 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/24!2006 13. API Number 50-029-22503-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/5/2006 14. Well Name and Number: PBU 15-39A FNL, 769 1464 FWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 1980' FNL, 1605' FWL, SEC. 22, T11 N, R14E, UM 8. KB Elevation (ft): 64.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4078' FNL, 2953' FWL, SEC. 22, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11543 + 8855 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676708 y- 5960036 Zone- ASP4 10. Total Depth (MD+TVD) 11650 + 8856 Ft 16. Property Designation: ADL 028306 TPI: x- 677557 y_ 5959539 Zone- ASP4 Total Depth: x- 678958 y- 5957474 Zone- ASP4 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 1900' (Approx.) 21. Logs Run: DIR / GR /RES / PWD, DIR / GR /RES / NEU / ABI 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD, SETTING D EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM .: TOP` BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set A rox. 13-3/8" 68# NT80 35' 3524' 35' 3524' 16" 1168 sx PF 'E' 375 sx Class 'G' 9-5/8" 47# NT-80S 32' 4 32' 429 ' 12-1/4" 701 sx Cla s'G' 7" 26# L-80 4124' 8320' 4124' 8248' 8-1/2" 197 sx LiteCrete 172 sx Class 'G' 4-1/2" 12.6# L-80 8151' 11650' 8093' 8856' 6-1/8" 433 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and '24'.' TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD Z-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8157' 8100' MD TVD MD TVD 9300' - 9750' 8865' - 8873' 9950' - 10250' 8880' - 8886' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10550' - 11230' 8878' - 8866' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 11330' - 11480' 8861' - 8856' 2100' Freeze Protect with 145 Bbls of Diesel 8190' - 8200' Cement Squeeze, 21.3 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: November 6, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 11/24/2006 Hours Tested 10 PRODUCTION FOR TEST PERIOD OIL-BBL 447 GAS-MCF 7,385 WATER-BBL -0- CHOKE SIZE 54 GAS-OIL RATIO 16,519 FIOW TUbing Press. 1,847 CaSing PfeSSUre 1,550 CALCULATED 24-HOURRATE• OIL-BBL 1,073 GAS-MCF 17,724 WATER-BBL -0- OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 ~ ! ~ I r - ~ „' nC~NTINUED ON REVERSE .SIDE . _ qn7 ~~`~,„ ~i~`~ ,~ 'J~~~ 28 GEOLOGIC MARKERS 7 29. NATION TESTS G~"+jC 4~ 9l-- Include and briefly s marize test results. List intervals tested, Nanne MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8331' 8258' None Shublik A 8377' 8301' Sadlerochit 8454' 8372' 45SB 8468' 8385' 44S6 8500' 8415' 43S6 8526' 8439' 42S6 /Zone 4A 8546' 8457' 41 SB 8604' 8509' Top CGL /Zone 3 8620' 8523' Base CGL /Zone 2C 8698' 8592' 23S6 /Zone 2B 8756' 8641' 22TS 8831' 8701' 21TS /Zone 2A 8892' 8744' Zone 1 B 8998' 8804' TDF /Zone 1A 9120' 8846' Base Sadlerochit 10379' 8884' Base Sadlerochit 10516' 8881' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Si d l ` ~~~~ e gne Title Technical Assistant Date Terrie Hubbl PBU 15-39A 206-086 Prepared By Name/Number. Terrie Hubble, 564-4628 Weil Number Permit No. / A rOVal No. Drilling Engineer: phil Smith, 564-4897 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. 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). ITeM 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 Digital Wellfile Page 1 of 1 Well Events for SurfaceWell - 15-~ Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 15 -> 15-39 Date Range: O1/Oct/2006 to 29/Nov/2006 Data Source(s): DIMS, AWGRS Events Source Well Date Description AWGRS 15-39A 11/01/2006 ASRC Well Test (Continue test from 10/31/06) 1699.1 bfpd 1652.9 bopd 2.34% W/C 31.943 mmscf/d 0.00 mm G/L 19325 GOR 176 beans A..WGR.S. 15-39A 10/31/2006 ASRC Well Testing (New well POP) continue from 10/30/06 AWGRS. 15-39A 10/30/2006 ASRC Well Test (New well POP) **Continue from 10/29/06 AWGRS 15-39A 10/29/2006 ASRC Well Test (New well- POP ) AWGRS 15-39A 10/27/2006 **** CONTINUE FROM 10/26/06 WSR *** PULL BK DGLV FROM STA. 2 @ 6127' (SLM) AND STA.1 @ 3372' (SLM). SET 1" BK DOME GLV IN STA. 1 AND 1" BK S/O GLV IN STA.2. PULLED 4 1/2 WHIDDEN CATCHER @ 8127' (SLM). *** WELL LEFT SHUT IN & TURNED OVER TO DSO *** _A_.WG.RS. 15-39A 10/26/2006 **** WELL SHUT IN ON ARRIVAL *** SET 4 1/2 WHIDDEN @ 8127' SLM. **** CONTINUED ON 10/27/06 WSR **** AWGRS 15-39A 10/24/2006 Continued from 10/23/06 WSR. Get 500 psi compressive strength on cement UCA. MU/RIH w/ 2 7/8" motor & 3.715" three blade convex mill. Dry tag cement top @ 8105' CTM. Begin milling from 8097' w/ frequent flopro sweeps. Mill to 8220', pump bottoms up flo pro sweep and perform injectivity test down backside due to erratic WHP before milling composite plug. NO INJECTIVITY established, WH pressured up to 2000 PSI with less than a BBL and it held solid. Erratic WHP was return MM plugging off. RBIH milling from 8220' to 8250'. Milled thru plug and pushed to 9045' before stalling. Continued making frequent flow pro sweeps and milled to 9700' chasing anything out to surface before continuing forward due to frequent stalls and heavy pick ups. Continued milling from 9083' to TD of 11543' CTMD with little to no motor work. Pumped a final 30 bbl flo pro sweep off bottom and chased to surface at 60%. FP wellbore from 2650' w/ water/meth. RDMO. Job complete. AWGRS 15-39A 10/23/2006 Continued from 10/22/06 WSR. POOH from setting composite plug @ 8240'. PT all surface valves. MU/RIH w/ 2.3" BDN. Burp/fluid pack IA w/ diesel. Tag plug, correct to set depth. Flag CT 10' above plug. Circ kill w/ KCL. IR 2 bpm @ 1540. Pump 21.3 bbl's of 15.8# cement laying in 1:1 with approx. 6.5 bbl's behind pipe. Park at safety and maintain 1775 PSI differential for one hour. Drop 3/4" ball and RIH jetting BIO from 7000' to 8100', make repeat passes and POOH @ 60% to surface. Trap 500 psi WHP. FP coil. Wash BOP's. Lay down BHA. Wait on cement. Continued on 10/24/06 WSR. AWGRS 15-39A 10/22/2006 *** WELL SHUT-IN UPON ARRIVAL*** MI CTU #9 .... 15,750' of 1-3/4 CT. RIH w/ WFT's MHA & 3.70" od Dummy Drift,& PDS Memory log. Jewerly log from 8900 to 8000. Paint flag @ 8200'. POH. POH & LD Drift and PDS Logging tools RIH w/ WFT Composite Bridge Plug. Tie-in to flag. Drop 5/8" ball. Set Composite @ 8240' mid-element. Top of plug is 8238.6'. Pull up to 8200'. Perform backside injectivity test: 2 bpm @ 1824 psi WHP. OK. POOH. Continued on 10/23/06 WSR. AWGRS 15-39A 10/16/2006 T/I/O = 2430/VAC/VAC. Temp = S/I. AL spoof dropped. TBG and IA FL (pre cement sqz). TBG FL @ 8183' (124 bbLs). IA FL @ 2610' (140 bbLs). AWGRS 15-39A 10/16/2006 TIO = 2500/vac/vac. Temp = SI. AL disconnected. TBG & IA FL (pre cmt sqz). TBG FL @ sta- 3 @ 8012' (122 bbls). IA FL @ 30' (2 bbls). Integral flange installed on IA. AWGRS 15-39A 10/08/2006 T/I/0=2500/0/0 MIT IA PASSED @ 1500 psi. (Shut In)(Post RWO) IA pressured up w/ 11.8 bbls Crude pumped. IA lost 50 psi in15 min. w/ total loss of 60 psi in 30 min. Final WHP's=2500/0/0 AWGRS 15-39A 10/02/2006 ***WELL SHUT IN ON ARRIVAL*** DRIFTED W/ 2' STEM, 3.70" CENT, S.BAILER TO 8999' SLM (13 DOGLEG, 67 DEV), NO SAMPLE. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** AWGRS 15-39A 10/01/2006 ***WELL SHUT IN ON ARRIVAL*** (POST RIG) PULL BALL & ROD FROM 8130' SLM PULLED 1"-BK- DCK-2 SHEAR VALVE FROM STA # 1 @ 3374' SLM SET 1"-BK DUMMY VALVE IN STA #1 @ 3374' SLM PULLED EMPTY RHC FROM 8135' SLM ** TURNED WELL OVER TO DSO, TO POP** Refresh List http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 11/29/2006 TREE = CM! WELLHCy4D = FMC ACTUATOR = BAKER C KB. ELEV = 64.20' BF. ELEV = ~ KOP = 4300' MD Max Angle = 95 @ 10521' Datum MD = 9273' -Datum TV D = -_-_ 8800' SS ~ 15-39A 13-3/8" CSG, 68#, NT-80, CYHE, I-j 3524, ID = 12.415" Minimum ID = 3.725" @ 8145' 4-1/2" HES XN NIPPLE TOP OF WHIPSTOCK 4290' SAFETY ES:***4-1 /2" CHROMETBC~'** 4-1i2" X NIP,ID = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3394 3394 0 KBG DOME BK 16 10/27/06 2 6144 6112 2 KBG SO BK 20 10!27/06 1 8012 7963 19 KBG DMY BK 0 09!20/06 4124' 7" X 9-5/8" BKR G2 ZXP LNR TOP PKR w / HMC LNR HANGER ~ILLOIJf WINDOW (15-39A) 4290' - 4307' ~EZ-SVB {08/22/06) I 4315' $079' -14-1(2" X NIP, ID = 3.813" 8100' 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 8326' 8124' 4-1/2" X NIP, ID = 3.813" 8145' 4-1/2" XN NIP, ID = 3.725" ~~ 5" X 7" BKR G2 ZXP LNR TOP PKR w/ HCM LNR HANGER 4-1/2" TBG, 12.6#, 13CR-80 VAMTOP, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 BTGMOD, .0383 bpf, ID = 6.276" I 8157' I PERFORATION SUMMARY REF LOG: LWD DATE 9/5/06 ANGLE AT TOP PERF: 23 @ 8190' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 8190 - 8200 S 10/23/06 2-1/2" 4 9300 - 9750 O 09/18/06 2-1/2" 4 9950 - 10250 O 09/18/06 2-112" 4 10550 - 11230 O 09/18/06 2-1/2" 4 11330 - 11480 O 09/18/06 3-318" 12 11554 - 11559 S 09!12/06 u 4-112" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 815T I wLEG 8176' 5" BTGM x 4-1/2" IBT XO, ID = 3.98" 77 FISH- BULLNOSE FROM MILLING UP EZSV (09/18/06) 11543' CTM -rWFD PLUG REMNANT {10/24h 11546' TOC (TAGGED 9/15/06) y 11560' FISH- 2 BULLNOSE's FROM MILLING UP EZSV's (09118106) DATE REV BY COMMEMS DATE REV BY COMMENTS 09/29/94 ORIGINAL COMPLETION 11/17/06 PJC DRLG DRAFT CORRECTION 09123!06 N27E SIDETRACK 12/05!05 COM/PAG WELLHEAD CORRECTION 10/14/06 BRD/ PJC DRLG DRAFT CORRECTION 10!24106 CJA/PAG SOZ PERF, PLUG FISH @ 11543' 10(27/06 DTR/PAG GLV C/O PRUDHOE BAY UNIT WELL: 15-39A PERMff No: 1060860 API No: 50-029-22503-01 SEC 22, T11 N, R14E, 4393.72' FEL & 4322.03' BP Exploration (Alaska) • ~ 05-Oct-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-39A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,259.38' MD Window /Kickoff Survey: 4,290.00' MD (if applicable) Projected Survey: 11,650.42' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ ~ ~ I ~ , Date I `1. U t~~~A?~l~l~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~v(o- O~~R STATE OF ALASKA ALASIL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG t~z'~ j ~ ~~~~ ~~~~~~~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ~ ~" "~ OPl~11t1~11~S1 ®Developm~'tRe~}~gploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/21/2006 12. Permit to Drill Number 206-086 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/24/2006 13. API Number 50-029-22503-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/5!2006 14. Well Name and Number: PBU 15-39A FNL, 769 1464 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 1980' FNL, 1605' FWL, SEC. 22, T11 N, R14E, UM 8. KB Elevation (ft): 64.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4078' FNL, 2953' FWL, SEC. 22, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11550 + 8855 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676708 y- 5960036 Zone- ASP4 10. Total Depth (MD+TVD) 11650 + 8856 Ft 16. Property Designation: ADL 028306 TPI: x- 677557 y_ 5959539 Zone- ASP4 Total Depth: x- 678958 y- 5957474 Zone- ASP4 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 1900' (Approx.) 21. Logs Run: DIR / GR /RES / PWD, DIR / GR /RES / NEU / ABI 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD' HOLE AMOUNT SIZE Wt. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arc is Set A rox. 13-3l8" 68# NT80 35' 3524' 35' 3524' 16" 1168 sx PF'E' 375 sx Class 'G' 9-5/8" 47# NT-80S 2' 32' 42 0' 12-1/4" 701 sx Class 'G' 7" 26# L-80 4124' 8320' 4124' 8248' 8-1/2" 197 sx LiteCrete 172 sx Class 'G' 4-1 /2" 12.6# L-80 8151' 11650' 8093' 8856' 6-1 /8" 433 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING .RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MO 2-1/2" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8157' 8100' MD TVD MD TVD 9300' - 9750' 8865' - 8873' 9950' - 10250' 8880' - 8886' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10550' - 11230' 8878' - 8866' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11330' -11480' 8861' - 8856' 2100' Freeze Protect with 145 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none . r f .~ eT cJ:Nalew `12.90 Mal None ~ COt~~L~TfOiV : fC~Z g0 T~/p Y~~±rE ~ '~-/ Form 10- 0 ed 312/2003 C TINUED ON REVERSE SIDE 4 ~ ~n 2i3. ~ GEOLOGIC MARK 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8331' 8258' None Shublik A 8377' 8301' Sadlerochit 8454' 8372' 45S6 8468' 8385' 44SB 8500' 8415' 43S6 8526' 8439' 42S6 /Zone 4A 8546' 8457' 41 SB 8604' 8509' Top CGL /Zone 3 8620' 8523' Base CGL /Zone 2C 8698' 8592' 23S6 /Zone 26 8756' 8641' 22TS 8831' 8701' 21TS /Zone 2A 8892' 8744' Zone 1 B 8998' 8804' TDF /Zone 1A 9120' 8846' Base Sadlerochit 10379' 8884' Base Sadlerochit 10516' 8881' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. b Signed TerrieHubble Title Technical Assistant Date J ~~~(p PBU 15-39A 206-086 Prepared ey NameAVumber.~ Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / A royal No. 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. ITEM 4b: TPI (Top of Producing Interval). IreM 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. IreM 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 Printed: 9/25/2006 11:26:43 AM BP EXPLORATION Operations Summary Report Page 1 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To ~,~ Hours l Task Code ~NPT ' Phase Description of Operations 8/18/2006 18:00 - 00:00 6.00 RIGD P PRE Rig released from 15-12B at 18:00 hrs. Pull out all modules and place for rig up. P/U matting boards and herculite. 8/19/2006 100:00 - 17:00 I 17.001 MOB I P 17:00 - 22:30 I 5.501 RIGU I P 22:30 - 00:00 1.50 RIGU P 8/20/2006 00:00 - 00:30 0.50 RIGU P No pressure on tubing, upper, and lower annulus. PRE Moving Rig from 15-12B to 15-39 Spot the sub base over 15-39A, set rig mats and spot pipe sheds, set rig mats and lay herculite for pits and motor complex, set complexes in place. Set rig mats and set pump complex in place. PRE Connect service lines, electrcal, water, steam Connect to Rig power R/U flowline, change airboots Rig up mud pump suction lines and pump line to rig floor PRE Finish all berming, level pipe shed R/U Lubricator and pull BPV Prepare to test mud pump line to rig floor DECOMP Accept rig ~ 00:01 hrs PJSM, Prespud with rig crew, Toolpusher Dave Richards & WSL Dave Newlon Test Mud pump and Mud line to rig floor to 3500 psi, O.K. 00:30 - 02:30 2.00 WHSUR P DECOMP Rig up lines to reverse heated seawater and flush tubing with heated "Safe Surf-O' sweep 02:30 - 05:00 2.50 WHSUR P DECOMP Reverse heated seawater and flush tubing with heated "Safe Surf-O'sweep 30 bbl Surf-O pill followed 320 bbl heated seawater, total of 350 bbls pumped, pumped pill ~ 6 bbl /min (125 psi), pumped 7.5 bbl/min (260 psi) for cleanup 05:00 - 07:00 2.00 WHSUR P DECOMP R/U lubricator and set TWC Test TWC to 1000 psi above and below 07:00 - 08:30 1.50 W HSUR P DECOMP Nipple Down Tree 08:30 - 09:30 1.00 WHSUR P DECOMP Inspect tubing hanger & 4 1/2 NSCT threads, OK Check Lock Down screws 09:30 - 14:30 5.00 BOPSU P DECOMP M/U Flange & Nipple up BOPE's, Connect Kill & Choke Lines Change airboots in flowline, C/O hydralic fitting on Choke Line HCR valve Grease Choke Valves 14:30 - 15:30 1.00 CONS N RREP DECOMP Repair Drip Pan drain -Drain damaged with bridge crane during Nipple up operation 15:30 - 18:30 3.00 BOPSU P DECOMP Finish Nipple up, Install Bell Nipple, Center stack, Hook up Safety cables and drain hoses 18:30 - 20:30 2.00 BOPSU P DECOMP Rig up test joint and testing equipment, function test BOPE's Space out test joint in stack, M/U Floor TIW valve and Top Drive to test joint PJSM meeting with rig crews, WSL, Toolpusher and AOGCC rep. Jeff Jones 20:30 - 00:00 3.50 BOPSU P DECOMP Conduct ROPE pressure test - 250 / 3500 for 5 minutes Witness by Dave Newlon (WSL), Dave Richards (toolpusher), And Jeff Jones (AOGCC) #1-Test Upper IBOP, Kill HCR, #1,2 choke manifold valve, Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Page 2 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DR ILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task I, Code NPT Phase ( Description of Operations 8/20/2006 20:30 - 00:00 3.50 BOPSU P DECOMP Annnular #2-Test Top pipe Rams, Lower IBOP, Manual Kill #3-Test Choke Manifold valves 6,5,3,8 and floor TIW valve #4-Test Choke Manifold valves 7,9,11,5 #5-Test Choke Manifold valves 10,12,14 & dart valve #6-Test Choke Manifold valves 13,15,16 #4 choke manifold vavle Failed, Repairing same Uni-bolt unions on the kill and choke line failed but retighten and Passed 8/21/2006 00:00 - 02:00 2.00 BOPSU P DECOMP Conduct BOPE pressure test - 250 / 3500 for 5 minutes Witness by Dave Newlon (WSL), Dave Richards (toolpusher), And Jeff Jones (AOGCC) #7-Test Choke Line HCR #8-Test Manual Choke valve #9-Test Lower Pipe Rams #10-Test Blind Rams Conduct BOP Accumulator Test, Starting Pressure 3000 psi, After Closure 1,700 psi, Initial 200 psi Recovery 20 sec, Final Pressure 3000 psi, Full Recovery Time 1 min 39 sec., 8 nitrogen bottles avg. of 2350 psi Repairing #4 choke manifold valve 02:00 - 03:00 1.00 BOPSU P DECOMP Rig down test equipment and Blow out choke manifold, Remove crossovers and UD test Joint 03:00 - 04:00 1.00 BOPSU P DECOMP PJSM on P/U Lubricator Rig up Lubricator and pull TWC 04:00 - 05:00 1.00 PULL P DECOMP Rig up floor to pull tubing hanger and UD 4 1/2" NSCT tubing 05:00 - 05:30 0.50 PULL P DECOMP Back out Lock Down screws and Pull Tubing hanger tro floor. 100k PUW (with blocks) / 52k sting wt. 05:30 - 06:00 0.50 PULL P DECOMP Circ. ~ 70 bbls/min / 100 psi Retested #4 choke manifold valve to 250 Low for 5 min / 3500 high for 5 min. Good test, Witness by WSL Dave Newlon & Toolpusher Dave Richards 06:00 - 06:30 0.50 PULL P DECOMP Monitor well, Well static 06:30 - 07:30 1.00 PULL P DECOMP Rig up Tubing handling equipment and control line spooler 07:30 - 15:30 8.00 PULL P DECOMP UD tubing Hanger, UD 107 jts of 4 1/2" 12.6# L-80 tubing UD SSSV and 24 of 29 SS control line bands UD 1 GLM 19.37' of tubing stub 15:30 - 16:00 0.50 PULL P DECOMP Clean floor and rig down tubing handling equip. 16:00 - 19:00 3.00 BOPSU P DECOMP P/U 4" test jt., set test plug, Test Bag, upper and lower pipe rams 250 low / 3500 high for 5 minutes/test Pull test plug and UD test jt. Witness by WSL Bill Decker &Toolpusher Jim Henson 19:00 - 20:00 1.00 BOPSU P DECOMP Install wear bushing, 13 1/2" OD / 8 3/4" ID Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date ~ From - To ~ Hours ' Task (Code ( NPT 8/21/2006 19:00 - 20:00 1.00 BOPSUF~ P 20:00 - 23:00 3.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 8/22/2006 00:00 - 04:00 4.00 CLEAN P 04:00 - 05:00 I 1.00 I CLEAN I P 05:00 - 05:30 0.50 CLEAN P 05:30 - 07:00 1.50 CLEAN P 07:00 - 09:00 I 2.001 CLEAN I P 09:00 - 13:00 I 4.001 ZONISO I P 13:00 - 14:30 I 1.501 ZONISO I P 14:30 - 17:00 I 2.501 STWHIPI P 17:00 - 18:00 1.00 STWHIP P 18:00 - 20:30 2.50 STWHIP P 20:30 - 21:30 1.00 STWHIP P 21:30 - 00:00 I 2.501 STWHIPI P 8/23/2006 100:00 - 00:30 I 0.50 I ST W H I P I P 00:30 - 01:30 I 1.00 I STW HIPI P 01:30 - 07:00 I 5.501 STWHIPI P 07:00 - 08:00 I 1.001 STWHIPI P 08:00 - 08:30 I 0.501 STWHIPI P Start: 8/20/2006 Rig Release: 9/21 /2006 Rig Number: Page 3 of 23 Spud Date: 9/7/1994 End: 9/21 /2006 Phase Description of Operations DECOMP Clear floor and rig up to MU BHA DECOMP M/U pilot mill and 8 1/2" watermelon mill, 9 5/8' csg. scpr, XO's 9 steel 6 1/4" DC's, 21 joints of 5" HWDP DECOMP Single in with 4" HT40 DP DECOMP RIH, 1x1, Tag stub ~ 4507' DECOMP Pump 30 bbl Surf-O sweep and Clrc. out Pump ~ 14 bbls /min = 1700 psi Total of 340 bbls pumped Monitor well for 10 min, well static DECOMP Service Top Drive and Draworks DECOMP POH with csg. scpr BHA DECOMP Rack back Drill collars, lay down crossovers, mills, and casing scraper DECOMP Rig up Schlumberger E-Line, Gamma Ray, and CCL to run EZ-SVB Set 9 5/8" EZ-SVB ~ 4,315' WLD POH with SWS and Rig down DECOMP RU to test 9 5/8" casing and EZ-SVB Test casing to 3500 psi for 30 minutes witnessed by WSL Decker and TP Henson RD casing test equipment WEXIT Pick up BHA02, Whipstock (set btm anchor pins to 15K), mills, Float sub, and UBHO sub, orient UBHO to whipstock face and RIH WEXIT RIH with collars and 5" HWDP out of derrick WEXIT RIH with 4" drill pipe out of derrick to 4,285' WEXIT Circulate Pipe clean, 7.5 bbls/min ~ 600 psi pre-job safety meeting for rigging up wireline and gyro WEXIT RU wireline and test gyrodata gyro RIH with Gyro First 3 seats all agreed, 139 degrees Azimuth Rotate string and work pipe, 85 degrees Azimuth POH with wireline and lay down gyro tool WEXIT Tag EZ-SVB C~3 4,311' PUW 142K, SOW 142K Sheared off with 40K, PU and confirm shear WEXIT Displace brine with 9.4 ppg LSND mud 420 GPM ~ 720 psi Pertorm SPR WEXIT Mill window, TOW C~ 4,290' PUW 147, SOW 145, RTW 145 Tq off 1-2K, on 2-5K ~ 110 RPM W OB=5-10K 400 GPM @ 700 psi No drag working through window with and without pump WEXIT Pump Super Sweep to clean shavings 520 GPM ~ 1015 psi MW in and out 9.4 WEXIT Perform FlTtest Pressured up to 590 psi in 7 strokes, current MW 9.4 ppg, TVD Printed: 9/25/2006 11:26:49 AM • • BP EXPLORATION Operations Summary Report Page 4 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To ~ Hours Task Code NPT " Phase Description of Operations __ _ __ 8/23/2006 108:00 - 08:30 ~ 0.50 STWHIP P ~ ~ WEXIT 4,298' 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00-10:00 1.00 STWHIP P WEXIT 10:00 - 14:00 4.00 STWHIP P WEXIT 14:00 - 16:00 2.00 STWHIP P WEXIT 16:00 - 17:00 1.00 DRILL P INT1 17:00 - 19:00 2.00 DRILL N RREP INT1 19:00 - 00:00 5.00 DRILL P INT1 8/24/2006 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 06:30 4.50 DRILL P INT1 06:30 - 07:00 0.50 DRILL P INT1 07:00 - 09:30 2.50 DRILL P INT1 09:30 - 10:00 0.50 DRILL P INT1 10:00 - 12:00 I 2.001 DRILL I P I I INT1 12:00 - 13:00 1.00 DRILL P INT1 13:00 - 16:00 3.00 DRILL P INT1 16:00 - 17:00 1.00 DRILL N DFAL INT1 17:00 - 20:00 3.00 DRILL P INT1 20:00 - 21:00 1.00 DRILL P INT1 21:00 - 00:00 3.00 DRILL P INT1 8/25/2006 00:00 - 02:30 1.50 DRILL ~ P INT1 Calculated Equivalent MW is 12.0 ppg Charted for 10 minutes, witnessed by C. Clemens Monitor Well, well static, pump dry job TOH with drill pipe Stand back HWDP, lay down rest of BHA. Mills in gauge Pull wear bushing, flush stack, function rams, install wear bushing Service Top Drive, Drawworks, and Iron Rough Neck Repair master air release valve on drawworks and repair pipe skate Pick up BHA3, program MWD, and shallow hole test MWD. single in 18 joints and rack back 6 stands TIH 1x1, fill pipe and test MWD ~ 3,000' 500 GPM ~ 1,300 psi Continue TIH 1x1 to 4,269', fill pipe and test MWD, 500 GPM ~ 1,390 psi Rig up wire line and Gyro RIH with Gyro and orient motor to slide through window Slide through window with pumps off, window slick Tagged up on fill at 4,313' and wash to bottom 500 GPM ~ 1,400 psi Drill from 4,318' to 4,332' in sliding mode 515 GPM ~ 1,500 psi W OB=5K RIH with Gyro for Survey and orientation Slide from 4,332' to 4,377' 520 GPM ~ 1,400 psi off bottom, 1,475 psi on bottom W OB=2K Difficulty getting MW D tool face Troubleshoot MWD, MWD intermittent tried various flow rates, staggered pumps, switched to 1 pump still having problems Drill from 4,377' to 4,490' in sliding mode with very little tool faces 520 GPM ~ 1,400 psi off bottom and 1,450 psi on bottom WOB=3K RIH with Gyro for Survey and check scribe line. Drill from 4,490' to 4553 in sliding mode, MWD signal getting better 515 GPM ~ 1,400 psi off bottom, 1,450 psi on bottom W OB=5K RIH with Gyro for Survey Drill from 4,553' to 4,618 in sliding mode 515 GPM ~ 1,400 psi off bottom, 1,475 psi on bottom WOB=5K 02:30 - 03:30 ~ 1.00 ~ DRILL ~ N ~ DFAL ~ INT1 ~ Attempt to get MWD Survey, cycled pumps, switched modes, Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 5 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date 'From - To ~ Hours I, Task Code ' NPT ' Phase. Description of Operations ------ 8/25/2006 02:30 - 03:30 f.00 DRILL N DFAL lNT1 surge pipe MWD back on 03:30 - 04:00 0.50 DRILL P INT1 Drill from 4,618' to 4,647' in sliding mode 04:00 - 04:30 0.50 DRILL N DFAL INT1 04:30 - 05:00 0.50 DRILL P INT1 05:00 - 05:30 0.50 DRILL N DFAL INT1 05:30 - 08:00 2.50 DRILL N DFAL INT1 08:00 - 10:00 I 2.001 DRILL I N I DFAL I INT1 10:00 - 11:00 1.00 DRILL N DFAL INT1 11:00 - 13:00 2.00 DRILL N DFAL INT1 13:00 - 15:00 2.00 DRILL N DFAL INT1 15:00 - 16:30 1.50 DRILL N DFAL INT1 16:30 - 18:00 1.50 DRILL N DFAL INT1 18:00 - 18:30 0.50 DRILL N DFAL INTi 18:30 - 20:45 2.25 DRILL N DFAL INTi 20:45 - 21:15 0.50 DRILL N DFAL INT1 21:15 - 00:00 I 2.751 DRILL I P I I INT1 8/26/2006 100:00 - 12:00 I 12.00 I DRILL I P I I INTi 12:00 - 00:00 I 12.001 DRILL I P I I INTi 8/27/2006 100:00 - 12:00 I 12.001 DRILL I P I I INT1 540 GPM ~ 1,650 psi off bottom, 1,750 psi on bottom W OB=3K Attempt MWD survey with no success, Gyro and trip to swap MWD RIH with Gyro for Survey Pre-job for Rigging down Gyro Pre-job for TOH Rig down Gyro Monitor well, well static 9.4 MW in and out, PUW 145 SOW 140 Pump dry job TOH to BHA Monitor well, change elevators Lay down 1 joint of 5" HW DP Rack back 7 stands 5" HWDP with Jars and 6 3/4" flex collars Pre-Job for Handling BHA Drain Motor and download MW D data Lay down failed MWD and pickup new MWD Orient Motor and up load MWD, up load failed Replace battery and up load to MW D TIH to 4" drill pipe Pre-Job for TIH Fill pipe and test MWD tool, 500 GPM ~ 1000 psi, good shallow hole test TIH to the window, fill pipe, test MWD, 500 GPM ~ 1,550 psi Slide through window without pumps or orienting Did not see anything, PUW=142 SOW=136 TIH to bottom with out any problems Drill from 4,647' to 4,761' in sliding mode 515 GPM ~ 1,550 psi off bottom, 1,650 psi on bottom WOB=3K, PUW=140 SOW=138 Directional drill from 4761' to 5465'. -PUW 145k, SOW 140k, RWt 140k, -515 gpm ~ 1620 psi off btm., 1800 psi on btm. -WOB 3-15k, TO on 3-4k, TO off 2k, @ RPM's 100, -MW 9.5 ppg in/out. Calc ECD = 9.9 /ACT ECD = 10.2 ADT=8.97 hrs / AST=7.51 hrs/ ART=1.46 hrs Directional drill from 5465' to 6250". -PUW 185k, SOW 155k, RWt 165k, -540 gpm X2200 psi off btm., 2550 psi on btm. -WOB 5-15k, TO on 8k, TO off 5k, ~ RPM's 100, -MW 9.5 ppg in/out. Calc ECD = 9.7 /ACT ECD = 10.2 ADT=7.31 hrs / AST=2.12 hrs/ ART=5.19 hrs Directional drill from 6250' to 7348'. -PUW 185k, SOW 160k, RWt 170k, -540 gpm X2200 psi off btm., 2550 psi on btm. -WOB 5-15k, TO on Sk, TO off 5k, C~ RPM's 100, Printed: 9/25/2006 11:26:49 AM • • BP EXPLORATION Operations Summary Report Page 6 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To ~' Hours ~ Task Code NPT Phase Description of Operations __ _ i 7/2006 00:00 - 12:00 12.00 DRILL P INT1 -MW 9.5 ppg in/out. Calc ECD = 9.9 /ACT ECD = 10. ADT=7.37 hrs / AST=3.35 hrs/ ART=4.09 hrs Pumped sweep ~ 06:00 (25 bbls, 100 vis, 45YP) sweep brought 30% increase in cuttings 12:00 - 00:00 12.00 DRILL P INT1 Directional drill from 7348' to 7819'. -PUW 190k, SOW 160k, RWt 175k, -540 gpm X2900 psi off btm., 3250 psi on btm. -WOB 5-15k, TQ on 8k, TO off 5k, ~ RPM's 100, -~ 7440' Increased MW 10.2 ppg in/out. No fluid loss Calc ECD = 10.55 /ACT ECD = 10.8 Sliding as per well plan for 4deg/100' ADT=7.04 hrs / AST=5.47 hrs/ ART=1.57 hrs 8/28/2006 00:00 - 12:00 12.00 DRILL P INT1 Directional drill from 7,819' to 8,198'. -PUW 200k, SOW 166k, RWt 175k, -500 gpm X2700 psi off btm., 2,950 psi on btm. -WOB 5-20k, TO on 5-8k, TO off 2-4k, ~ RPM's 100, Calc ECD = 10.55 /ACT ECD = 10.8 Sliding as per well plan for 4deg/100' ADT=7.76 hrs / AST=7.13 hrs/ART=0.63 hrs 12:00 - 14:30 2.50 DRILL P INT1 Rotate from 8,198' to 8,305' and start the scratch and sniff technique PUW 200k, SOW 165k, RWt 180k, 500 gpm X2700 psi off btm., 2,850 psi on btm. -WOB 5-10k, TO on 5-7k, TO off 4-5k, ~ RPM's 100, Calc ECD = 10.55 !ACT ECD = 10.8 ADT=2.05 hrs / AST=0.0 hrs/ ART=2.05 hrs 14:30 - 15:30 1.00 DRILL P INT1 Circulate Sample up for Geology, no sign of Sag River 500 GPM ~ 2,700 psi 15:30 - 16:30 1.00 DRILL P INT1 Rotate 10' to 8,315' Circulate Sample up for Geology, no sign of Sag River 500 GPM ~ 2,700 psi 16:30 - 17:30 1.00 DRILL P INT1 Rotate 5' to 8,320' Circulate Sample up for Geology, Top of Sag River in sample 500 GPM ~ 2,700 psi Pre-job for trip out of hole and Air slips installation 17:30 - 20:15 2.75 DRILL P INT1 Monitor well, Static - 10.2 ppg in/out Pull 22 stands with no over pulls exceeding 10K and taking proper fill 20:15 - 00:00 3.75 DRILL P INT1 23 stands out, 6,300', pulling tight 40K over and not taking proper fill Work pipe multiple times, would not wipe clean Screwed in and started back reaming. Attempted to pull next stand dry but still pulling tight, tight hole started at the base of the West Sack 1. Back ream to 4,550' 8/29/2006 00:00 - 00:30 0.50 DRILL P INT1 CBU at 4,500', Cal ECD=10.55 ECD dropped from 11.2 to 10.78 after BU 500 GPM ~ 2,400 psi 00:30 - 02:30 2.00 DRILL P INT1 Madd Pass from 4,400' to 4,000' ~ 300'/hr for tie in log 02:30 - 05:30 3.00 DRILL P INT1 Service rig and Cut and Slip drilling line 05:30 - 08:30 3.00 DRILL P INT1 TIH was slick, as a precaution washed the last stand to bottom, no fill on bottom 8/2 2 Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Paye 7 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To Hours I Task Code' NPT ~ Phase ~ Description of Operations 8/29/2006 ~ 08:30 - 11:30 3.00 ~ DRILL P ~ ~ INT1 Stage pumps up to 500 GPM CBU 11:30 - 12:00 0.501 DRILL P 12:00 - 14:30 ~ 2.50 ~ DRILL. ~ P 14:30 - 17:00 2.50 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 22:30 I 5.001 DRILL I P 22:30 - 23:00 ~ 0.50 ~ CASE P 23:00 - 23:30 0.50 CASE P 23:30 - 00:00 0.50 CASE P 8/30/2006 ~ 00:00 - 06:00 6.00 CASE P 06:00 - 07:30 1.50 CASE P 07:30 - 08:30 1.00 CASE P 07:00 - 12:30 5.50 CASE P 12:30 - 13:30 1.00 CASE P 13:30 - 15:00 I 1.501 CASE I P 15:00 - 16:30 I 1.501 CEMT I P Pump sweep - Hi Vis /Weighted 500 GPM ~ 3,120 psi, 100 RPMs Calculated ECD - 10.5 ECD before sweep - 10.97, After sweep - 10.74 10.2 MW in and out PUW=200K, SOW=168K, RTW=182K INT1 Observe well, well static Pump dry job POH Pumps down, PUW=210K, SOW=165K INT1 POH to window, no problems hole slick PUW=135K, SOW=130K Monitor well for 10 mins, well static INT1 POH to BHA INT1 Prejob safety meeting for handling BHA Monitor well, well static INT1 Change elevators, lay down HWDP, Jars, Collars, Download MWD tools, Lay down MWD and Motor. Function Blind Rams LNR1 Monitor well, welt static Prejob safety meeting for rigging up liner running tools LNR1 Rig up 7" liner running tools LNR1 Run 7" liner, baker lock shoe joint, float collar, and landing collar joints. LNR7 RIH PU 7" liner to window fill on the fly, top off every 5 jnts Total of 103 joints ran. 7 sloid 8.250" straight blade centralizers ran free floating on first 7 joints. LNR1 Pick up liner hanger/packer and one joint of 4" DP LNR1 Circulate 1 liner volume at window 126 GPM ~ 250 psi PUW=147K, SOW=140K LNR1 RIH with 4" DP filling every 10 stands LNR1 Pick up cement head Wash and work last 6' to get liner on bottom ~ 8320' TOL ~ 4124' Fult returns while running 7" liner. LNRi Stage pumps up, could not get over 4.5 BPM 2.5 BPM 550 psi 10% Flow show returns 3.0 BPM 650 psi 15% Flow show returns 3.5 BPM 680 psi 20% Flow show returns 4.0 BPM 725 psi 21 % Flow show returns 4.5 BPM 846 psi 29% Flow show returns Hole trying to pack off above 4.5 BPM PUW=220K, SOW=155K Full retruns with no losses while circulating. Held Prejob safety meeting for cementing LNRi Pressure test cement lines to 4,500 psi Pump 40 bbls of MudPUSH II ~ 10.5 ppg Pump 114.5 bbls of LiteCRETE Lead ~ 11.0 ppg Pump 35.5 bbls of Class G tail C~ 15.8 ppg kick plug out, positive indication plug left cement head Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary :Report Page 8 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABORS 27E Rig Number: Date ~ Prom - To Hours Task Code ~ NPT ~, Phase 8/30/2006 ~ 16:30 - 17:30 ~ 1.00 CEMT P ~ ~ LNR1 17:30 - 18:00 0.501 CASE I P LNR1 18:00 - 19:30 19:30 - 20:00 20:00 - 21:00 21:00 - 00:00 8/31 /2006 00:00 - 00:30 00:30 - 01:30 01:30 - 02:00 02:00 - 07:30 1.50 I CASE I P 0.50 CASE P 1.00 CASE P 3.00 CASE P 0.50 CASE P 1.00 BOPSU P 0.50 BOPSU P 5.50 BOPSU P 07:30 - 08:30 1.00 BOPSU P 08:30 - 10:30 2.00 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 12:00 1.00 DRILL P LNR1 LNR1 LNR1 LNR1 LNR1 LNR7 LNR1 LNR1 LNR1 PROD1 PROD1 PROD1 Description of Operations Switch over to rig and displace cement as per schlumberger pumping schedule. 264 strokes to catch cement 366 strokes to pick up liner wiper plug, 700 psi spike 1,940 strokes to bump the plug, bumped plug with 2,800 psi Hanger set. Full returns throughout cement job, no losses to well. Bleed off pressure, floats holding Pressure back up to 2,800 psi, stack 75K Ibs on hanger Pressure up to 4,000 psi, positive indication that packer set at 3,800 psi Bleed off pressure and rotate 15 turns to the right to release Pressure up to 1000 psi, pick up until indications pack off was out, increase flow rate to 500 GPM for 30 bbls Set down with dogs to check liner packer Circulate cement out 450 GPM ~ 1,690 psi MudPUSH II back at 1,700 strokes, 18 bbls of cement back to surface Casing unloading, shakers not getting any better after 4 x bottoms up Lay down cement head and single to allow for increased circulation rate and reciprocate pipe Circulate casing clean 600 GPM @ 1430 psi Shakers clean, TOH TOH to Liner hanger running tool Lay down Liner Hanger/Packer running tool Pull wear ring Wash out stack before BOP test due to large volume of cutting and cement coming back after cement job. Make up test joint and rig up for BOP test Test BOPs, AOGCC waived witness as per Chuck Schieve BOP test witnessed by Joey LeBlanc WSTL, Rick Brumley NTP, Chris Clemens WSTL, Tim Leigh NTP Low test pressure 250 psi, High test pressure 3,500 psi #1 Upper Well Control Valve, Top Pipe Rams, choke 1, 2, Kill HCR #2 Choke 3,4,5,6, Manual Kill, Lower Well Control Valve #3 Choke 7,8,9, TIW #4 Choke 10,11,12 #5 Choke 13,14,15 #6 Choke HCR #7 Manual Choke #8 Lower Pipe Rams #9 Annular #10 IBOP #11 Blind Rams Pull test plug, drain stack, install wear ring, blow down lines, test alarms Make up Motor, MWD, and bit, orient Upload to MWD tools Pick up collars, 1 joint of drill pipe and shallow hole test the Printed: 9/25/2006 11:26:49 AM BP EXPLORATION .....Operations Summary Report Page 9 of 23 Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To Hours Task ~, Code ~ NPT Phase Description of Operations 8/31/2006 ~ 11:00 - 12:00 1.00 DRILL P ( PROD1 MWD 12:00 - 21:00 9.00 DRILL P PROD1 RIH picking up pipe 21:00 - 22:30 I 1.501 DRILL I P 22:30 - 23:00 I 0.50 ~ CASE I P 23:00 - 00:00 I 1.001 DRILL I P 9/1/2006 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:30 I 1.001 DRILL I P 03:30 - 04:30 I 1.001 DRILL I P 04:30 - 05:30 1.00 DRILL P 05:30 - 06:30 1.00 DRILL P 06:30 - 07:00 0.50 DRILL P 07:00 - 07:30 0.50 DRILL P 07:30 - 12:00 4.501 DRILL I P Single in 123 joints Shallow hole test MWD ~ 2,700' Fill pipe X3,865' and 5,546', testing MWD after filling No problems entering liner lap ~ 4,124' PROD1 Wash from 8,056' to 8,156', Held apre-job safety meeting for casing test while circulate to string out cement Rig up casing test equipment LNRi Pressure test casing to 3,500 psi and chart fro 30 min Pressure did not bleed off, good test PROD1 Wash down to top of cement, tagged ~ 8,229' 170 GPM ~ 1,600 psi 3.5K fUlbs of torque ~ 40 RPMs PUW=185K, SOW=155K, RTW=160K PROD1 Drill float equipment and cement 170 GPM ~ 1,250 psi, WOB=5, 3.5K fUlbs ~ 40 RPMs Tagged cement C 8,229' Landing Collar ~ 8,235' 210 GPM ~ 1,770 psi, WOB=5, 4.5K ft/Ibs ~ 40 RPMs Float Collar ~ 8,276' Stopped drilling ~ 8,311' to displace to FloProSF PROD1 Held Pre-job safety meeting for displacement while Circulating bottoms up +400 stokes to clean out casing 320 GPM ~ 3,200 psi, 4.8K ft/Ibs ~ 40 RPMs, reciprocating pipe PROD1 Displace to FloPro 320 GPM 1,975 psi, 40 RPMs, reciprocating pipe 75 bbs of water 30 bbl Hi Vis spacer 420 bbls FloProSF 8.5 ppg PROD1 Clean old LSND mud from Possum Belly and under shakers PROD1 Drill out shoe and 20' of new hole for FIT 280 GPM ~ 1630 psi off, 1830 psi on W 06=5-10K Tq 3K off, 4.5K on ~ 50 RPMs PROD1 Circulate mud before FIT PROD1 FIT Hole depth 8,340' Shoe depth 8,320' Shoe TVD 8,247' MW 8.4 ppg Test Pressure 690 psi EMW = 10.0 ppg Charted for 10 minutes PROD1 Slide/Rotate from 8,340' to 8,650' 260 GPM ~ 1,700 psi off, 1900 psi on Tq 1.7K off, 3.OK on ~ 60 RPMs PUW 175K, SOW 155K, RWT 165K ADT=3.86, AST=1.16, ART=2.70 Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 10 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours ', Task Code NPT Phase ~ Description of Operations 9/1/2006 12:00 - 00:00 12.00 DRILL P PROD1 Slide/Rotate from 8,650' to 9,197' 260 GPM ~ 1,830 psi off, 2,100 psi on Tq 2-3K off, 3-5K on ~ 60 RPMs PUW 180K, SOW i60K, RWT 172K ADT=7.43, AST=5.06, ART=2.37 9/2/2006 00:00 - 05:00 5.00 DRILL P PROD1 Drill as per DD from 9,197' to 9,339' Geology decided they want nukes in the ground therefore we will not drill to the first fault before tripping 280GPM ~ 1,800 psi off, 2,100 psi on bottom W06=10-20, Tq 2.3K off, 4.2K on ~ 50 RPMs PUW=180K, SOW=160K, RWT=172K 05:00 - 06:00 1.00 DRILL P PROD1 Erratic torque, spent one hour attempting to drill, could not rotate or slide Trip to inspect bit, assume it is under gauge 06:00 - 07:00 1.00 DRILL P PROD1 Circulate bottoms up 280 GPM ~ 1,750 psi Tq 2.5K ~ 60 RPMs PUW=180K, SOW=160K, RWT=167K MW 8.5 ppg in and out Monitor well, well static 07:00 - 07:30 0.50 DRILL P PROD1 POH 5 stands, no tight spots, took proper fill PUW=189K, SOW=160K 07:30 - 08:30. 1.00 DRILL P PROD1 Change out Top Drive Compensator Seal Monitor well, well static 08:30 - 10:00 1.50 DRILL P PROD1 POH to 8,226', Drop dart to open cir sub 10:00 - 11:00 1.00 DRILL P PROD1 Pump Hi Vis Sweep 25 bbls FV=150, 45 YP Stage pumps up to 600 GPM ~ 1,610 psi 20% increase in cuttings from increased rate and additional 5% increase when sweep returned MW 8.5 in and out Monitor well, well static Pump dry job and POH 11:00 - 14:00 3.00 DRILL P PROD1 POH to BHA 14:00 - 17:00 3.00 DRILL P PRODi Rack back collars, Dial motor down to 1.5 ABH, change bit, download MWD tools 16:00 - 17:30 1.50 DRILL P PROD1 Orient, upload to MWD tools Monitor well, well static 17:30 - 18:30 1.00 DRILL P PROD1 Pulser test MWD before picking up Nukes 18:30 - 19:30 1.00 DRILL P PRODi Prejob safety meeting for handling source Load sources in Logging tool 19:30 - 20:00 0.50 DRILL P PROD1 Run collars out of derrick and pick up Jars 20:00 - 00:00 4.00 DRILL P PROD1 Trip in hole to 4,550', filling across top of hole, Fill pipe every 30 stands 9/3/2006 00:00 - 02:00 2.00 DRILL P PROD1 Trip in hole from 4,550' to 8,257' Fill pipe at shoe PUW=173K, SOW=158K 02:00 - 02:30 0.50 DRILL P PROD1 Rig service, Lubricate Top Drive 02:30 - 03:00 0.50 DRILL P PROD1 Trip in hole from 8,260' to 8,918' Taking weight, multiple wipes would not clean it up 03:00 - 04:30 1.50 DRILL P PROD1 Screw in and ream under gauge hole to bottom 250 GPM ~ 1400 psi, WOB=10-20K, Tq=3-5K @ 40 RPMs 04:30 - 08:30 4.00 DRILL P PROD1 Mad Pass from 9,339' up to 8,634' Top of conglomerates Printed: 9/25/2006 11:26:49 AM BP EXPLORATfON Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Start: 8/20/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date 9/3/2006 9/4/2006 From - To ~ Hours ~~ Task ~ Code ' NPT ~ Phase 04:30 - 08:30 4.00 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 12:00 3.00 DRILL P PRODi 12:00 - 16:00 4.00 DRILL P PROD1 16:00 - 17:00 ~ 1.00 DRILL P 17:00 - 00:00 I 7.001 DRILL I P 00:00 - 01:30 1.50 DRILL P 01:30 - 01:45 0.25 DRILL P 01:45 - 06:00 I 4.251 DRILL I P 06:00 - 12:00 6.00 DRILL P 12:00 - 00:00 I 12.001 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 Page 11 of 23 Spud Date: 9/7/1994 End: 9/21 /2006 Description of Operations 275 GPM ~ 1,570 psi, Tq=3K ~ 40 RPMs RIH to 9,339', no tight spots encountered Drill as per DD from 9,339' to 9,430' 300GPM ~ 1,650 psi off, 2,050 psi on bottom W0B=10-20, Tq 3K off, 4.OK on f~ 70 RPMs PUW=190K, SOW=158K, RWT=177K ART=0.42, AST=0.64, ADT=1.06 Drill as per DD from 9,430' to 9,603' 300GPM ~ 1,790 psi off, 2,000 psi on bottom W06=5-25K, Tq 2.8K off, 4.OK on ~ 80 RPMs PUW=184K, SOW=160K, RWT=174K Replace #2 Liner /SWAB #1 Mud Pump; Clean suction screen, repair seal, adjust pulsation dampener #2 mud pump. Drill as per DD from 9,603' to 9,765' Difficulty sliding, added tubes, helped some but still slow digging 300GPM ~ 1,800 psi off, 2,150 psi on bottom W06=5-25K, Tq 3K off, 4.OK on ~ 80 RPMs PUW=188K, SOW=154K, RWT=172K ART=1.27, AST=3.64, ADT=4.91 Drill as per DD from 9,765' to 9,770' Gain 20 bbls in 20 min Stopped drilling, picked up and did a flow check Well static Strapped pits, 2 hour gain was only 4 bbls Cleaned eyes on pit sensors and PVT dropped back to same as strap Drill as per DD from 9,765' to 9,895' Difficulty sliding, added more tubes, Total concentration 3.6% Still hanging up while trying to slide, slow digging in sliding mode, rotates at 100-200'/hr Checked and there are beads available, will try nut plug on next slide 300GPM ~ 1,800 psi off, 2,080 psi on bottom WOB=5-20K, Tq 2K off, 4.OK on ~ 80 RPMs PUW=182K, SOW=150K, RWT=166K PROD1 Drill as per DD from 9,895' to 10,120' While sliding a sweep was pumped and sliding ROP went from 9'/hr to 100'/hr 210 strokes after the sweep came out the bit. (51bs/bbl nut plug, 4 drums EMI776, 10 bbls FloPro) 300GPM ~ 1,800 psi off, 2,070 psi on bottom W06=5-10K, Tq 3K off, 4.OK on @ 80 RPMs PUW=180K, SOW=150K, RWT=165K ADT=6.28, AST=4.42, ART=1.86 PROD1 Drill as per DD from 10,120' to 10,657' Pump sweeps as needed for sliding Tagged the Kavik ~ 10,379' and came out ~ 10,516' 300GPM ~ 1,800 psi off, 2,100 psi on bottom W06=5-10K, Tq 3K off, 4,5K on ~ 80 RPMs PUW=176K, SOW=154K, RWT=170K ADT=6.43, AST=4.42, ART=2.01 Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 12 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date From - To ~ Hours ~ Tasl: Cade ~ NPT ~ Phase Description of Operations 9/5/2006 00:00 - 12:00 12.00 DRILL P PROD1 Drill as per DD from 10,657' to 11,223' Pump sweeps as needed for sliding 300GPM ~ 2,110 psi off, 2,350 psi on bottom W0B=5-10K, Tq 4K off, 5.5K on ~ 80 RPMs PUW=180K, SOW=148K, RWT=165K ADT=5.66, AST=3.33, ART=2.33 12:00 - 19:30 7.50 DRILL P PRODi Drill as per DD from 11,223' to 11,650' Pump sweeps as needed for sliding 300GPM ~ 2,200 psi off, 2,550 psi on bottom W0B=5-10K, Tq 4K off, 5.5K on ~ 80 RPMs PUW=180K, SOW=148K, RWT=165K ADT=4.92, AST=0.69, ART=4.23 19:30 - 20:50 1.33 DRILL P PROD1 Circulate bottoms up before wiper trip, 4,200 strokes 320 GPM C~ 2,360 psi, Tq = 3.5K ~ 80 RPMs MW=8.6 in and out Pumps down, PUW=200, SOW=160 20:50 - 21:00 0.17 DRILL P PROD1 Monitor well, well static 21:00 - 21:30 0.50 DRILL P PROD1 Trip out to Mad Pass point, from 11,650' to 11,420' Hole was in good shape, no over pulls and correct displacement 21:30 - 00:00 2.50 DRILL P PROD1 Begin mad pass, from 11,420' to 9,700' 200'/hr max 300 GPM ~ 2040 psi 3.5K ~ 40 RPMs 9/6/2006 00:00 - 05:30 5.50 DRILL P PROD1 Mad Pass to 9,700' 200'/hr max speed 300 GPM ~ 1,900 psi 3.5K ~ 40 RPMs 05:30 - 06:00 0.50 DRILL P PROD1 Trip from 9,700' to the shoe Hole in good shape, no over pulls and taking proper fill 06:00 - 09:00 3.00 DRILL P PROD1 Service Top Drive, Drawworks, and crown PJSM on cut and slip Drilling Line Cut and Slip Drilling Line 09:00 - 10:30 1.50 DRILL P PROD1 TIH, no tight spots and proper displacement Wash down last stand as a precaution 300 GPM ~ 2,100 psi Tq=4.5K ~ 90 RPMs 10:30 - 12:30 2.00 DRILL P PROD1 Circulate Hi Vis Sweep around 24 bbls =Vis 150+, 8.7 MW, 25 YP 300 GPM ~ 2,350 psi Tq=4.5K @ 90 RPMs 30% increase in cuttings with return of sweep MW = 8.7 in and out PUW=189, SOW=160, RWT=165 12:30 - 12:45 0.25 DRILL P PROD1 Observe well, well static 12:45 - 14:00 1.25 DRILL P PROD1 POH to the shoe, 8,320' No tight spots, hole took proper fill 14:00 - 16:00 2.00 DRILL PROD1 Drop dart to open cir sub, sheared ~ 1,400 psi Stage pumps up to 650 GPM ~ 2,220 psi Tq=2K ~ 40 RPMs MW=8.7 in and out 16:00 - 16:10 0.17 DRILL P PROD1 Monitor well Well Static Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 27E Date ~ From - To Hours ~, Task Code ~ NPT I' 9/6/2006 18:30 - 18:40 I 0.17 DRILL P ~~ 18:40 - 19:30 0.83 DRILL P 19:30 - 21:00 1.50 DRILL P 21:00 - 22:30 1.50 DRILL P 22:30 - 00:00 1.50 BOPSU P 9/7/2006 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:30 1.00 BOPSU P 02:30 - 03:00 0.50 CASE P 03:00 - 04:00 1.00 CASE P 04:00 - 10:30 6.50 CASE P 10:30 - 11:00 0.50 CASE P 11:00 - 11:30 0.50 CASE P 11:30 - 15:30 4.00 CASE P 15:30 - 16:30 1.00 CASE P 16:30 - 19:00 2.50 CASE P 19:00 - 19:40 0.67 CASE P 19:40 - 20:10 0.50 CASE P Start: 8/20/2006 Rig Release: 9/21 /2006 Rig Number: i Page 13 of 23 Spud Date: 9/7/1994 End: 9/21 /2006 Phase ' Description of Operations PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 20:10 - 00:00 I 3.831 CASE I N I DFAL I PROD1 POH to the BHA Monitor Well Well Static Lay down Jars and Drill Collars PJSM for handling Source Unload Sources Down load MWD tools Lay down MWD, LW D, and Motor Pull wear ring, pickup test joint, fill stack for BOP test Test BOP's with 4 1/2" test Jt. BOP test witnessed by Joey LeBlanc BP WSL, Dave Richards NAD TP Low test pressure 250 psi, High test pressure 3,500 psi #1 Annular and Choke valve #16 #2 Upper Variable Rams #3 Lower Variable Rams Rig down BOP test equipment and install wear ring Pre-job safety meeting with Casing hand, Crew, and Baker Discussed Rig up, Liner make up procedure, running order, Liner Hanger/Packer pick up and running procedure Rig up liner running equipment RIH with liner Baker lock first 3 joints Fill with mud and check floats Continue to RIH, 1 -Centralizer per joint for first 79 joints Pick up Liner hanger and single from pipe shed Circulate 1.5 liner volumes 3 bbls/min ~ 200 psi PUW=91 K, SOW=90K, HWT=90K RIH on drill pipe to the shoe, 8,320' Fill every 10 stands Circulate bottoms up at the shoe before going into open hole 6 bbls/min ~ 670 psi, 37 % on returns PUW=152, SOW=142 RIH to 11,650' Fill every 10 stands As a precaution, wash last joint to bottom, did not tag on std 86 Pick up cement head and 10' pup Rig up Tee with cement line and wash down line Wash to bottom, tagged bottom 1' in on pup joint Stage pumps up from 2.5 bbls to 5.0 bbls/min while reciprocating pipe On the 7th stroke up, while reciprocating, we noticed a decrease of 22,000 Ibs in our pick up weight, 200 psi drop in pressure, and a 7% increase in Returns. We thought we lost the liner and went back down. After working up and down 3 to 4 feet multiple times we thought we were still stung in, with pack off and dogs in place therefore 50,000Ibs was set down on the running tool to prevent it from unseating while latching up the liner wiper plug. A Hi Vis sweep with 24 sacks of Med nut plug and 4 gallons of die was circulated around to see if we were circulating through Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 14 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date 'From - To Hours ; Task ~ Code NPT Phase ~ Description of Operations 9!7/2006 20:10 - 00:00 3.83 CASE N DFAL PROD1 the liner or if the pack off and dogs were out allowing us to circulate on top of the liner. Surface to Surface with out the liner was 4,230 strokes, with the liner would be 5,290 strokes and the sweep came back at 3,500 strokes. 9/8/2006 00:00 - 01:30 1.50 CASE P PROD1 01:30 - 02:30 1.00 CASE N RREP PRODi 02:30 - 05:30 3.00 CASE P PROD1 05:30 - 06:00 0.50 CASE P PRODi 06:00 - 08:30 I 2.501 CASE I N IDFAL I PROD1 08:30 - 12:00 I 3.501 CEMT I N IDFAL PROD1 12:00 - 15:00 I 3.001 CEMT I N IDFAL I PROD1 15:00 - 15:30 0.50 CEMT N DFAL PROD1 15:30 - 16:30 1.00 BOPSU N DFAL PROD1 16:30 - 19:00 I 2.50 19:00 - 19:30 I 0.50 N IDFAL PRODI N (DFAL PRODI 19:30 - 20:30 1.00 BOPSU N DFAL PROD1 20:30 - 22:00 1.50 CEMT N DFAL PROD1 22:00 - 23:00 1.00 CEMT P PROD1 23:00 - 00:00 1.00 CEMT N DFAL PROD1 9/9/2006 100:00 - 05:00 I 5.001 CEMT I N IDFAL I PROD1 05:00 - 09:30 I 4.501 CEMT I N IDFAL I PROD1 Assumption was made that we did loose the liner and the dogs and pack off are no longer in place. Trip out to see if the dog sleeve sheared which will determine if we set the packer. POH with drill pipe Problems with compensator on Top Drive, Service Top Drive POH with drill pipe Lay down single and Liner running tool Dog sleeve sheared screws therefore assumption is packer set Packer requires 24,500 Ibs to set and dog sleeve requires 29,500 Ibs to shear Mobilize Schlumberger Wire Line Change out Derrick light Clean floor Monitor well, well static PJSM with Schlumberger Wire Line Rig up to Lubricator Rig up Wire Line RIH with Tubing punch 10' long, 4 shots per foot Top of Packer is at 8,149', bottom of hanger is at 8,175', 7" shoe ~ 8,320' Punch holes from 8,190' to 8,200' Monitor well, well static TOH with Wire line Rig down Schlumberger Wire Line Monitor well, well static Pull wear ring Install test plug Change upper rams from variable 3 1/2" x 6" to 2 7/8" Install test joint Test upper 2 7/8" Rams Low 250 psi, High 3,500 psi Plan forward meeting to discuss objectives, PJSM for picking up Packer and 2 7/8" drill pipe Rig down BOP test equipment Pull test plug Install wear ring Rig up to run 2 7/8" Drill Pipe Rig service., lubricate Rig Pick up EZ drill SVB squeeze packer assembly and 2 7/8" drill pipe Picking up 2 7/8" drill pipe out the shed Circulate after 50 joints and 111 joints picked up. At 50 Joints, 3.0 bbls/min ~ 420 psi At 111 Joints 3.0 bbls/min ~ 630 psi RIH with 4" drill pipe Circulate ever 20 stands 20 stands in 3 bbls/min ~ 700 psi Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 15 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ' From - To Hours Task I, Code NPT Phase 9/9/2006 05:00 - 09:30 09:30 - 12:00 4.50 2.50 CEMT CEMT N N DFAL DFAL PROD1 PROD1 12:00 - 13:30 I 1.501 CEMT I N I DFAL I PROD1 13:30 - 16:00 2.50 CEMT N DFAL PROD1 16:00 - 16:30 0.50 CEMT N DFAL PROD1 16:30 - 19:00 2.50 CEMT N DFAL PROD1 19:00 - 19:30 0.50 CEMT N DFAL PROD1 19:30 - 20:00 0.50 CEMT P PROD1 20:00 - 21:30 1.50 CEMT N DFAL PROD1 21:30 - 00:00 I 2.501 CEMT I N I DFAL I PROD? 9/10/2006 ~ 00:00 - 04:45 4.75 CEMT I N 04:45 - 07:30 I 2.751 CEMT I N 07:30 - 11:00 3.50 CEMT N 11:00 - 13:30 2.50 CEMT N DFAL IPRODI DFAL I PROD1 DFAL PROD1 DFAL PROD1 Description of Operations 40 stands in 3 bbls/min ~ 720 psi Stand 58, PUW=170K, SOW=140K 8,980 59 2/3 stands in started taking weight, try to work pipe but can't move EZSVB, work up to 190K, work down to 130K Try to circulate, EZSVB appears to be packed off, put 1,200 psi on EZSVB and it would not bleed off, reverse circulate, pressure up 1,200 psi, no go, Try down drill pipe again, pressure up 2,000 psi, no go Pulled up to 205K -sheared out & set EZSV. Pulled up 30 tt. Un-plug setting tool /stinger & regain circulation Run back down, set 30K on EZSV to confirm set. Attempt to pump thrrough EZSV -still plugged. Pulled up 30 tt. Pump 8 bbls/min ~ 3,160 psi to clean casing Monitor well, well static POH to 2 7/8" Drill Pipe RU to handle and rack back 2 7/8" drill pipe POH racking back 2 7/8" drill pipe Lay down mechanical setting tool Lubricate rig and top drive Pre-job safety meeting for picking up BHA Rig up tongs for 3 1/8" BHA Pick up BHA RIH with clean out BHA 3 bladed mill on a 3 1!8" motor with a cir sub and jars Run 24 stands of 2 7/8" drill pipe Circulate ~ 20 stands 2 bbls/min ~ 315 psi RIH with remaining 13 stands of 2 7/8" drill pipe RIH with 4" drill pipe filling every 20 stands Tagged up on 7" liner top ~ 4,124', picked up, set slips, rotated 1/4 tum, tagged again, picked up, set slips, rotate 1/4 turn and it went down no problem Continue RIH to 4 1/2" liner top, did not see 4 1/2" liner top Tagged up ~ 8,950, stacked 10K. Picked up and brought pumps up to 70 GPM ~ 740 psi to wash down PUW=159K, SOW=150K Did not see anything until 29' in on stand 59, 8,979'. Tagged up and stalled motor, shut down pumps, bleed it off, pick up and increase flow rate to 105 GPM ~ 1,100 psi. Went back down and started milling up packer. Off bottom 105 GPM 1,100 psi WOB=2-4 105 GPM 1,160 psi WOB=4-6 105 GPM 1,400 psi TIH pushing remaining debris from packer to Landing Collar 2.5 bbl/min ~ 1,200 psi Drop ball to open cir sub 7.5 bbl/min ~ 3,340 psi Pump Hi Vis Sweep surface to surface 27 bbis, 150+ Vis, 24 YP Clean hole ~ 6,000 strokes MW=8.7 in and out Monitor well, well static Printed: 9/25/2006 71:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date ~ From - To I, Hours Task Code ~ NPT ~ '~ ~._~_ 9/10/2006 13:30 - 15:30 2.00 CEMT N 15:30 - 16:30 1.00 CEMT P 16:30 - 18:30 2.00 CEMT N 18:30 - 19:30 1.00 CEMT N 19:30 - 20:30 I 1.001 CEMT I N Start: 8/20/2006 Rig Release: 9/21/2006 Rig Number: Phase DFAL PROD1 PROD1 DFAL PROD1 DFAL IPRODI DFAL IPRODI 20:30 - 22:00 1.50 CEMT N DFAL PROD1 22:00 - 22:30 0.50 CEMT N DFAL PROD1 22:30 - 00:00 1.50 CEMT N DFAL PROD1 9/11/2006 00:00 - 00:30 0.50 CEMT N DFAL PROD1 00:30 - 01:30 1.00 CEMT N DFAL PROD1 01:30 - 02:00 0.50 CEMT N DFAL PROD1 02:00 - 03:00 1.00 CEMT N DFAL PROD1 03:00 - 10:30 7.50 CEMT N DFAL PROD1 10:30 - 11:30 I 1.001 REMCMTN I DFAL 1 PROD1 11:30 - 11:45 0.25 CEMT N DFAL PROD1 11:45 - 15:45 4.00 CEMT N DFAL PROD1 15:45 - 16:15 0.50 CEMT N DFAL PROD1 16:15 - 18:00 1.75 CEMT N DFAL PROD1 18:00 - 18:30 0.50 CEMT N DFAL PROD1 18:30 - 19:30 1.00 CEMT P PROD1 Page 16 of 23 Spud Date: 9/7/1994 End: 9/21 /2006 Description of Operations POH to 4 1/2" liner lap ~ 8,149' to circulate across liner lap Rig service - Draworks /Top Drive, install blower hose Circulate 4 1/2" liner top clean 27 bbls Hi Vis Sweep, t50+Vis, 24 YP 9.1 bbl/min ~ 3,400 psi 10 RPMs while reciprocating across liner lap MW=8.7 in and out Monitor well, well static POH to 7,443' Positions 4" pipe in 7" liner lap Circulate to clean 7" liner top 27 bbls Hi Vis Sweep, 150+ Vis, 24 YP 9.3 bbl/min ~ 3,800 psi 10 RPMs while reciprocating pipe across liner lap MW=8.7 in and out Monitor well, well static Pump Dry Job, POH POH to 2 7/8" drill pipe Rig up tongs for 2 7/8" drill pipe POH racking back 2 7/8" drill pipe Pre-Job safety meeting with new crew Discussed current situation of well New requirements for PVT and Flow paddle testing tourly New drills and method for reporting drills New requirements on IADC reporting Performed a HACL on racking back and running in hole 2 7/8" drill pipe out of the derrick POH racking back 2 7/8" drill pipe Lay down BHA, Junk boot baskets had 1/2 cup of metal Pre-Job Safety meeting with Schlumberger for picking up pert gun Pick up Perf gun RIH with drill pipe out of derrick gun is ported and pipe will-fill on it's own getting back proper displacement No pumping till guns are on bottom PJSM on firing gun PUW=180K, SLOW=160K Tag Junk with Perf gun Pick up, break single and drop ball Tag up on junk, Pick up to up weight +1', and circulate ball down Circulate 2 bbls/min @ 690 psi for 53 bbls, ball seated Pump 2 more bbls, pressured up to 2,800 psi, positive indication gun fired at surface Pick up 30' Monitor well, well static POH to 2 7/8" pipe, hole taking proper fill Rig up 2 7/8" handling equipment POH to pert gun racking back 2 7/8" drill pipe hole taking proper fill Lay down Perf gun. All shots fired. Rig Service -Lubricate Rig, Crown, Top Drive, Drawworks, Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 17 of 23 Operations.. Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date .From - To Hours ' Task Code ~ NPT ~ Phase ~ Description of Operations --- __ 9/11/2006 18:30 - 19:30 1.00 CEMT P PROD1 swap power tongs over 19:30 - 20:30 1.00 CEMT N DFAL PROD1 Break pup off bottom of cement head 20:30 - 00:00 I 3.501 CEMT I N I DFAL I PRODi 9/12/2006 00:00 - 00:30 0.50 CEMT N DFAL PROD1 00:30 - 05:30 5.00 CEMT N DFAL PROD1 05:30 - 10:00 I 4.501 CEMT I N I DFAL I PRODi 10:00 - 10:30 I 0.501 CEMT I N I DFAL I PRODi 10:30 - 11:30 1.00 CEMT N DFAL PROD1 11:30 - 13:00 1.50 CEMT P PROD1 13:00 - 15:30 I 2.501 CEMT I P I I PROD1 15:30 - 17:30 2.001 CEMT P I PROD1 17:30 - 18:00 0.50 CEMT N DFAL PROD1 18:00 - 19:00 1.00 CEMT N DFAL PROD1 19:00 - 19:30 0.50 CEMT N DFAL PROD1 19:30 - 21:30 2.00 CEMT N DFAL PROD1 21:30 - 00:00 I 2.50 I CEMT I N I DFAL I PROD1 Make up EZSVB, mechanical setting tool RIH with drill pipe out of derrick, pump every 30 stands, 3 bbls/min max Change elavators and clear floor to RIH w/4" DP RIH => 8149', pumping every 30 stands to keep pipe clear Pump down each stand in the 4 1/2" liner to prevent packing off EZSVB 1.4 bbls/min ~ 430 psi PUW=148K, SOW=144K ~ 9108' took 4k down wt. Work to free up EZSV-B, work 10k over up and 15k down Pump tube pill around while circ. at 1.5(440 psi) - 2.2(600 psi) bbl/min Up rate to 3 bpm /845 psi 15k over up and 10 down, no success Packer sheer at 15k over Extend stinger and establish circulation: 1 bpm = 380 psi 2 bpm = 540 psi 3 bpm = 760 psi 4 bpm = 1050 psi 5 bpm = 1400 psi PJSM, M/U cement head and rig up to cement 4 1/2" liner PJSM, break circ. with cement manifold and cement lines Test rig & cement lines to 4000 psi, O.K. Estabilish circulation -same rates & pressures as through TD. Sting in & establish circulation: 1 bpm = 450 psi 2 bpm = 650 psi 3 bpm = 950 psi 4 bpm = 1340 psi 5 bpm = 1825 psi PJSM, Start 4 1/2' liner cement job 'pump 40.90 bbl mud push spacer, *pump 90.3 bbl of class "G" batched cement flushed lines with 3.2bb1 water displaced ~ 4 bpm with rig pumps, caught cement ~ 33 bbl, pumped 98 bbls, shut down pumps and unstung from EZSVB CIP ~ 15:09 CBU, Staged pump to 8 bpm / 3400 psi 15 bbls of excess cement back to surface POH to TOL ~ 8168' Circ. ~ top of 4 1/2" liner , 9 bpm / 3450 psi, pump24 bbl hi-vis sweep / 150+vis POH to 7604' Circulate surface to surface pump 26 bbl hi-vis sweep / 150+ vis, 8.7 ppg POH Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 18 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING t Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To Hours Task ,Code ( NPT Phase Description of Operations 9/13/2006 00:00 - 02:00 2.00 CEMT N DFAL PROD1 02:00 - 03:00 1.00 CASE P PROD1 03:00 - 05:00 2.00 CASE N DFAL PROD1 05:00 - 06:00 1.00 CASE N DFAL PROD1 06:00 - 09:30 3.50 CASE N DFAL PROD1 09:30 - 11:30 2.00 CASE P PROD1 11:30 - 14:00 2.50 CASE N DFAL PROD1 14:00 - 16:30 2.50 DRILL N DFAL PROD1 16:30 - 22:00 I 5.501 DRILL I N I DFAL I PROD1 22:00 - 00:00 I 2.001 DRILL I N I DFAL I PROD1 9/14/2006 100:00 - 05:30 I 5.501 DRILL I N I DFAL I PROD1 05:30 - 06:00 0.50 DRILL N DFAL PROD1 06:00 - 07:00 1.00 DRILL N DFAL PROD1 07:30 - 09:00 1.50 DRILL N DFAL PROD1 09:00 - 11:30 2.50 DRILL N DFAL PROD1 11:30 - 12:30 I 1.001 DRILL I N I DFAL I PROD1 12:30 - 14:00 1.50 DRILL N DFAL PROD1 14:00 - 15:30 1.50 DRILL N DFAL PROD1 PJSM, POH with EZSV setting tool and 2 7/8" DP PJSM, Pull wear bushing, Run BOP's wash tool and flush stack, service wear bushing and place in wellhead, set LDS PJSM & HACL, Install barriers & caution signs at rig floor entrances Pull Rotary Master bushings and Clean out drip pan under rig floor PJSM, pick up BOT EZSV mill out & liner Clean out BHA RIH w/ 2 7/8" DP, filling every 20 stds. RIH w/ 20 stds. of 4" DP PJSM, Slip and cut 104' of drilling line Repair bolts on brake pad Service top drive PJSM, RIH w/4" DP, fill every 20 stds. Tag cement stringer @ 9074', wash down to 9104' ~ 2.7 bpm, 1425 psi Tag EZ-SVB @ 9104' and drill out, no rotation WOB 3K, 25 RPM, 2K tq 1560K PUW, 150 SOW, No cement under EZ-SVB Wash down to top of cement C~ 10870', 2.8 bpm / 1150 psi no rotation Drill cement f/ 10,870 - 11,046, no rotation 2.8 bpm 1150 psi off 1450 on btm PUW 165 / 150 SOW Pump 2 Hi-Vis sweeps (150+, 33 yp, 8.8 pp) Back ream each stand ~ 10 rpm Firm cement Drill cement f/ 11,046 -11550 2.8 bpm 1300 psi off 1700 on btm PUW 175 / 155 SOW / 160 RtWt Pump3 Hi-Vis sweeps (150+, 33 yp, 8.8 pp) Back ream each stand ~ 10 rpm 5-10k WOB, Firm cement Drop ball and shear circ. sub. Pump Hi-Vis sweep while reciprocating pipe 70 spm / 3500 psi 20 rpm / 1.5k ft/Ibs TO Monitor well (static) POH from 11550 => 9320' Pump out from 9320 => 8195 (just inside TOL) 84 spm / 3500 psi 25 rpm / 1.5k fUlbs TO Pump Hi-Vis sweep @ TOL while reciprocating pipe 84 spm / 3500 psi 25 rpm / 1.5k ft/Ibs TO RIH to 11550'. no fill Pump Hi-Vis sweep while reciprocating pipe 80 spm / 3500 psi Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date From - To Hours Task Code, NPT 9/14/2006 ~ 14:00 - 15:30 1.50 DRILL N 15:30 - 17:00 1.50 DRILL N 17:00 - 18:30 1.50 DRILL N 18:30 - 19:30 ~ 1.001 DRILL N 19:30 - 20:00 I 0.501 DRILL I N Page 19 of 23 Spud Date: 9/7/1994 Start: 8/20/2006 End: 9/21 /2006 Rig Release: 9/21 /2006 Rig Number: Phase Description of Operations DFAL PROD1 15 rpm / 1.5k fUlbs TO 25 bbl sweep / 300+ vis, 50 YP, 8.8 ppg 30% increase in returns DFAL PROD1 POH to 9300' DFAL PROD? Pump out 9300 => 8168' 15 rpm / 1.5k tq 8.4 bppm / 3500 psi DFAL PROD1 Circ. ~ TOL Pump Hi-Vis sweep while reciprocating pipe 80 spm / 3500 psi 15 rpm / 1.5k ft/Ibs TO 25 bbl sweep / 300+ vis, 50 YP, 8.8 ppg 30% increase in returns DFAL PROD1 POOH w/ 6 stands to 7604 bit depth, 4" ~ top of 7" casing 20:00 - 21:30 1.50 DRILL N DFAL PROD1 Pump Hi-Vis / WT. sweep while reciprocating pipe 86 spm / 3500 psi 15 rpm / 1.5k ft/Ibs TO 25 bbl sweep / 150+ vis, 36 YP, 11.3 ppg 55% increase in returns 21:00 - 00:00 3.00 DRILL N DFAL PROD1 9/15/2006 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 02:30 1.00 BOPSU P PROD1 02:30 - 06:30 4.00 BOPSU P PROD1 Pump slug to POH POH (tested Choke manifold while POH) Tested Choke Manifo-d to 250 psi/ 3,500 psi. Charted all test. All Tests• held 5 min each. Witness of Test Waived by AGOCC Rep. Chuck Sheve. Test Witnessed by BP WSL Dave Newlon / Nabors Toolpusher Dave Richards Testing Sequence; (1.) Choke Valve 2 (2.) Choke Valves 3,4,5 & 6, ( 3.) Choke Valves 7,8 & 9, ( 4.) Choke Valves 10, 11 & 12, ( 5.) Choke Valves 13, 14 & 15 PJSM, POH and UD clean out BHA Clear Floor and prepare for BOP test PJSM, Pull wear bushing and drain stack PJSM, Tested BOPE's Utilizing 4-1/2" , 4", 2 7/8" Test Joints. Test All Rams, Annular, Choke and Kill Line Valves, Floor Safety Valves to 250 psU 3,500 psi. All Tests held 5 min each and charted. Witness of Test Waived by AGOCC Rep.Chuck Sheve. Test Witnessed by BP WSL Dave Newlon / Nabors Toolpusher Dave Richards Test Sequence (cont. from 9-14-2006) (6) 4" test JT. -upper IBOP- HCR, Kill_Choke Valve #16-Hydril Annular (7 )Lower IBOP- Lower Pipe rams (4" dp) (8) TIW (9j 4 1/2" test jt., Dart Valve- Inside Kilt-HCR choke-Hydrill Annular (10) Inside choke valve (11) Lower Pipe on 4 1/2" (12) 2 7/8" DP, Hydrill Annular - 2 7/8 TIW (13) 2 7/8" top rams Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 20 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours ', Task Code NPT Phase ' 9/15/2006 02:30 - 06:30 4.00 BOPSU P PROD1 06:30 - 08:00 1.50 CASE N DFAL PRODi 08:00 - 08:30 08:30 - 09:00 09:00 - 10:30 10:30 - 17:30 0.50 BOPSU N 0.50 CASE N 1.50 CASE N 7.00 CASE N DFAL PROD1 DFAL PRODi DFAL PROD1 DFAL PRODi 17:30 - 20:00 I 2.501 CASE I N I DFAL I PROD1 20:00 - 20:30 0.50 CASE N DFAL PRODi 20:30 - 21:00 0.50 CASE N DFAL PRODi 21:00 - 23:00 2.00 CASE N DFAL PROD1 23:00 - 00:00 1.00 CASE N DFAL PROD1 9/16/2006 00:00 - 01:30 1.50 CASE N DFAL PROD1 01:30 - 04:00 2.50 CASE N DFAL PRODi 04:00 - 05:30 1.50 CASE N DFAL PROD1 05:30 - 08:00 2.50 CASE N DFAL PROD1 08:00 - 11:00 3.00 CASE N DFAL PROD1 11:00 - 18:30 7.50 CASE N DFAL PROD1 18:30 - 20:30 2.00 CASE N DFAL PROD1 20:30 - 21:30 1.00 BOPSU N DFAL PROD1 Description of Operations (14) Blind Rams PJSM, Rig up and test Casing Tested to 1500, 36 strokes ,bled down to 1100 over 5 min Tested to 1200, 23 strokes ,bled down to 1000 over 4 min Test surface equip. to 3500, O.K. Install wear bushing, run in LDS PJSM, R/U power tongs& prepare rig floor to P/U BHA M/U BHA, Bull nose, csg. scprs and XO's, Circ. sub, Jars, XO RIH w/2 7/8 DP, M/U 7" csg scpr, XO's, Circ. Sub PJSM, RIH w/4" dp (fill every 20 stds) Pump down 8867-9244 Took 10k down ~ 9080', work through without issues and did not see any problems working through problem area RIH => 11,417, no problems Wash down to 4 1/2" TOL, no probelms, tag ~ 11546 PUW 182 /SOW 158 5.5 bpm / 2900 psi Pump Hi-Vis weighted sweep, sweep incresed cutting by 20 POH POH to 9242 Pump out to 8149 TOL 323 gpm / 3400 psi Wipe through trouble area ~ 9080- 9170 without problems Pump Hi-Vis weighted sweep around RIH to 11542' No problems RIH Pump 100 bbl of fresh water w/1 drum Safe -Surf, Displace to seawater ~ 300 GPM / 3800 psi, 20 rpm TO 2-3k fUlbs PUW 185 SOW 180 Pump till clean seawater S-S Monitor well for 15 min, Static POH, No problems ~ 9100' UD 7" csg. Scraper , set 2 7/8" DP back and UD 4 1/2" csg scraper Change top Pipe rams to 3 1/2" x 6" variable rams Pull wear bushing and set test plug, Test top set of pipe rams to 250 low and 3500 high, each test held for 5 min. Witness by BP WSL Dave Newlon & Nabors Toolpusher Dave Richards 21:30 - 00:00 ~ 2.50 ~ EVAL ~ N ~ DFAL ~ PROD1 ~ R/U SWS, P/U lubricator and packoff, test to 1500 psi M/U SWS -SCMT, XY caliper, Spinner with Tractor logging tools 9/17/2006 00:00 - 06:30 6.50 EVAL N DFAL PROD1 Wireline Log with SWS -SCMT, XY caliper, Spinner log. Log with Tractor logging tool Unable to log under pressure due severity of leak Attempted to pressure up to 2000 psi, unable to get above Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 21 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 9/17/2006 00:00 - 06:30 6.50 EVAL N DFAL PROD1 1300 psi due to an infectivity rate of 4 bbl/min and 1300 psi. Able to maintain 1300 psi injecting ~ 2 bbl/min Total seawater lost during logging operation = 57 bbls Performed static spinner logs 06:30 - 07:30 I 1.001 EVAL I N 07:30 - 09:30 ~ 2.00 I CASE ~ P 09:30 - 10:30 1.00 EVAL N 10:30 - 12:00 I 1.501 BOPSUR P 12:00 - 14:00 ~ 2.00 I BOPSUFI P 14:00 - 18:00 I 4.001 PERFOBI P 18:00 - 18:30 I 0.501 PERFOBI P 18:30 - 20:30 I 2.001 PERFOBI P 20:30 - 21:30 I 1.001 PERFOBI P 21:30 - 00:00 I 2.501 PERFOl3l P 9/18/2006 100:00 - 02:30 ( 2.501 PERFOB P 02:30 - 03:00 0.50 PERFO P 03:00 - 10:30 7.50 PERFO P 10:30 - 11:30 1.00 PERFO P 11:30 - 13:00 I 1.501 PERFOBI P 13:00 - 19:30 I 6.501 PERFOBI P 19:30 - 21:30 I 2.001 PERFOBI P DFAL ~ PROD1 ~ Rig down SWS E-line, lubricator and logging tools Anchorage rig team evaluating logs PROD1 Service top drive and & drawworks, Adjust brakes and check TDS hydraulics DFAL OTHCMP Developed plan forward with Anchorage rig team. It was decided that that we had good cement behind pipe allowing Sufficient isolation OTHCMP Change out Top Pipe Rams from 3 1/2" X 6" varaibles to 2 7/8" pipe rams OTHCMP PJSM, pull wear bushing, set test plug Test Top pipe rams to 250 low / 3500 high All tests held for 5 min. and charted Install wear bushing and UD test joint Witness by BP WSL Bill Decker and Nabors toolpusher Jimmy Hensen OTHCMP PJSM, R/U floor to handle 2 7/8' DP, RIH w 23 stds of 2 7/8" DP UD 69 joints of 2 7/8" DP OTHCMP Clear rig floor of 2 7/8" DP handling equipment and ready floor to handle pert. guns OTHCMP P/U perforating handling equip. & load pipe shed with Perf guns OTHCMP PJSM w/ rig crew &SWS tech rep, TP &WSL. After discussion, it was determined that ball type firing head was needed due to the pressure limitations encountered previously while logging spinner. OTHCMP Make up SWS Perforating guns &RIH 54 guns in hole by midnight. Rebuild firing head. OTHCMP Make up SWS Perforating guns Total 104 guns 1580' loaded plus 626' of blanks' plus firing head and Hyd. disconnect total of 2206' 4 SPF Perforating guns OTHCMP UD perf gun handling equip and prepare floor to RIH with guns OTHCMP PJSM, RIH with Perf. guns on 2 7/8" DP and 4" DP OTHCMP PJSM, Screw in ~ 11542', break circ. ~ 2 BPM / 420 psi, Tag cement @ 11550', Drop ball & circ. ~ 26PM / 420 psi, Space out to guns to 11,480', fire guns ~ 11:20 perfs ~ 11480-11330, 11225 -10550, 10230 -9950, 9741 - 9300 OTHCMP POH w/ 25 stands of 4" DP Monitor well, losses ~ 30-40 bbl/hr OTHCMP UD 4" DP Seawater losses ~ 30-40 bbl / hr OTHCMP Slip and cut drilling line Monitor losses, 30-40 bbl/hr Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date From - To ~ Hours ~ Task 'Code NPT 9/18/2006 21:30 - 22:00 0.50 PERFO~ P 22:00 - 00:00 2.00 PERFO P 9/19/2006 00:00 - 01:30 1.50 PERFO~ P 01:30 - 02:00 0.50 PERFO P 02:00 - 02:30 0.50 PERFO P 02:30 - 08:30 6.00 PERFOB~ P 08:30 - 10:30 2.00 PERFO P 10:30 - 13:30 3.00 PERFO P 13:30 - 20:00 6.50 PERFO P 20:00 - 21:00 1.00 BUNCO 21:00 - 00:00 3.00 BUNCO 9/20/2006 100:00 - 01:30 01:30 - 02:00 02:00 - 15:30 1.50 0.50 13.50 15:30 - 17:30 2.00 17:30 - 19:30 2.00 19:30 - 22:00 2.50 22:00 - 23:00 1.00 23:00 - 00:00 I 1.00 9/21/2006 100:00-04:30 04:30 - 07:30 4.50 I BOPSUFi P 3.001 WHSUR ( P Page 22 of 23 Spud Date: 9/7/1994 Start: 8/20/2006 End: 9/21 /2006 Rig Release: 9/21/2006 Rig Number: Phase Description of Operations OTHCMP Adjust Bales on Top Drive Monitor losses, 30-40 bbl/hr OTHCMP UD 4 " DP and 2 7/8" DP Total seawater losses for today ~ 449 bbls OTHCMP PJSM, Finish Laying down 2 7/8" DP OTHCMP PJSM, Clear floor and Rig Up to lay down Perforating guns OTHCMP Pre job Safety meeting on Laying Down Perf guns with SWS perforating technicians, Nabors Rig crew, Nabors Toolpusher and BP WSL OTHCMP UD 104 - 2 1/2" perforating guns, Afl shots fired OTHCMP Lay Down perforating guns, Running tools, subs & elevators Clean rig floor and prepare to UD 4" DP OTHCMP RIH with 61 stands from derrick OTHCMP UD 183 joints of 4" DP RUNCMP Pull wear bushing and make up Landing joint and crossovers RUNCMP R/U Tong, Elevators, Bales and handling equipment to run 4 1/2" 13CR80 tubing RUNCMP PJSM, Finish R/U Tubing Tongs, Elevators, Bales and handling equipment to run 4 1/2" 13CR80 tubing RUNCMP Perform Pre-job safety meeting with rig crew, BOT and NAD casing hands RUNCMP Run 4.5" completion string as per program. Used compensator and torque turn on all connections (4440 fUlbs). Measure space out for landing 6' into TBR tubing hanger, bottom out on No Go with WLEG in liner top packer at 8156", PUW 140k, SOW 130k -189 joints total of 4 1/2" 13Cr80 VAM Top tubing -1 - 7" x 4.5 BOT S-3 packer -3 - 4.5 x 1 "GLM -3 - 4.5" X" Nippples -1 - 4.5" "XN" Nippple w/W LEG RUNCMP Change elevators, R/D Compensator Make up hanger on landing jt, land hanger and RILDS. 4.5" tubing set at 8156' with the WLEG 6' into the top of the liner top packer. UD tubing handling equipment RUNCMP PJSM,Reverse circ.134 bbls of Corrosion inhibited seawater followed by 196 bbls of clean seawater EC1124A corrision inhibitor used RUNCMP Drop ball/bar landing in the RHC-M plug, hold PJSM, pressure up to 3,500 psi on 4-1/2" tubing setting prod. packer, hold and record on chart 30 minutes, OK. Bled tubing off to 1,500 psi, pressure up on the 9-5/8"x7" annulus to 3,500 psi, hold and record on chart for 30 minutes. OK RUNCMP Shear DCK-2 shear valve ~ 3395', pumped down annulus ~ 2BPM / 800 psi, 6 bbls pumped pumped down tubing @ 2BPM / 640 psi, 3 BPM = 1100 psi, 7.5 bbls pumped RUNCMP Install TWC and test both sides to 1000 psi, Blow down lines RUNCMP N/D BOPE's, set stack back on stump, N/D flowline, turnbuckles drip pan and drain hoses RUNCMP N/U well head, changing top valve Printed: 9/25/2006 11:26:49 AM BP EXPLORATION Page 23 of 23 Operations Summary Report Legal Well Name: 15-39 Common Well Name: 15-39A Spud Date: 9/7/1994 Event Name: REENTER+COMPLETE Start: 8/20/2006 End: 9/21/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/21/2006 Rig Name: NABORS 27E Rig Number: Date ~ From - To ~ Hours ~! Task Code NPT ~, Phase Description of Operations 9/21/2006 07:30 - 09:00 1.50 WHSUR P RUNCMP Test pack off to 5000 psi for 15 min. Test tree to 250 psi low and 5000 high for 5 min. charted, O.K. 09:00 - 10:00 1.00 WHSUR P RUNCMP R/U lubricator and pull TWC with Drill site Maintenance 10:00 - 12:30 2.50 WHSUR P RUNCMP R/U Little Red Pumping services to pump Freeze protection. Test all lines to 3000 psi, O.K. Pump down the backside of the tubing with i 45 bbls of diesel ~ 2 BPM = 500 psi 12:30 - 13:30 1.00 WHSUR P RUNCMP U-Tube Diesel from annulus to tubing. Calculated diesel cap on well at 2100' ss TVD 13:30 - 15:30 2.00 WHSUR P RUNCMP Set BPV with lubricator, Test BPV to 1000 psi / 5 min. Blow down Little Red and remove hard lines L/D Lubricator Install Flange on annulus valve and install needle valves and gauges Secure well , no pressure on annulus or tubing. Rig Released ~ 15:30 hrs Printed: 9/25/2006 11:26:49 AM Halliburton Com any P Survey Report Company: BP Amor_o Date: fli22i2006 Time: 1641_p5 Page: 1 ' i'icld: Prudhoe bay Co -ordina~el~lO R eference: Weii: 75-39, Tru e North time: PB DS 15 Ve rtical l7 ~U) Reference: 15-39A: 64.2 ~~ ell: 15-39 Section (1ti1 Reference: WeII (O.OON,O.OOE,140.08Azi) ~~ clipath: 15-39A Survey Calcuiaiiun Method: Minimum Curva ture Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2006 Well: 15-39 Slot Name: T 5-39 Well Position: +N/-S 1188.28 ft Northing: 5960035.53 ft Latitude: 70 17 46.923 N +E/-W 438.88 ft Easti ng : 676707.84 ft Longitude: 148 34 8.421 W Position Uncertainty: 0.00 ft Wellpath: 15-39A Drilled From: 15-39 500292250301 Tie-on Depth: 4259.38 ft Current Datum: 15-39A: Height 64.20 ft Above System Datum: Mean Sea Level Magnetic Data: 8/21/2006 Declination: 24.32 deg Field Strength: 57653 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.90 0.00 0.00 140.08 Survey Program for Definitive Wellpath Date: 9/22/2006 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 214.72 4259.38 1 : MWD - Standard (214.72-108 M WD MWD -Standard 4290.00 4556.00 15-39A GyroData (4 290.00-4556. G YD-GC-SS Gyrodata gyro single shots 4635.03 11598.52 15-39A IIFR+MS+SAG (4635.03-11 M WD+IFR+MS MWD +IFR + Multi Station Survey 111) incl Azim 1 ti U S_ys TVD VIS E/W MapN MapE Tool I ~t deg __ deg ft ft ft ft ft ft __ ' 32.90 0.00 0.00 - 32.90 -31.30 0.00 0.00 5960035.53 676707.84 TIE LINE 214.72 0.08 318.50 214.72 150.52 0.10 -0.08 5960035.62 676707.75 MWD 304.72 0.07 101.08 304.72 240.52 0.13 -0.07 5960035.66 676707.77 MWD 395.86 0.31 146.64 395.86 331.66 -0.09 0.12 5960035.45 676707.96 MWD 484.23 0.20 170.50 484.23 420.03 -0.44 0.28 5960035.10 676708.13 MWD 574.43 0.22 143.08 574.43 510.23 -0.73 0.41 5960034.81 676708.26 MWD 662.61 0.31 130.23 662.61 598.41 -1.02 0.69 5960034.53 676708.55 MWD 752.15 0.68 139.73 752.14 687.94 -1.58 1.22 5960033.98 676709.09 MWD 841.38 0.20 122.62 841.37 777.17 -2.07 1.69 5960033.50 676709.58 MWD 931.53 0.51 125.60 931.52 867.32 -2.39 2.15 5960033.19 676710.05 MWD 1021.43 0.31 100.81 1021.42 957.22 -2.67 2.71 5960032.93 676710.62 MWD 1112.25 0.62 83.26 1112.23 1048.03 -2.66 3.44 5960032.96 676711.34 MWD 1209.76 0.77 100.06 1209.74 1145.54 -2.71 4.61 5960032.93 676712.51 MWD 1303.64 0.60 60.46 1303.61 1239.41 -2.58 5.66 5960033.09 676713.56 MWD 1399.29 0.66 67.04 1399.25 1335.05 -2.11 6.60 5960033.57 676714.49 MWD 1493.32 0.96 39.19 1493.28 1429.08 -1.29 7.60 5960034.42 676715.47 MWD 1590.86 0.86 46.43 1590.80 1526.60 -0.15 8.65 5960035.58 676716.49 MWD 1684.76 0.53 37.98 1684.70 1620.50 0.67 9.42 5960036.43 676717.25 MWD 1781.38 0.72 54.70 1781.31 1717.11 1.38 10.20 5960037.15 676718.00 MWD 1876.83 0.11 236.88 1876.76 1812.56 1.67 10.61 5960037.45 676718.41 MWD 1971.87 0.37 56.73 1971.80 1907.60 1.79 10.79 5960037.58 676718.58 MWD 2068.15 0.77 79.20 2068.07 2003.87 2.08 11.68 5960037.89 676719.47 MWD 2162.60 0.29 104.43 2162.52 2098.32 2.14 12.54 5960037.97 676720.32 MWD 2259.06 0.18 102.33 2258.98 2194.78 2.05 12.92 5960037.88 676720.71 MWD 2354.06 0.25 223.77 2353.98 2289.78 1.87 12.93 5960037.70 676720.72 MWD 2449.48 0.10 156.24 2449.40 2385.20 1.64 12.81 5960037.47 676720.61 MWD 2543.34 0.04 52.65 2543.26 2479.06 1.59 12.87 5960037.42 676720.67 MWD 2640.06 0.24 231.37 2639.98 2575.78 1.48 12.74 5960037.31 676720.54 MWD ., Halliburton Company Survey Report Company: BP Amoco llate: 9!22/2006 Time: 16:41:05 Yage: 2 Field: Pru dhoe Bay Co-ordinatc(ivE) Reference: Well: 15-39, Tru e North Site: PB DS 15 Vertic al (TVD) Reference: 15-39A: 64.2 Well: 15- 39 Section (VS) Reference: Well (O.OON,O.O OE,140.08Azi} ~N'ellpath: 15- 39A Survcv Calculati on Method: Minimum Curvature Db: Oracle Sure cc ~tU Inc! Azim T'VU Sys Tb'D N/S E!W MapN MapE _- ~ fool ft deg deg ft ft ft ft ft ft 2734.99 0.40 208.79 2734.91 2670.71 1.07 12.43 5960036.89 676720.24 MWD 2830.32 0.62 174.27 2830.23 2766.03 0.26 12.32 5960036.08 676720.15 MWD 2922.35 0.67 178.85 2922.26 2858.06 -0.77 12.38 5960035.05 676720.23 MWD 3019.48 0.73 189.89 3019.38 2955.18 -1.95 12.28 5960033.87 676720.17 MWD 3114.50 0.49 216.95 3114.39 3050.19 -2.87 11.94 5960032.94 676719.84 MWD 3209.51 -0.73 232.40 3209.40 3145.20 -3.56 11.21 5960032.23 676719.13 MWD 3305.73 0.50 278.30 3305.61 3241.41 -3.88 10.31 5960031.90 676718.24 MWD 3401.30 0.32 308.09 3401.18 3336.98 -3.65 9.69 5960032.11 676717.61 MWD 3472.55 0.17 6.24 3472.43 3408.23 -3.43 9.54 5960032.33 676717.46 MWD 3593.54 0.21 10.24 3593.42 3529.22 -3.03 9.60 5960032.73 676717.51 MWD 3688.37 0.13 357.62 3688.25 3624.05 -2.75 9.63 5960033.01 676717.53 MWD 3783.54 0.18 355.27 3783.42 3719.22 -2.49 9.61 5960033.26 676717.51 MWD 3877.80 0.19 349.08 3877.68 3813.48 -2.19 9.57 5960033.56 676717.46 MWD 3973.41 0.22 345.27 3973.29 3909.09 -1.86 9.49 5960033.90 676717.37 MWD 4068.95 0.14 334.82 4068.83 4004.63 -1.58 9.40 5960034.18 676717.27 MWD 4164.06 0.14 28.05 4163.94 4099.74 -1.37 9.40 5960034.38 676717.27 MWD 4259.38 0.13 0.04 4259.26 4195.06 -1.16 9.46 5960034.60 676717.32 MWD 4290.00 0.16 10.39 4289.88 4225.68 -1.08 9.47 5960034.67 676717.33 GYD-GC-SS 4388.00 1.81 167.76 4387.86 4323.66 -2.46 9.82 5960033.30 676717.71 GYD-GC-SS 4457.00 3.05 331.06 4456.84 4392.64 -1.92 9.16 5960033.83 676717.04 GYD-GC-SS 4556.00 8.10 346.28 4555.34 4491.14 7.17 6.23 5960042.84 676713.90 GYD-GC-SS 4635.03 9.59 22.04 4633.49 4569.29 18.69 7.38 5960054.39 676714.78 MWD+IFR+MS 4741.00 13.25 50.75 4737.42 4673.22 34.57 20.11 5960070.56 676727.13 MWD+IFR+MS 4835.41 13.47 75.38 4829.35 4765.15 44.20 39.15 5960080.64 676745.93 MWD+IFR+MS 4927.97 14.14 102.33 4919.33 4855.13 44.51 60.64 5960081.45 676767.42 MWD+IFR+MS 5018.27 16.74 120.25 5006.41 4942.21 35.60 82.67 5960073.06 676789.64 MWD+IFR+MS 5112.00 16.71 132.91 5096.21 5032.01 19.62 104.21 5960057.59 676811.55 MWD+IFR+MS 5205.49 16.39 133.42 5185.82 5121.62 1.40 123.63 5960039.84 676831.40 MWD+IFR+MS 5298.61 15.43 131.56 5275.38 5211.18 -15.85 142.44 5960023.03 676850.61 MWD+IFR+MS 5394.06 13.24 120.37 5367.87 5303.67 -29.80 161.38 5960009.53 676869.87 MWD+IFR+MS 5487.13 11.63 109.34 5458.76 5394.56 -38.30 179.43 5960001.46 676888.11 MWD+IFR+MS 5583.26 9.11 88.43 5553.35 5489.15 -41.30 196.19 5959998.85 676904.93 MWD+IFR+MS 5678.18 6.67 83.03 5647.36 5583.16 -40.43 209.18 5960000.03 676917.90 MWD+IFR+MS 5769.53 3.83 102.28 5738.33 5674.13 -40.43 217.43 5960000.22 676926.14 MWD+IFR+MS 5862.98 3.40 99.85 5831.59 5767.39 -41.57 223.21 5959999.22 676931.95 MWD+IFR+MS 5958.93 3.10 98.55 5927.39 5863.19 -42.44 228.57 5959998.47 676937.33 MWD+IFR+MS 6056.08 1.79 92.00 6024.45 5960.25 -42.89 232.69 5959998.13 676941.46 MWD+IFR+MS 6147.17 1.96 89.66 6115.49 6051.29 -42.93 235.67 5959998.16 676944.44 MWD+IFR+MS 6241.78 1.94 90.88 6210.04 6145.84 -42.94 238.89 5959998.22 676947.66 MWD+IFR+MS 6337.34 2.05 87.73 6305.55 6241.35 -42.90 242.21 5959998.34 676950.98 MWD+IFR+MS 6432.05 1.90 79.82 6400.20 6336.00 -42.56 245.45 5959998.76 676954.21 MWD+IFR+MS 6525.20 1.71 75.61 6493.30 6429.10 -41.94 248.32 5959999.45 676957.06 MWD+IFR+MS 6621.45 1.06 52.11 6589.53 6525.33 -41.03 250.41 5960000.40 676959.13 MWD+IFR+MS 6715.08 1.00 46.64 6683.14 6618.94 -39.94 251.69 5960001.52 676960.38 MWD+IFR+MS 6809.39 0.92 48.57 6777.44 6713.24 -38.87 252.85 5960002.61 676961.52 MWD+IFR+MS 6904.43 0.70 55.24 6872.47 6808.27 -38.04 253.90 5960003.47 676962.55 MWD+IFR+MS 6996.51 0.42 48.92 6964.54 6900.34 -37.50 254.62 5960004.03 676963.25 MWD+IFR+MS 7091.33 0.95 120.73 7059.36 6995.16 -37.67 255.56 5960003.88 676964.20 MWD+IFR+MS 7184.24 5.00 126.30 7152.12 7087.92 -40.46 259.48 5960001.18 676968.19 MWD+IFR+MS 7278.90 6.58 125.52 7246.30 7182.10 -46.05 267.22 5959995.77 676976.05 MWD+IFR+MS 7371.81 7.80 126.95 7338.48 7274.28 -52.94 276.59 5959989.11 676985.58 MWD+IFR+MS 7465.38 9.02 127.10 7431.04 7366.84 -61.18 287.52 5959981.13 676996.70 MWD+IFR+MS Halliburton Company ~, Survey Report Company: BP Amoco Date: 9/22/2006 'l'ime: 16:41:05 Page: 3 Field: Prudhoe Bay Co-ordinate(\E) Reference: Well: 15-39, True North Sitc: PB DS 15 Vertical ('I'VD) Reference: 15-39A: 64.2 Wcll: 15-39 Section (VS) Reference: Well (O.OON,O.OOE,140.08Azi) Wcllpath: 15-39A Survcy Calculation Method: Minimum Curvature Ut,: Oracle Sure e~ __ _ - _ -- 11D Incl Atim TVD SysTVD tA`/S N;/W MapN ~ NIapE Ibol~ ft deg deg ft ft ft ft ft ft - - _ __ 7550.13 9.83 130.03 7514.64 7450.44 -69.84 298.36 5959972.73 677007.74 MWD+IFR+MS 7654.71 10.90 131.54 7617.52 7553.32 -82.14 312.59 5959960.77 677022.26 MWD+IFR+MS 7749.39 12.61 133.44 7710.21 7646.01 -95.18 326.80 5959948.06 677036.77 MWD+IFR+MS 7844.55 14.10 131.53 7802.79 7738.59 -110.01 343.02 5959933.62 677053.33 MWD+IFR+MS 7938.18 17.04 127.05 7892.98 7828.78 -125.84 362.51 5959918.25 677073.19 MWD+IFR+MS 8034.23 19.39 129.38 7984.21 7920.01 -144.44 386.07 5959900.22 677097.18 MWD+IFR+MS 8126.93 22.69 133.36 8070.72 8006.52 -166.49 410.97 5959878.76 677122.59 MWD+IFR+MS 8222.45 23.74 132.52 8158.51 8094.31 -192.13 438.54 5959853.78 677150.75 MWD+IFR+MS 8251.51 23.29 132.34 8185.15 8120.95 -199.95 447.10 5959846.16 677159.49 MWD+IFR+MS 8340.17 22.71 132.59 8266.77 8202.57 -223.34 472.65 5959823.38 677185.58 MWD+IFR+MS 8374.57 22.41 131.33 8298.53 8234.33 -232.17 482.47 5959814.79 677195.60 MWD+IFR+MS 8466.39 21.61 120.87 8383.69 8319.49 -252.41 510.13 5959795.20 677223.73 MWD+IFR+MS 8561.86 26.03 123.15 8471.01 8406.81 -272.89 542.78 5959775.49 677256.85 MWD+IFR+MS 8595.36 25.63 122.31 8501.16 8436.96 -280.79 555.06 5959767.89 677269.31 MWD+IFR+MS 8625.57 26.98 124.03 8528.25 8464.05 -288.11 566.26 5959760.83 677280.68 MWD+IFR+MS 8652.50 27.86 124.67 8552.15 8487.95 -295.11 576.50 5959754.07 677291.08 MWD+IFR+MS 8687.10 29.25 125.93 8582.54 8518.34 -304.67 589.99 5959744.83 677304.79 MWD+IFR+MS 8718.33 32.11 127.03 8609.40 8545.20 -314.15 602.80 5959735.66 677317.82 MWD+IFR+MS 8749.60 34.42 126.71 8635.54 8571.34 -324.44 616.52 5959725.70 677331.78 MWD+IFR+MS 8780.75 35.62 126.53 8661.05 8596.85 -335.10 630.87 5959715.38 677346.37 MWD+IFR+MS 8813.32 38.89 128.84 8686.97 8622.77 -347.16 646.46 5959703.68 677362.24 MWD+IFR+MS 8843.91 42.06 130.36 8710.24 8646.04 -359.82 661.75 5959691.39 677377.82 MWD+IFR+MS 8875.30 46.30 130.80 8732.75 8668.55 -374.05 678.36 5959677.55 677394.76 MWD+IFR+MS 8906.33 49.81 130.98 8753.49 8689.29 -389.16 695.80 5959662.86 677412.55 MWD+IFR+MS 8937.92 54.23 131.34 8772.92 8708.72 -405.55 714.54 5959646.92 677431.67 MWD+IFR+MS 8969.37 58.90 131.47 8790.24 8726.04 -422.90 734.22 5959630.04 677451.75 MWD+IFR+MS 8999.55 62.70 131.63 8804.97 8740.77 -440.37 753.93 5959613.03 677471.87 MWD+IFR+MS 9029.94 67.19 132.36 8817.83 8753.63 -458.79 774.39 5959595.10 677492.75 MWD+IFR+MS 9061.28 69.50 132.90 8829.40 8765.20 -478.51 795.81 5959575.89 677514.63 MWD+IFR+MS 9092.80 73.94 132.99 8839.28 8775.08 -498.90 817.72 5959556.02 677537.01 MWD+IFR+MS 9123.96 77.61 133.40 8846.94 8782.74 -519.57 839.73 5959535.88 677559.50 MWD+IFR+MS 9156.89 81.51 133.78 8852.90 8788.70 -541.90 863.18 5959514.11 677583.47 MWD+IFR+MS 9179.04 82.31 132.92 8856.02 8791.82 -556.95 879.13 5959499.44 677599.77 MWD+IFR+MS 9219.75 84.36 132.42 8860.74 8796.54 -584.35 908.86 5959472.74 677630.13 MWD+IFR+MS 9249.36 86.53 132.16 8863.10 8798.90 -604.21 930.69 5959453.40 677652.42 MWD+IFR+MS 9278.80 88.45 132.05 8864.38 8800.18 -623.93 952.51 5959434.20 677674.70 MWD+IFR+MS 9338.32 87.90 131.98 8866.28 8802.08 -663.75 996.71 5959395.44 677719.82 MWD+IFR+MS 9381.15 87.66 131.83 8867.94 8803.74 -692.34 1028.56 5959367.61 677752.33 MWD+IFR+MS 9433.28 88.16 132.80 8869.84 8805.64 -727.41 1067.09 5959333.46 677791.66 MWD+IFR+MS 9484.11 89.08 134.07 8871.06 8806.86 -762.34 1103.98 5959299.40 677829.37 MWD+IFR+MS 9526.95 89.95 134.68 8871.43 8807.23 -792.30 1134.60 5959270.17 677860.69 MWD+IFR+MS 9574.42 90.01 134.80 8871.44 8807.24 -825.71 1168.32 5959237.56 677895.18 MWD+IFR+MS 9621.02 90.23 135.62 8871.35 8807.15 -858.79 1201.15 5959205.28 677928.77 MWD+IFR+MS 9670.50 89.07 138.57 8871.65 8807.45 -895.02 1234.83 5959169.84 677963.29 MWD+IFR+MS 9715.56 89.03 139.31 8872.40 8808.20 -929.00 1264.43 5959136.58 677993.68 MWD+IFR+MS 9767.80 88.67 139.34 8873.44 8809.24 -968.61 1298.47 5959097.78 678028.64 MWD+IFR+MS 9810.18 86.84 140.76 8875.10 8810.90 -1001.07 1325.66 5959065.97 678056.58 MWD+IFR+MS 9862.57 86.86 140.55 8877.98 8813.78 -1041.52 1358.82 5959026.31 678090.69 MWD+IFR+MS 9905.60 88.70 142.92 8879.65 8815.45 -1075.28 1385.45 5958993.19 678118.10 MWD+IFR+MS 9945.66 89.45 142.19 8880.30 8816.10 -1107.08 1409.80 5958961.97 678143.19 MWD+IFR+MS 10000.21 88.64 142.24 8881.21 8817.01 -1150.18 1443.22 5958919.67 678177.61 MWD+IFR+MS 10046.11 87.35 139.72 8882.81 8818.61 -1185.82 1472.10 5958884.72 678207.31 MWD+IFR+MS 10094.86 87.22 141.53 8885.12 8820.92 -1223.46 1502.99 5958847.82 678239.08 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Date: 9/22/2006 Time: 16:41:05 Page: 4 Field: Prudhoe Bay Cu-ordinate(\E) Reference: Well: 15-39, True North ', Site: PB DS 15 Vertical (TVD) Reference: 15-39A: 64.2 I Wcll: 15-39 Section (VS) Reference: Well (O.OON,0.OOE,140.OSAzi) Wcllpath: 15-39A Sun~ey Calculation IVlethod: __ -- Minimum Curvature Db: Oracle Sur~ eo MD Incl nzim TVD Sys "fVD Y/S EIW A1apN D1apE 'fool ft deg deg ft ft ft ft ft ft 10141.98 90.39 142.10 8886.10 8821.90 -1260.49 1532.11 5958811.49 678269.06 MWD+IFR+MS 10189.92 90.43 143.75 8885.76 8821.56 -1298.73 1561.01 5958773.94 678298.85 MWD+IFR+MS 10236.07 89.86 146.79 8885.64 8821.44 -1336.66 1587.29 5958736.65 678326.02 MWD+IFR+MS 10283.06 89.64 147.51 8885.85 8821.65 -1376.13 1612.78 5958697.79 678352.43 MWD+IFR+MS 10326.70 91.87 150.51 8885.27 8821.07 -1413.53 1635.25 5958660.93 678375.76 MWD+IFR+MS 10376.73 90.74 153.49 8884.13 8819.93 -1457.69 1658.73 5958617.34 678400.27 MWD+IFR+MS 10421.64 90.98 154.20 8883.46 8819.26 -1497.99 1678.52 5958577.51 678421.01 MWD+IFR+MS 10470.85 90.50 154.03 8882.82 8818.62 -1542.26 1700.00 5958533.76 678443.52 MWD+IFR+MS 10521.11 95.33 155.47 8880.27 8816.07 -1587.65 1721.41 5958488.89 678465.99 MWD+IFR+MS 10564.39 95.11 155.05 8876.33 8812.13 -1626.79 1739.44 5958450.19 678484.94 MWD+IFR+MS 10609.07 94.57 155.63 8872.56 8808.36 -1667.25 1758.02 5958410.18 678504.46 MWD+IFR+MS 10658.28 94.19 155.94 8868.80 8804.60 -1712.00 1778.14 5958365.92 678525.63 MWD+IFR+MS 10702.86 90.50 156.19 8866.98 8802.78 -1752.71 1796.21 5958325.65 678544.65 MWD+IFR+MS 10752.23 90.12 155.50 8866.71 8802.51 -1797.75 1816.41 5958281.10 678565.90 MWD+IFR+MS 10796.29 89.58 154.76 8866.83 8802.63 -1837.73 1834.94 5958241.57 678585.36 MWD+IFR+MS 10847.05 89.10 155.01 8867.41 8803.21 -1883.68 1856.49 5958196.14 678607.98 MWD+IFR+MS 10890.98 89.28 155.61 8868.03 8803.83 -1923.59 1874.84 5958156.67 678627.26 MWD+IFR+MS 10939.80 89.06 156.38 8868.74 8804.54 -1968.19 1894.69 5958112.56 678648.16 MWD+IFR+MS 10984.94 89.20 156.17 8869.43 8805.23 -2009.51 1912.85 5958071.68 678667.29 MWD+IFR+MS 11035.22 89.44 156.88 8870.02 8805.82 -2055.62 1932.88 5958026.05 678688.39 MWD+IFR+MS 11079.87 91.15 156.42 8869.79 8805.59 -2096.61 1950.58 5957985.49 678707.04 MWD+IFR+MS 11130.88 90.87 155.61 8868.89 8804.69 -2143.21 1971.31 5957939.40 678728.86 MWD+IFR+MS 11177.04 90.55 155.03 8868.32 8804.12 -2185.15 1990.58 5957897.92 678749.12 MWD+IFR+MS 11224.18 93.58 155.05 8866.62 8802.42 -2227.85 2010.46 5957855.70 678769.99 MWD+IFR+MS 11271.04 93.21 154.76 8863.85 8799.65 -2270.22 2030.30 5957813.82 678790.82 MWD+IFR+MS 11319.65 93.03 155.11 8861.20 8797.00 -2314.18 2050.86 5957770.35 678812.41 MWD+IFR+MS 11365.22 92.61 156.17 8858.96 8794.76 -2355.65 2069.63 5957729.35 678832.15 MWD+IFR+MS 11412.28 92.47 155.74 8856.88 8792.68 -2398.58 2088.79 5957686.88 678852.31 MWD+IFR+MS 11455.77 90.49 155.81 8855.75 8791.55 -2438.23 2106.63 5957647.66 678871.07 MWD+IFR+MS 11505.25 90.11 155.58 8855.49 8791.29 -2483.32 2126.99 5957603.06 678892.49 MWD+IFR+MS 11557.73 89.88 154.54 8855.50 8791.30 -2530.90 2149.12 5957556.02 678915.73 MWD+IFR+MS 11598.52 89.88 155.16 8855.58 8791.38 -2567.83 2166.46 5957519.51 678933.93 MWD+IFR+MS 11650.42 89.88 155.16 8855.69 8791.49 -2614.93 2188.26 5957472.94 678956.83 PROJECTED TREE = CNV W H~kP, D = FMC ACTUATOR = fB. ELEV - BAKER C 64.20' BF. ELEV - 32.33' KOP = 4300' MD Max Angle= 95.33 Datum MD ~DatumTVD= 8800'SS • 15-39A FROM DRAG -DRAFT SA~ NOTES: *'~~ CH1?C'~ME TBG ""~` 2196' 4 1/2" X Nipple, ID = 3.813 13-3/8" CSG, 68#, NT-80, 3524' CY HE, ID = 12.415" ~t1[ t~rr~ 1 x.725" 8145° 4-1/2" TBG, 12.6#, 13-CR, ID = 3.958" 8942' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3394 3394 0 KBG DMY BK 0 1011/06 2 6144 6112 2 KBG DMY 5BK 0 9120;06 3 8012 7963 19 KBG DMY SBK 0 9120106 $079' 4 1/2" X Nipple (3.813" ID) CEMENT DUMP IN IA 4695' - 5580' TOP OF 7" LNR I 9-5/8" CSG, 47#, NT-80S, ID = 8.681" I 8173' 8326' TOC-abandonment 9000' PERFORATION SUMMARY REF LOG: UNAVAILABLE ANGLE AT TOP F~RF: 23 ~ 8190' Note: Re~ter to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-1f2" 4 8190-8200 O 09>'08106 2-112" 4 9300 - 9750 O 09/18/06 2-1r'2" 4 9950-10250 O 09118(06 4-112" 5 10005 - 10195 S 08/15/06 4-1/2" 5 10260 - 10735 S 08/15/06 2-112" 4 10550 - 11230 O 09118/06 2-~ 112'" 5 11331 - 11480 O 09/19/06 2-1,'2" 6 11554 - 11559 S 09(12f06 7"LNR, 29#, NT-95 HS, 10823' 4124` -Top of 7" Liner 4121' 95/8" x 7" Hanger /liner top packer 4290' ~ 9 5/8" Window GAS LIFT MANDRELS $100' 7" x 5" Baker S3 Packer 8124' 4 1/2" X Nipple (3.813" ID) 8145' 4 112" XN Nipple (3.725" ID) 8151' 4 1/2" Hanger i liner top packer 8157' 4 1/2" WLEG 8320' - 7" 26# L-80 (6.276" ID) 4 1/2" 12.6#, L-80 IBT-M, 3.$13" ID 11650' 10614' DATE REV BY COMMENTS DATE REV BY COMMENTS 09!29!94 ORIGINAL COMPLETION 05/31/06 PGS Proposed 2006 Sidetrack 09/21/06 CPC Actual Sidetrack 09(23106 PAG DRLG DRAFT CORRECTIONS 10/01/06 JCM/PAG GLV C/O PRUDHOE BAY UNfr WELL: 15-39A PERMrr No: 1941150 API No: 50-029-22503-01 SEC 22, T11 N, R14E, 4393.72' FEL & 4322.03' FNL BP F~cploration (Alaska} err ~. n 7ooc Sc~~m~er er N0.3982 Alaska Data 8: Consulting Services ab l~ - Q ~Ip Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATrN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lea DP.ACrlntlnn n~to wi r•..i,.. rn 10/06/06 3-29/J-32 11414759 SBHP SURVEY 09/04!06 1 L4-10 11285941 MEM PROD PROFILE 09115/08 1 L2-21A 11421023 LDL 09/11/08 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 NIA INJECTION PROFILE 09103/08 1 Z-31 11414379 INJECTION PROFILE 09104106 1 S-276 11285940 MEM PROD PROFILE 09/14!06 1 P-13 11414277 INJECTION PROFILE 09/03106 1 X-33 11421024 LDL 09/12/06 1 Z-19A NIA MDT 09/08106 1 A-17 11414381 USIT 09/07/06 1 X-01 11422981 USIT 09109/06 1 H-04A 11285942 SCMT 09117/06 1 15-39A 11212888 SCMT 09/18/08 1 C-09A 11209808 MCNL 06118!08 1 1 C-18A 11285934 MCNL 07/29108 1 1 Z-146 40013765 OH EDIT OF MWDILWD 07131108 1 1 Alaska Data & Consulting Services Petrotechnical Data Center 1R2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth :] • ~°~~ 1 I q~ I~ ~ ~ ~ ~ ~ ~ FRANK H. MURKOWSK/, GOVERNOR ~t~~ ~ ~~+ OIL ~ ~ ~'~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQATIOI~T COriAII5SIOI~T ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-39A BP Exploration (Alaska) Inc. Permit No: 206-086 Surface Location: 1464' FNL, 769' FWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 3985' FNL, 2858' FWL, SEC. 22, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~, `94 ~l STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMN~ON PERMIT TO DRILL 20 AAC 25.005 v~~,H- 41~R /~o~ ~EDEIVED JlIN 15 2006 Ah~L.. n:1 o n 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ~ ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1c. Speci i I ~SSIOf1 ^ Coalbed Methrh~~ Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 15-39A c(ri,(o~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11511 TVD 8879 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: R14E UM 1464' FNL 769' FWL 22 T11N SEC 7. Property Designation: ADL 028306 Pool , , , , , . Top of Productive Horizon: 2072' FNL, 1726' FWL, SEC. 22, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: / July 26, 2006 Total Depth: 3985' FNL, 2858' FWL, SEC. 22, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 30,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-676708 y-5960036 Zone-ASP4 10. KB Elevation Plan (Height above GL): 63.8' feet 15. Distance to Nearest Well within Pool: 312' 16. Deviated Wells: Kickoff Depth: 4304 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 .035) Downhole: 4100 Surface: 3300 18. Casin Pr ram: Speciftcations To - Settin De th -Bottom Quantity o . nt, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1 /2" 7" 26# L-80 BTC-M 4196' 4150' 4150' 8346' 8264' 192 sx LiteCrete, 173 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3311' 8200' 8130' 11511' 8879' 00 sx Class 'G' 19. PRESENT WELL GONDITtON SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10823 Total Depth TVD (ft): 8810 Plugs (measured): 8835 Effective Depth MD (ft): 10780 Effective Depth TVD (ft) 8812 Junk (measured): 10614 Casing; Length Size Cement Volume Mp TVD Conductor J Structural 110' 20" 260 sx Arcticset A rox. 110' 110' Surface 3489' 13-3/8" 1168 sx PF 'E', 375 sx Class 'G' 3524' 3524' Intermediate 8294' 9-5/8" 701 sx Class 'G' 8326' 8297' Production Liner 2643' 7" 440 sx Class 'G' 8180' - 10823' 8162' - 8810' Perforation Depth MD (ft): 10005' -10735' Perforation Depth TVD (ft): 8837' - 8813' 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 Phil Smith, 564-4897 Printed Name D e Wesley Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5153 Date ~~~ ~~'~~O Terrie Hubble, 564-4628 Commission Use-Only Permit To Drill Number: API Number: Permit Appro I 50-029-22503-01-00 Date: See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales Samples Req'd: ^ Yes ` ~,No Mud Log Req'd: ^ Yes •~~~No g~~ $5~ 1?~ ~7~ ~ 7~5~~ ~~• HzS Measures: `Yes ^ No irec onal Survey ReG'd:~Yes ^ No i~cYsur~~ ~n ZO ~~ C ZS. 0 3s Ct~ ~C, ~, a,tfer-~.a.{'e t3o~ / ^ S a S r~ f~r~ ~~cl. APP -~ej 'f~X THE COMMISSI Date ~p/~v ,COMMISSIONER Form 10-401 Revised 12/2005 4 ~' ~ ~ ~ + ~ ~ `'~ `~~~ i S~hmlt {n ^upltcate • • Well Name: 15-39A Planned Well Summary Horizontal Well 15-39A Well Sidetrack Target Zone 1 A Type Producer Objective API Number: 50-029-22503-01 Current Status 15-39 Shut-In and P&A Procedures commencing Estimated Start Date: 26-July-2006 Time to Com lete: 21.6 Da s Surface Northin Eastin Offsets TRS Location 5,960,036 676,708 1463' FNL / 770' FWL 11 N, 14E, 22 Northin Eastin TVDss Offsets TRS Target 5,959,450 677,680 -8,820 2072' FNL / 1726' FWL 11 N, 14E, 22 Locations 5,958,810 678,250 -8,820 2725' FNL / 2280' FWL 11 N, 14E, 22 Bottom Northin Eastin TVDss Offsets TRS Location 5,957,565 678,860 -8,815 3985' FNL / 2858' FWL 11 N, 14E, 22 i Planned KOP: 4304'MD / 4240'TVDss Planned TD: 11,511'MD / 8,815' TVDss Ri Nabors 7 I CBE: 31.3' RTE: 63.8' Directional -Sperry P06 KOP: 4304' MD Maximum Hole Angle: ~24° in the 8-1/2" intermediate section (tangent sail angle) ~90° in the 6-1 /8" horizontal section Close Approach Wells: All wells pass major risk close approach criteria. The closest well is K-38 at 61' ctr-ctr (23' allowable deviation) at 4683' planned MD. Surve Pro ram: MW D Standard + IFR /Cassandra / MS Nearest Pro ert Line: 30500' to the PBU property line Nearest Well within Pool: 15-32A is 312' away from planned well 15-39A at 9787' planned MD. 15-39A Permit to Drill Application Page • Formation Markers 15-39A (Based on 5ORl Formation Estimated Formation Tops (TVDss) (TVDbkb) (MDbkb) Estimated Pore Press. ( EMW / Psi) SV1 -4050 10 UG4 -4545 4609 4611 UG3 -4806 4870 4875 UG1 -5290 5354 5365 WS2 -5830 5894 5906 WS1 -6035 6099 6111 CM3 -6270 6334 6346 CM2 -6680 6744 6756 CM1 -7415 7479 7495 THRZ -7740 7804 7843 BHRZ -7930 7994 8051 Put River -7970 8034 8095 9.8 / 4100 LCU -7990 8054 8117 TSGR -8200 8264 8346 TSHU A -8240 8304 8390 TSHU B -8260 8324 8412 TSHU C -8275 8339 8428 TSAD -8300 8364 8455 45SB -8315 8379 8472 44S6 -8340 8404 8499 42SB -8385 8449 8548 TCGL -8445 8509 8614 BCGL -8520 8584 8696 23SB -8575 8639 8757 22TS -8640 8704 8836 21TS -8675 8739 8883 TZ1 B -8735 8799 8976 TZ1AlTDF -8780 8844 9069 7.2 / 3300 BSAD/Kavik -8820 8884 9267 Casing/Tubing Program Id~ 2 ~~~ Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg / j (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-1/z" 7" 26# L-80 BTC-M 7,240 5,410 4,196' 4150' / 8346' / 4150' 8264' 6-1/8" 4 ~/z" 12.6# L-80 IBT-M 10,160 10,530 3,311' 8200' / 11,511' / 8130' 8,879' Tubing 41/z" 12.6# 13Cr- Vam 10,160 10,530 8,170' 33' / 33' 8203' / 80 To 8,133' 15-39A Permit to Drill Application Page ~ • Mud Program Whipstock Milling Mud Properties: LSND Whin Stock Window 9-5/8". 47# Densit PV YP API FL HTHP FL MBT PH 9.4 8-16 30-35 <10 N/C <15 9.5-10 Intermediate Mud Properties: LSND 8-1/2" hole section De th Interval Densit PV YP API FL HTHP FL MBT PH 4,300'-7,800' 9.4 - 10-18 22-26 <5 N/C <18 9.5-10 7,800'-8,346' HRZ & Put R 0. 12-22 18-24 3.0-4.0 <8.0 <20 9.5-10 Production Mud Properties: FLOPRO SF Reservoir Drill-in Fluid 6-1 /8" hole section De th Interval Densit PV YP LSVR API FI H Con or404 8,346-11,511 8.4 - 8.5 6-12 24-30 >25,000 <8.0 9.5 >5000 m Logging Program 8-1/2" Intermediate: Sample Catchers -None Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neu/ABI (Neu/Den MAD pass after trip for bit then realtime mode for drillin . Open Hole: None Cased Hole: None Cement Proaram Casin Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: 3046' pe hole w/ 40% excess, 150' Lead TOC: ,950' D 200' above Liner To Tail: 1,000' en hole with 40% excess, plus Tail TOC: 7,346' MD Total Cement Volume: Spacer 40 bbls of Viscosified Lead 112 bbls, 627 cuft, 9 Tail 35.8 bbls, 201 cuft, Temp BHST = 180° F. BH Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 3,165' of open hole with 40% excess, 80 7" x 4" DP excess. Tail TOC: 8,150' MD (200' above Liner Top) Total Cement Volume: Spacer 40 bbls of Viscosifie Lead None Tail 83.3 bbls, 468 cuft, Temp BHST ~ 190° F. BH and 200' of 9-5/8" X 4" DP excess. 0' shoe track acer weighted to 10.5 pp , ud I ks 11.0 LiteCrete, .2 ft3/s~ sks 15.8 Ib/gal Class G + adds - 126° F estimated by Schlumberge 150' 4-'/2" x 6-1/8" liner lap, and 200' pacer weighted to 10.0 ppg (Mud Push II )'0 sks 15.8 Ib/gal Class G + adds - .1J 147° F estimated by Schlumberper 15-39A Permit to Drill Application Page 3 Surface and Anti-Collision Issues • Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 15-38 and 15-40 are nearest at 30' away. Close Approach Shut-in Wells: All wells pass major risk close approach criteria. The closest well is K-38 at 61' ctr-ctr (23' allowable deviation) at 4683' planned MD. Hydrogen Sulfide DS15 is not designated as an H2S site. Recent H2S data from the pad is as follows: .~.-.- Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 15-38A No sam les - 15-40A 8 2/1 /2001 15-32A No sam les - 15-12A 6 3/1/2001 15-21 A 50 2/24/2001 DS 15 is not an H2S drill site. H2S readings are typically 10 ppm or less. Faults We expect to cross two small faults with the proposed 15-39A wellbore. It is anticipated that the first fault will be crossed at 10010 ft. MD and the second fault at 10600 ft. MD. Fault #1 is a NE-SW trending fault with throw of 10-25 ft. down to the SE. It has been crossed previously by the 15-32A well with no losses. Fault #2 is also a NE-SW trending fault with throw of 10-20 ft. down to the NW. Although Fault #2 appears to be small in lateral extent, it is likely a segment of the same fault system as Fault #4 to the east. Neither Fault #2 nor #4 have been crossed by any previous wells. The 15-39 parent well did not experience any lost circulation 15-39A Permit to Drill Application Page 4 • ~ Well Control ~ Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blindlshear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 15-39A will be 14 days. Below is an excerpt from the permit to drill application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRII.LING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 4100psi ~ 8044' TVDbkb 9.8 pp EMW) Maximum surface ressure 33 si (.10 psi/ft as radient to surface) Kick tolerance 2.3 bls with a 12.0 pp FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 psi surface ressure Inte rit Test - 8-1/2" hole 12.0 pp FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3300 psi C«~ -8780' TVDss (7.3 pp EMW) Maximum surface ressure 250 si (.10 psi/ft as radient to surface) Kick tolerance init with a 10.0 p FIT Planned BOP test pressure am's test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 psi surface ressure Inte rit Test - 6-1/8" hole 10.0 pp FIT after drillin 20' of new hole Planned com letion fluids 8.5 pp Seawater / 7.2 p Diesel Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 15-39A Permit to Drill Application Page 5 Drilling Hazards and Contingencies POST THI5 NOTICE IN THE DOGHOUSE I. Wetl Control A. The Ivishak in this fault block is expected to be under-pressured at 7.30 ppg EMW. This pressure is estimated based on offset well pressures. I1. Lost Circulation/Breathing A. Lost circulation is unlikely. If it occurs, follow the LCM decision tree. B. DS15 has somewhat of a history of lost circulation events while drilling in the reservoir section and normally occur when crossing faults. There are two expected fault crossings identified for this directional trajectory. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 52.3 bbls with 10.2 ppg mud, 12.0 ppg FIT, and an 9.8 ppg pore pressure in the Put River sand. This FIT should prove up adequate formation strength for expected ECD's. Kick tolerance drops to 25 bbls with an 11.0 ppg FIT. Notify the ODE and Drilling Manger if a 12.0 ppg FIT is not achieved at the window. B. The Kick Tolerance for the production hole section is infinite with 8.5 ppg mud, 10.0 ppg FIT, and an 8.8 ~ ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. C. Integrity Testing Test Point Test Depth Test EMW (Ib/gal) t e 9-$/8" 20-ft minimum from the 9-5/g" FIT 12.0 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues within the reservoir. Centralizers will be run to mitigate. VI. Hydrogen Sulfide A. DS15 is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are in the 10 PPM range based on the last samples taken in 2005. VII. Faults A. We expect to cross two small faults with the proposed 15-39A wellbore. It is anticipated that the first fault will be crossed at 10010 ft. MD and the second fault at 10600 ft. MD. Fault #1 is a NE-SW trending fault with throw of 10-25 ft. down to the SE. It has been crossed previously by the 15-32A well with no losses. Fault #2 is also a NE-SW trending fault with throw of 10-20 ft. down to the NW. Although Fault #2 appears to be small in lateral extent, it is likely a segment of the same fault system as Fault #4 to the east. Neither Fault #2 nor #4 have been crossed by any previous wells. The 15-39 parent well did not experience any lost circulation. VIII. Anti-Collision Issues All wells pass major risk close approach criteria. The closest well is K-38 at 61' ctr-ctr (23' allowable deviation) at 4683' planned MD. CONSULT THE DS 15 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 15-39A Permit to Drill Application Page 6 • • Operations Summary Pre-Riq Operations: 1. Rig up slick-line. Drift 4 1/2" tubing to bridge plug at 8835'. 2. Fluid pack tubing and inner annulus. 3. R/U coiled tubing. Drill out bridge plug at 8835'. RIH, drift/drill to top of fish at 10,614'. Circulate well to seawater. POH, LD motor and bit. 4. RIH and plug and abandon the perforations with 15.8ppg `G' slurry, from cleanout depth to -9,000'md. The estimated cement volume required is 60 bbls. This is based upon 1614' of 7" 29# liner. POOH. 5. R/U slick-line, drift the 4 ~/z" tubing to tag TOC. POOH. 6. RU SWS E-line. RIH and jet cut the 4'h", 12.6# tubing in the middle of a joint at ~4,500'md. 7. Circulate the well to seawater through the tubing cut, until returns are clean. Attempt a CMIT T X IA to 3,500psi for 30 minutes. 8. Bleed casing and annulus pressures to zero. Freeze protect the well to ~2,200'md with diesel. 9. Function all tubing and lock down screws. Test both the 9 5/8" casing and the tubing pack-off. 10. Set a BPV. Remove the well house and the flow line. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MI/RU Nabors 27E. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test ROPE. Pull TWC. 4. Pull the 4 1/2" tubing from the pre-rig tubing cut at ~4500'md. 5. M/U an 8'/z" mill assembly. RIH, picking up 4" drill pipe, drift the 9 5/8" casing to the tubing stump at 4500'md. POOH. 6. R/U E-line and GR/CCL. M/U a HES 9 5/8" CIBP. RIH and set the CIBP at ~4320'md, such that a collar will not be cut while milling the window. POOH. 7. Test the 9 5/8" casing to 3,500psi against bridge plug. a Baker 9 5/8" whip stock assembly. RIH, orient whip stock with gyro and set on CIBP. 9. Shear free from the whip stock. Displace the well to the 9.4ppg LSND milling and drilling fluid. 10. Mill window in 9 5/8" casing at ~4300'md, plus drill/mill ~20' beyond the middle of the window. 11. Circulate the well clean. Pull up into the 9 5/8" casing and attempt an F1T to 12.Oppg EMW. POOH. ~j 12. M/U an 8-1/2" drilling assembly with Dir/GR/Res/PWD and wet connect. Drill 8-1/2" intermediate hole. 0 13. Prior to cutting the HRZ, weight up to 10.2ppg LSND mud (9.6 needed for HRZ, but 10.2 needed for Put River and Kingak Drilling) 14. Drill ahead to casing point at the top of the Sag River, estimated at a depth of 8346'md. 15. Circulate and condition hole as needed. POOH. UD assembly. 16. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150'~- of overlap. Displace the cement with the 10.Oppg LSND mud. POOH. I 17. M/U a 6-1/8" drilling assembly with Dir/GR/RES and an Insert bit. RIH to the landing collar. 18. Pressure test the well bore to 3,500psi for 30 minutes. Record the test. ~ 19. Drill out cement and float equipment to the shoe. Displace the well to 8.5ppg Flo-Pro fluid. J, 20. Drill out the shoe, plus 20' of new formation. Conduct an FIT to 10.Oppg EMW.~ 21. Drill ahead, per directional proposal, to the end of the build section, at ~9300'md. POOH for horizontal assembly once directional requirement has been met. ~-- 22. PU Neu/Den. RIH, MAD pass build section. Drill ahead to an estimated TD of 11,511'md. 23. Circulate and condition hole as needed. POOH. UD assembly. / 24. Run and cement a 4-1/2", 12.6#, L-80 liner. Displace the cement with perf pill and mud. 25. Release from liner, displace well to clean seawater above the liner top. POOI,I, UD LRT. 26. Pressure test well bore to 3,500psi for 30 minutes. Record the test. ~ 27. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Expected interval is 1000- 1200ft of horizontal section near well TD. 28. POOH. UD all drill pipe and pert guns. 29. Run 4-1/2", 12.6#, 13Cr-80, Vam Top completion tying into the 4-1/2" liner top. /i 30. Space and land the completion. RILDS. 31. Reverse circulate the annulus to seawater with Corrosion Inhibitor. 32. Drop the ball /rod. Set the packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 15-39A Permit to Drill Application Page 7 • • 33. Install a TWC. 34. Nipple down the BOPE. Nipple up the adapter and tree and test to 5,000psi. Pull the TWC. 35. Reverse in sufficient volume of diesel to freeze protect both the tubing and the IA to 2,200'. Allow the diesel to U-tube to equilibrium. 36. Install a BPV. Secure the well. 37. Rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. 15-39A Permit to Drill Application Page 8 TREE = CNV WELLHEAD=' ACTUATOR = FMC BAKER C KB. ELEV = 66' BF. ELEV.- KOP = ~ 7908' Max Angle = 97 @ 9514' Datum MD = Datum TV D = 9361' 8800' SS 13-3/8" CSG, 68#, NT-80, CYHE, ID = 12.415" 3524' CEMENT DUMP IN IA 4695' - 5580' TBG PUNCH (1SPF) 5640' - 5670' (01/20/00) 5760' - 5780' TOP OF 7" LNR 8173' 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 8326' TBG PUNCH (4 SPF) (10/26/99) ~ $$10' - 8820' S/~' NOTES: TROUBLE WELL - T x IA COM M (NEEDS DSSSV, PRIOR K VLV W ELL). 3 LEAKS IN TBG -SSSV @ 3335', KINLEY SURVEY INDICATED TBG IN POOR CONDITION. IBP AND SAND PLUG IN WELL LDL INDICATES LEAK @ 2197'. 2197' 4-1/2" HES SERIES 10 SSSV. LOCKED OUT 04/15/95, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3284 3284 1 TGPD RK *2 5447 5447 0 TGPD RK 3 7085 7085 0 TGPD RK 4 8143 8128 22 TGPD RK *GLM #2 IS COVERED BY CEMENT 8835' I~ 4-1/2" HALIB FZSV BRIDGE PLUG SET 10/26/99 II Minimum ID = 3.812" @ 2197' 4-1/2" HES SERIES 10 SSSV 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 8942' PERFORATION SUMMARY REF LOG: UNAVAILABLE ANGLE AT TOP PERF: 94 @ 10005' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1 /2" 5 10005 - 10195 C 10/01 /94 4-1/2" 5 10260 - 10735 C 10/01/94 $1 858' I~ 4-1/2" OTIS X NIP, ID = 3.812" I 8878' 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.89" 8913' 4-1 /2" OTIS X NIP, ID = 3.812" 8930' 4-1/2" OTIS XN NIP, ID = 3.725" 8942' 4-1/2" TUBING TAIL 8936' ~ ELMD TT LOGGED 03/21/96 NOTE: WELL PREPARED FOR SIDETRACK 10614' ~ FISH -IBP FAILED-PUSHED TO 10697' CTM 10/18/99 PBTD I~ 10780' 7" LNR, 29#, NT-95 HS, .0371 bpf, ID = 6.184" I~ 10823' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/29/94 ORIGINAL COMPLETION 06/27/01 RN/TP CORRECTIONS 02/27/03 CNJ/KK CORRECTIONS 12/05/05 COM/PAG WELLHEAD CORRECTION PRUDHOE BAY UNf>- WELL: 15-39 PERMff No: "1941150 API No: 50-029-22503-00 SEC 22, T11 N, R14E, 4393.72' FEL & 4322.03' FNL BP Exploration (Alaska) 15-39 ; Edo CM/ WELLHEAD = ' FMC ACTUATOR = BAKER C KB. ELEV..- 66' BF. ELEV.- KOP = _ ~ 4300' MD Max Angle = Datum MD = Datum TV D = 8800' SS -3 A SA~NOTES: 5 9 13-3/8" CSG, 68#, NT-80, 3524' CY HE, ID = 12.415" Minimum ID = 3.812" @ 2200' 4-1 /2" HES SERIES 10 SSSV 4-1/2" TBG, 12.6#, 13-Cr, ID = 3.958" 8942' CEMENT DUMP IN IA 4695' - 5580' TOP OF 7" LNR ~ 9-5l8" CSG, 47#, NT-80S, ID = 8.681" ~ 8173' 8326' 8346' 7" 26# L-80 (6.276" ID) / 4 1/2" 12.6#, L-80 BTRS, 3.813" I 11511' TOC -abandonment 9000' PERFORATION SUMMARY REF LOG: UNAVAILABLE ANGLE AT TOP PERF: 94 @ 10005' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" 5 10005 - 10195 C 10/01/94 4-1/2" 5 10260- 10735 C 10/01/94 T' LN329~#, Nf-96~ 10623 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/29/94 ORIGINAL COMPLETION 05/31/06 PGS Proposed 2006 Sidetrack PRUDHOE BAY UNfr WELL: 15-39A PERMIT No: 1941150 API No: 50-029-22503-01 SEC 22, T11 N, R14E, 4393.72' FEL & 4322.03' FNL BP Exploration (Alaska) 2200' 4 1/2" X Nipple, ID = 3.813 4150` -Top of Liner 4304' 9 5/8" Window GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8135' 4 1/2" X Nipple (3.813" ID) 8150' 7" x 4 1/2" Baker S3 Packer 8170' 4 1/2" X Nipple (3.813" ID) 8190' 4 1/2" XN Nipple (3.725" ID) 8200' 4 1/2" Hanger /liner top packer 8203' 4 1!2" WLEG 11(1 tlY Amucu ('alrnWnv MyhuJ: Mmtmum l'urv-aun ~M~ ImvSy~tm: I%('W5A Scm McWxl: Tmr lyNnkx Wn6 Fn.H 5mime: 174p1nil ~ l'mmr w~ Mawl: Mules l4vv1 4000 a 0 0 6 D E 2 H Itl]'Iat6N('E WF(1NANl1(IN Cn-vN6at IWF.l Wvluc'n'c•: Wea l'evlm: IS-?Y, ine WxW Vullulll'VUI Neliuavce 1.3 ~ ?I ~ fi? WI 5a0.m (V511G-Imercc: 5411- Il(WN.U Wtl Mrv J I><•ph n.imene- 125 ~ 11 l b?,%p ('aluLU~v AkWd: Mmmu®('unmme TARGET DETALLS Name 7VD +N.-S +E'-W Northing EuYing Shape 15-39A T3 8N78.N0 -25211.61 21193.61 595756A011 678860.IN1 Point IS-39A T 1 8883.8(1 -6UN.26 958.IY 595945(LIN) 6776811.IN1 Point IS-39A T2 8883.SU -126L53 1513.112 SYSNSIU.INI 6782SO.IN1 Point -.-I_, I~ 1600 S1nevEY 1MU%: W1M PLw: I S-J9A wpub (I 5-79/Plao I S-79A1 - UgxhFm I>.7%h li. Survey/1'lav Tlwl ('fealal d)':'I mY IaLiNvs~Y 6ataN)(a;IrpmWly-S.'?3;?U116 d?WW IISIIJS 1'tavn~l5-?YA wpU6 Vdtl MWU~UR~MS ('IuckN- Uale: xe.~iewW: Dale: w[dt uerAUs Na me .W-S -a/-W W mllo% li t mg IaWUb Wv%mde 561 11 ?9 II%52N d)%.%% 3')fi11U?33? 5757U7.1t4 7a'IT36.H_?N 135 ?JU%JIIW WA SECTION DETAll.S Sec MD lnc Azi TVD +N'-S +E'-W DLeg TFace VSec Target ~. 1 4304.00 0.18 14.62 4303.88 -1.04 9.48 0.00 0.00 6.85 2 4324.00 2.49 71.06 4323.87 -0.87 9.90 12.00 60.00 6.99 3 4504.00 8.69 117.60 4502.99 -5.90 25.67 4.00 61.00 20.94 4 5404.00 8.69 117.60 5392.66 -66.88 146.12 0.00 0.00 146.34 5 5619.00 0.09 117.60 5606.83 -76.49 160.67 4.00 -180.00 161.50 6 7129.00 0.09 117.60 7116.83 -77.54 162.69 0.00 0.00 163.59 7 7722.65 23.83 118.21 7693.45 -135.26 270.32 4.00 0.61 276.77 8 8706.47 23.83 118.21 6593.38 -323.14 620.64 0.00 0.00 645.13 9 9266.83 90.00 135.00 6883.80 -608.26 958.19 12.00 16.26 1080.14 IS-39A TI 10 9301.35 90.00 139.14 8883.80 -633.53 981.69 12.00 90.00 1114.59 11 9993.36 90.00 139.14 8883.80 -1156.92 1434.39 0.00 0.00 1806.46 12 10124.32 90.00 147.00 8883.80 -1261.53 IS 13.02 6.00 90.00 1937.17 15-39AT2 13 10269.34 90.22 155.70 8883.52 -1388.67 1582.45 6 0o s8 56 '079.35 14 11511.34 90.22 155.70 8878.80 -2520.61 2093.61 a nu ouu 'J6 69 l i-?9,A "I3 FORMATION TOP DETAILS No. TVDPath MDPath Formation _ I 4608.80 4611.04 UG4 ~~ , ~ 2 4869.80 4875.07 UG3 3 5353.80 5364.68 UGI `- - 4 5893.80 5905.97 WS2 ---~- S 6098.80 6110.97 WSI ---- ' - 6 6333.80 6345.97 CM3 7 6743.80 6755.97 CM2 --- - 8 7478.80 7495.01 CMI __ 9 7803.80 7843.29 THRZ ____ _ _ 10 7993.80 SOS 1.00 BHRZ __ II 8028.80 8089.26 T1C - 12 6043.80 8105.66 Put Ricer -- ~ 13 6053.80 6116.59 LCU '-`- - - 14 8263.80 8346.16 TSGR "~ -~ _-- - 15 8303.80 8389.89 TS}IA ----- - 16 8323.60 8411.76 TSHB --- 17 8336.80 8428.16 TSHC 18 8363.60 8455.49 TSAD 19 8378.60 8471.88 45SB _ 20 8403.80 8499.21 44SB 21 8448.80 8548.41 42S6 22 8508.80 8614.00 TCGL 23 8583.80 8695.99 BCGL `~'i-'--" 24 6638.80 8757.35 2358 -- 25 8703.80 8836.10 22TS '- 26 8738.80 8682.96 21TS -- 27 8798.80 8976.31 TZIB _T 28 8843.80 9069.19 TDF 29 8883.80 9266.83 BSAD 3200 4000 4600 Vertical Section at 140.29° [SOOfbin] CASMG DETAILS No. TVD MD Name Siu 1 8263.80 8346.16 7" 7.000 2 8878.80 11511.00 4112" 4.500 i ('l)MI'ANY ULfA1Lti W~~IIU:N<'1: WFUIU.NI'N)N tlY Am 'u ('.~x nLva IN:1~1141 W~a ('Wrt IS-19. fnc Wxlh []() ('a4ule M,hW. M um( un'atme ven.:wUtu)Iiv( stl Ill Yll S ~ 1i 1114'1 ~ 144- (11III1N OIIDIi1 I- tiY~mm: 11( WhA Yuo MmWnl: fret l'Y4m4 N~~Ith Imx Ymlecc: t]IgYUI ~ ('amg W' MnhW: Itulcy tlmxrl M~ ,I IkYt4141 i S ~ tl t 6t.YU 1' 4 LI~m hl Ihhl. Mmwum( Num TARGET DETAILS Name TVD +N.'-S +E,'-W Northing Easting Shape IS-39A T3 6678.80 -2520.61 2093.61 5957565.00 678860.00 Point IS-39A Poly 8883.80 -364.78 855.88 5959691.00 677572.00 Polygon IS-39A TI 8883.80 -608.26 958.19 5959450.00 677680.00 Poiut IS-39A T2 8883.80 -1261.53 1513.02 5958810.00 678250.00 Poiut 1 ,,, ..~ L~..7 1 I I A x °o 2 0 ('~ - I '~ a tiliKVliY Yx(x~WVM YLw: I S-39A Wp16 (I S-i9~Pla0 I S-39A) Ihg4 Fm IKpIh 1'o Ym, y/Yhe 3mJ ('cmltul t3r:lroy JaWlxN4r 6a4atU(uj4p.cunitc: Si?4i_U116 Ot1141M1 11511!3 YLOm,l: 15-39A wpMi VON MWU~It'It~MJ ('6~ti4(xl: Uate: WFL. UF.'IAII ti Nme *W-S .~-W NnMmg F:Wmg lumut WogNdn ti4x IS-tY IINX 2N JlaxM 5'J6IX1353t fi74]U].%J ]U ITJM1.9.tN 10. tJ'UX.J21W WA SECTION DETAILS Sec MD Inc Azi TVD +N/-S +&-W DLeg TFace VSec Target I 4304.00 0.18 14.62 4303.88 -1.04 9.48 0.00 0.00 6.85 2 4324.00 2.49 71.06 4323.87 -0.87 9.90 12.00 60.00 6.99 3 4504.00 8.69 117.60 4502.99 -5.90 25.67 4.00 61.00 20.94 4 5404.00 8.69 117.60 5392.66 -68.88 146.12 0.00 0.00 146.34 5 5619.00 0.09 117.60 5606.83 -76.49 160.67 4.00 -180.00 161.50 6 7129.00 0.09 117.60 7116.83 -77.54 162.69 0.00 0.00 163.59 7 7722.65 23.83 118.21 7693.45 -135.26 270.32 4.00 0.61 276.77 8 8706.47 23.63 118.21 8593.38 -323.14 620.64 0.00 0.00 645.13 9 9266.83 90.00 135.00 8883.80 -608.26 958.19 12.00 18.26 1080.14 IS-39A T1 10 9301.35 90.00 139.14 8883.80 -633.53 981.69 12.00 90.00 1114.59 1~T-' II 9993.36 90.00 139.14 8683.80 -1156.92 1434.39 0.00 0.00 1806.46 [ { 12 10124.32 90.00 147.00 8883.80 -1261.53 1513.02 6.00 90.00 1937.17 IS-39A T2 13 10269.34 90.22 155.70 8683.52 -1388.67 1582.48 6.00 88.56 2079.35 - 14 11511.34 9022 155.70 8878.80 -2520.61 2093.61 0.00 0.00 3276.69 IS-39A T3 CASPVG DETAILS No. TVD MD Name Size "- ~ - - ~ - ~ ~ - - ~ - ~ ~ ~ ~ ~ 1 8263.80 8346.16 7" 7.000 I _ 2 8678.80 11511.00 4 IR" 4.500 - ~--~-~~" -~ FORMATION TOP DETAILS - - ~- -~ - - ~ - - ~ - - -- ~ ~ No. TVDPath MDPath Formation - . _. -. 1 4608.80 4611.04 UG4 _ _ _ __ __ 2 4869.60 4875.07 UG3 3 5353.80 5364.68 UGI -. _ 4 5893.80 5905.97 WS2 - 5 60 8.80 61 6 6 t-±--r-~- --~-~- - - 7 6743.80 6755.97 CM2 --,- -• - - ~ ------ ---' 8 7478.80 7495.01 CMI .. . ~ . _ _..... ._ - 9 7803.80 7843.29 THRZ . - 10 7993.80 8051.00 BHRZ . 11 80'_8.80 8089.26 TIC 12 8043.80 8105.66 Put River 13 8053.80 8116.59 LCU - -~-~- - - _ ~_ - 14 8263.80 8346.16 TSGR ' ~ ~ - ~ - ~ IS 8303.80 8389.89 TSHA '-' -- 16 8323.80 8411.76 TSHB {~{------~~~---!!!---~~~---- - 17 8338.80 6428.16 TSHC }--~--[--j--- ~i - _- _ IS 8363.80 8455.49 TSAD JI~I IL_IL_ -~-i 19 6378.80 6471.88 45S6 I i ;___T_ ~ ~__.. _....._ I -. 20 8403.80 849921 44SB - _. 21 8448.80 8546.41 4286 _ _ _ _. - - 22 6508.80 8614.00 TCGL 23 8583.60 8695.99 BCGL 24 8638.80 8757.35 2386 - - ~ ~ - - ~ ~ - - - 25 8703.60 8836.10 21TS " ~ - - - - 26 8738.80 8882.96 21TS - - - - - - 27 8798.80 8976.31 TZIB - ~ -- -- - 28 8843.80 9069.19 TDF . - ~- 29 8883.80 9266.83 BSAD • 0 600 1200 1800 2400 3000 3600 4200 4800 5400 West(-)%East(+) [600Win] • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/24/2006 Time: 15:55:09 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-39, True North Site: PB DS 15 Vertical (TVD) Reference: 32.5 + 31.3 63.8 Well: 15-39 Section (VS) Reference;: Well (O.OON,O.OOE,140.29Azi) Wellpath: Plan 15-39A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 15-39A wp06 Date Composed: 7/20/2005 Version: 48 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 15 TR-11-14 UNITED STA TES :North S lope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-39 Slot Name: 15-39 Well Position: +N/-S 1188.28 ft Northing: 5960035.53 ft Latitude: 70 17 46.923 N +E/-W 438.88 ft Easting : 676707.84 ft Longitude: 148 34 8.421 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size. Name ft ft in in 8346.16 8263.80 7.000 8.500 7" 11511.00 8878.80 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 0.00 SV2 0.00 0.00 0.00 SV1 0.00 0.00 4611.04 4608.80 UG4 0.00 0.00 4875.07 4869.80 UG3 0.00 0.00 5364.68 5353.80 UG1 0.00 0.00 5905.97 5893.80 WS2 0.00 0.00 6110.97 6098.80 WS1 0.00 0.00 6345.97 6333.80 CM3 0.00 0.00 6755.97 6743.80 CM2 0.00 0.00 7495.01 7478.80 CM1 0.00 0.00 7843.29 7803.80 THRZ 0.00 0.00 8051.00 7993.80 BHRZ 0.00 0.00 8089.26 8028.80 TJC 0.00 0.00 8105.66 8043.80 Put River 0.00 0.00 8116.59 8053.80 LCU 0.00 0.00 8346.16 8263.80 TSGR 0.00 0.00 8389.89 8303.80 TSHA 0.00 0.00 8411.76 8323.80 TSHB 0.00 0.00 8428.16 8338.80 TSHC 0.00 0.00 8455.49 8363.80 TSAD 0.00 0.00 8471.88 8378.80 45S6 0.00 0.00 8499.21 8403.80 4456 0.00 0,00 8548.41 8448.80 42SB 0.00 0.00 8614.00 8508.80 TCGL 0.00 0.00 8695.99 8583.80 BCGL 0.00 0.00 8757.35 8638.80 23S6 0.00 0.00 8836.10 8703.80 22TS 0.00 0.00 8882.96 8738.80 21 TS 0.00 0.00 8976.31 8798.80 TZ1 B 0.00 0.00 9069.19 8843.80 TDF 0.00 0.00 9266.83 8883.80 BSAD 0.00 0.00 U Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/24/2006 Time: 15:55:09 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference:. Well: 15-39, True North Site: PB DS 15 Vertical (TVD) Reference: 32. 5 + 31.3 63.8 Well: 45-39 Section (VS) Reference: We11(O.OON,O.OOE,140.29Azi) Wellpathc Plan 15-39A Survey Calculation Method: Minimum Curvature Db: OraGe Targets Map Map <--- Latitude --> ~-- Longitude ---> Name Description TVD +Nl5 +E/-W Northing Fasting' Deg Min Sec. Deg Min Sec Dip. Dir. ft ft ft ft ft = 15-39A T3 8878.80 -2520.61 2093.61 5957565.00 678860.00 70 17 22.130 N 148 33 7.417 W 15-39A Poly 8883.80 -364.78 855.88 5959691.00 677572.00 70 17 43.335 N 148 33 43.475 W -Polygon 1 8883.80 -364.78 855.88 5959691.00 677572.00 70 17 43.335 N 148 33 43.475 W -Polygon 2 8883.80 -581.21 658.72 5959470.00 677380.00 70 17 41.206 N 148 33 49.222 W -Polygon 3 8883.80 -1286.20 1328.37 5958781.00 678066.00 70 17 34.272 N 148 33 29.709 W -Polygon 4 8883.80 -1910.25 1661.82 5958165.00 678414.00 70 17 28.134 N 148 33 19.995 W -Polygon 5 8883.80 -2698.87 1974.38 5957384.00 678745.00 70 17 20.377 N 148 33 10.893 W -Polygon 6 8883.80 -2643.58 2260.78 5957446.00 679030.00 70 17 20.920 N 148 33 2.547 W -Polygon 7 8883.80 -2175.64 2099.73 5957910.00 678858.00 70 17 25.523 N 148 33 7.236 W -Polygon 8 8883.80 -1046.94 1576.08 5959026.00 678308.00 70 17 36.625 N 148 33 22.488 W 15-39A T1 8883.80 -608.26 958.19 5959450.00 677680.00 70 17 40.940 N 148 33 40.494 W 15-39A T2 8883.80 -1261.53 1513.02 5958810.00 678250.00 70 17 34.514 N 148 33 24.327 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Targe t ft deg deg ft ft ft deg/100ft deg/100ft degf100ft deg 4304.00 0.18 14.62 4303.88 -1.04 9.48 0.00 0.00 0.00 0.00 4324.00 2.49 71.06 4323.87 -0.87 9.90 12.00 11.58 282.20 60.00 4504.00 8.69 117.60 4502.99 -5.90 25.67 4.00 3.44 25.86 61.00 5404.00 8.69 117.60 5392.66 -68.88 146.12 0.00 0.00 0.00 0.00 5619.00 0.09 117.60 5606.83 -76.49 160.67 4.00 -4.00 0.00 -180.00 7129.00 0.09 117.60 7116.83 -77.54 162.69 0.00 0.00 0.00 0.00 7722.65 23.83 118.21 7693.45 -135.26 270.32 4.00 4.00 0.10 0.61 8706.47 23.83 118.21 8593.38 -323.14 620.64 0.00 0.00 0.00 0.00 9266.83 90.00 135.00 8883.80 -608.26 958.19 12.00 11.81 3.00 18.26 15-39A T1 9301.35 90.00 139.14 8883.80 -633.53 981.69 12.00 0.00 12.00 90.00 9993.36 90,00 139.14 8883.80 -1156.92 1434.39 0.00 0.00 0.00 0.00 10124.32 90.00 147.00 8883.80 -1261.53 1513.02 6.00 0.00 6.00 90.00 15-39A T2 10269.34 90.22 155.70 8883.52 -1388.67 1582.48 6.00 0.15 6.00 88.56 11511.34 90.22 155.70 8878.80 -2520.61 2093.61 0.00 0.00 0.00 0.00 15-39A T3 Survey MD Incl Azim TVI) Sys TVD VS N/S E/W DLS MapN MapE TooUCa ft deg deg ft ft ft ft ft deg/100ft ft ft 4304.00 0.18 14.62 4303.88 4240.08 6.85 -1.04 9.48 0.00 5960034.71 676717.34 Start Dir 1 4324.00 2.49 71.06 4323.87 4260.07 6.99 -0.87 9.90 12.00 5960034.90 676717.75 Start Dir 4/ 4400.00 4.78 104.92 4399.72 4335.92 10.16 -1.14 14.52 4.00 5960034.73 676722.38 MWD+IFR 4500.00 8.53 117.33 4499.03 4435.23 20.39 -5.62 25.13 4.00 5960030.50 676733.10 MWD+IFR 4504.00 8.69 117.60 4502.99 4439.19 20.94 -5.90 25.67 4.00 5960030.24 676733.64 End Dir 4600.00 8.69 117.60 4597.89 4534.09 34.31 -12.62 38.51 0.00 5960023.82 676746.64 MWD+IFR 4611.04 8.69 117.60 4608.80 4545.00 35.85 -13.39 39.99 0.00 5960023.09 676748.13 UG4 4700.00 8.69 117.60 4696.74 4632.94 48.25 -19.61 51.90 0.00 5960017.14 676760.18 MWD+IFR 4800.00 8.69 117.60 4795.59 4731.79 62.18 -26.61 65.28 0.00 5960010.46 676773.72 MWD+IFR 4875.07 8.69 117.60 4869.80 4806.00 72.64 -31.86 75.33 0.00 5960005.45 676783.89 UG3 4900.00 8.69 117.60 4894.45 4830.65 76.12 -33.61 78.66 0.00 5960003.78 676787.27 MWD+IFR 5000.00 8.69 117.60 4993.30 4929.50 90.05 -40.61 92.05 0.00 5959997.10 676800.81 MWD+IFR 5100.00 8.69 117.60 5092.15 5028.35 103.98 -47.60 105.43 0.00 5959990.42 676814.35 MWD+IFR 5200.00 8.69 117.60 5191.00 5127.20 117.92 -54.60 118.81 0.00 5959983.74 676827.90 MWD+IFR 5300.00 8.69 117.60 5289.86 5226.06 131.85 -61.60 132.20 0.00 5959977.06 676841.44 MWD+IFR 5364.68 8.69 117.60 5353.80 5290.00 140.86 -66.12 140.85 0.00 5959972.74 676850.20 UG1 5400.00 8.69 117.60 5388.71 5324.91 145.79 X8.60 145.58 0.00 5959970.38 676854.98 MWD+IFR 5404.00 8.69 117.60 5392.66 5328.86 146.34 -68.88 146.12 0.00 5959970.11 676855.53 Start Dir 4° 1 5500.00 4.85 117.60 5487.98 5424.18 156.78 -74.11 156.14 4.00 5959965.11 676865.67 MWD+IFR 5600.00 0.85 117.60 5587.83 5524.03 161.36 -76.41 160.54 4.00 5959962.92 676870.12 MWD+IFR -ent IS IS 4 Sperry-Sun BP Planning Report • .Company: BP Amoco Date: 5/24/2006 Time: 15:55:09 Page: 3 Field: Prudhoe Bay Co-ordinate{N E) Reference: Well: 15-39, True North , .Situ: PB DS 15 Vertical (TYD) Reference: 32, 5 + 31.3 63.8 Well: 15-39 Section (VS) Reference: Well (OOON,O.OOE,140.29Azi); Wellpaths Plan 15-39A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azun TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg ,deg ft fit ft ft ft deg/100ft ft ft' 5619.00 0.09 117.60 5606.83 5543.03 161.50 -76.49 160.67 4.00 5959962.85 676870.26 End Dir 5700.00 0.09 117.60 5687.83 5624.03 161.61 -76.54 160.78 0.00 5959962.79 676870.37 MWD+IFR 5800.00 0.09 117.60 5787.83 5724.03 161.75 -76.61 160.92 0.00 5959962.73 676870.50 MWD+IFR 5900.00 0.09 117.60 5887.83 5824.03 161.89 -76.68 161.05 0.00 5959962.66 676870.64 MWD+IFR 5905.97 0.09 117,60 5893.80 5830.00 161.90 -76.69 161.06 0.00 5959962.66 676870.64 WS2 6000.00 0.09 117.60 5987.83 5924.03 162.03 -76.75 161.18 0.00 5959962.59 676870.77 MWD+IFR 6100.00 0.09 117.60 6087.83 6024.03 162.17 -76.82 161.32 0.00 5959962.53 676870.91 MWD+IFR 6110.97 0.09 117.60 6098.80 6035.00 162.18 -76.83 161.33 0.00 5959962.52 676870.92 WS1 6200.00 0.09 117.60 6187.83 6124.03 162.31 -76.89 161.45 0.00 5959962.46 676871.04 MWD+IFR 6300.00 0.09 117.60 6287.83 6224.03 162.44 -76.96 161.58 0.00 5959962.39 676871.18 MWD+IFR 6345.97 0.09 117.60 6333.80 6270.00 162.51 -76.99 161.64 0.00 5959962.36 676871.24 CM3 6400.00 0.09 117.60 6387.83 6324.03 162.58 -77.03 161.72 0.00 5959962.33 676871.31 MWD+IFR 6500.00 0.09 117.60 6487.83 6424.03 162.72 -77.10 161.85 0.00 5959962.26 676871.45 MWD+IFR 6600.00 0.09 117.60 6587.83 6524.03 162.86 -77.17 161.98 0.00 5959962.19 676871.58 MWD+IFR 6700.00 0.09 117.60 6687.83 6624.03 163.00 -77.24 162.12 0.00 5959962.13 676871.72 MWD+IFR 6755.97 0.09 117.60 6743.80 6680.00 163.08 -77.28 162.19 0.00 5959962.09 676871.79 CM2 6800.00 0.09 117.60 6787.83 6724.03 163.14 -77.31 162.25 0.00 5959962.06 676871.85 MWD+IFR 6900.00 0.09 117.60 6887.83 6824.03 163.28 -77.38 162.38 0.00 5959961.99 676871.99 MWD+IFR 7000.00 0.09 117.60 6987.83 6924.03 163.42 -77.45 162.52 0.00 5959961.93 676872.12 MWD+IFR 7100.00 0.09 117.60 7087.83 7024.03 163.55 -77.52 162.65 0.00 5959961.86 676872.26 MWD+IFR 7129.00 0.09 117.60 7116.83 7053.03 163.59 -77.54 162.69 0.00 5959961.84 676872.29 Start Dir 4/ 1 7200.00 2.93 118.19 7187.80 7124.00 165.32 -78.42 164.33 4.00 5959961.00 676873.96 MWD+IFR 7300.00 6.93 118.20 7287.41 7223.61 173.28 -82.48 171.90 4.00 5959957.12 676881.62 MWD+IFR 7400.00 10.93 118.20 7386.18 7322.38 187.65 -89.81 185.57 4.00 5959950.12 676895.46 MWD+IFR 7495.01 14.73 118.20 7478.80 7415.00 207.19 -99.77 204.15 4.00 5959940.59 676914.27 CM1 7500.00 14.93 118.20 7483.63 7419.83 208.38 -100.38 205.28 4.00 5959940.01 676915.41 MWD+IFR 7600.00 18.93 118.20 7579.27 7515.47 235.35 -114.13 230.93 4.00 5959926.86 676941.38 MWD+IFR 7700.00 22.93 118.21 7672.66 7608.86 268.44 -131.01 262.40 4.00 5959910.73 676973.23 MWD+IFR 7722.65 23.83 118.21 7693.45 7629.65 276.77 -135.26 270.32 4.00 5959906.67 676981.25 End Dir 7800.00 23.83 118.21 7764.20 7700.40 305.73 -150.03 297.86 0.00 5959892.55 677009.13 MWD+IFR 7843.29 23.83 118.21 7803.80 7740.00 321.94 -158.30 313.28 0.00 5959884.65 677024.73 THRZ 7900.00 23.83 118.21 7855.68 7791.88 343.17 -169.13 333.47 0.00 5959874.30 677045.18 MWD+IFR 8000.00 23.83 118.21 7947.15 7883.35 380.61 -188.22 369.08 0.00 5959856.05 677081.22 MWD+IFR 8051.00 23.83 118.21 7993.80 7930.00 399.71 -197.96 387.24 0.00 5959846.74 677099.60 BHRZ 8089.26 23.83 118.21 8028.80 7965.00 414.03 -205.27 400.86 0.00 5959839.75 677113.39 TJC 8100.00 23.83 118.21 8038.62 7974.82 418.06 -207.32 404.69 0.00 5959837.79 677117.26 MWD+IFR 8105.66 23.83 118.21 8043.80 7980.00 420.17 -208.40 406.70 0.00 5959836.76 677119.30 Put River 8116.59 23.83 118.21 8053.80 7990.00 424.27 -210.49 410.60 0.00 5959834.77 677123.24 LCU 8200.00 23.83 118.21 8130.10 8066.30 455.50 -226.42 440.30 0.00 5959819.54 677153.31 MWD+IFR 8300.00 23.83 118.21 8221.57 8157.77 492.94 -245.51 475.90 0.00 5959801.29 677189.35 MWD+IFR 8346.16 23.83 118.21 8263.80 8200.00 510.22 -254.33 492.34 0.00 5959792.86 677205.99 7" 8389.89 23.83 118.21 8303.80 8240.00 526.60 -262.68 507.91 0.00 5959784.88 677221.76 TSHA 8400.00 23.83 118.21 8313.05 8249.25 530.38 -264.61 511.51 0.00 5959783.03 677225.40 MWD+IFR 8411.76 23.83 118.21 8323.80 8260.00 534.78 -266.86 515.70 0.00 5959780.89 677229.64 TSHB 8428.16 23.83 118.21 8338.80 8275.00 540.92 -269.99 521.54 0.00 5959777.90 677235.55 TSHC 8455.49 23.83 118.21 8363.80 8300.00 551.16 -275.21 531.27 0.00 5959772.91 677245.40 TSAD 8471.88 23.83 118.21 8378.80 8315.00 557.29 -278.34 537.11 0.00 5959769.91 677251.31 45S6 8499.21 23.83 118.21 8403.80 8340.00 567.53 -283.56 546.84 0.00 5959764.92 677261.16 44SB 8500.00 23.83 118.21 8404.52 8340.72 567.82 -283.71 547.12 0.00 5959764.78 677261.44 MWD+IFR 8548.41 23.83 118.21 8448.80 8385.00 585.95 -292.95 564.36 0.00 5959755.94 677278.89 42S6 8600.00 23.83 118.21 8495.99 8432.19 605.26 -302.81 582.73 0.00 5959746.53 677297.49 MWD+IFR 8614.00 23.83 118.21 8508.80 8445.00 610.51 -305.48 587.71 0.00 5959743.97 677302.54 TCGL ent S S S • • Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/24/2006 Time: 15:55:09. 'Page: 4 Field: Prudhoe Bay. Co-ordinate(N E) Reference: ' Well: 15-39, True: North Site: PB DS 15 V ertical (TVD) Reference: 32. 5 + 31.3 63.8 Well: 15-39 Section (VS) Reference: Well (O.OON,O.QOE,140.29Azi) Wellpath: Plan 15-39A S urvey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft ; 8895.99 23.83 118.21 8583.80 8520.00 641.21 -321.14 616.91 0.00 5959729.01 677332.09 BCGL 8700.00 23.83 118.21 8587.47 8523.67 642.71 -321.90 618.34 0.00 5959728.27 677333.53 MWD+IFR 8706.47 23.83 118.21 8593.38 8529.58 645.13 -323.14 620.64 0.00 5959727.09 677335.87 Start Dir 1 0 8757.35 29.69 122.06 8638.80 8575.00 666.64 -334.70 640.40 12.00 5959716.00 677355.89 23SB 8800.00 34.66 124.36 8674.89 8611.09 688.35 -347.16 659.37 12.00 5959703.99 677375.15 MWD+IFR 8836.10 38.89 125.90 8703.80 8640.00 709.21 -359.60 677.03 12.00 5959691.97 677393.10 22TS 8882.96 44.41 127.51 8738.80 8675,00 739.47 -378.23 701.97 12.00 5959673.94 677418.47 21TS 8900.00 46.42 128.02 8750.76 8686.96 751.32 -385.66 711.57 12.00 5959666.73 677428.23 MWD+IFR 8976.31 55.46 129.96. 8798.80 8735.00 809.38 -422.95 757.53 12.00 5959630.53 677475.06 TZ16 9000.00 58.27 130.47 8811.75 8747.95 828.90 -435.76 772.67 12.00 5959618.09 677490.50 MWD+IFR 9069.19 66.49 131.82 8843.80 8780.00 889.38 -476.08 818.78 12.00 5959578.86 677537.53 TDF 9100.00 70.15 132.36 8855.18 8791.38 917.71 -495.27 840.02 12.00 5959560.18 677559.22 MWD+IFR 9200.00 82.05 133.98 8879.17 8815.37 1013.86 -561.58 910.67 12.00 5959495.55 677631.40 MWD+IFR 9266.83 90.00 135.00 8883.80 8820.00 1080.14 -608.26 958.19 12.00 5959450.00 677680.00 15-39A T1 9300.00 90.00 138.98 8883.80 8820.00 1113.24 -632.51 980.81 12.00 5959426.29 677703.18 MWD+IFR 9301.35 90.00 139.14 8883.80 8820.00 1114.59 -633.53 981.69 12.00 5959425.29 677704.09 End Dir 9400.00 90.00 139.14 8883.80 8820.00 1213.22 -708.15 1046.23 0.00 5959352.22 677770.36 MWD+IFR 9500.00 90.00 139.14 8883.80 8820.00 1313.20 -783.78 1111.65 0.00 5959278.15 677837.53 MWD+IFR 9600.00 90.00 139.14 8883.80 8820.00 1413.18 -859.41 1177.06 0.00 5959204.08 677904.71 MWD+IFR 9700.00 90.00 139.14 8883.80 8820.00 1513.16 -935.05 1242.48 0.00 5959130.01 677971.88 MWD+IFR 9800.00 90.00 139.14 8883.80 8820.00 1613.14 -1010.68 1307.90 0.00 5959055.94 678039.06 MWD+IFR 9900.00 90.00 139.14 8883.80 8820.00 1713.12 -1086.31 1373.32 0.00 5958981.87 678106.23 MWD+IFR 9993.36 90.00 139.14 8883.80 8820.00 1806.46 -1156.92 1434.39 0.00 5958912.72 678168.94 Start Dir 6/ 10000.00 90.00 139.54 8883.80 8820.00 1813.10 -1161.96 1438.72 6.00 5958907.79 678173.39 MWD+IFR 10100.00 90.00 145.54 8883.80 8820.00 1912.98 -1241.31 1499.51 6.00 5958829.90 678236.03 MWD+IFR 10124.32 90.00 147.00 8883.80 8820.00 1937.17 -1261.53 1513.02 6.00 5958810.00 678250.00 15-39A T2 10200.00 90.11 151.54 8883.72 8819.92 2011.90 -1326.57 1551.68 6.00 5958745.90 678290.18 MWD+IFR 10269.34 90.22 155.70 8883.52 8819.72 2079.35 -1388.67 1582.48 6.00 5958684.54 678322.43 End Dir : 1 10300.00 90.22 155.70 8883.41 8819.61 2108.91 -1416.61 1595.10 0.00 5958656.90 678335.70 MWD+IFR 10400.00 90.22 155.70 8883.03 8819.23 2205.32 -1507.75 1636.25 0.00 5958566.76 678378.98 MWD+IFR 10500.00 90.22 155.70 8882.65 8818.85 2301.72 -1598.89 1677.41 0.00 5958476.62 678422.27 MWD+IFR 10600.00 90.22 155.70 8882.27 8818.47 2398.13 -1690.03 1718.56 0.00 5958386.48 678465.55 MWD+IFR 10700.00 90.22 155.70 8881.89 8818.09 2494.53 -1781.17 1759.72 0.00 5958296.34 678508.83 MWD+IFR 10800.00 90.22 155.70 8881.51 8817.71 2590.93 -1872.31 1800.87 0.00 5958206.20 678552.11 MWD+IFR 10900.00 90.22 155.70 8881.13 8817.33 2687.34 -1963.45 1842.02 0.00 5958116.06 678595.40 MWD+IFR 11000.00 90.22 155.70 8880.74 8816.94 2783.74 -2054.58 1883.18 0.00 5958025.92 678638.68 MWD+IFR 11100.00 90.22 155.70 8880.36 8816.56 2880.14 -2145.72 1924.33 0.00 5957935.78 678681.96 MWD+IFR 11200.00 90.22 155.70 8879.98 8816.18 2976.55 -2236.86 1965.49 0.00 5957845.64 678725.24 MWD+IFR 11300.00 90.22 155.70 8879.60 8815.80 3072.95 -2328.00 2006.64 0.00 5957755.50 678768.53 MWD+IFR 11400.00 90.22 155.70 8879.22 8815.42 3169.35 -2419.14 2047.79 0.00 5957665.36 678811.81 MWD+IFR 11500.00 90.22 155.70 8878.84 8815.04 3265.76 -2510.28 2088.95 0.00 5957575.22 678855.09 MWD+IFR 11511.00 90.22 155.70 8878.80 8815.00 3276.36 -2520.30 2093.47 0.00 5957565.31 678859.85 41/2" 11511.34 90.22 155.70 8878.80 8815.00 3276.69 -2520.61 2093.61 0.00 5957565.00 678860.00 15-39A T3 gent c: Terri: Hubble BP Exploration AK Inc. PO Box T96612 MB 7-5 Anchorage, AK 9951.9 PAY TO THE ORDER OF rti n .4.1,. ,. /1. ,. • ss-si, z52 281 "Mastercard Check" AnchorageCAK_ 99501 MEMO '~•~~~ DATE ~~ ~ ~ ~ ~~ ~C'C s J~.°i~ DOLLARS ~:L2520006D~:99L46227L556~~' 028E • • TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~,~~~~~' ,~ PTD# .~, ~~ ~ ~ ~' Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) I ~ APPLIES ~ MULTI LATERAL The permit is for a new wellbore segment of existing we[1 (If Last two digits in permit No. API No. 50- - API number are , between 60-69) ~ Production should continue to be reported as a function of the original API number stated above. ~ i PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs ~ ~ acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055, Approval to perforate and produce /inject is contingent ~ i ~ upon issuance of a conservation order approving a spacing exception. assumes the i ~ liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or i from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well] until after jCompany NameZhas 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 rogram. Rev: 1 /25/06 C:\jody\transmittal checklist . ~HECt(LIST .Field & Pool PRUDHOE BAY PRUDHOE OIL - 640150 _ __ Well Name: PRUDHOE BAY-UNIT 15-39A _ Program DEV _ Well bore seg _,,n0860 Company BP EXPLORATI.ON_(ALASKA) INC _ __ _ Initial ClasslType - - _ _ _ _r_~ _ - - -- - _DEV/1-OIL GeoArea 890 Unit .1.1650 On/Off Shore On Annular Disposal ,..-~. _ _.._.~.- - ~ _~ _-.z-~.-qs ~ : ~_ -- Administration i,1 ~_ - - - - - _ Permit-fee attached - Yes - .. ~_ . ~12 Lease number appropriate. Yes - ~3 Unique well_name and number Yes - - ~4 Well Iccated in a defined pool _ Yes - _ - li5 Well located proper distance-from drilling unit b_oundary_ Yes - - '6 Well located proper distance from other wells Yes 7 Sufficient acreage available in-drilling unit, - Yes - - - 8 If deviated, is wellbore plat included Yes - ~I9 Operator only affected party - Yes 10 Operator has-appropriate_bond in force - Yes j11 Permit-can be issued without conservation order - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ . - - - _ ~i12 Permit-can be issued without administrative-approval Yes Appr Date I~13 Can permit be approved before 15-daywait- - Yes e. _ ' 15 All wells within 1I4 mile area of review identified (For service well only) NA- ~16 Pre-produced injector;. duration of pre-p[oduction less-than.3 months-(for_seNice well-only) - NA- - - - - - - I17 Nonconven, gas conforms to A$31.05,0300.1.A),(j,2.A-p) NA- 1~18 _-- --- Conducto[string_provided - ... NA_ _ __ _ __ __ ---- Engineering x',19 Sutfacerasing-protects all known tl$DWS - NA- _ - - - - 20 I CMT. voladequate-to circulate_on conductor & surf csg - NA - !21 CMT-vol adequate_t4 tie-in long string to surf csg NA - ~~22 CMT_will coverall knownproductiye horizons- . - - - - Yes Adequate excess.. 23 Casing designs adequate f_or C, T, B & permafrost - _ - Yes _ - - 1124 Adequate tankage-or reserve pit Yes - Nabors 27E._ '25 If-a-re-drill, has-a 10-403 for abandonment been approved Yes _ 611612006.- ~,26 Adequate wellbore separation proposed _ .. - _ - - - . Yes - . - _ - ~27 If diverter required, does it meet-regulations- - _ - NA- _ . - _ _ - .Sidetrack... i28 Drilling fluid-program schematic 8 equip list adequate... - Yes - . IutaX MW-10:2_ppg. Appr Date ''29 BOPES, do they meet-regulation - - - _ _ - - -Yes - - WGA 6/19/2006 'x,30 BOPE-press rating appropriate; test to_(put prig in comments)- . - Yes Test to 3500. psi. fv1Sf? 33.00 psi, '31 Choke_manifold complies wlAPl_RP-53 (May 84)_ - .. Yes - '~32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - -Yes - 33 Is presence of H2S gas probable - - - No Not an H2$ pad. '34 Mechanical condition of wells within AOR verified ~Forservice well only) - NA- - - X35 Permit_can be issued wlo_kydrogen-sulfide measures _ NO- - - - --- -- _ _ -- Geology ,36 Data presented on_ potential overpressure zones - - - - - - - - - - - - - - - - - - - - NA 'I37 Sesmic.analysis of shalfowgas-zones Appr Date 38 Seabed condition survey (ifoff-shore) ' RPC 611612006 39 Contact namelpho_ne for weekly-progress reports [exploratory only] - NA- - - Geologic Engineering P ' Date; Date Dat/e Q ~~~issioner: ~ ~'~ any-"- ~ ly D,6 Co s r ~ ( / ' Q~ _CU1 _ __ -- -~~---_ ----__ --_ __ _----- • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Penmmitting Process but is part of the history file. To improve the readability of the Well History fiiie and to sinm.plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. IJo special effort has been made to chronologically organize this category of information. 15-39a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 08 17:12:13 2007 Reel Header Service name .............LISTPE Date. ...... ...........07/11/08 Ori9in ...................STS Reel Name. .... .. ....UNKNOWN Continuation Number..:...01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................07/11/08 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: 15-39A API NUMBER: 500292250301 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 08-NOV-07 JOB DATA MWD RUN 1 MWD RUN 2 MAD RUN 2 Job NUMBER:. w-0004580096 w-0004580096 w-0004580096 LOGGING ENGINEER: B. TRANI B. TRANI B. TRANI OPERATOR WITNESS: C. CLEMENS C. CLEMENS C. CLEMENS MWD RUN 3 MWD RUN 4 MAD RUN 4 JOB NUMBER: w-0004580096 w-0004580096 W-0004580096 LOGGING ENGINEER: B. TRANI B. TRANI B. TRANI OPERATOR WITNESS: C. CLEMENS C. CLEMENS C. CLEMENS SURFACE. LOCATION SECTION: 22 TOWNSHIP: 11N RANGE: 14E FNL: 1464 FSL: FEL: FWL: 769 Page 1 ~(J~~~~ ~ t S~a~- 15-39a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 64.20 GROUND LEVEL: 31.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4290.0 2ND STRING 6.125 7.000 8320.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 15-39 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 4290'MD/4290'TVD. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW MILLED PRIOR TO THE ADDITION OF MWD TOOLS TO THE BHA. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON(CTN), AND AZIMUTHAL LITHO-DENSITY (ALD). 5. MAD PASS DATA WERE ACQUIRED OVER 3 SEPATATE INTERVALS: 4400'MD-3960'MD +/- FOR TIE-IN AFTER RUN 2; 9339'MD-8600'MD+/- PRIOR TO DRILLING RUN 4 (TO IDENTIFY THE GOC); AND 10350'MD-9650'MD+/- AFTER REACHING TD ON RUN 4 (FOR AN INVASION PROFILE). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP), DATED 8/8/07, QUOTING AUTHORIZATION OF ROGER FURLEY. HOWEVER, MAD DATA WERE CORRECTED (SHIFTED) TO MWD DATA. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 15-39A WITH API# 50-029-22503-01. THIS WELL REACHED A TOTAL DEPTH OF 11650'MD/8856'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM Page 2 15-39a.tapx SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED-HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125~~ BIT MUD WEIGHT: 8.45-8.7 PPG MUD SALINITY: 4200-6600 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPX RPS RPM ROP NPHI FCNT NCNT PEF RHOB DRHO 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3962.5 4280.0 4280.0 4280.0 4280.0 4280.0 4290.5 9246.5 9246.5 9246.5 9260.5 9260.5 9260.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 11584.0 11591.0 11591.0 11591.0 11591.0 11591.0 11650.0 11556.0 11556.0 11556.0 11571.0 11571.0 11571.0 Page 3 15-39a.tapx --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 3962.5 4647.5 MWD 2 4647.5 8320.0 MWD 3 8320.0 9339.0 MwD 4 9339.0 11650.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT . FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3962.5 11650 7806.25 15376 3962.5 11650 FONT MWD CNTS 359.52 1106.36 660.523 4620 9246.5 11556 NCNT MWD CNTS 23345.3 36588.3 29784.2 4620 9246.5 11556 RHOB MWD G/CM 2.059 3.311 2.39415 4622 9260.5 11571 DRHO MWD G/CM -0.175 0.391 0.0438055 4622 9260.5 11571 RPD MWD OHMM 0.59 2000 124.739 14623 4280 11591 RPM MWD OHMM 0.54 2000 95.7404 14622 4280 11591 RPS MWD OHMM 0.53 2000 80.9257 14623 4280 11591 RPX MWD OHMM 0.51 1845.21 46.0283 14623 4280 11591 FET MWD HOUR 0.11 89.62 2.04241 14623 4280 11591 GR MWD API 7.68 525.94 82.6453 15244 3962.5 11584 PEF MWD BARN 0.83 7.41 2.30977 4622 9260.5 11571 ROP MWD FT/H 0.02 964.8 136.122 14720 4290.5 11650 NPHI MWD PU-5 14.93 32.51 23.4419 4620 9246.5 11556 Page 4 r! M 15-39a.tapx First Reading For Entire File..........3962.5 Last Reading For Entire File...........11650 File Trailer Service name... .....STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EoF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3960.5 RAT 3999.0 FCNT 8537.5 NPHI 8537.5 NCNT 8537.5 RHOB 8551.0 PEF 8551.0 DRHO 8551.0 RPD 8572.5 FET 8572.5 RPM 8572.5 RPS 8572.5 RPx 8572.5 all MAD runs merged using earliest passes. STOP DEPTH 10452.0 10662.5 9232.5 9232.5 9232.5 9245.5 9245.5 9245.5 10462.0 10462.0 10462.0 10462.0 10462.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MWD 2 1 MWD 4 1 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Page 5 MERGE TOP MERGE BASE 3960.5 8320.0 8537.5 11650.0 ~ ~ . 15-39a.tapx optical log depth units......... Feet Data Reference Point ..............undefined Frame Spacing....... .........60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD Pu-S 4 1 68 52 14 Furst Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3960.5 10662.5 7311.5 13405 3960.5 10662.5 FONT MAD CNTS 289.5 2658.1 868.861 1391 8537.5 9232.5 NCNT MAD CNTS 19450 44977.1 30383.3 1391 8537.5 9232.5 RHOB MAD G/CM 2.027 2.824 2.29876 1390 8551 9245.5 DRHO MAD G/CM -0.165 0.317 0.0397871 1390 8551 9245.5 RPD MAD OHMM 7.15 2000 256.298 3054 8572.5 10462 RPM MAD OHMM 6.18 2000 147.346 3054 8572.5 10462 RPS MAD OHMM 5.94 689.26 94.0436 3054 8572.5. 10462 RPX MAD OHMM 5.72 256.49 .56.5623 3054 8572.5 10462 FET MAD HOUR 25.75 59.83 38.944 3054 8572.5 10462 GR MAD API 10.49 274.06 62.5385 3868 3960.5 10452 PEF MAD BARN 0.6 5.98 1.87534 1390 8551 9245.5 RAT MAD FT/H 0.36 1683.79 216.215 4016 3999 10662.5 NPHI MAD Pu-S 6.35 34.84 19.3021 1391 8537.5 9232.5 First Reading For Entire File..........3960.5 Last Reading For Entire File...........10662.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. .....1.0.0 Date of Generation.... .07/11/08 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLI6.003 Page 6 15-39a.tapx service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3962.5 RPM 4280.0 FET 4280.0 RPS 4280.0 RPD 4280.0 RPx 4280.0 ROP 4290.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: • header data for each bit run in separate files. 1 .5000 25-AUG-06 Incite 66.37 Memory 4647.0 4290.0 4647.0 .0 8.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RE5I5. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 3 STOP DEPTH 4610.0 4602.5 4602.5 4602.5 4602.5 4602.5 4647.5 8.500 .0 Fresh water Gel 9.34 51.0 9.5 1600 5.5 1.940 80.0 1.640 96.0 1.900 80.0 1.920 80.0 Page 7 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15-39a.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MwD010 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MwD010 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3962.5 4647.5 4305 1371 3962.5 4647.5 RPD MWDO10 OHMM 1.69 2000 48.8663 646 4280 4602.5 RPM MWDO10 OHMM 1.6 1703.96 20.938 646 4280 4602.5 RPS MWDO10 OHMM 1.67 1608.69 13.7472 646 4280 4602.5 RPX MWDO10 OHMM 1.39 1845.21 10.8547 646 4280 4602.5 FET MWDO10 HOUR 0.48 6.87 2.44407 646 4280 4602.5 GR MWDO10 API 22.33 120.79 60.6409 1296 3962.5 4610 ROP MWDO10 FT/H 0.09 575.74 101.87 715 4290.5 4647.5 First Reading For Entire File..........3962.5 Last Reading For Entire File...........4647.5 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type ................L0 Next-File Name...........STSLIB.004 Physical EOF Page 8 • • 15-39a.tapx File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 4603.0 8274.0 RPD 4603.0 8274.0 RPM 4603.0 8274.0 FET 4603.0 8274.0 RPX 4603.0 8274.0 GR 4610.5 8281.5 ROP 4648.0 8320.0 LOG HEADER DATA DATE LOGGED: 28-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8320.0 TOP LOG INTERVAL (FT): 4647.0 BOTTOM LOG INTERVAL (FT): 8320.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .4 MAXIMUM ANGLE: 23.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY. 10718517 EWR4 ELECTROMAG. RES IS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4311.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.940 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.560 100.0 Page 9 • 15-39a.tapx MUD FILTRATE AT MT: 1.930 79.0 MUD CAKE AT MT: 1.950 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. .. Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4603 8320 6461.5 7435 4603 8320 RPD MWD020 OHMM 0.59 67.49 2.95411 7343 4603 8274. RPM MWD020 OHMM 0.54 71.65 2.91088 7343 4603 8274 RPS MWD020 OHMM 0.53 114.27 2.96402 7343 4603 8274 RPX MWD020 OHMM 0.51 113.14 2.93561 7343 4603 8274 FET MwD020 HOUR 0.11 20.01 1.03893 7343 4603 8274 GR MWD020 API 7.68 401.01 103.911 7343 4610.5 8281.5 ROP MWD020 FT/H 0.09 451.77 157.658 7345 4648 8320 First Reading For Entire File..........4603 Last Reading For Entire File...........8320 File Trailer Service name... .......STSLI6.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.005 Page 10 15-39a.tapx Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 8274.5 9285.5 FET 8274.5 9285.5 RPX 8274.5 9285.5 RPM 8274.5 9285.5 RPS 8274.5 9285.5 GR 8282.0 9278.5 ROP 8320.5 9339.0 LOG HEADER DATA DATE LOGGED: 02-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9339.0 TOP LOG INTERVAL (FT): 8320.0 BOTTOM LOG INTERVAL (FT): 9339.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.6 MAXIMUM ANGLE: 88.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8320.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 44.0 MUD PH: 8.$ MUD CHLORIDES (PPM): 6800 FLUID LOSS (C3): 7.6 Page 11 15-39a.tapx RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .400 79.0 MUD AT MAX CIRCULATING TERMPERATURE: .320 100.0 MUD FILTRATE AT MT: .420 79.0 MUD CAKE AT MT: .450 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8274.5 9339 8806.75 2130 8274.5 9339 RPD MwD030 OHMM 1.13 2000 308.782 2023 8274.5 9285.5 RPM MWD030 OHMM 0.92 2000 281.786 2023 8274.5 9285.5 RPS MWD030 OHMM 0.93 1876.3 140.288 2023 8274.5 9285.5 RPX MWD030 OHMM 0.54 477.6 72.1334 2023 8274.5 928.5.5 FET MWD030 HOUR 0.36 89.62 5.233 2023 8274.5 9285.5 GR MWD030 API 11.56 525.94 57.3503 1994 8282 9278.5 ROP MWD030 FT/H 1.44 256.47 96.785 2038 8320.5 9339 First Reading For Entire File..........8274.5 Last Reading For Entire File...........9339 File Trailer Service name... .......STSL2g.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 Page 12 • • 15-39a.tapx File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log he ader data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9246.5 11556.0 NPHI 9246.5 11556.0 FONT 9246.5 11556.0 DRHO 9260.5 11571.0 PEF 9260.5 11571.0 RHOB _ 9260.5 11571.0 GR 9279.0 11584.0 RPS 9286.0 11591.0 FET 9286.0 11591.0 RPM 9286.0 11591.0 RPD 9286.0 11591.0 RPx 9286.0 11591.0 ROP 9339.5 11650.0 LOG HEADER DATA DATE LOGGED: 06-SEP-06 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT): 11650.0 TOP LOG INTERVAL (FT): 9339.0 BOTTOM LOG INTERVAL (FT): 11650.0 BIT ROTATING SPEE D (RPM): - HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 156401 ALD Azimuthal Litho-Dens 183652 Page 13 15-39a.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 • 6.125 8320.0 Fresh water Gel 9.55 43.0 9.3 6600 6.7 .400 71.0 .200 147.0 .420 71.0 .500 71.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOS MwD040 G/CM 4 1 68 12 4 DRHO MwD040 G/CM 4 1 68 16 5 RPD MwD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MwD040 OHMM 4 1 68 28 8 RPX MwD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MwD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9246.5 11650 10448.3 4808 9246.5 11650 FONT MWD040 CNTS 359.52 1106.36 660.523 4620 9246.5 11556 NCNT MWD040 CNTS 23345.3 36588.3 29784.2 4620 9246.5 11556 Page 14 15-39a.tapx RHOB MWD040 G/CM 2.059 3.311 2..39415 4622 9260.5 11571 DRHO MWD040 G/CM -0.175 0.391 0.0438055 4622 9260.5 11571 RPD MWD040 OHMM 15.25 2000 248.563 4611 9286 11591 RPM MWD040 OHMM 13.2 2000 172.423 4611 9286 11591 RPS MWD040 OHMM 10.33 2000 188.447 4611 9286 11591 RPX MWD040 OHMM 8.96 988.43 108.128 4611 9286 11591 FET MWD040 HOUR 0.46 30 2.18434 4611 9286 11591 GR MWD040 API 21.37 260.31 65.9024 4611 9279 11584 PEF MWD040 BARN 0.83 7.41 2.30977 4622 9260.5 11571 ROP MWD040 FT/H 0.02 964.8 124.542 4622 9339.5 11650 NPHI MWD040 PU-S 14.93 32.51 23.4419 4620 9246.5 11556 First Reading For Entire File..........9246.5 Last Reading For Entire File...........11650 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. .... ..1.0.0 Date of Generation.... .07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3960.5 4361.0 RAT 3999.0 4398.5 LOG HEADER DATA DATE LOGGED: 28-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 -DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4400.0 TOP LOG INTERVAL (FT): 3960.0 BOTTOM LOG INTERVAL (FT): 4400.0 Page 15 ~ • 15-39a.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ,4 MAXIMUM ANGLE: 23.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4311.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 49.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 1800 FLUID Loss (C3): 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.940 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.560 100.0 MUD FILTRATE AT MT: 1.930 79.0 MUD CAKE AT MT: 1.950 79.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MAD021 API 4 1 68 4 2 RAT MAD021 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3960.5 4398.5 4179.5 877 3960.5 4398.5 GR MAD021 API 22.68 107.96 52.1773 802 3960.5 4361 RAT MAD021 FT/H 6 376 290.286 800 3999 4398.5 Page 16 ~ ~ 15-39a.tapx First Reading For Entire File..........3960.5 Last Reading For Entire File.. ..........4398.5 File Trailer Service name... ....:..STSL2B.007 Service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 8537.5 9232.5 NPHI 8537.5 9232.5 FCNT 8537.5 9232.5 PEF 8551.0 9245.5 RHOB 8551.0 9245.5 DRHO 8551.0 9245.5 GR 8564.0 10452.0 RPS 8572.5 9265.5 RPD 8572.5 10462.0 FET 8572.5 9265.5 RPM 8572.5 9265.5 RPx 8572.5 9265.5 RAT 8628.5 9326.0 LOG HEADER DATA DATE LOGGED: 06-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10350.0 TOP LOG INTERVAL (FT): 8600.0 BOTTOM LOG INTERVAL (FT): 10350.0 Page 17 • • 15-39a.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $(,$ MAXIMUM ANGLE: 95.3 .TOOL. STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 156401 ALD Azimuthal Litho-Dens 183652 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8320.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.55 MUD VISCOSITY (S): 43.0 MUD PH: 9,3 MUD CHLORIDES (PPM): 6600 FLUID LOSS (C3): 6.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .400 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .200 147.0 MUD FILTRATE AT MT: .420 71.0 MUD CAKE AT MT: .500 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF {IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent.value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD041 CNTS 4 1 68 4 2 NCNT MAD041 CNTS 4 1 68 8 3 RHOB MAD041 G/CM 4 1 68 12 4 DRHO MAD041 G/CM 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPX MAD041 OHMM 4 1 68 32 9 Page 18 ~ ~ 15-39a.tapx FET MAD041 HOUR 4 1 68 36 10 GR MAD041 API 4 1 68 40 11 PEF MAD041 BARN 4 1 68 44 12 RAT MAD041 FT/H 4 1 68 48 13 NPHI MAD041 PU-5 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8537.5 10462 9499.75 3850 8537.5 10462 FCNT MAD041 CNTS: 289.5 2658.1 868.861 1391 8537.5 9232.5 NCNT MAD041 CNTS 19450 44977.1 30383.3 1391 8537.5 9232.5 RHOB MAD041 G/CM 2.027 2.824 2.29876 1390 8551 9245.5 DRHO MAD041 G/CM -0.165 0.317 0.0397871 1390 8551 9245.5 RPD MAD041 OHMM 7.15 2000 256.298 3054 8572.5 10462 RPM MAD041 OHMM 6.18 2000 207.471 1387 8572.5 9265.5 RPS MAD041 OHMM 5.94 689.26 112.224 1387 8572.5 9265.5 RPX MAD041 OHMM 5.72 256.49 61.2134 1387 8572.5 9265.5 FET MAD041 HOUR 25.75 45.4 36.6439 1387 8572.5 9265.5 GR MAD041 API 10.49 274.06 65.2488 3066 8564 10452 PEF MAD041 BARN 0.6 5.98 1.87534 1390 8551 9245.5 RAT MAD041 FT/H 0.36 1345.65 241.357 1396 8628.5 9326 NPHI MAD041 Pu-5 6.35 34.84 19.3021 1391 8537.5 9232.5 First Reading For Entire File..........8537.5 Last Reading For Entire File...........10462 File Trailer service name... .......sT5LI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/11/08 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.009 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................07/11/08 Origin....... ..........STS Tape Name. .... ........UNKNOWN .. Continuation Number......01 Next Tape Name...........UNKNOWN Comment5 .................STS LI5 Reel Trailer Service name .............LISTPE Date . ...................07/11/08 Ori9in ...................STS Reel Name. .... ..... .UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services writing Library. scientific Technical services Page 19 15-39a.tapx Physical EOF Physical EOF End Of LIS File Page 20